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INDONESIA
OUTLOOK & STATISTICS 2006
Editorial Team : Dr. Ir. Widodo Wahyu Purwanto, DEA Ir. Yulianto Sulistyo Nugroho, M.Sc, Ph.D Ir. Rinaldy Dalimi, MSc, Ph.D Dr. A. Harsono Soepardjo, M.Eng Ir. Abdul Wahid, MT Ir. Dijan Supramono, M.Sc Dinna Herminna, ST Teguh Ahmad Adilina, ST
Editorial Address : Pengkajian Energi Universitas Indonesia Gedung Engineering Center Lantai 3 Fakultas Teknik Universitas Indonesia Depok 16424, Indonesia Phone : (62-21) 7866461, 7873117 Facsimile : (62-21) 7873117 http://peui.eng.ui.ac.id
PENGKAJIAN ENERGI UNIVERSITAS INDONESIA
i
INDONESIA ENERGY OUTLOOK AND STATISTICS 2006
ISBN No. 979-95967-1-8
Book Size
: A4 (21 cm x 29.7 cm)
Number of Pages : 276 pages Type of Paper
: Matte Paper 120 gram
Cover Material
: Art Carton 260 gram, Full Color
Language
: English
Circulation
: 500 Books
Editor
: Pengkajian Energi Universitas Indonesia
Published by: Pengkajian Energi Universitas Indonesia Gedung Engineering Center Lantai 3 Fakultas Teknik Universitas Indonesia Depok
First Printing, December 2006
All rights reserved. This book, or parts thereof, may not be reproduced in any form without prior written permission of the published. This may be cited with reference to the source.
Copyright © 2006 by Pengkajian Energi Universitas Indonesia ii
PREFACE Realizing the fact that accurate and complete energy data are essential for energy modeling and analysis, Pengkajian Energi Universitas Indonesia (PE UI) published the first edition of Indonesia Energy Outlook and Statistics in 1998. The energy projection included in the book was produced by a dynamic program called Indonesia Energy Outlook System Dynamic (INOSYD) developed by the PE-UI experts. Following the success of the first edition, PE UI published the second edition of the book completed with the multimedia version (CD included) in 2002. During the period of 2003 to 2006 experts at PE UI have made major improvements in INOSYD model including the Reference Energy system (RES), energy infrastructure and macro economic modules. The progress in the INOSYD model inspires the preparation and publication of the third edition. The 2006 edition contains latest data of Indonesia economic indicators related to energy use; energy prices in Indonesia; energy statistics data of Indonesia starting from its reserves or potentials, export and import, production and consumption; electric power statistics both of power production and consumption; selected world energy statistics including the prices. This edition adds new data on energy infrastructures such as oil and gas refineries, storage facilities, pipelines, coal harbors, railways and power generations. The energy projections to year 2025 were produced by running the INOSYD model. The analysis of the model would give benefits to central and regional governments, some institutions, industry, and academics involved in energy research and communities concerning energy uses. Besides the projections of some conventional energy economic parameters, the readers will find interesting forecast on primary and final energy supply, demand, and contributions as well as new plant capacity required to meet the forecast and the corresponding investment costs based on capital expenditures. The book also contains analysis of perspective of energy at present and in the future. It provides some laws in energy and policy of national energy and energy conservation. A special chapter is dedicated to review the current state and future direction of energy technologies. The format and lay-out of the tables and graphs are enhanced by colored printing. Data and projections of energy will be published in 3 formats: 1. Books, 500 copies. 2. CD, 500 copies. 3. Executive summary up loaded in the website of PEUI. PEUI intent to donate some copies to universities in Indonesia. The data were contributed by several 20 institutions and individuals involved in energy in Indonesia and abroad. Most of the data referred to documents and publications published by those institutions and some were provided by them. We would like to express our gratitude for their beneficial contributions. The publication of the books is the result of significant efforts by individuals in the Editorial Team. The team is much indebted to editorial assistants for their valuable assistance in preparation of the books. The team also would like to thank to the Directorate for Research and Public Services and Rector of University of Indonesia for their support to the book publications. Eventually, we are aware that the publication may not be perfect and requires incessant improvements. We are dilated to receive any corrections and constructive suggestions from readers. It is our intentions to maintain the book to be published periodically. We would like to extend our sincere appreciation to all parties, whom we cannot mention one by one, who have contributed for the publication of the third edition of the Indonesia Energy Outlook and Statistics. Pengkajian Energi Universitas Indonesia Chief Editor,
Dr. Ir. Widodo Wahyu Purwanto, DEA
iii
iv
FOREWORD
I am sincerely delighted to welcome the publication of the 2006 edition of “Indonesia Energy Outlook and Statistics”. Referring to the title, I presume that the book signifies two parts of the information, i.e. on the statistical data of energy sectors in Indonesia and the forecast of energy sector in the future. The success of national development program aiming to improve people’s quality of life and welfare inevitably relies on the development of energy sectors. In fact, almost all aspects of human life such as residential, commercial, transportation and industrial can not be separated from the need of energy. Indonesia has abundant primary energy reserves for some types but limited reserves for others. The availability of the current energy data and forecast is important for securing energy supply. The energy outlook and statistics can support the development of new policies intend to maintain the sustainability of energy sector as well as the development of all sectors associated with energy. I hope this book could be used as a reference for any institution or individual involved in energy research, studies and policy development either in upstream or downstream of energy sectors. The book could also be an important reference for those, who work in both public and private academic institution interested in energy development. Finally, I would like to extend my sincere appreciation to the Editorial Team for their commitments to continuously improve and publish this important series on regular basis. My appreciation is also extended to other parties for their contributions to the content of the book as well as to several companies for providing financial assistance, through which, without them it would be difficult to publish this book.
University of Indonesia Rector,
Prof. dr. Usman Chatib Warsa PhD. SpMK
v
CONTENT PREFACE
.................................................................................................................iii
FOREWORD ................................................................................................................. v CONTENT
................................................................................................................ vi
I. ENERGY OUTLOOK AND ANALYSIS OF INDONESIA ............................................ 1 OVERVIEW OF INOSYD ................................................................................................ 3 (Indonesia Energy Outlook by System Dynamic)............................................................ 3 ENERGY PROJECTION OF INDONESIA BY INOSYD................................................. 6 Figure 1.2
Population...............................................................................................6
Figure 1.3
Gross Domestic Product.........................................................................7
Figure 1.4
Petroleum Fuels Consumption by Sector ...............................................8
Figure 1.5
Natural Gas Consumption by Sector ......................................................9
Figure 1.6
Coal Consumption by Sector................................................................10
Figure 1.7
Electricity Consumption by Sector........................................................11
Figure 1.8a
Total Energy Consumption by Sector (including Biomass) .................12
Figure 1.8b
Total Energy Consumption by Sector (excluding Biomass) .................13
Figure 1.9
Industrial Energy Consumption by Type...............................................14
Figure 1.10
Commercial Energy Consumption by Type .........................................15
Figure 1.11
Residential Energy Consumption by Type (include Biomass) ..............16
Figure 1.12
Transportation Energy Consumption by Type ......................................17
Figure 1.13
Electricity Energy Consumption by Type ..............................................18
Figure 1.14a
Total Energy Consumption by Type (including Biomass) .....................19
Figure 1.14b
Total Energy Consumption by Type (excluding Biomass) ....................20
Figure 1.15
Total Energy Consumption by GDP Scenario ......................................21
Figure 1.16
Crude Oil Balance ................................................................................22
Figure 1.17
Natural Gas Balance ............................................................................23
Figure 1.18
Coal Balance ........................................................................................24
Figure 1.19
Energy Production by Type ..................................................................25
Figure 1.20
Total Energy Balance ...........................................................................26
Figure 1.21
Reserves-Production Ratio of Crude Oil ..............................................27
vi
Figure 1.22
Reserves-Production Ratio of Natural Gas ..........................................27
Figure 1.23
Reserves-Production Ratio of Coal ......................................................28
Table 1.1
R/P Ratio of Crude Oil, Gas, Coal ........................................................28
Figure 1.24
CO2 Emission per Sector .....................................................................29
Figure 1.25
NOx Emission per Sector .....................................................................30
Figure 1.26
SOx Emissions per Sector....................................................................31
Figure 1.27
Total Capacity of Oil Refinery...............................................................32
Figure 1.28
Total Capacity of Gas Refinery.............................................................32
Figure 1.29
Total Capacity of Power Generator ......................................................33
Figure 1.30
Investment Cost of Oil ..........................................................................33
Figure 1.31
Investment Cost of Gas ........................................................................34
Figure 1.32
Investment Cost of Coal .......................................................................34
Figure 1.33
Investment Cost of Electricity ...............................................................34
Table 1.2
Intensity of Total Energy Consumption.................................................35
Table 1.3
GDP Elasticity of Energy Consumption ................................................36
Table 1.4
Emissions per GDP ..............................................................................37
Table 1.5
Emissions per Capita............................................................................38
Figure 1.34
Contribution of Primary Energy Supply ................................................39
Figure 1.35
Contribution of Final Energy Consumption ...........................................40
ENERGY ANALYSIS, PERSPECTIVE, and POLICY.................................................. 41 1.1 Oil and Gas ..................................................................................................... 41 1.2 Coal................................................................................................................. 46 1.3 Renewable Energy.......................................................................................... 48 1.4 Electricity......................................................................................................... 51
II. SELECTED ECONOMIC INDICATORS OF INDONESIA........................................ 55 Table 2.1
Population, GDP, Energy Consumption, Energy Intensity, and Energy Consumption per Capita, 1990 – 2005.................................................57
Table 2.2
Average Rates of Foreign Currencies and Gold in Market, 1997-2005 ..............................................................................................................57
Table 2.3
Description of Indonesia Macroeconomics, 1997 – 2005.....................58
vii
Table 2.4
Gross Domestic Product based on Current Market Prices by Industry Origin, 1999-2005.................................................................................59
Table 2.5
Gross Domestic Product based on Constant 2000 Market Prices by Industry Origin, 2002-2005 ...................................................................60
Table 2.6
Figures of Indonesian Oil & Gas Export and Import, 1990-2005 ..........61
Table 2.7
Investment in Oil and Gas, 1997-2004 .................................................61
Table 2.8a
Ratio of Electrification and Electricity Consumption per Capita, 2003..62
Table 2.8b
Ratio of Electrification and Electricity Consumption per Capita, 2004..63
Table 2.8c
Ratio of Electrification and Electricity Consumption per Capita, 2005..64
III. ENERGY PRICES IN INDONESIA .......................................................................... 65 Table 3.1
Average of Indonesian Crude Oil Prices, 1998-2005 ...........................67
Table 3.2
Average of Selected Crude Oil Prices, 1999-2005...............................67
Table 3.3a
Indonesian Crude Oil Prices by Type, 2003 .........................................68
Table 3.3b
Indonesian Crude Oil Prices by Type, 2004 .........................................69
Table 3.3c
Indonesian Crude Oil Prices by Type, 2005 .........................................70
Table 3.4
Domestic Fuel Prices, 2003-April 2006 ................................................71
Table 3.5a
Domestic Avgas Selling Prices, 2005...................................................73
Table 3.5b
International Avgas Selling Prices, 2005 ..............................................74
Table 3.6a
Pertamina Domestic Avtur Selling Prices, 2005 ...................................75
Table 3.6b
International Avtur Selling Prices, 2005................................................76
Table 3.7
Fuel Oil Subsidy, 1995-2005 ................................................................77
Table 3.8
Gas Domestic Prices, Jan 2006 .........................................................77
Table 3.9a
International Coal Price Trend..............................................................78
Table 3.9b
Indonesian Coal Export Price Trend....................................................78
Table 3.10
Averaged Generation Cost of PLN Power Plants, 1993-2005..............79
Table 3.11
Averaged Selling Price of Electricity by Type of Customer, 1992-2005 ..............................................................................................................79
Table 3.12
Price of Fuels for Electricity, 1992-2005...............................................80
viii
IV. ENERGY RESERVES AND POTENTIALS OF INDONESIA ................................. 81 Table 4.1
Oil and Gas Reserves, 1995-2005 .......................................................83
Table 4.2
Coal Reserves by Province, 2005 ........................................................84
Table 4.3
Potential and Installed Capacities of Geothermal Energy in Sumatra, December 2004 ....................................................................................87
Table 4.4
Potential and Installed Capacity of Geothermal Energy in Java, December 2004 ....................................................................................89
Table 4.5
Potential and Installed Capacity of Geothermal Energy in East Region of Indonesia, December 2004 .............................................................91
Table 4.6
Potential of Microhydro Energy > 20 kVA (15 kW) (measured by PLN)93
Table 4.7
Potential of Microhydro Energy > 20 kVA (15 kW) (measured by non PLN) in Sumatera and Java ................................................................94
Table 4.8
Potential of Microhydro Energy > 20 kVA (15 kW) (measured by non PLN) in Kalimantan and Sulawesi ........................................................95
Table 4.9
Potential of Microhydro Energy > 20 kVA (15 kW) (measured by non PLN) in East Region of Indonesia ........................................................96
Table 4.10
Potential of Solar Energy......................................................................97
Table 4.11
Potential of Wind Energy in West Region of Indonesia measured by BMG) ....................................................................................................98
Table 4.12
Potential of Wind Energy in East Region of Indonesia (measured by BMG) ....................................................................................................99
Table 4.13
Potential of Biomass Energy ..............................................................100
Table 4.14
Potential of Biogas Energy .................................................................101
Table 4.15
Potential of Peat Energy.....................................................................102
V. ENERGY PRODUCTION AND CONSUMPTION IN INDONESIA ......................... 103 Table 5.1
Production of Energy, 1997-2005.......................................................105
Table 5.2
Energy Supply by Type of Primary Energy, 1990-2004 .....................106
Table 5.3
Energy Consumption by Type of Final Energy, 1990 – 2004 .............107
Table 5.4
Final Energy Consumption by Sector, 1990 – 2004 ...........................108
Table 5.5
Petroleum Fuel Consumption by Sector, 1990 – 2004 .......................109
Table 5.6
Gas Consumption by Sector, 1990 – 2004.........................................110
Table 5.7
Coal Consumption by Sector, 1990-2004...........................................111
ix
Table 5.8a
Petroleum Fuel Sales in Residential Sector, 2000-2005 ....................112
Table 5.8b
Petroleum Fuel Sales in Transportation Sector, 2000-2005...............112
Table 5.8c
Petroleum Fuel Sales in Industry Sector, 2000-2005 .........................113
Table 5.8d
Petroleum Fuel Sales in Electricity Sector, 2000-2005 ......................113
Table 5.9a
Petroleum Fuel Sales per Region, 2003.............................................114
Table 5.9b
Petroleum Fuel Sales per Region, 2004.............................................115
Table 5.9c
Petroleum Fuel Sales per Region, 2005.............................................116
Table 5.10
Crude Oil Production by Production Schemes, 1995 – 2005 .............117
Table 5.11
Condensate Production by Production Scheme, 1995 – 2005 ...........118
Table 5.12
Production of Naphtha and LSWR by Refinery, 1996 – 2005 ............119
Table 5.13a
Production of various Fuels by Refinery, 2003 ...................................120
Table 5.13b
Production of various Fuels by Refinery, 2004 ...................................121
Table 5.13c
Production of various Fuels by Refinery, 2005 ...................................122
Table 5.14a
Production of Oil and Gas by Refinery, 2003 .....................................123
Table 5.14b
Production of Oil and Gas by Refinery, 2004 .....................................124
Table 5.14c
Production of Oil and Gas by Refinery, 2005 .....................................125
Table 5.15
Natural Gas Production by Production Scheme, 1995 – 2005 ...........126
Table 5.16
Production and Utilization of Natural Gas, 1999-2005 .......................127
Table 5.17
Production of LNG, 1999 – 2005 ........................................................128
Table 5.18
Production of LPG, 2001 – 2005 ........................................................129
Table 5.19
Gas Sales of PT. PGN (Persero) by Sector, 1995 – 2005 .................130
Table 5.20
Coal Production by Company, 1999-June 2006 .................................131
Table 5.21
Domestic Coal Sales by Company , 1998 -2004 ................................133
Table 5.22
Domestic Coal Sales by Industry, 1998-2004 ....................................135
Table 5.23
Coal Quality by Company...................................................................136
Table 5.24
Electricity Production by Type of Power Plant of PLN, 1992 – 2005 .137
Table 5.25
Fuel Consumption for PLN Power Plant, 1989-2005..........................138
Table 5.26
Own-Uses, Losses, and Factors in PLN Electricity, 1993-2005 .........138
Table 5.27
Electricity Sold by PLN by Sector, 1996-2005....................................139
Tabel 5.28a
Load Balance of PLN Electricity, 2003 ...............................................140
Tabel 5.28b
Load Balance of PLN Electricity, 2004 ...............................................141
Table 5.28c
Load Balance of PLN Electricity, 2005 ...............................................142
x
VI. EXPORTS AND IMPORTS OF ENERGY IN INDONESIA.................................... 143 Table 6.1
Export of Energy, 1997 – 2005...........................................................145
Table 6.2
Import of Energy, 1995 – 2005 ...........................................................146
Table 6.3
Import of Crude Oil by Type, 2000 – 2005 .........................................147
Table 6.3
Import of Crude Oil by Type, 2000 – 2005 (Continued)......................148
Table 6.4
Import of Refinery Products, 2000 – 2005..........................................149
Table 6.5
Export of Crude Oil by Destination Country, 1997 – 2005..................150
Table 6.6
Export of Condensate by Destination Country, 1997 – 2005 .............151
Table 6.7
Export of Refinery Product, 1999– 2005 ...........................................152
Table 6.8
Export of Refinery Product by Destination Country, 1999 –2005 .......153
Table 6.9
Export of LNG by Destination Country, 1995 –2005 ..........................154
Table 6.10
Export of LPG by Destination Country, 2000 – 2005..........................155
Table 6.11
Coal Export by Company, 1999 – 2005..............................................156
Table 6.12
Coal Export by Destination Country, 1999 – 2005 .............................157
VII. INFRASTRUCTURE OF ENERGY IN INDONESIA............................................. 159 Table 7.1
Installed Capacities of Oil Refinery Plants, 1999 – 2005....................161
Table 7.2a
Fuel Oil Sales & Distribution Channels of Pertamina and Partner .....161
Table 7.2b
Non-Fuel Oil Sales & Distribution Channels of Pertamina and Partners ..............................................................................................162
Table 7.3
Oil Fuel Pipeline .................................................................................162
Table 7.4
Number of Oil Fuels Public Station and Kerosene Agents .................163
Table 7.5
Oil Fuel Storage Tanks of PT PERTAMINA (Persero) in Sumatera and Java ....................................................................................................164
Table 7.6
Oil Fuel Storage Tanks of PT PERTAMINA (Persero) in Kalimantan, Sulawesi, and Papua..........................................................................165
Table 7.7
Distribution Gas Pipeline of PT PGN (Persero) ..................................165
Table 7.8
Gas Pipeline .......................................................................................166
Table 7.9
Transacted Gas Pipeline Project in 2005 & 2006 ...............................166
Table 7.10
Design and Production Capacities of LNG Plant...............................167
Table 7.11
Main Coal Harbor ...............................................................................167
Table 7.12
Number of PLN Power Plants, 1992 – 2005.......................................168
xi
Table 7.13
Installed and Rated Capacities of PLN Power Plants, 1992 – 2005...169
Tabel 7.14a
Captive Power Plants, 2003 ...............................................................170
Tabel 7.14b
Captive Power Plants, 2004 ...............................................................171
Table 7.14c
Captive Power Plants, 2005 ...............................................................172
VIII. SELECTED WORLD ENERGY STATISTICS..................................................... 173 Table 8.1
World Oil Proven Reserves; 1985, 1995, 2004, 2005 ........................175
Table 8.2
World Oil Production, 2000 – 2005.....................................................176
Table 8.3
World Oil Consumption, 2000 – 2005.................................................177
Table 8.4
World Oil Refinery Capacities, 2000 – 2005.......................................179
Table 8.5
World Natural Gas Proven Reserves; 1985, 1995, 2004, 2005 .........180
Table 8.6
World Natural Gas Production, 1997 – 2005......................................181
Table 8.7
World Natural Gas Consumption, 1997 – 2005..................................182
Table 8.8
World Coal Proven Reserves by Type, 2005 .....................................184
Table 8.9
World Coal Production, 1995-2005 ....................................................185
Table 8.10
World Coal Consumption, 1997-2005 ................................................186
Table 8.11
World Primary Energy Production by Source, 1980-2004..................188
Table 8.12
World Primary Energy Consumption, 1997-2005 ...............................189
Table 8.13
World Primary Energy Consumption by Fuel, 2004-2005 ..................191
Table 8.14
World Hydroelectricity Consumption, 2000-2005 ...............................193
Table 8.15
World Spot Crude Oil Prices, 1980 – 2005.........................................195
Table 8.16
World Average Gas Prices, 1984 – 2005 ...........................................196
Table 8.17
World Average Coal Prices, 1987 – 2005 ..........................................197
IX. CURRENT AND FUTURE ENERGY TECHNOLOGY .......................................... 199 9.1
Petroleum Technology........................................................................201
9.2
Natural Gas Technology.....................................................................206
9.3
Coal Technology.................................................................................210
9.4
Renewable Energy Technology..........................................................215
9.5
Electricity Technology.........................................................................226
xii
X. ECONOMICS OF ALTERNATIVE FUELS AND ELECTRICITY GENERATION .. 229 XI. ENERGY REGULATIONS .................................................................................... 237 XII. ENERGY CONSERVATION ................................................................................ 243
APPENDICES ............................................................................................................. 253 A1. Gross Energy Content ..........................................................................................253 A.2 Conversion Factor ................................................................................................255 A3. Glossary
............................................................................................................257
REFERENCES ........................................................................................................... 269 PROFILE OF EDITORS ............................................................................................. 273 SPONSORS ............................................................................................................. 275
xiii
xiv
ENERGY OUTLOOK & ANALYSIS
I. ENERGY OUTLOOK AND ANALYSIS OF INDONESIA
PENGKAJIAN ENERGI UNIVERSITAS INDONESI
2
OVERVIEW OF INOSYD (Indonesia Energy Outlook by System Dynamic)
Indonesia Energy Outlook by System Dynamic (INOSYD) has been developed by Pengkajian Energi Universitas Indonesia (PEUI) since 1997. The INOSYD model is written in dynamic simulation software called POWERSIM. Modeling framework of INOSYD illustrated in Figure I consists of three basic sub-models: (1) Energy system sub-model, (2) Macro-economic sub-model, and (3) Environmental sub-model.
Energy infrastructure infrastructure Energy Energy Resources
Energy conversion
Transmission and Distribution
Primary Energy
Power Power generation, generation, refineries
Piping, Piping, cable, cable, tankers, tankers, Ports, and storage Ports, and storage
Final Final energy energy
Energy Energy demand demand Sectors and types Sectors and types
ENERGY SUB MODEL
Technology, Emission coefficient ENVIRONMENT SUB- MODEL
Social accounting matrix (SAM)
GDP
MACROECONOMIC SUB MODEL -
Figure 1.1 INOSYD model framework
The energy system sub-model consists of supply and demand of energy services including infrastructures. The supply side of primary energy production such as oil, natural gas and coal are modeled dynamically, except for the renewable. The demand side of the energy services is divided into several sectors including industry, commercial, domestic and transportation, as well as electricity sector and modeled using econometric approach. The supply and demand sides are linked using a Reference Energy System (RES) module. The conversion, transportation and end-use technology aspects, the cost and performance characteristics of these technologies that are potentially available for use in the energy system are considered in the RES. The macro-economic sub-model is developed based on Indonesia’s Social Accounting Matrix (SAM), and completed with the population growth, GDP and energy prices which are considered as exogenous variables. The environmental sub-model considers the interaction between energy system and the emission from the activities for energy conversion, production and use.
3
Supply of energy module comprises national energy balance as network of energy flows (RES) starting from supply of different forms of primary energy such as crude oil, gas, coal and renewable resources i.e. biomass, geothermal, and hydro etc., primary energy conversion into final energies via power generations and refineries, transmission and distribution as well as storage to end-user devices for each demand sector. Each link of the network represents some activities relating to an energy efficiency coefficient and losses. Mathematically, RES is divided in sequential vectors representing stages of energy transformation. We start from right to left or from total demand by sector to supply of primary energy. Vn is calculated from its predecessor, Vn-1, by the following form: Vn = T x V n-1
(1)
where T is a transformation matrix of RES with the coefficient of efficiency and losses as elements of matrix. For the supply of primary energy especially fossil fuels, the INOSYD model allows the calculation of remaining reserves and reserve to production ratio of each fossil fuel. In addition, reserve to production ratio can be set at a constant value for the policy proposes, and then the demand will be fulfilled by imports. Energy infrastructure module consists of existing energy infrastructure, capital expenditures and O&M cost of energy conversion technologies (power generation, refineries) and transmission and distribution systems for oil, gas, coal and electricity, associated with learning curve of capital expenditure of emerging energy technologies. Infrastructures in this sub module are oil and gas refinery, depot, gas pipeline, coal railroad, coal harbor and power generator. This sub model can estimate the investment of energy infrastructures and the costs of energy supply or production of final energy such as electricity and petroleum products, and LNG. Development of energy demand module is critical element at both the aggregate sectors at national level such as industrial, transportation, commercial, residential both electricity and fuels and aggregate fuel types. In the earlier approach, demand model is developed by dynamic approach, but the results were not satisfied due to insufficient data for energy demand sectors. Thus, currently we use an econometric approach resulting in more simplified model. Typically equation is written as follows: Dn = f (GDP, population, price, intensity or elasticity)
(2)
It should be noted that to simulate the price impacts, demand model must include energy price in the equation above. However, in the most cases it is difficult to estimate demands due to the fact that relationship between demand and price is inconsistent. In addition, we should consider that the energy demand is also affected by the limitation of energy
4
infrastructures. Hence, the potential demand can be greater than the current demand and the shape of energy market is still developing. Concerning environment sub-model, it is constructed based only on emission coefficients taken from Intergovernmental Panel on Climate Change (IPCC) guidelines 1996 for different types of energy technologies for energy conversion units and end-user devices. Emission consists of CO2, SOx and NOx. Macroeconomic sub-model is developed based on Indonesia’s Social Accounting Matrix (SAM) in 1999 with dimension of 109 x 109 sectors and reduced to 58 x 58 sectors. By using SAM, the impact energy policy i.e. energy price shock and change of share of energy supply on GDP can be simulated. Having specified assumed levels of energy demands, INOSYD can be used as optimization tool using POWERSIM Solver to determine the combination of technologies which meet those needs at overall least cost of energy supply with some constraints added. In the simulation context, INOSYD can be operated in top-down approach and bottomup approach models. Typical top-down approaches are impact of GDP growth rate on supply and demand of energy and environment, and impact of energy price shock on energy system and environments. On the other hands, a bottom-up approach may describe impacts of energy technology on macroeconomic and environment. The GDP projection uses the assumption of 6% growth per year for the base case; while the population projection uses an assumption of 1.20% growth. For making a projection until 2025, INOSYD uses data mostly from years 1990 through 2005.
5
ENERGY PROJECTION OF INDONESIA BY INOSYD Figure 1.2
Population
(Million Persons) 300
275
250
225
200
175 1990
1995
2000
2005
Data
2010
2015
2020
2025
Projection
(Million) Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Population 179.248 181.763 184.278 186.794 189.309 191.825 194.340 199.837 202.873 203.047 205.843 208.647 212.003 215.276 217.854 220.923 223.574 226.257 228.972 231.720 234.501 237.315 240.162 243.044 245.961 248.912 251.899 254.922 257.981 261.077 264.210 267.380 270.589 273.836 277.122 280.447
6
Figure 1.3
Gross Domestic Product
(Billion Rupiah) at constant price 2000 6,000,000 5,000,000 4,000,000 3,000,000 2,000,000 1,000,000 0 1990
1995
2000
2005
Data
Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
2010
2015
2020
2025
Base Case
(Billion Rupiah at constant price of year2000) Gross Domestic Product Base Case 875,025 936,400 999,721 1,151,729 1,238,570 1,340,380 1,445,173 1,513,095 1,314,475 1,324,874 1,389,770 1,442,985 1,506,124 1,579,559 1,660,579 1,753,571 1,851,771 1,953,618 2,061,067 2,184,731 2,315,815 2,454,764 2,602,050 2,758,173 2,923,663 3,099,083 3,285,028 3,482,130 3,691,058 3,912,521 4,147,273 4,396,109 4,659,875 4,939,468 5,235,836 5,549,986
7
Figure 1.4
Petroleum Fuels Consumption by Sector
(Million BOE) 1,000 900 800 700 600 500 400 300 200 100 0 1990
1995
Industry
Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Industry 39.33 40.39 46.49 52.55 56.10 61.53 62.35 64.84 68.31 79.72 85.24 87.51 87.36 79.44 88.65 92.11 95.43 98.93 104.13 108.36 112.75 117.31 122.05 126.98 132.09 137.41 142.93 148.66 154.62 160.81 167.23 173.90 180.82 188.01 195.47 203.21
2000
Commercial
Commercial 2.34 3.03 3.88 4.97 5.49 5.96 6.50 6.85 5.75 5.83 6.13 6.22 6.32 6.41 6.51 6.92 7.24 7.59 8.11 8.54 8.99 9.46 9.96 10.48 11.02 11.59 12.19 12.81 13.47 14.16 14.87 15.63 16.41 17.23 18.09 18.99
2005
2010
Residential
Residential 39.45 40.00 40.50 41.10 41.86 42.65 43.49 46.47 48.98 50.85 52.79 55.09 57.91 60.14 60.86 63.07 65.38 67.80 70.99 73.78 76.68 79.68 82.80 86.03 89.39 92.86 96.46 100.20 104.07 108.09 112.25 116.57 121.04 125.68 130.48 135.46
2015
Transportation
Transportation 93.42 101.46 110.87 120.28 124.11 135.10 149.10 157.12 148.89 154.02 163.41 170.35 176.50 184.64 198.25 208.26 216.57 225.40 238.63 249.38 260.60 272.30 284.50 297.23 310.50 324.33 338.75 353.79 369.45 385.78 402.79 420.51 438.96 458.18 478.20 499.04
2020
2025
Electricity
(Million BOE) Electricity 35.79 40.50 43.95 47.91 28.61 22.48 25.10 34.63 31.17 35.41 37.57 39.22 50.33 54.70 60.78 70.45 61.39 51.08 40.18 26.64 11.11 11.54 12.03 12.53 13.04 13.57 14.10 14.63 15.17 15.71 16.25 16.79 17.32 17.84 18.34 18.82
8
Figure 1.5
Natural Gas Consumption by Sector
(Million BOE) 450 400 350 300 250 200 150 100 50 0 1990
1995
2000
Industry
Commercial
2005
2010
Residential
2015
Transportation
2020
2025
Electricity
(Million BOE)
Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Industry 11.11 11.41 12.29 11.98 18.67 19.64 18.31 23.46 17.94 32.12 37.75 47.89 45.86 44.21 68.66 72.20 75.83 79.69 85.04 89.71 94.63 99.81 105.28 111.04 117.11 123.50 130.25 137.35 144.84 152.73 161.04 169.80 179.02 188.75 198.99 209.78
Commercial 0.08 0.10 0.12 0.13 0.15 0.17 0.19 0.21 0.19 0.19 0.20 0.21 0.21 0.21 0.21 0.26 0.40 0.57 0.77 0.98 1.22 1.48 1.78 2.11 2.47 2.87 3.31 3.80 4.34 4.94 5.59 6.31 7.10 7.96 8.91 9.95
Residential 0.04 0.04 0.04 0.04 0.05 0.06 0.07 0.07 0.08 0.07 0.08 0.09 0.10 0.10 0.11 0.13 0.29 0.46 0.64 0.83 1.04 1.25 1.48 1.71 1.96 2.23 2.51 2.80 3.11 3.43 3.77 4.13 4.51 4.90 5.32 5.75
Transportation 0.00 0.01 0.01 0.02 0.03 0.04 0.05 0.05 0.07 0.08 0.07 0.06 0.05 0.05 0.05 0.07 1.03 2.09 3.30 4.61 6.06 7.64 9.39 11.29 13.38 15.66 18.15 20.86 23.82 27.03 30.52 34.31 38.42 42.88 47.70 52.93
Electricity 2.84 2.73 2.62 11.96 32.94 45.07 59.97 46.65 45.49 48.41 46.51 43.91 37.88 35.99 34.27 25.65 28.53 31.71 35.95 40.02 44.46 47.10 50.15 53.40 56.85 60.53 64.44 68.60 73.02 77.73 82.73 88.06 93.72 99.74 106.14 112.94
9
Figure 1.6
Coal Consumption by Sector
(Million BOE) 600 500 400 300 200 100 0 1990
1995
2000
Industry
Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Industry 10.58 10.86 12.05 13.69 14.15 16.60 15.47 16.06 17.83 26.86 36.22 37.51 38.80 40.14 55.34 58.27 61.29 64.51 68.94 72.83 76.94 81.27 85.84 90.67 95.75 101.12 106.78 112.76 119.06 125.70 132.71 140.11 147.90 156.12 164.79 173.94
Commercial
Commercial 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
2005
2010
Residential
Residential 0.00 0.00 0.00 0.00 0.01 0.02 0.04 0.06 0.07 0.09 0.09 0.09 0.10 0.10 0.10 0.10 0.11 0.12 0.13 0.13 0.14 0.15 0.16 0.17 0.18 0.19 0.20 0.21 0.22 0.23 0.24 0.26 0.27 0.28 0.30 0.31
2015
Transportation
2020
2025
Electricity
Transportation 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
(Million BOE) Electricity 16.67 18.72 17.99 16.59 19.34 19.55 27.71 34.74 37.18 39.86 45.56 47.26 47.09 50.85 51.09 55.71 65.91 77.20 91.65 106.19 122.26 131.49 142.14 153.65 166.07 179.49 193.98 209.63 226.52 244.76 264.45 285.71 308.66 333.43 360.17 389.03
10
Figure 1.7
Electricity Consumption by Sector
(Million BOE) 300 250 200 150 100 50 0 1990
1995
2000
Industry
Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Industry 10.48 11.69 13.73 14.22 13.90 15.01 17.04 18.44 17.67 19.22 21.86 21.82 22.58 22.37 24.72 26.77 28.90 31.30 34.66 37.73 41.07 44.70 48.63 52.89 57.53 62.55 68.02 73.97 80.44 87.51 95.23 103.67 112.95 123.16 134.43 146.68
2005
Commercial
Commercial 2.78 3.14 3.37 3.82 4.17 4.89 5.78 6.65 7.61 8.04 8.94 9.55 9.97 11.15 12.99 14.15 15.37 16.76 18.67 20.45 22.39 24.50 26.78 29.26 31.93 34.81 37.92 41.26 44.85 48.69 52.79 57.16 61.78 66.66 71.78 77.12
2010
Residential
2015
2020
2025
Transportation
Residential 5.52 6.33 7.15 8.08 8.97 10.46 11.99 13.91 15.24 16.47 18.73 20.44 20.84 21.92 23.61 24.51 25.40 26.21 27.63 28.62 29.58 30.55 31.51 32.47 33.42 34.35 35.25 36.13 36.96 37.73 38.43 39.04 39.53 39.86 40.00 40.13
(Million BOE) Transportation 0.01 0.01 0.01 0.01 0.01 0.01 0.02 0.02 0.02 0.02 0.03 0.03 0.03 0.03 0.03 0.04 0.04 0.04 0.05 0.05 0.06 0.07 0.07 0.08 0.09 0.10 0.11 0.12 0.13 0.14 0.16 0.17 0.19 0.21 0.23 0.26
11
Figure 1.8a Total Energy Consumption by Sector (including Biomass) (Million BOE) 2,500
2,000
1,500
1,000
500
0 1990
1995
2000
Industry
Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Industry 82.84 86.00 96.52 104.70 115.38 125.50 126.05 135.82 134.92 171.22 194.50 207.66 207.19 198.61 249.41 261.53 273.80 286.98 305.70 321.78 338.75 356.67 375.57 395.53 416.61 438.87 462.40 487.28 513.60 541.45 570.96 602.24 635.45 670.74 708.29 748.09
2005
Commercial
Commercial 5.71 6.93 8.30 10.18 11.21 12.55 14.15 15.48 15.01 15.55 16.85 17.56 18.09 19.37 21.32 23.00 24.74 26.69 29.43 31.92 34.61 37.53 40.67 44.06 47.71 51.64 55.86 60.38 65.23 70.42 75.95 81.84 88.10 94.72 101.69 109.00
2010
Residential
2015
2020
2025
Transportation
Residential 226.55 230.41 234.28 238.36 242.20 246.35 250.26 259.56 266.90 272.25 280.30 288.04 295.40 302.64 308.10 316.97 338.61 347.98 361.44 372.40 383.63 395.16 407.02 419.19 431.68 444.51 457.66 471.15 484.97 499.12 513.60 528.40 543.50 558.88 574.51 590.61
( Million BOE) Transportation 93.43 101.48 110.89 120.31 124.15 135.15 149.16 157.19 148.99 154.13 163.51 170.44 176.59 184.73 198.34 208.38 217.66 227.56 242.03 254.12 266.82 280.17 294.20 308.96 324.52 340.93 358.28 376.70 396.34 417.42 440.27 465.36 493.36 525.31 562.73 605.79
12
Figure 1.8b Total Energy Consumption by Sector (excluding Biomass) (Million BOE) 1,800 1,600 1,400 1,200 1,000 800 600 400 200 0 1990
1995
2000
Industry
2005
Commercial
2010
Residential
2015
2020
2025
Transportation
( Million BOE) Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Industry 71.48 74.34 84.55 92.43 102.82 112.78 113.18 122.80 121.75 157.92 181.07 194.72 194.60 186.16 237.37 249.35 261.44 274.43 292.78 308.62 325.38 343.09 361.80 381.57 402.48 424.59 447.98 472.74 498.96 526.74 556.20 587.47 620.69 656.03 693.68 733.61
Commercial 5.21 6.28 7.37 8.92 9.81 11.02 12.48 13.71 13.54 14.06 15.28 15.98 16.50 17.77 19.71 21.32 23.01 24.91 27.55 29.97 32.60 35.44 38.52 41.84 45.42 49.27 53.42 57.88 62.66 67.78 73.26 79.09 85.29 91.86 98.79 106.06
Residential 45.01 46.37 47.70 49.23 50.89 53.20 55.58 60.51 64.37 67.48 71.70 75.71 78.94 82.26 84.68 87.82 91.18 94.58 99.39 103.37 107.44 111.63 115.95 120.38 124.94 129.62 134.42 139.33 144.36 149.48 154.70 159.99 165.34 170.72 176.09 181.66
Transportation 93.43 101.48 110.89 120.31 124.15 135.15 149.16 157.19 148.99 154.13 163.51 170.44 176.59 184.73 198.34 208.37 217.65 227.53 241.98 254.05 266.72 280.01 293.96 308.60 323.97 340.09 357.01 374.77 393.40 412.95 433.46 454.99 477.57 501.27 526.14 552.22
13
Figure 1.9
Industrial Energy Consumption by Type
(Million BOE) 800 700 600 500 400 300 200 100 0 1990
1995
2000
Petroleum Fuels
2005
Natural Gas
2010
Coal
2015
Renewable
2020
2025
Electricity
( Million BOE) Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Petroleum Fuels 39.33 40.39 46.49 52.55 56.10 61.53 62.35 64.84 68.31 79.72 85.24 87.51 87.36 79.44 88.65 92.11 95.43 98.93 104.13 108.36 112.75 117.31 122.05 126.98 132.09 137.41 142.93 148.66 154.62 160.81 167.23 173.90 180.82 188.01 195.47 203.21
Natural Gas 11.11 11.41 12.29 11.98 18.67 19.64 18.31 23.46 17.94 32.12 37.75 47.89 45.86 44.21 68.66 72.20 75.83 79.69 85.04 89.71 94.63 99.81 105.28 111.04 117.11 123.50 130.25 137.35 144.84 152.73 161.04 169.80 179.02 188.75 198.99 209.78
Coal 10.58 10.86 12.05 13.69 14.15 16.60 15.47 16.06 17.83 26.86 36.22 37.51 38.80 40.14 55.34 58.27 61.29 64.51 68.94 72.83 76.94 81.27 85.84 90.67 95.75 101.12 106.78 112.76 119.06 125.70 132.71 140.11 147.90 156.12 164.79 173.94
Renewable 11.35 11.66 11.97 12.26 12.56 12.72 12.88 13.02 13.17 13.30 13.43 12.94 12.59 12.45 12.04 12.17 12.36 12.55 12.92 13.15 13.37 13.58 13.77 13.96 14.13 14.29 14.42 14.54 14.64 14.71 14.76 14.77 14.75 14.70 14.61 14.48
Electricity 10.48 11.69 13.73 14.22 13.90 15.01 17.04 18.44 17.67 19.22 21.86 21.82 22.58 22.37 24.72 26.77 28.90 31.30 34.66 37.73 41.07 44.70 48.63 52.89 57.53 62.55 68.02 73.97 80.44 87.51 95.23 103.67 112.95 123.16 134.43 146.68
14
Figure 1.10
Commercial Energy Consumption by Type
(Million BOE) 120 100 80 60 40 20 0 1990
1995
2000
Petroleum Fuels
2005
Natural Gas
2010
Coal
2015
Renewable
2020
2025
Electricity
( Million BOE) Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Petroleum Fuels 2.34 3.03 3.88 4.97 5.49 5.96 6.50 6.85 5.75 5.83 6.13 6.22 6.32 6.41 6.51 6.92 7.24 7.59 8.11 8.54 8.99 9.46 9.96 10.48 11.02 11.59 12.19 12.81 13.47 14.16 14.87 15.63 16.41 17.23 18.09 18.99
Natural Gas 0.08 0.10 0.12 0.13 0.15 0.17 0.19 0.21 0.19 0.19 0.20 0.21 0.21 0.21 0.21 0.26 0.40 0.57 0.77 0.98 1.22 1.48 1.78 2.11 2.47 2.87 3.31 3.80 4.34 4.94 5.59 6.31 7.10 7.96 8.91 9.95
Coal 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
Renewable 0.51 0.65 0.93 1.26 1.40 1.53 1.67 1.77 1.47 1.49 1.57 1.58 1.59 1.60 1.60 1.67 1.73 1.78 1.88 1.95 2.01 2.08 2.15 2.23 2.30 2.37 2.44 2.50 2.57 2.63 2.70 2.75 2.81 2.86 2.90 2.94
Electricity 2.78 3.14 3.37 3.82 4.17 4.89 5.78 6.65 7.61 8.04 8.94 9.55 9.97 11.15 12.99 14.15 15.37 16.76 18.67 20.45 22.39 24.50 26.78 29.26 31.93 34.81 37.92 41.26 44.85 48.69 52.79 57.16 61.78 66.66 71.78 77.12
15
Figure 1.11
Residential Energy Consumption by Type (include Biomass)
(Million BOE) 700 600 500 400 300 200 100 0 1990
1995
2000
Petroleum Fuels
2005
Natural Gas
2010
Coal
2015
Renewable
2020
2025
Electricity
( Million BOE) Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Petroleum Fuels 39.45 40.00 40.50 41.10 41.86 42.65 43.49 46.47 48.98 50.85 52.79 55.09 57.91 60.14 60.86 63.07 65.38 67.80 70.99 73.78 76.68 79.68 82.80 86.03 89.39 92.86 96.46 100.20 104.07 108.09 112.25 116.57 121.04 125.68 130.48 135.46
Natural Gas 0.04 0.04 0.04 0.04 0.05 0.06 0.07 0.07 0.08 0.07 0.08 0.09 0.10 0.10 0.11 0.13 0.29 0.46 0.64 0.83 1.04 1.25 1.48 1.71 1.96 2.23 2.51 2.80 3.11 3.43 3.77 4.13 4.51 4.90 5.32 5.75
Coal 0.00 0.00 0.00 0.00 0.01 0.02 0.04 0.06 0.07 0.09 0.09 0.09 0.10 0.10 0.10 0.10 0.11 0.12 0.13 0.13 0.14 0.15 0.16 0.17 0.18 0.19 0.20 0.21 0.22 0.23 0.24 0.26 0.27 0.28 0.30 0.31
Renewable 181.54 184.04 186.59 189.13 191.31 193.15 194.67 199.05 202.54 204.77 208.61 212.33 216.46 220.38 223.42 229.15 247.43 253.40 262.05 269.03 276.19 283.53 291.07 298.80 306.74 314.88 323.24 331.81 340.61 349.64 358.90 368.41 378.16 388.16 398.42 408.95
Electricity 5.52 6.33 7.15 8.08 8.97 10.46 11.99 13.91 15.24 16.47 18.73 20.44 20.84 21.92 23.61 24.51 25.40 26.21 27.63 28.62 29.58 30.55 31.51 32.47 33.42 34.35 35.25 36.13 36.96 37.73 38.43 39.04 39.53 39.86 40.00 40.13
16
Figure 1.12 Transportation Energy Consumption by Type (Million BOE) 700 600 500 400 300 200 100 0 1990
1995
2000
Petroleum Fuels
Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Petroleum Fuels 93.42 101.46 110.87 120.28 124.11 135.10 149.10 157.12 148.89 154.02 163.41 170.35 176.50 184.64 198.25 208.26 216.57 225.40 238.63 249.38 260.60 272.30 284.50 297.23 310.50 324.33 338.75 353.79 369.45 385.78 402.79 420.51 438.96 458.18 478.20 499.04
2005
Natural Gas
Natural Gas 0.00 0.01 0.01 0.02 0.03 0.04 0.05 0.05 0.07 0.08 0.07 0.06 0.05 0.05 0.05 0.07 1.03 2.09 3.30 4.61 6.06 7.64 9.39 11.29 13.38 15.66 18.15 20.86 23.82 27.03 30.52 34.31 38.42 42.88 47.70 52.93
2010
Coal
Coal 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00
2015
Renewable
2020
2025
Electricity
Renewable 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.01 0.02 0.03 0.04 0.07 0.10 0.15 0.24 0.36 0.55 0.83 1.27 1.93 2.94 4.47 6.81 10.37 15.79 24.04 36.59 53.56
( Million BOE) Electricity 0.01 0.01 0.01 0.01 0.01 0.01 0.02 0.02 0.02 0.02 0.03 0.03 0.03 0.03 0.03 0.04 0.04 0.04 0.05 0.05 0.06 0.07 0.07 0.08 0.09 0.10 0.11 0.12 0.13 0.14 0.16 0.17 0.19 0.21 0.23 0.26
17
Figure 1.13 Electricity Energy Consumption by Type (Million BOE) 700 600 500 400 300 200 100 0 1990
1995
2000
Petroleum Fuels
2005
Natural Gas
2010
Coal
2015
2020
2025
Renewable
( Million BOE)
Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Petroleum Fuels 35.79 40.50 43.95 47.91 28.61 22.48 25.10 34.63 31.17 35.41 37.57 39.22 50.33 54.70 60.78 70.45 61.39 51.08 40.18 26.64 11.11 11.54 12.03 12.53 13.04 13.57 14.10 14.63 15.17 15.71 16.25 16.79 17.32 17.84 18.34 18.82
Natural Gas 2.84 2.73 2.62 11.96 32.94 45.07 59.97 46.65 45.49 48.41 46.51 43.91 37.88 35.99 34.27 25.65 28.53 31.71 35.95 40.02 44.46 47.10 50.15 53.40 56.85 60.53 64.44 68.60 73.02 77.73 82.73 88.06 93.72 99.74 106.14 112.94
Coal 16.67 18.72 17.99 16.59 19.34 19.55 27.71 34.74 37.18 39.86 45.56 47.26 47.09 50.85 51.09 55.71 65.91 77.20 91.65 106.19 122.26 131.49 142.14 153.65 166.07 179.49 193.98 209.63 226.52 244.76 264.45 285.71 308.66 333.43 360.17 389.03
Renewable 2.69 2.95 3.69 3.20 3.36 3.88 4.10 3.35 4.95 4.92 12.08 13.15 11.68 11.13 14.29 15.16 14.68 17.76 21.63 25.59 30.03 31.87 34.01 36.28 38.71 41.29 44.05 46.99 50.12 53.46 57.01 60.80 64.85 69.15 73.74 78.62
18
Figure 1.14a Total Energy Consumption by Type (including Biomass) (Million BOE) 2,500
2,000
1,500
1,000
500
0 1990
1995
2000
Petroleum Fuels
2005
Natural Gas
2010
Coal
2015
2020
2025
Renewable
(Million BOE)
Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Petroleum Fuels 210.33 225.38 245.70 266.81 256.17 267.72 286.55 309.90 303.10 325.82 345.15 358.39 378.42 385.33 415.05 440.81 446.01 450.78 462.04 466.70 470.13 490.29 511.34 533.25 556.04 579.76 604.43 630.09 656.79 684.54 713.39 743.38 774.55 806.94 840.58 875.53
Natural Gas 14.07 14.29 15.08 24.13 51.85 64.98 78.58 70.44 63.77 80.87 84.62 92.15 84.09 80.57 103.31 98.31 106.09 114.51 125.71 136.15 147.40 157.29 168.07 179.55 191.77 204.79 218.65 233.41 249.12 265.85 283.65 302.60 322.77 344.22 367.06 391.36
Coal 27.24 29.58 30.04 30.28 33.51 36.18 43.22 50.85 55.08 66.81 81.87 84.86 85.99 91.09 106.53 114.09 127.31 141.83 160.72 179.16 199.34 212.91 228.14 244.48 262.01 280.80 300.96 322.59 345.80 370.69 397.41 426.07 456.83 489.84 525.26 563.28
Renewable 196.08 199.30 203.18 205.85 208.63 211.29 213.33 217.20 222.12 224.48 235.69 239.99 242.32 245.56 251.35 258.16 276.19 285.49 298.48 309.72 321.60 331.06 341.00 351.27 361.87 372.83 384.15 395.85 407.94 420.44 433.37 446.74 460.56 474.87 489.67 504.99
19
Figure 1.14b Total Energy Consumption by Type (excluding Biomass) (Million BOE) 2,000 1,800 1,600 1,400 1,200 1,000 800 600 400 200 0 1990
1995
2000
Petroleum Fuels
2005
Natural Gas
2010
Coal
2015
2020
2025
Renewable
(Million BOE)
Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Petroleum Fuels 210.33 225.38 245.70 266.81 256.17 267.72 286.55 309.90 303.10 325.82 345.15 358.39 378.42 385.33 415.05 440.81 446.01 450.78 462.04 466.70 470.13 490.29 511.34 533.25 556.04 579.76 604.43 630.09 656.79 684.54 713.39 743.38 774.55 806.94 840.58 875.53
Natural Gas 14.07 14.29 15.08 24.13 51.85 64.98 78.58 70.44 63.77 80.87 84.62 92.15 84.09 80.57 103.31 98.31 106.09 114.51 125.71 136.15 147.40 157.29 168.07 179.55 191.77 204.79 218.65 233.41 249.12 265.85 283.65 302.60 322.77 344.22 367.06 391.36
Coal 27.24 29.58 30.04 30.28 33.51 36.18 43.22 50.85 55.08 66.81 81.87 84.86 85.99 91.09 106.53 114.09 127.31 141.83 160.72 179.16 199.34 212.91 228.14 244.48 262.01 280.80 300.96 322.59 345.80 370.69 397.41 426.07 456.83 489.84 525.26 563.28
Renewable 1.84 2.07 2.67 2.26 2.15 2.51 2.40 1.98 3.24 3.19 7.85 8.55 7.59 7.24 9.29 9.86 9.55 11.55 14.07 16.64 19.51 20.66 22.00 23.43 24.94 26.55 28.27 30.09 32.04 34.10 36.30 38.63 41.12 43.76 46.56 49.55
20
Figure 1.15 Total Energy Consumption by GDP Scenario (Million BOE) 2,500
2,000
1,500
1,000
500
0 1990
1995
2000
2005
Data
Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
2010
2015
2020
2025
Base Case
(Million BOE) Total Energy Consumption 409 425 450 474 493 520 540 568 566 613 655 684 697 705 777 810 843 878 928 970 1,015 1,062 1,111 1,162 1,217 1,273 1,333 1,396 1,462 1,531 1,604 1,680 1,761 1,845 1,934 2,028
21
Figure 1.16 Crude Oil Balance
(Million BOE)
1,000 900 800 700 600 500 400 300 200 100 0 1990
1995
Production
Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Production 534 581 551 558 588 586 583 577 569 546 517 489 457 419 401 336 339 335 328 324 322 321 321 322 322 323 325 328 331 335 340 346 352 359 366 374
2000
2005
2010
Domestic Consumption
Domestic Consumption 223 240 262 278 269 280 298 324 319 342 355 369 389 386 420 434 453 461 476 486 495 516 538 561 585 611 637 664 692 721 752 784 816 851 886 923
2015
Export
2020
2025
Import
Export 330 330 293 283 324 302 284 289 280 285 224 240 217 189 179 160 152 145 138 132 126 120 114 109 104 99 94 90 86 82 78 74 71 68 64 61
(Million BOE) Import 58 44 49 56 62 69 72 63 72 102 80 120 137 150 192 220 236 243 264 273 280 304 328 353 380 408 437 466 497 528 560 594 628 664 701 739
22
Figure 1.17
Natural Gas Balance
(Million BOE) 1,400 1,200 1,000 800 600 400 200 0 1990
1995
Production
Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Production 508 443 464 478 528 539 586 569 535 551 521 504 546 567 544 544 519 534 555 586 557 590 637 686 736 764 794 826 859 896 934 975 1,018 1,065 1,114 1,166
2000
2005
2010
Domestic Consumption
Domestic Consumption 33 34 36 41 75 90 94 100 86 125 137 166 157 153 208 221 235 251 272 291 311 333 356 381 407 435 465 497 531 567 606 646 690 736 785 838
2015
Export
2020
2025
Import
Export 230 230 241 246 268 253 269 267 264 285 263 235 255 293 284 266 302 303 305 318 270 284 310 335 361 363 366 368 371 374 377 380 384 388 392 396
(Million BOE) Import 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
23
Figure 1.18 Coal Balance (Million BOE) 1,400 1,200 1,000 800 600 400 200 0 1990
1995
Production
Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Production 47 60 102 109 136 172 198 232 263 308 344 374 413 474 537 602 648 673 704 734 762 788 816 845 876 902 935 970 1,006 1,044 1,084 1,125 1,170 1,216 1,265 1,316
2000
2005
2010
Domestic Consumption
Domestic Consumption 29 31 33 31 34 38 42 53 59 71 94 95 96 108 136 148 156 172 193 212 230 245 262 280 300 315 336 358 382 408 435 464 495 527 562 600
2015
Export
2020
2025
Import
Export 18 28 70 78 102 134 156 178 204 237 250 279 317 366 401 454 492 501 512 522 532 543 554 565 576 588 599 611 624 636 649 662 675 688 702 716
(Million BOE) Import 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
24
Figure 1.19 Energy Production by Type (Million BOE) 1,400 1,200 1,000 800 600 400 200 0 1990
1995
2000
Crude oil
Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Crude Oil 534 581 551 558 588 586 583 577 569 546 517 489 457 419 401 336 339 335 328 324 322 321 321 322 322 323 325 328 331 335 340 346 352 359 366 374
2005
Natural Gas
Natural Gas 508 443 464 478 528 539 586 569 535 551 521 504 546 567 544 544 519 534 555 586 557 590 637 686 736 764 794 826 859 896 934 975 1,018 1,065 1,114 1,166
2010
Coal
2015
2020
2025
Renewable
Coal 47 60 102 109 136 172 198 232 263 308 344 374 413 474 537 602 648 673 704 734 762 788 816 845 876 902 935 970 1,006 1,044 1,084 1,125 1,170 1,216 1,265 1,316
(Million BOE) Renewable 196 199 203 206 209 211 213 217 222 224 236 240 242 246 251 258 276 285 298 310 322 331 341 351 362 373 384 396 408 420 433 447 461 475 490 505
25
Figure 1.20 Total Energy Balance (Million BOE) 4,000 3,500 3,000 2,500 2,000 1,500 1,000 500 0 1990
1995
Energy Production
Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
2000
2005
Demand of Energy
Energy Production 1,285 1,283 1,321 1,351 1,462 1,508 1,580 1,594 1,589 1,629 1,619 1,607 1,659 1,705 1,733 1,741 1,782 1,828 1,886 1,954 1,962 2,030 2,115 2,204 2,296 2,362 2,438 2,519 2,604 2,695 2,791 2,893 3,000 3,114 3,234 3,362
2010
2015
Export of Energy
Demand of Energy 480 503 532 556 586 619 646 693 684 761 818 865 880 889 1,011 1,055 1,116 1,163 1,232 1,290 1,346 1,413 1,485 1,561 1,640 1,718 1,806 1,898 1,995 2,097 2,205 2,318 2,438 2,563 2,696 2,836
2020
2025
Import of Energy
Export of Energy 579 589 603 608 694 688 709 735 748 807 736 754 790 849 864 879 945 949 954 972 928 947 978 1,009 1,041 1,050 1,060 1,070 1,080 1,092 1,104 1,117 1,130 1,144 1,159 1,174
(Million BOE) Import of Energy 58 44 49 56 62 69 72 63 72 102 80 120 137 150 192 220 236 243 264 273 280 304 328 353 380 408 437 466 497 528 560 594 628 664 701 739
26
Figure 1.21 Reserves-Production Ratio of Crude Oil (Year) 14 12 10 8 6 4 2 0 1990
1995
2000
2005
2010
2015
2020
2025
Data Projection with INOSYD's scenario,where Reserve to Production Ratio of Crude Oil is fixed at 12 years Projection with INOSYD's scenario, without R/P constraint
Figure 1.22 Reserves-Production Ratio of Natural Gas (Year) 35 30 25 20 15 10 5 0 1990
1995
2000
2005
Data
2010
2015
2020
2025
Projection
27
Figure 1.23 Reserves-Production Ratio of Coal 900 800 700 600 500 400 300 200 100 0 1991
1996
2001
2006 Data
Table 1.1 Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
2011
2016
2021
Projection
R/P Ratio of Crude Oil, Gas, Coal Crude Oil Unfixed 11 10 11 10 9 8 8 8 9 10 10 10 10 11 11 9 9 8 8 7 7 6 6 5 5 4 4 4 3 3 2 2 2 2 1 1
Crude Oil Fixed at 12 years 11 10 11 10 9 8 8 8 9 10 10 10 10 11 11 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12 12
Natural Gas Fixed at 15 years 0 26 25 25 27 24 24 24 26 30 33 33 30 29 32 29 31 31 29 28 29 28 26 24 23 22 21 20 19 18 17 17 16 15 14 13
(Year) Coal Fixed at 35 years 0 837 495 467 378 303 265 228 203 174 156 144 131 114 101 90 84 80 76 73 70 67 65 62 59 57 55 52 50 48 45 43 41 39 36 34
28
Figure 1.24 CO2 Emission per Sector (Million Ton) 1,400 1,200 1,000 800 600 400 200 0 1990
1995
2000
Industry
Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Industry 35.18 36.13 40.06 43.89 48.09 52.51 51.78 55.00 56.03 71.69 82.20 86.92 86.85 83.67 105.38 110.06 114.80 119.84 127.03 133.11 139.48 146.16 153.15 160.48 168.17 176.22 184.65 193.49 202.76 212.46 222.63 233.29 244.46 256.16 268.42 281.27
Commercial
Commercial 1.34 1.74 2.28 2.95 3.26 3.55 3.88 4.09 3.42 3.47 3.66 3.70 3.78 3.82 3.87 4.10 4.31 4.54 4.88 5.16 5.46 5.78 6.11 6.46 6.84 7.23 7.65 8.09 8.56 9.05 9.57 10.11 10.69 11.30 11.95 12.63
2005
2010
Residential
Residential 133.50 135.34 137.19 139.08 140.81 142.34 143.68 147.76 151.07 153.31 156.59 159.96 163.81 167.27 169.53 174.16 186.92 191.81 198.74 204.44 210.29 216.31 222.51 228.88 235.43 242.17 249.10 256.24 263.57 271.11 278.87 286.85 295.06 303.51 312.19 321.12
2015
Transportation
2020
2025
Electricity
Transportation 40.40 43.88 47.95 52.03 53.68 59.09 65.20 68.62 64.81 66.58 71.38 74.65 77.28 81.04 87.21 91.38 95.66 99.90 106.14 111.32 116.75 122.44 128.40 134.65 141.21 148.07 155.27 162.81 170.71 178.99 187.67 196.76 206.28 216.26 226.72 237.67
(Million tons) Electricity 32.64 36.82 38.78 38.40 37.76 39.81 46.24 55.64 57.86 62.12 67.93 69.33 72.52 77.58 86.77 92.50 98.55 104.21 112.59 119.81 124.66 133.07 142.74 153.10 164.21 172.09 183.94 196.59 210.10 224.50 239.88 256.14 273.48 291.97 311.69 332.71
29
Figure 1.25 NOx Emission per Sector (Thousand Ton) 5,000 4,500 4,000 3,500 3,000 2,500 2,000 1,500 1,000 500 0 1990
1995
Industry
Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Industry 83.72 85.98 96.46 106.49 118.43 130.32 128.09 137.34 139.20 183.04 211.84 226.67 226.54 217.65 279.67 292.59 305.62 319.47 339.09 355.81 373.36 391.77 411.09 431.35 452.62 474.94 498.36 522.93 548.71 575.76 604.14 633.92 665.17 697.96 732.36 768.46
2000
2005
Commercial
2010
Residential
Commercial 1.73 2.24 2.92 3.78 4.18 4.54 4.96 5.24 4.38 4.45 4.69 4.74 4.81 4.87 4.93 5.23 5.50 5.79 6.22 6.59 6.97 7.37 7.80 8.25 8.73 9.23 9.77 10.33 10.93 11.56 12.22 12.92 13.66 14.44 15.27 16.14
2015
Transportation
Residential 132.61 134.44 136.27 138.16 139.92 141.52 142.94 147.37 150.97 153.44 156.92 160.53 164.71 168.40 170.66 175.43 187.83 192.93 200.09 206.01 212.11 218.39 224.86 231.51 238.37 245.42 252.69 260.17 267.87 275.80 283.97 292.37 301.03 309.94 319.11 328.56
2020
2025
Electricity
Transportation 402.59 437.24 477.79 518.41 534.91 587.80 648.67 682.80 645.17 663.26 710.35 742.61 768.78 805.91 866.99 908.62 951.44 994.38 1,057.25 1,109.68 1,164.68 1,222.39 1,282.93 1,346.45 1,413.07 1,482.97 1,556.29 1,633.20 1,713.87 1,798.50 1,887.26 1,980.35 2,078.00 2,180.41 2,287.81 2,400.46
(Thousand tons) Electricity 84.78 95.62 100.97 100.49 98.72 104.46 121.60 146.37 151.75 163.07 177.25 180.96 189.32 201.90 225.37 240.12 256.12 270.18 291.49 309.53 321.24 343.24 368.60 395.80 424.98 445.69 476.89 510.20 545.78 583.77 624.33 667.22 712.98 761.80 813.89 869.44
30
Figure 1.26 SOx Emissions per Sector (Thousand Ton) 1,400 1,200 1,000 800 600 400 200 0 1990
1995
Industry
Year 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025
Industry 28.44 29.21 31.68 34.62 35.93 39.52 38.57 39.71 42.27 53.80 64.83 66.06 67.09 67.25 84.59 88.38 92.31 96.48 102.40 107.43 112.72 118.27 124.08 130.19 136.59 143.31 150.36 157.76 165.52 173.66 182.21 191.17 200.57 210.44 220.79 231.64
2000
2005
Commercial
Commercial 1.12 1.45 1.90 2.45 2.69 2.93 3.20 3.37 2.81 2.86 3.02 3.04 3.07 3.10 3.13 3.30 3.43 3.56 3.78 3.95 4.13 4.31 4.49 4.69 4.89 5.09 5.30 5.51 5.74 5.96 6.19 6.43 6.67 6.91 7.15 7.40
2010
Residential
2015
Transportation
Residential 181.54 184.04 186.59 189.13 191.31 193.15 194.67 199.05 202.54 204.77 208.61 212.33 216.46 220.38 223.42 229.15 247.43 253.40 262.05 269.03 276.19 283.53 291.07 298.80 306.74 314.88 323.24 331.81 340.61 349.64 358.90 368.41 378.16 388.16 398.42 408.95
2020
2025
Electricity
Transportation 17.55 19.06 20.84 22.63 23.34 25.78 28.44 29.92 28.26 29.01 31.11 32.53 33.69 35.35 38.06 39.87 41.63 43.33 45.89 47.97 50.14 52.41 54.78 57.25 59.82 62.51 65.31 68.23 71.28 74.45 77.76 81.21 84.81 88.55 92.46 96.53
(Thousand tons) Electricity 40.68 46.07 48.19 44.53 39.41 37.76 44.44 60.50 64.32 69.19 81.51 81.87 86.44 95.60 113.00 121.47 129.24 139.36 153.47 166.41 175.78 187.83 201.68 216.54 232.48 243.08 259.97 278.00 297.26 317.82 339.77 363.13 388.07 414.69 443.10 473.41
31
Figure 1.27 Total Capacity of Oil Refinery
(Million BOE) 1,375 1,175
975 775 575
375 175 1985
1990
1995
2000
2005
2010
2015
2020
2025
2030
Data
Projection
2015
2020
2025
2030
Figure 1.28 Total Capacity of Gas Refinery (Million BOE) 475
425 375
325 275
225 175 1985
1990
1995
2000
2005
Data
2010
Projection
32
Figure 1.29 Total Capacity of Power Generator Total Capacity of Power Generator
(GW) 140 120 100 80 60 40 20 0 1985
1990
1995
2000
2005
2010
2015
Data
Projection
2020
2025
2030
Figure 1.30 Investment Cost of Oil (Million USD) 40,000 35,000 30,000 25,000 20,000 15,000 10,000 5,000 0 2004
2006
2008
2010
2012
2014 Oil Refinery
2016
2018
2020
2022
2024
Depo
33
Figure 1.31 Investment Cost of Gas (M illion USD) 9,000 8,000 7,000 6,000 5,000 4,000 3,000 2,000 1,000 0 2004
2006
2008
2010
2012
2014
Gas Refinery
2016
2018
2020
2022
2024
Gas Pipeline
Figure 1.32 Investment Cost of Coal (M illion USD) 1,600 1,400 1,200 1,000 800 600 400 200 0 2004
2006
2008
2010
2012
2014
2016
Coal Railroad
2018
2020
2022
2024
2020
2022
2024
Coal Harbor
Figure 1.33 Investment Cost of Electricity (M illion USD) 45,000 40,000 35,000 30,000 25,000 20,000 15,000 10,000 5,000 0 2004
2006
2008
2010
2012
Power Generator
2014
2016
2018
Transmission & Distribution
34
Table 1.2
Year
Intensity of Total Energy Consumption
Primary Energy Consumption per GDP
Primary Energy Consumption per Capita
TOE/Million USD (at constant price of 2000)
TOE/Person
1990
67.01
0.37
1991
63.77
0.38
1992
65.04
0.39
1993
58.98
0.41
1994
57.81
0.42
1995
56.40
0.44
1996
54.59
0.45
1997
55.98
0.47
1998
63.61
0.46
1999
70.19
0.51
2000
71.88
0.54
2001
73.28
0.57
2002
71.37
0.57
2003
68.75
0.56
2004
74.36
0.63
2005
73.53
0.65
2006
73.60
0.68
2007
72.74
0.70
2008
73.02
0.73
2009
72.13
0.76
2010
71.04
0.78
2011
70.34
0.81
2012
69.73
0.84
2013
69.13
0.88
2014
68.55
0.91
2015
67.75
0.94
2016
67.16
0.98
2017
66.59
1.02
2018
66.03
1.05
2019
65.49
1.10
2020
64.96
1.14
2021
64.43
1.18
2022
63.91
1.23
2023
63.41
1.28
2024
62.91
1.33
2025
62.43
1.38
35
Table 1.3
Year
GDP Elasticity of Energy Consumption
Annual Growth Rate (%)
GDP Elasticty
Energy Consumption
GDP
1991
3.99
7.01
0.57
1992
5.92
6.76
0.88
1993
5.24
15.21
0.34
1994
4.10
7.54
0.54
1995
5.40
8.22
0.66
1996
3.87
7.82
0.49
1990
1997
5.27
4.70
1.12
1998
-0.39
-13.13
0.03
1999
8.37
0.79
10.57
2000
6.85
4.90
1.40
2001
4.35
3.83
1.14
2002
1.98
4.38
0.45
2003
1.16
4.88
0.24
2004
10.18
5.13
1.98
2005
4.21
5.60
0.75
2006
4.07
5.60
0.73
2007
4.16
5.40
0.77
2008
5.70
6.30
0.90
2009
4.57
6.30
0.73
2010
4.59
6.30
0.73
2011
4.61
6.50
0.71
2012
4.62
6.50
0.71
2013
4.64
6.50
0.71
2014
4.66
6.50
0.72
2015
4.67
6.50
0.72
2016
4.69
6.50
0.72
2017
4.71
6.50
0.72
2018
4.72
6.50
0.73
2019
4.74
6.50
0.73
2020
4.76
6.50
0.73
2021
4.77
6.50
0.73
2022
4.79
6.50
0.74
2023
4.81
6.50
0.74
2024
4.82
6.50
0.74
2025
4.84
6.50
0.74
36
Table 1.4
Emissions per GDP
CO2 Emission per GDP
NOx Emission per GDP
SOx Emission per GDP
Year
CO2 Ton/Million USD (2000 Prices)
NOx Ton/Million USD (2000 Prices)
SOx Ton/Million USD (2000 Prices)
1990
248.81
0.72
0.28
1991
236.06
0.72
0.27
1992
238.56
0.73
0.26
1993
214.93
0.67
0.23
1994
205.11
0.65
0.21
1995
198.67
0.65
0.20
1996
192.63
0.65
0.19
1997
196.01
0.66
0.20
1998
227.05
0.74
0.23
1999
241.48
0.79
0.24
2000
246.06
0.81
0.25
2001
244.92
0.82
0.25
2002
240.41
0.81
0.24
2003
234.42
0.79
0.24
2004
244.22
0.83
0.25
2005
241.20
0.83
0.25
2006
241.98
0.83
0.25
2007
238.55
0.82
0.25
2008
238.76
0.82
0.25
2009
235.27
0.81
0.24
2010
230.77
0.80
0.24
2011
227.61
0.80
0.24
2012
224.76
0.79
0.23
2013
222.00
0.78
0.23
2014
219.32
0.78
0.23
2015
215.55
0.77
0.22
2016
212.85
0.76
0.22
2017
210.22
0.76
0.22
2018
207.66
0.75
0.21
2019
205.16
0.74
0.21
2020
202.72
0.74
0.21
2021
200.32
0.73
0.21
2022
197.98
0.72
0.20
2023
195.71
0.72
0.20
2024
193.48
0.71
0.20
2025
191.32
0.71
0.20
37
Table 1.5
Year
Emissions per Capita
CO2 Emission per Capacity
NOx Emission per Capacity
SOx Emission per Capacity
CO2 Ton/Person
NOx Ton/Person
SOx Ton/Person
1990
1.35599
0.00394
0.00150
1991
1.39684
0.00416
0.00154
1992
1.44486
0.00442
0.00157
1993
1.47948
0.00464
0.00157
1994
1.49812
0.00473
0.00155
1995
1.54983
0.00505
0.00156
1996
1.59915
0.00538
0.00159
1997
1.65691
0.00560
0.00166
1998
1.64237
0.00538
0.00168
1999
1.75905
0.00575
0.00177
2000
1.85468
0.00613
0.00189
2001
1.89104
0.00630
0.00190
2002
1.90675
0.00639
0.00192
2003
1.92024
0.00650
0.00196
2004
2.07825
0.00710
0.00212
2005
2.13740
0.00734
0.00218
2006
2.23747
0.00763
0.00230
2007
2.29956
0.00788
0.00237
2008
2.39933
0.00827
0.00248
2009
2.47640
0.00858
0.00257
2010
2.54429
0.00886
0.00264
2011
2.62838
0.00920
0.00272
2012
2.71862
0.00956
0.00282
2013
2.81257
0.00993
0.00291
2014
2.91041
0.01032
0.00301
2015
2.99615
0.01068
0.00309
2016
3.09892
0.01109
0.00319
2017
3.20577
0.01152
0.00330
2018
3.31686
0.01197
0.00341
2019
3.43239
0.01243
0.00353
2020
3.55254
0.01291
0.00365
2021
3.67698
0.01341
0.00378
2022
3.80641
0.01394
0.00391
2023
3.94105
0.01448
0.00405
2024
4.08112
0.01504
0.00419
2025
4.22684
0.01563
0.00434
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Figure 1.34 Contribution of Primary Energy Supply
Renewable* 14.83%
Renewable** 0.38%
Crude Oil 19.32%
Crude Oil 22.60%
Coal 40.45%
Coal 34.58%
Natural Gas 31.26%
Natural Gas 36.57%
1,740.75 Million BOE
1,488.26 Million BOE
Year: 2005
Year: 2005
Crude Oil 13.69%
Renewable* 15.78%
Renewable** Crude Oil 0.76% 16.13%
Coal 45.01%
Natural Gas 32.33%
Coal 38.20%
Natural Gas 38.09%
2,362.35 Million BOE
2,004.75 Million BOE
Year: 2015
Year: 2015
Crude Oil 11.14%
Renewable* 15.02%
Renewable** 0.98%
Crude Oil 12.98%
Coal 45.61%
Natural Gas 34.69%
Natural Gas 40.42%
Coal 39.15%
3,361.67 Million BOE
2,885.05 Million BOE
Year: 2025
Year: 2025
*) with Biomass and Hydro **) without Biomass and Hydro
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Figure 1.35 Contribution of Final Energy Consumption
Electricity 10.44% Coal 14.13%
Petroleum Fuel 61.72%
Natural Gas 13.71%
627.43 Million BOE
Year: 2005 Electricity 12.50%
Coal 17.07% Petroleum Fuel 54.24%
Natural Gas 16.19%
1,054.83 Million BOE
Year: 2015 Electricity 14.66%
Petroleum Fuel 48.00%
Coal 19.14%
Natural Gas 18.20%
1,802.03 Million BOE
Year: 2025
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ENERGY ANALYSIS, PERSPECTIVE, and POLICY
Aftermath economic crisis in 1998, energy sector in Indonesia experienced dynamic changes signified by considerable growth of energy demand and amendment of legislations and regulations of energy compounded by oil price hikes. Since then, we are aware that in the future there would be a turning point where Indonesia becomes a net energy importer rather than a net energy exporter. Currently Indonesia is a net oil importer as the oil production nationally steadily declines. It should be noted that natural gas production follows oil to decline. As a result, Indonesia is no longer a largest LNG exporter in the near future. It is a high time to look closely the sustainability of national energy supply while improving the utilization of energy alternatives which are more sustained. Facing such unfavorable situation, government of Indonesia prioritizes improvement of national energy supply security by issuing Blue Print Energy Policy 2005 and national energy policy by issuing Presidential Decree 5/2006. Measures to ensure the supply security include diversification of energy sources, rationalization of energy pricing and improvement of energy efficiency. In addition to that, the government will propose an energy bill. However, the success of the supply security is also dependent on the readiness of supporting policies and all energy stake-holders. Some further analysis on each energy sector will be addressed in the following sections.
1.1 Oil and Gas Current Conditions In 2005, Indonesia’s oil reserves are around 8.63 billion barrels, with proven reserves of 4.19 billion barrels corresponding to 0.4% of world proven reserves, and potential reserves of 4.44 billion barrels. A large amount of proven oil reserve is located onshore. Central Sumatra is the largest oil producing province (e.g. the Duri and Minas oil fields). Other major fields are located in East Kalimantan, Northwestern Java, and the Natuna Sea. Indonesian crude oil production including condensate is about 342 million barrels in 2005. This production gradually declined 33% from year of 2000 due to ageing oil fields and lack of investment for exploration and development. The total revenue from crude oil export has increased to US$ 8.2 billion in 2005 compared to US$ 6.3 billion in 2000 due to higher price of crude oil though the export volume was lower in 2005. While the import value of crude was US$ 6.5 billion in 2005. At present Indonesia have nine refineries, with a total installed capacity of 1.1 million barrel per day (bpd). The largest refineries are in Cilacap – Central Java of 348,000 bpd, in Balikpapan – Kalimantan of 260,000 bpd, and in Balongan – East Java of 125,000 bpd. However, since the installed capacity of the refineries is unchanged as opposed to the
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increasing domestic fuel consumption, the import value of petroleum product has augmented significantly. The import figure of petroleum products in 2005 was about 158 million barrels corresponding to US$ 10.3 billion. For comparison, the import volume in 2000 was only 87 million barrels or US$ 2.9 billion. In the same time Indonesia export refined products was about US$ 2.05 billion. So the net financial balance of oil is minus US$ 6.6 billion. Domestic petroleum fuels consumption increased to 354 million barrels in 2005 from 293 million barrels in 2000, corresponding with share of 62% of total final energy consumption. Most of domestic fuel consumption is used by transportation (30%), industry (44%) and household (16%) sectors. In 2005, domestic fuel prices are still the subsidized price mainly for kerosene except high grade petroleum fuels and for industrial proposed. This policy is intended to minimize the impact of fuel price to the lower income groups. However, since the amount of fuel subsidy has reached a staggering value of Rp. 68 trillion in 2001, the government is planning to ease the budget by limiting the subsidy to ~ Rp. 30 trillion in 2003. A new pricing policy was introduced in which the domestic fuel price is gradually set to follow the trend of the international fuel price. However, in 2005, crude oil prices increased significantly up to ~ 60 US$/barrel that cause reincreasing fuel subsidies at level Rp. 99.5 trillion that extremely costly to economy. Indonesia’s natural gas reserves in 2005 are 185.8 trillion cubic feet (tcf). About 97.3 tcf is proven and 88.5 tcf is probable reserves. This corresponds to almost 2.7 % of world proven natural gas reserves. More than 70 % of natural gas reserves are located offshore which far from demand centre, with the largest reserves are in East Kalimantan, Natuna Island, Papua, Aceh, and South Sumatra. The most promising new finds are Wiriagar, Berau, and Muturi fields located in Papua, with total proven reserves of about 14.4 tcf, and Donggi, Centre of Sulawesi. Indonesia’s natural gas gross production decreased slightly to 2.98 tcf in 2005 from 3.15 tcf in 2003. For liquefied natural gas (LNG), total production capacity of LNG Plants at Arun and Bontang are 12.85 and 21.64 billion ton per year, respectively. The current Indonesia’s LNG and LPG production are 23.7 million metric tons and 1.8 million metric tons per year, respectively. The major markets for Indonesian LNG are Japan, South Korea and Taiwan. An export through pipeline to Singapore and Malaysia accounted for about 4.8% of the total natural gas production. The development of BP’s Tangguh gas field in Papua is intended for markets in China. The total revenue for LNG export has increased to US$ 9.1 billion in 2005 compared with US$ 6.8 billion in 2000 due to higher price of LNG. Most of the natural gas produced (about 60 %) was processed into liquefied natural gas (LNG) for export purposes. The rest is consumed domestically, mainly for industries and electricity. Increasing gas domestic demand however not follows by development of natural gas production, domestic infrastructures and appropriate gas pricing policy. The sign of tightening supply of natural gas was observed when faced supply shortages gas for domestic utilization such as fertilizer industry, ceramic industry and electricity as well as the deferment of some LNG cargoes for export.
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Projection The projections for oil and gas sectors for time horizon up to 2025 are as follows. For reserves-to-production ratio (R/P) equal to 10 years. Total domestic demand of crude oil will reach 923 million BOE at 2025 which is 2.1 times the consumption in 2005. In 2012 the crude production is expected to equalize the crude import where the import contributes 61% of the oil domestic consumption. The contribution will increase to reach 80% or 739 million BOE in 2025. As to balance of natural gas, it is interesting that at year of 2009 the domestic natural gas consumption reaches to value of natural gas exports (~300 million BOE). At period of 20052025, domestic natural gas consumption production attain 838 million BOE with average growth rate per year is almost 6.8% driven mainly by the growth in industrial and electricity sectors. Currently Indonesia is expected to remain the world’s biggest LNG exporter in the next few years however LNG production capacity is to decline in the long term due to declining natural gas reserves and increasing domestic utilization. In twenty years, the total primary energy consumption originating from oil and gas at 2025 will increase significantly close to 2.1 times for oil (923 million BOE) and 3.8 times for gas (838 million BOE) compared to the 2005’s figures. The rate of energy consumption (oil and gas) is still higher than the finding rate of new oil and gas reserves. In 2025, the total final energy consumption will still be dominated by oil fuels and gas (66.2%) compared to about 75% in 2005 (excluded biomass). In the near future, the roles of oil and gas sector are still important in securing national energy supply. The total emission of CO2, NOx, and SOx in 2025 will reach a value of 1,200 million ton, 4.4 million ton, and 3.7 million ton compared to 450 million ton, 1.7 million ton, and 2 million ton in 2005, respectively. Regarding oil and gas infrastructures at 2025, Indonesia needs to construct new petroleum refineries with capacity 2 times to current refinery capacity, correspond to 2.2 million b/d capacities with an assumption of no imported petroleum fuels. This corresponds to accumulative investment of US$ 35 billion. An additional storage facility requires new investment around US$ 10.5 billion. For natural gas infrastructure, estimated total investment ~ US$ 10 billion including gas refineries and pipeline gas. All estimated investments are calculated based only on capital expenditures.
Policy The dynamic situation of Indonesia’s oil and gas sector is occurring, reflected by the introduction oil and gas law (UU No. 22 tahun 2001) As consequences oil and gas industries are deregulated whereas dominant state-own companies that have monopoly characteristics are changed toward competitive oil and gas industry structure. The fact that the implementation of oil and gas law has some limitations due to lack of clarity in transition policy to become fully deregulated, in action plans and in other supporting policy instruments. In addition, new institutions such as BPMIGAS (Oil and Gas Upstream
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Executing Body) and BPH MIGAS (Oil and Gas Downstream Regulatory Body) need to have clear authorities and Directorate General of Oil and Gas, however, needs better job coordination with BPMIGAS and BPH MIGAS. Ideally, a regulator in its role can bring in more investments in the oil and gas. The regulator should be autonomous and independent. The rules of games should be transparent with minimal external interference. The regulator should balance the interests of the customers, the producers, and other stakeholders. In the upstream of oil and gas sector, the government would set a competitive fiscal terms to attract investors for development of mature and frontier areas including marginal and depleting fields. The role of national entrepreneurs in exploration activity is smalls; the government would make the indigenous companies enter into exploration activities so that more benefits will come to Indonesia. The government should reform to enhance good practice of government agencies in interacting with investors. In the downstream oil and gas sector, the Indonesian faces a number of obstacles mainly limited infrastructures of energy in conversion, transportation, distribution and storage and disincentives in the pricing of domestic petroleum products and gas as well as supply shortage of kerosene and gas for domestic purposes. In downstream oil sector, the capacity of petroleum refineries and storage capacity should be increased to accommodate the growing domestic demand. Reform in lifestyle of energy consumption especially kerosene and LPG usages must be performed. Kerosene is high quality fuel and expensive, its properties close to jet fuels. It is necessary to make real efforts to promote the consumption of non-oil fuels such as gas, briquette and biofuels to substitute kerosene, simultaneously by eliminating the oil-based fuel subsidies. For the short term, LPG is an alternative solution to substitute kerosene, however for the long term LPG usage for urban area fuels is expensive if city gas pipelines are available. LPG is commonly used in remote areas in which gas networks unavailable and in the future LPG is vital feedstock for petrochemical industry since source of naphtha is limited. Petroleum market reform can proceed from the supply chain into the retail market and result in competing wholesale distributors and retail outlets. However, some obstacles to the market reform are appeared such as domestic petroleum fuels are still subsidizes and disparity of consumption between regions (Java and Sumatra vs. other inlands). The fact shows that any subsidy given by the government does not immediately give benefits to low-income communities. Instead, it raises irregularities in communities leading to the scarcity of kerosene in the fields. A campaign to improve public awareness and care should be launched so that they will appreciate the use of non-renewable energy and eventually they start opting to use energy alternatives. Certain key conditions need to be met to achieve reform in the petroleum product market are transport and storage facilities must be sufficient to cope with the demand, requirements for investors to enter the market must be simplified and prices need to reflect differences in regional transport costs and market size. Barriers to enter the market need to be
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abolished, in particular, unnecessary legal and administrative procedures. Open access needs to be introduced to monopolistic facilities (such as marine terminals, storage facilities, and pipelines) through nondiscriminatory tariffs and quality standards need to be set for products that take into account the market characteristics and maximize the number of supply sources. Proper fiscal terms and incentives are needed to promote private investment to participate in infrastructure development. In gas sector, Indonesian traditional gas market is still dominated by LNG export commodity. Unfortunately, the current global LNG market is greater choice of suppliers such as Australia, Malaysia, Qatar, and many others. The LNG business is growing and globalizing rapidly, driven by its increasing cost competitiveness and increasing gas demand. On the other hand, contribution of Indonesian natural gas domestic market is still limited. The utilization is mainly for power generation, fertilizer, and industry as well as flare. Despite of higher domestic gas demand, an old paradigm that natural gas development is aimed to increase the government revenue rather than to increase economic growth still persists. The development should lead to enhancing economic trickle down effects to maximize gas value chains. The domestic price of natural gas is still low so that there is reluctancy of gas producers to meet domestic lack of natural gas supply. This is also related to the prices of fertilizers and electricity which haven’t reached their economic values. In the future, government should adjust its policy in natural gas especially gas pricing policy, the development of reliable integrated gas network/logistic by considering gas balance in the future and, the development of new options of infrastructure through the application of emerging technologies such as LNG CNG, GTL, GTC, and GTW and complementary integration to traditional pipeline gas. This new market is aimed to provide support for national security of energy supply, to achieve more efficient energy consumption in more environmentally responsible manner, and to encourage the use of cleaner alternative fuels and high gas values added. The role of government to assure direction of gas market transformation is extremely essential. This can be done by establishing gas market and sector reforms through clear and transparent regulatory process, rational pricing framework, and introducing clear and innovative scheme providing special incentives such as fiscal and rational wellhead gas price to facilitate new investment for natural gas development. Finally, a good understanding of the enormous interests of the oil and gas industry and a well-defined and articulated political commitment are essential for structural reform. Prices usually need to be corrected, a new regulatory framework put in place, and certain key conditions met during a transition period to ensure that a truly competitive market is established. As a nation we should be responsible to improve national productivities for each calory of oil and gas used. It is unethic if we only used it to fullfil our current life style in energy comsumption or to pay our debt without concerning in its sustainability for future generation. The national energy policy needs to be more integrative by considering all type of energy resources and more sustainable energy approach.
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1.2 Coal Current Conditions Coal reserves in Indonesia are characterised by thick seams, often 5-15 meter thick across substantial areas and up to 70 meter thick in places. Most of the coal seams are close to the surface. Consequently, around 95% of Indonesia’s coal are at present produced from surface mining operation.
As indicated by the Directorate of Coal, Ministry of Energy and
Mineral Resources, Indonesia has significant coal resources of 38.8 billion million tons of identified coal deposits, of which 11.5 billion tons are classified as measured resources and 27.3 billion tons as indicated, inferred and hypothetical resources, with 5.4 billion tons classified as commercially exploitable reserves. Major coal resource areas are Kalimantan and Sumatra, estimated at 21.2 billion tons and 17.5 billion tons, respectively. The coal mined in Indonesia generally has heat values ranging between 5,000 and 7,000 kcal/ kg, with low ash and sulfur levels. The average sulfur content of commercially produced Indonesian coals is below 1.0 percent. The Indonesia’s coal producers include: (a) the state-owned mines operated by PTBA, (b) coal contractors, (c) coal mining authorization, and (d) coal operatives. From mine to port or barge loading facilities, coal is transported by conveyor belt, as most of the coal deposits are usually close to the coast or navigable waterway. The major existing coal loading infrastructures include approximately 640 km single railway track in Sumatera and 18 coal harbors in Sumatera and Kalimantan with a combined loading capacity of over 75 million tons per year. Most of the terminals are classified as small and medium capacity (5,000 - 6,000 DWT) while four terminals classified as large capacity (150,000 – 200,000 DWT) are located in East and South Kalimantan. Indonesia’s coal production increased sharply from 77 million tons in 2000 to 150 million tons in 2005. Indonesia’s domestic demand for coal is currently small relative to its production. Of the 2005 coal production figure, about 40 million tons was consumed domestically, mainly for power generation of about 25 million tons and the rest for cement production. The remaining 110 million tons which represented about 73% of total production was exported. The share of coal in Indonesia’s primary energy supply rose from 15 percent in 2000 to 18.5 percent in 2005, primarily due to the development of coalfired power plants. Coal is preferable as an energy source due to its relatively low price compared with oil and natural gas.
Projection INOSYD projections for coal sector for time horizon up to 2025 are as follows. In 2025, coal production will reach 346 million tons per year, of which a half would be consumed domestically. In 2025, the share of coal to total primary energy supply will reach about 30 % and up to 60 % for electricity generation. Electricity generation is expected to continuously dominate domestic coal consumption in 2025. The 2025’s figure for coal production (more than doubling the 2005’s figures) will only be possible to achieved by furthering exploration activities and
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massive investments in coal infrastructures and conducive mining policy. Without such investments in coal exploration, due to sharp increase in coal production, the reserves to production ratio for coal may fall below 50 years in 2025. According to INOSYD projection, new development of coal infrastructures including double tracking of Sumatra’s rail line and railways infrastructures in Kalimantan require accumulative investment amounts to about US$1,500 million.
Policy The dynamic situation of Indonesia’s mining including coal mining sector is occurring, reflected by the introduction of Autonomy laws passed in 1999, law No. 22 on political autonomy and its revision (law No. 32/2004), law No. 33/2004 on financial arrangement between government and local governments, PP 75/2001 on mining contract at regional level and PP No. 104/2001 on royalty arrangement in mining sector, law No. 41 of 1999 on forestry and its revision (Perpu No. 1 Tahun 2004). Currently new law on The economic crisis and the dynamic situation in mining sector has affected the coal sector as shown by the declined of coal investment (foreign and domestic) which was declined from $778 million in 1997 to $135 million in 2001. Between 2002 and 2003, according to the Energy Ministry, coal investment did rise, from $61 million to $90 million, primarily due to higher coal prices. Other aspects to be considered are as follows: (i) the overlapping of land usage for forestry and mining sectors as reflected by the introduction of Perpu No. 1 of 2004 to revise law No. 41 of 1999; (ii) there is no national stocks to secure energy and electricity supply; (iii) most of Indonesian coal is considered as lower rank coal which is preferable for domestic usage; (iv) the existing coal infrastructure limits further extensions of coal exploration and mining activities. Despite dynamic situations, it is expected that coal share in domestic electricity generation and cement production will follow an increased trend. Coal would provide a significant contribution in replacing Indonesia’s dependence on oil and natural gas, particularly, for power generation and industrial sectors. This will be a consequence of the changing pattern of energy production in Indonesia, and a government policy of diversifying domestic energy consumption away from oil in order to preserve Indonesian’s oil declining reserves. However, in securing a smooth transition to greater coal utilizations, Indonesia would require strategic policy, considerations and clear measures to meet the challenges. Some of crucial policies to be considered are as follows:
Securing domestic coal supply by coal national stock and integrated coal production planning at national level.
Increasing exploration activities to improve coal deposit status and coal infrastructure development.
Creating conducive climate for new investments (direct foreign and domestic) in coal mining activities, by introduction of comprehensive mining law, clear regulations and policies that promotes the clean and rational development of coal sector.
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Greater usage of locally available fuels for regional development such as by minemouth power-plant fueled by low rank coals.
Introduction of coal up-grading technology for greater use of low rank coals as well as to increase its economic values.
Promoting cleaner coal technology research and development activities as well as underground mine activities.
Promoting good coal mining and handling practices through out coal life cycles including post mining site reclamation.
activities.
1.3 Renewable Energy Current Conditions Indonesia is a vast archipelago located in the globe equator. Since Indonesia lies in the equator, the average daily radiation in most places is quite intense (approximately 4 kWh/m2) and therefore solar energy have abundant potential. Indonesia also has great potential of other renewable energy resources such as geothermal, hydropower, wind energy, and biomass. The total of potential of geothermal energy is 19,658 MW. Approximately 30 percent of the reserves (8,100 MW) are located in Java. The remaining is situated in Sumatera (4,885 MW), Sulawesi, and in other islands. Total installed capacity of geothermal power plant is 903 MW or 4.01 % of its potential. The total hydropower potential is estimated to be 75,000 MW, 34,000 MW of which is exploitable. About 60 percent of these resources are located in Kalimantan and Papua. The potential of microhydro energy is found in West Sumatra, Bengkulu, West Kalimantan and Central Sulawesi, while the large installed capacities of the micro hydro potential are found in North Sumatra, Bengkulu, Center of Java and West Java. The micro hydro (PLTM) potential in Indonesia is estimated as 459.91MW. The PLTM has benefited for power generation in the remote areas (20.85 MW or 4.54 % of the potential). Total installed capacity of solar energy in Indonesia, especially photovoltaic, is about 6.5 MW. This total capacity is used to supply electricity for water pumps, vaccine refrigerators, or lighting (solar home system). The solar home system installation is the most dominant application, which comprises about 5.5 MW. Solar home system is a lighting system using photovoltaic energy producing about 50 watt for each family and built in remote areas where electricity grids are not available. The wind speed in Indonesia is approximately between 2 to 6 m/s. This speed range is suitable for small (10 kW) to medium scale (10 kW to 100 kW) power generations used as energy sources for lighting, water pump, television, radio, and aeration in earthen dam, etc. The main wind energy potential areas are located in East and West Nusa Tenggara which have the
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average wind speeds of more than 5 m/s. The approximate wind power potential in Indonesia is about 9,286.61 MW and only 0.5 MW of which has been used for generating power. Biomass is biological power source, mainly originated from the waste of forest, agriculture, and plantation commodities. Based on the phases, biomass can be grouped into solid biomass, biogas, and liquid biomass. Solid biomass potential spreads across Indonesia as follows: Papua (6,8 GW), East Java (5.4 GW), Central Java (4 GW), West Java (3,7 GW), East Kalimantan (3,2 GW), Central Kalimantan (3 GW), South Sulawesi (92,5 GW), North Sumatra (2,4 GW), West Kalimantan (2,2 GW), South Sumatera (1,8 GW), Lampung (1,7 GW), Riau (1,6 GW), Aceh (1,3 GW), West Sumatra, Jambi, South Kalimantan, Central Sulawesi, NTT & Maluku (each 1 GW). Biogas energy potential from droppings of cows, buffaloes, and pigs can be found in all provinces with different quantities. Province of East Java has the most biogas energy potential of 125,9 MW and followed by Central Java (63 MW), NTT (56,7 MW), North Sumatra (46,8 MW), Aceh (42,7 MW), South Sulawesi (26,8 MW), West Java (40,1 MW), Bali (32 MW), NTB (28,2 MW), South Sumatra (26,8 MW), and West Sumatra. Provinces of Central Sulawesi, West Kalimantan, North Sulawesi, Lampung and Southeast Sulawesi have biogas energy potential between 10 MW until 19 MW each. In other provinces the potential of biogas energy is less than 10 MW. Peat potentials spread across Sumatra, Kalimantan, and Papua with thickness variability. Sumatera peat can reach deepest about 17 m. According to Directorate General of Electricity and Energy Development, Ministry of Energy and Mineral Resources, the potential of peat in Indonesia amounts to 97.93 X 1012 MJ. The huge potential is located in Riau (39.06 x1012 MJ), West Kalimantan (16.22 x 1012 MJ), & Central Kalimantan (12.23 x 1012 MJ). Other regions such as Aceh, North Sumatra, South Sumatra, South Kalimantan, East Kalimantan and East Sulawesi respectively have peat potentials of less than 7 x 1012 MJ.
Projection INOSYD projections for renewable energy sector up to 2025 are as follows. In 2025, total renewable consumption (including biomass) will reach 505 million BOE or almost double the 2004’s consumption figure (251.35 million BOE). By excluding biomass component in renewable energy consumption, the total demand of renewable energy was 9.29 million BOE in 2005 and projected to rise to 49.55 Million BOE in 2025. However, in terms of the proportion of renewable energy (including biomass) in Indonesia’s energy mix, its figure is projected to decline from 28.69% in 2004 to 21.63% in 2025. If we exclude the biomass component from the renewable energy consumption, the proportion of renewable energy in Indonesia’s energy mix is projected to be about 2.64% in 2025. Comparison between both projections above shows that biomass energy has predominating role in the utilization of renewable energy in Indonesia. In the projection using INOSYD, each sector (industrial, commercial, residential and transportation sectors) uses typical types of renewable energy as final energy. Transportation sector is projected to utilize biodiesel and biethanol in forthcoming years. Residential sector particularly in rural areas consume wood waste from harvesting activities and from forests for
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cooking. In industrial sector small- and medium-sized industries may use to some extent wood waste for their industry’s process. For generating electricity, it is projected that contribution of renewable energy predominantly comes from hydrothermal and geothermal energy. In comparison to other types of energy (petroleum fuels, coals and natural gas), in industrial sector, the contribution of renewable energy to final energy consumption from years 2004 to 2025 reduces from 4.83% to 1.94%, though its consumption quantity increases from 12.04 to 14.48 million BOE. In commercial sector, the contribution of renewable energy also reduces from 7.51% in 2004 to 2.70% in 2025 with its consumption quantity increasing from 1.60 million BOE in 2004 to 2.94 million BOE in 2025. In residential sector, the contribution slightly reduces from 72.52% in 2004 to 69.24% in 2025 with its consumption quantity increasing from 223.42 million BOE to 408.95 million BOE. A contrary situation occurs in transportation sector where the contribution of renewable energy slightly increases from none in 2004 to 8.84% in 2025 thanks to the introduction of biofuels in transportation. As a final energy for electricity generation, the contribution of renewable energy increases in terms of quantity from 14.29 million BOE in 2004 to 78.62 million BOE in 2025. In terms of proportion in energy mix for electricity generation, its contribution also increases from 8.91% in 2004 to 13.05% in 2025. As a primary energy, the contribution of renewable energy to the whole energy mix increases from 251.35 million BOE in 2004 to 504.99 million BOE in 2025 and its proportion in the whole energy mix 28.69% in 2004 to 21.62% in 2025.
Policy The future of Indonesia’s renewable energy usage in the next decade will depend on government policy on this energy sector. Some crucial policies for renewable energy sector to be considered are as follows:
Reform on regulation framework to boost the utilization of renewable energy in households, industry and electricity generation.
Increasing the use of small-scale electricity power generation using local renewable energy sources.
Creating clear policy on investment and funding schemes, such as (i) wider roles of private sector, BUMN, BUMD, and cooperatives in the development of renewable energy; (ii) incentive policy making; (iii) creative funding mechanism.
Policy in human resource developments through education and training, and knowledge and technology transfer.
Increasing infrastructure and supporting industries related to the development of renewable energy sector.
Accelerating adjustment of the price of fossil fuel energy towards its economic price.
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1.4 Electricity Current Condition In 2006 the average growth of electricity demand in Indonesia is about 7.5% per year. This growth figure doesn’t show a normal growth rate due to two main reasons. Firstly, the government subsidizes the electricity, and secondly, the growth number actually only shows the electric company’s capability to fill the electricity demands from the consumers. In fact, there are still huge numbers of waiting lists for the electricity. The average elasticity for electricity is around 1.5 showing that the major part of electricity usage in Indonesia is still not productive and efficient. This means an increase of 1 percent in economic growth requires 1.5 percent growth in electricity consumption. In 2005, Indonesia’s electrical generating capacity (PLN only) is 22,515 MW with more than 30 million consumers. In Java alone, the installed capacity in year 2005 was 16,355 MW with peak load of 14,824 MW. The peak load for Indonesia is considered to be about 19,263 MW. This peak load figure is not the real peak load since it was determined from the total of region’s peak load. The real peak load should come from an interconnected system. Therefore, the planning for Indonesia’s peak load is supposed to be made per regions which are interconnected, not based on the number of Indonesian peak burden. The electricity sold by PLN in Indonesia is 107,032 GWh, where Java consumes 83,3% of total electricity sold. In 2005, electrification ratio was still low at 54 percent for Indonesia, 57 percent for Java and 48 percent for outside Java.
Projection In the period of 2025, electricity demand is reaching 440.5 GWh corresponds to 270 million BOE, with 83% fueled by coal and natural gas. Contribution of renewable energy is only 13.1%. The highest electricity consumptions are projected to be industrial sector of 55% and household sector of 29.2 %. In comparison to current total installed capacity of power generation, in the year 2025, around 70,000 MW new power plants are needed to support the economic and social growth. The cost for adding the power plant infrastructure to 2025 is projected to be about US$ 55,000 Million.
Policy Main problems of Indonesian electricity sector are electricity shortages in some regions; high oil price resulting in huge government subsidy; limited spare capacity of electricity infrastructures, i.e. the power generation and transmission network capacities. One factor that may cause lack of new investment in this sector is the fact that electricity tariff applied is yet from its economic price that may be due to considered to attracted new investments in this sector. In general, due to unreliability in electricity transmission and distribution, some potential customers provide their own self-generation plants.
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16,000
Household Commercial Industry TOTAL
Electricity consumption (MW)
14,000 12,000 10,000 8,000 6,000 4,000 2,000 0
6
8
10
12
14
16
18
20
22
24
2
4
6
Time Figure 1.36 Typical daily load curve of Java – Madura – Bali system [PLN, 2006] According to the daily load curve of electricity demand (Figure 1.36), the peak load occurs in the evening and mainly contributed by household sector. During the peak load time, PLN adds the electricity supply by operating oil based electricity generation plants, such as gas turbine, diesel engine, etc. In 2005, Indonesia managed to reduce subsidies for oil products. Indonesia began to set up mechanisms to formulate industrial oil product prices and high grade oil product prices for transportation reflecting price changes in the world oil market. However, since oil based power plants are still widely used to supply electricity demand during peak hours, the sharp increase in oil prices since 2005 has forced the government to provide huge subsidy to electricity sector. In 2005, about IDR 12.5 trillion (US$ 1.38 billion) of government expenditure went to electricity subsidies. The electricity policies to be considered in the near future are :
For well-established areas the provision of electricity can be undertaken efficiently through competition and transparency in a healthy business climate with regulations that provide the same treatment to all business players and provide benefits fairly and evenly to consumers.
Priorities for new investments and developments of more efficient and environmentally friendly power generation plants and electricity transmission.
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The greatest utilization of domestically produced goods and services that are competitive and yield added value so as to result in the development of the national electricity industry;
Initiave to tackle the existing electricity crisis in several regions.
Based on partnership program in energy audit for buiding and industrial sectors, energy saving up to 25 percent is possible. Thus, effective energy conservation measures for building and industries are recommended as part of demand side management.
Easy access to the grid with contracts for transmission must not present a barrier.
Removal of regulatory barriers to competition in generation and distribution.
Rationalization of electricity sale price
Reducing the dependency to oil fuels and increasing the role of natural gas, coal and renewable energy sources for power generation.
53
54
SELECTED ECONOMIC INDICATORS II. SELECTED ECONOMIC INDICATORS OF INDONESIA
PENGKAJIAN ENERGI UNIVERSITAS INDONESI
55
56
Table 2.1
Population, GDP, Energy Consumption, Energy Intensity, and Energy Consumption per Capita, 1990 – 2005
Population Year
Energy Consumption
GDP
Million
Growth (%)
1
2
Billion Rp.
Growth (%)
3
4
Energy Intensity
Million BOE
Growth (%)
5
6
1990
179.25
875,025
1991
181.76
1.40
936,400
7.01
428
1992
184.28
1.38
999,721
6.76
454
1993
186.79
1.37
1,151,729
15.21
1994
189.31
1.35
1,238,570
1995
191.83
1.33
1,340,380
1996
194.34
1.31
1997
199.84
1998
Million TOE/ Million Rupiah GDP (7) = (5)/(3)
411
Energy Consumption per Capita Million TOE/ Million People (8) = (5)/(1)
0.0635
0.3102
3.90
0.0618
0.3183
5.65
0.0613
0.3327
478
5.06
0.0561
0.3458
7.54
498
4.07
0.0544
0.3556
8.22
526
5.24
0.0530
0.3704
1,445,173
7.82
547
3.84
0.0511
0.3802
2.83
1,513,095
4.70
575
4.98
0.0514
0.3891
202.87
1.52
1,314,475
-13.13
573
-0.38
0.0589
0.3818
1999
203.05
0.09
1,324,874
0.79
621
7.74
0.0634
0.4134
2000
205.84
1.38
1,389,770
4.90
664
6.45
0.0646
0.4359
2001
208.65
1.36
1,442,985
3.83
693
4.14
0.0649
0.4486
2002
212.00
1.61
1,505,216
4.50
707
1.99
0.0635
0.4505
2003
215.28
1.54
1,577,171
4.78
715
1.16
0.0613
0.4488
2004
216.38
1.30
1,656,826
5.05
787
9.19
0.0642
0.4917
2005
219.21
1.30
1,749,547
5.60
Source: Statistical Year Book of Indonesia, 2000-2005, Indonesian Bureau of Statistics (Processed)
Table 2.2
Average Rates of Foreign Currencies and Gold in Market, 1997-2005 Rupiah
1997
1998
1999
2000
2001
2002
2003
2004*
2005
4,650 7,709 3,040 1,198 2,422 600 28,457
8,025 13,336 4,923 2,112 7,497 1,036 84,511
7,100 11,495 4,622 1,868 6,901 914 8,288 66,208
9,595 14,299 5,318 2,525 7,874 1,230 7,820 71,875
10,400 15,080 5,309 2,736 8,408 1,333 9,141 80,000
8,940 14,334 5,065 2,353 7,441 1,146 8,783 85,000
8,465 15,076 6,347 2,258 7,449 1,090 9,602 100,000
9,290 17,888 7,242 2,445 1,195 97,500
9,900 17,358 7,335 2,650 1,303 n.a
US Dollar English Pound Australian Dollar Malaysia Ringgit Jepang Yen Hong Kong Dollar Uni Europe Euro Gold * Data at October 2004 except gold
Sources: Statistical Year Book of Indonesia, 2000-2005, Indonesian Bureau of Statistics Bank Indonesia, www.bi.go.id
57
Table 2.3
Description of Indonesia Macroeconomics, 1997 – 2005 Unit
Description Population
million
Unemployment Growth of real GDP Growth of real GDP (non oil-gas) GDP Inflation rate Nominal exchange rate Export Export of non oilgas commodities Import Import of non oilgas commodities Government Budget
% % % billion Rp. % Rp/US$ Million US$ Million US$ Million US$ Million US$
1999
2000
2001
2002
2003
2004*
2005
203.047
205.843
208.647
212.003
215.276
217.840
219.205
6.4
6.1
8.1
9.2
9.5
9.9
0.79
4.90
3.83
4.38
4.88
5.13
n.a
1.09
5.31
5.11
5.09
5.80
6.17
n.a
1,324,874
1,389,770
1,442,985
1,506,124
1,579,559
1,660,579
2.01
9.35
12.55
10.03
6.79
6.06
7,100.00
9,595.00
10,400.00
8,940.00
8,465.00
9,290.00
9,900.00
48,665.40
62,124.00
56,320.90
57,158.80
61,058.20
71,584.60
85,660.00
38,873.20
47,757.40
43,684.60
45,046.10
47,406.80
55,939.30
66,428.40
240,033.00
33,514.80
30,962.10
31,288.90
32,550.70
46,524.50
57,700.90
20,322.20
27,495.30
25,490.30
24,763.10
24,939.80
34,792.50
40,243.20
1,749,547
- Revenues
billion Rp.
219,604
152,900
263,200
301,900
336.200
349.900
380,400
- Expenditure
billion Rp.
219,604
197,000
315,700
344,000
370.600
374.300
397,800
- Surplus/Deficit Realization of Government Budget
billion Rp.
0
-44,100
-52,500
-42,100
-34.400
-24.400
-17,400
- Revenues
billion Rp.
245,325
205,000
301,100
300,200
342.800
407.800
495,400
- Expenditure
billion Rp.
245,192
221,000
341,600
327,900
377.200
435.700
509,400
- Surplus/Deficit Difference of Budgeted and Realization
billion Rp.
133
-16,000
-40,500
-27,700
-34.400
-27.900
14,000
- Revenues
billion Rp.
-25,721
-52,100
-37,900
1,700
-6.600
-57.900
-115,000
- Expenditure
billion Rp.
-25,588
-24,000
-25,900
16,100
-6.600
-61.400
-111,600
7.99
6.901
7.822
8.107
2.337
Current Account
Million US$
5,782
Service Net
Million US$
-14,859
-17.051
-15,795
-15.69
-16.456
-13.604
Capital Transaction
Million US$
-4,569
-7.896
-7.617
-1.103
-950
584
Foreign Assets Domestic investment
Million US$
27,054
29,394
28,016
32.039
36.296
34.802
53,550.0
17,496.5
58,816.0
25,307.6
48,484.8
37,140.4
Foreign investment
million US$
10,890.5
6,087.0
15,055.9
9,789.1
13,207.2
10,279.8
billion Rp.
Inflation rate
%
2.01
9.35
12.55
10.03
6.79
6.06
175,508
190,317
204,067
224.759
247.143
Demand Deposits
billion Rp.
115,566
Time Deposits
billion Rp.
387,071
390,543
446,198
447,480
433.127
421.288
billion Rp.
122,981
154,328
172,611
193,468
244.44
296.647
Saving Deposits
* Data at October 2004 Sources: Statistical Year Book of Indonesia, 2004, Indonesian Bureau of Statistics Bank Indonesia, www.bi.go.id
58
Table 2.4
Gross Domestic Product based on Current Market Prices by Industry Origin, 1999-2005
1999
2000
2001
2002
2003
2004
2005
215,686.7
217,897.9
263,327.9
298,876.8
35,653.7
354,435.3
365,559.6
109,925.3
175,262.5
182,007.8
161,023.8
169,535.6
196,892.4
285,086.6
72,424.9
129,220.9
115,335.1
93,092.0
94,780.4
120,640.5
168,132.4
27,696.1
34,495.7
52,560.3
51,277.5
55,659.7
54,533.9
90,392.2
9,804.3
11,545.9
14,112.4
16,654.3
19,095.5
21,718.0
26,562.0
285,873.9
314,918.4
506,319.6
553,746.6
590,051.3
652,729.5
765,966.7
35,127.6
54,279.9
63,344.6
69,660.0
78,641.0
86,981.9
133,984.0
250,746.3
260,638.5
442,975.0
484,086.6
511,410.3
565,747.6
631,982.7
Electricity, Gas, & Water Supply
13,429.1
16,519.3
10,854.8
15,392.0
19,540.9
22,855.4
24,993.2
a. Electricity
11,201.4
13,797.1
7,640.8
10,822.5
13,985.7
15,556.8
17,097.4
353.2
462.1
1,614.8
2,022.3
2,317.5
3,089.3
3,749.8
Agriculture, Livestock, Forestry, & Fishery Mining & Quarrying a. Crude Petroleum & Natural Gas b. Non Oil & Gas Mining c. Quarrying Manufacturing Industry a. Oil & Gas Manufacturing b. Non Oil & Gas Manufacturing
b. City Gas c. Water Supply Construction Trade, Hotel, and Restaurant Transport & Communication Financial, Ownership, Business Services Services Gross Domestic Product
1,874.5
2,260.1
1,599.2
2,547.2
3,237.7
4,209.3
4,146.0
67,616.2
76,573.4
89,298.9
101,573.5
112,571.3
134,388.1
173,440.6
175,835.4
199,110.4
267,656.1
314,646.7
337,840.5
372,340.0
426,994.0
55,189.6
62,305.6
77,187.6
97,970.3
118,267.3
140,604.2
180,968.7
71,220.2
80,459.9
135,369.8
154,442.2
174,323.6
194,542.2
228,107.9
104,955.3
121,871.4
152,258.0
165,602.8
198,069.3
234,244.4
275,640.9
1,099,731.7
1,264,918.8
1,684,280.5
1,863,274.7
2,045,853.5
2,303,031.5
2,729,708.2
Source: Statistical Year Book of Indonesia, 2000-2005, Indonesian Bureau of Statistics
59
Table 2.5
Gross Domestic Product based on Constant 2000 Market Prices by Industry Origin, 2002-2005 (Billion Rupiah)
2002
2003
2004
2005
Agriculture, Livestock, Forestry, & Fishery
231,613.5
240,387.3
248,222.8
254,391.3
Mining & Quarrying
169,932.0
167,603.8
160,100.4
162,642.0
108,130.6
103,087.2
98,636.3
96,473.4
b. Non Oil & Gas Mining
49,066.5
51,007.3
46,947.1
50,588.6
c. Quarrying
12,734.9
13,509.3
14,517.0
15,580.0
419,387.8
441,754.9
469,952.4
491,699.5
52,179.5
52,609.3
51,583.9
48,849.4
b. Non Oil & Gas Manufacturing
367,208.3
389,145.6
418,368.5
442,850.1
Electricity, Gas, & Water Supply
9,868.2
10,349.2
10,889.8
11,596.6
a. Electricity
6,769.1
7,104.1
7,468.5
7,988.3
b. City Gas
1,358.4
1,498.6
1,639.5
1,745.8
c. Water Supply
1,740.7
1,746.5
1,781.8
1,862.5
84,469.8
89,621.8
96,333.6
103,403.8
Trade, Hotel, and Restaurant
243,266.6
256,516.6
271,104.9
294,396.3
Transport & Communication
76,173.1
85,458.4
96,896.7
109,467.1
Financial, Ownership, Business Services
131,523.0
140,374.4
151,187.8
161,959.6
Services
138,982.4
145,104.9
152,137.3
159,990.7
1,505,216.4
1,577,171.3
1,656,825.7
1,749,546.9
a. Crude Petroleum
& Natural Gas
Manufacturing Industry a. Oil & Gas Manufacturing
Construction
Gross Domestic Product
Source: Statistical Year Book of Indonesia, 2005, Indonesian Bureau of Statistics
60
Table 2.6
Figures of Indonesian Oil & Gas Export and Import, 1990-2005 (million US$)
Year
Export
Import
1990
11,071.1
1,956.4
1991
10,894.9
2,310.3
1992
10,670.9
2,115.0
1993
9,745.8
2,170.4
1994
9,693.6
2,367.4
1995
10,464.4
2,910.8
1996
11,721.80
3,595.5
1997
11,622.5
3,924.1
1998
7,872.1
2,653.7
1999
9,792.2
3,681.1
2000
14,366.6
6,019.5
2001
12,636.3
5,471.8
2002
12,112.7
6,525.8
2003
13,651.4
7,610.9
2004
15,645.3
11,732.0
2005
19,231.6
17,457.7
Source: Statistical Year Book of Indonesia, 2004, Indonesian Bureau of Statistics
Table 2.7
Investment in Oil and Gas, 1997-2004 (Million US$)
Exploration
Development
Production
Administration
Total
1997
1,048
792
2,435
497
4,772
1998
1,080
988
2,303
47
4,418
1999
520
790
2,250
488
4,048
2000
428
583
2,442
478
3,931
2001
425
733
2,615
429
4,202
2002
574
983
3,374
507
5,438
2003
244
1,165
3,458
438
5,305
2004
779
2,097
3,931
685
7,492
Source: Petrominer, No. 09/Sept 15, 2005
61
Table 2.8a Ratio of Electrification and Electricity Consumption per Capita, 2003 PLN Unit/Province Region of Naggroe Aceh. D Region of North Sumatera Region of West Sumatera Region of Riau Region of South Sumatera, Jambi & Bengkulu North Sumatera - South Sumatera - Jambi - Bengkulu Region of Bangka Belitung Regionof Lampung Region of West Kalimantan Region of South & Central Kalimantan - South Kalimantan - Central Kalimantan Region of East Kalimantan Region North, Central Sulawesi & Gorontalo - North Sulawesi - Gorontalo - Central Sulawesi Region of South & Southeast Sulawesi - South Sulawesi - South East Sulawesi Region of Maluku - Maluku - North Maluku Region of Papua Distribution of Bali Region of West Nusa Tenggara Region of East Nusa Tenggara PT PLN Batam Total Non Java Distribution East Java Distribution Central Java - Central Java - Yogyakarta Distribution West Java - West Java - Banten Distribution Jaya & Tangerang Total Java Total Indonesia
Population (x 1000)
Number of Households (x 1000)
Number of Electrified Households
Electrification Ratio (%)
kWh Sold per Capita
4,097.3
1,003.6
569,988.0
56.8
141.0
12,093.0
2,819.8
1,868,503.0
66.3
343.2
4,322.1
1,071.0
648,652.0
60.6
322.9
5,153.7
1,292.4
450,018.0
34.8
235.0
11,636.6
2,693.4
1,002,852.0
37.2
163.7
7,393.8
1,642.0
633,391.0
38.6
173.4
2,538.4
652.0
201,080.0
30.8
166.3
1,704.5
399.4
168,381.0
42.2
118.0
925.0
231.4
127,377.0
55.1
235.7
6,969.5
1,770.8
642,552.0
36.3
159.3
4,291.4
1,000.2
418,115.0
41.8
173.7
5,134.5
1,407.6
679,752.0
48.3
238.3
3,110.9
853.4
497,687.0
58.3
296.3
2,023.6
554.2
182,065.0
32.9
149.2
2,660.9
699.6
351,926.0
50.3
390.3
5,295.0
1,402.3
617,426.0
44.0
159.5
2,078.4
598.9
316,203.0
52.8
236.6
872.6
239.1
83,623.0
35.0
110.6
2,344.1
564.3
217,600.0
38.6
109.3
10,396.6
2,434.7
1,254,546.0
51.5
192.1
8,402.1
1,966.1
1,093,423.0
55.6
214.2
1,994.5
468.7
161,123.0
34.4
98.9
1,908.1
407.5
189,159.0
46.4
111.4
1,166.1
249.5
126,306.0
50.6
123.6
742.0
158.0
62,853.0
39.8
92.3
2,430.6
644.7
161,914.0
25.1
150.3
3,270.9
872.8
569,807.0
65.3
510.6
4,224.5
1,131.9
311,073.0
27.5
91.1
4,007.5
855.5
188,372.0
22.0
53.5
459.9
141.4
94,721.0
67.0
1,426.7
89,277.0
21,880.7
10,146,753.0
46.4
223.1
35,452.0
10,064.3
5,697,684.0
56.6
405.1
35,250.8
9,406.6
5,317,719.0
56.5
281.1
32,066.7
8,414.4
4,723,057.0
56.1
273.7
3,184.2
992.1
594,662.0
59.9
355.1
43,871.0
12,484.7
6,138,618.0
49.2
560.5
37,890.1
10,544.5
5,628,781.0
53.4
527.0
5,980.9
1,940.2
509,837.0
26.3
773.0
11,301.6
2,726.4
2,696,780.0
98.9
1,916.7
125,875.4
34,682.0
19,850,801.0
57.2
560.2
215,152.4
56,562.7
2,997,554.0
53.0
420.4
Source: PLN Statistics 2003, PT PLN (Persero)
62
Table 2.8b Ratio of Electrification and Electricity Consumption per Capita, 2004
PLN Unit/Province Region of Naggroe Aceh. D
Population (x 1000)
Number of Households (x 1000)
Number of Electrified Households
Electrification Ratio (%)
kWh Sold per Capita
4,089.1
1,024.5
602,401
58.80
171.55
Region of North Sumatera
12,123.4
2,861.4
1,929,419
67.43
366.23
Region of West Sumatera
4,535.5
1,079.1
676,977
62.74
323.44
Region of Riau
5,157.4
1,363.7
473,671
34.73
274.34
Region of South Sumatera, Jambi & Bengkulu North Sumatera
10,802.9
2,756.1
1,069,134
38.79
197.41
- South Sumatera
6,628.4
1,678.4
666,454
39.71
215.9
- Jambi
2,625.3
667.0
226,233
33.92
180.59
- Bengkulu
1,549.1
410.6
176,447
42.97
146.84
Region of Bangka Belitung
1,023.8
234.9
127,746
54.39
228.78
Regionof Lampung
7,063.8
1,806.5
638,284
35.33
171.19
Region of West Kalimantan
4,033.2
1,027.8
437,973
42.61
197.57
Region of South & Central Kalimantan 5,097.5
1,444.1
706,915
48.95
243.53
- South Kalimantan
3,226.9
868.5
515,549
59.36
284.49
- Central Kalimantan
1,870.6
575.6
191,366
33.25
172.87
Region of East Kalimantan
2,612.0
691.0
378,435
54.77
470.31
Region North, Central Sulawesi & Gorontalo
5,308.5
1,440.3
648,132
45.00
179.39
- North Sulawesi
2,158.6
611.7
327,095
53.48
256.32
897.3
246.0
88,317
35.90
118.13
2,252.6
582.6
232,720
39.94
130.07 209.37
- Gorontalo - Central Sulawesi Region of South & Southeast Sulawesi
10,291.8
2,488.8
1,269,812
51.02
- South Sulawesi
8,369.1
2,001.7
1,105,720
55.24
230.97
- South East Sulawesi
1,922.7
487.1
164,092
33.69
115.36
Region of Maluku
2,116.7
412.4
208,693
50.61
127.45
- Maluku
1,243.9
252.9
136,126
53.83
141.78
872.8
159.5
72,567
45.50
107.03
Region of Papua
2,516.3
674.5
168,993
25.05
158.23
Distribution of Bali
3,397.3
886.0
587,705
66.33
558.03
Region of West Nusa Tenggara
4,083.7
1,237.6
313,246
25.31
101.72
Region of East Nusa Tenggara
4,155.9
872.3
192,983
22.12
55.19
554.3
138.2
109,112
78.93
1,341.98
78.08
- North Maluku
PT PLN Batam PT PLN Tarakan
153.6
30.3
23,662
Total Non Java
89,116.7
22,469.5
10,563,293
Distribution East Java
36,481.8
10,144.4
5,831,893
57.49
450.11
Distribution Central Java
35,766.3
9,497.6
5,552,216
58.46
303.17
- Central Java
32,542.8
8,497.6
4,928,259
58.00
294.96
- Yogyakarta
3,223.5
1,000.6
623,957
62.36
386.04
Distribution West Java
46,239.7
13,364.1
6,360,947
47.60
590.04
- West Java
38,610.9
11,324.1
5,821,886
51.41
563.87
7,628.9
2,040.0
539,061
26.42
724.70
10,249.7
2,775.0
2,787,621
100.45
2,292.99
Total Java
128,737.5
35,781.1
20,532,677
57.38
606.4
Total Indonesia
217,854.2
58,250.6
31,095,970
53.38
459.47
- Banten Distribution Jaya & Tangerang
685.82 247.21
Source: PLN Statistics 2004, PT PLN (Persero)
63
Table 2.8c Ratio of Electrification and Electricity Consumption per Capita, 2005 Population (x 1000)
PLN Unit/Province Region of Naggroe Aceh. D
Number of Households (x 1000)
Number of Electrified Households
Electrification Ratio (%)
kWh Sold per Capita
4,037.9
1,051.2
606,222
57.67
173.09
Region of North Sumatera
12,326.7
2,923.6
2,002,956
68.51
374.26
Region of West Sumatera
4,595.2
1,093.4
695,167
63.58
343.91
Region of Riau
5,887.7
1,241.8
497,537
40.07
264.2
Region of South Sumatera, Bengkulu
Jambi & 11,011.4
2,836.4
1,119,564
39.47
217.73
- South Sumatera
6,755.9
1,725.9
696,620
40.36
240.02
- Jambi
2,657.3
686.1
239,670
34.93
196.87
- Bengkulu
1,598.2
424.4
183,274
43.18
158.14
Region of Bangka Belitung
1,061.0
240.0
127,869
53.28
253.23
Regionof Lampung
7,166.5
1,851.8
696,809
37.63
186.78
Region of West Kalimantan
4,098.5
1,061.5
455,255
42.89
186.78
Region of South & Central Kalimantan
5,144.2
1,490.8
738,413
49.53
205.43
- South Kalimantan
3,240.1
889.5
538,746
60.56
259.27
- Central Kalimantan
1,904.1
601.2
199,667
33.21
303.52
Region of East Kalimantan
2,810.9
749.6
396,049
52.83
183.96
Region North, Central Sulawesi & Gorontalo
5,376.6
1,487.4
679,041
45.65
464.99
- North Sulawesi
2,181.9
628.8
338,586
53.85
189.69
909.7
254.4
93,413
36.71
267.93
2,285.0
604.2
247,042
40.89
128.26
- Gorontalo - Central Sulawesi Region of South & Southeast Sulawesi
10,452.4
2,317.2
1,288,909
55.62
139.44
- South Sulawesi
8,493.7
1,808.6
1,119,963
61.93
219.42
- South East Sulawesi
1,958.7
508.6
168,946
33.22
120.5
Region of Maluku
2,145.0
417.5
228,845
54.81
145.17
- Maluku
1,259.4
255.5
147,937
57.89
164.16
885.6
162.0
80,908
49.95
118.16
Region of Papua
2,518.4
708.9
173,022
24.41
170.56
Distribution of Bali
3,432.1
906.9
607,287
66.97
610.33
Region of West Nusa Tenggara
4,143.5
1,303.1
317,952
24.40
109.07
Region of East Nusa Tenggara
4,218.8
893.2
199,390
22.32
61.28
616.4
142.6
123,692
86.76
1,336.39
- North Maluku
PT PLN Batam PT PLN Tarakan
157.7
31.2
25,529
81.72
749.61
Total Non Java
91,200.5
22,748.1
10,979,508
48.27
260.27
Distribution East Java
36,695.1
10,296.3
5,956,586
57.85
483.21
Distribution Central Java & Yogyakarta
36,194.8
9,658.0
5,724,255
59.27
327.49
- Central Java
32,914.6
8,639.8
5,080,088
58.80
319.65
- Yogyakarta
3,280.2
1,018.2
644,167
63.26
406.13
Distribution West Java & Banten
48,375.7
14,357.6
6,636,034
46.22
597.16
- West Java
598.17
39,066.7
11,853.7
6,060,583
51.13
- Banten
9,309.0
2,503.9
575,451
22.98
592.92
Distribution Jaya & Tangerang
8,860.8
2,454.6
2,878,539
117.27
2,801.42
Total Java
130,126.4
36,766.5
21,195,414
57.65
640.11
Total Indonesia
221,326.9
59,514.6
32,174,922
54.06
483.59
Source: PLN Statistics 2005, PT PLN (Persero)
64
ENERGY PRICES
III. ENERGY PRICES IN INDONESIA
PENGKAJIAN ENERGI UNIVERSITAS INDONESIA
65
66
Table 3.1
Average of Indonesian Crude Oil Prices, 1998-2005 (US$/Barrel)
Year
Months 1998
1999
2000
2001
2002
2003
2004
2005
January
14.51
11.04
24.40
24.41
18.57
31,35
30.97
42.39
February
13.46
10.56
26.08
25.83
18.80
32,04
30.96
44.74
March
12.14
12.07
27.04
25.37
22.39
30,36
33.16
53.00
April
13.20
15.12
24.04
26.83
24.88
27,41
32.89
54.88
May
12.92
15.94
27.65
27.85
25.01
26,51
37.53
48.72
June
12.09
15.95
29.87
27.25
23.87
26,15
36.12
52.92
July
12.51
12.51
29.71
24.72
24.88
26,92
37.10
55.42
August
12.07
12.07
30.08
24.36
25.60
28,46
42.61
61.09
September
12.09
12.09
32.99
24.55
26.85
26,88
44.31
61.36
October
12.93
12.93
32.09
19.59
27.40
29,21
49.21
58.11
November
11.85
11.85
31.14
18.17
26.42
29,48
40.63
53.96
December
9.99
9.99
25.58
17.68
30.22
30,50
35.51
54.64
Sources : Indonesia Oil and Gas Statistics 1996-2004, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources Ministry of Energy and Mineral Resources, www.esdm.go.id
Table 3.2
Average of Selected Crude Oil Prices, 1999-2005 (US$/Barrel)
ICP
1999
2000
2001
2002
2003
2004
17.52
28.47
23.88
24.58
28.77
37
2005 53.43a)
Basket OPEC
17.34
27.55
23.24
24.32
28.02
36.05
Arabian Light
17.43
26.76
23.18
24.30
27.52
34
50.64
Minas
17.69
28.70
24.40
25.51
29.57
36
WTI
19.27
30.36
26.02
26.11
30.90
41.44
56.51
Brent
17.88
28.38
24.59
24.98
28.70
38.23
54.44
Dubai
17.22
26.20
22.02
23.82
26.90
33.66
49.36
48.27b)
a) Estimated b) Estimated from www.eia.doe.gov
Sources: Oil & Gas Statistics of Indonesia, 1999-2005 Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources Ministry of Energy and Mineral Resources, www.esdm.go.id Energy Information and Administration. www.eia.doe.gov
67
Table 3.3a Indonesian Crude Oil Prices by Type, 2003 (US$/Barrel) No
Months
Crude Oil Jan
Feb
Mar
Apr
May
Jun
Jul
Aug
Sep
Oct
Nov
Dec
1
SLC
31,94
31,41
30,16
28,89
27,83
26,82
27,06
28,03
26,44
29,16
29,64
31,10
2
Arjuna
30,99
32,69
30,63
26,25
25,43
25,78
27,26
29,33
27,77
29,58
29,75
30,20
3
Attaka
31,71
33,47
31,31
26,96
26,11
26,22
27,70
29,86
28,34
30,44
30,18
30,59
4
Cinta
30,69
30,85
29,25
27,51
26,59
25,94
26,23
27,13
25,82
28,20
28,46
29,75
5
Duri
29,91
30,49
28,78
26,06
25,73
25,26
25,58
26,51
24,65
26,66
27,18
28,51
6
Widuri
30,78
30,96
29,28
27,53
26,62
25,93
26,27
27,11
25,80
28,16
28,38
29,75
7
Belida
31,43
33,15
31,19
26,93
25,92
25,68
27,35
29,54
28,23
30,46
30,10
30,35
8
Senipah Cond.
31,40
33,26
31,30
26,80
25,86
25,96
27,26
29,43
28,12
30,14
30,03
30,53
9
Anoa
32,11
33,87
31,71
27,36
26,51
26,62
27,10
30,26
28,74
30,84
30,58
30,99
10
Arun condensate
31,40
33,26
31,30
26,80
25,86
25,96
27,26
29,43
28,12
30,14
30,03
30,53
11
Arimbi
29,84
31,54
29,48
25,10
24,28
24,63
26,11
29,18
26,62
28,43
28,60
29,05
12
Badak
31,71
33,47
31,31
26,96
26,11
26,22
27,70
29,86
28,34
30,44
30,18
30,59
13
Bekapai
31,71
33,47
31,31
26,96
26,11
26,22
27,70
29,86
28,34
30,44
30,18
30,59
14
Bentayan
29,98
29,45
28,20
26,93
25,87
24,86
25,10
26,07
24,48
27,20
27,68
29,14
15
Bontang R.Cond.
31,64
36,69
34,25
23,42
23,27
26,10
27,25
29,22
27,49
30,00
32,00
34,06
16
Bula
29,41
29,99
28,28
25,56
25,23
24,76
25,08
26,01
24,15
26,16
26,68
28,01
17
Bunyu
31,94
31,41
30,16
28,89
27,83
26,82
27,06
28,03
26,44
29,16
29,64
31,10
18
Camar
31,37
33,07
31,01
26,63
25,81
26,16
27,64
29,71
28,15
29,96
30,13
30,58
19
Geragai
32,13
31,60
30,35
29,08
28,02
27,01
27,25
28,22
26,63
29,35
29,83
31,29
20
HandilMix
31,14
32,84
30,78
26,40
25,58
25,93
27,41
29,48
27,92
29,73
29,90
30,35
21
Jambi
32,13
31,60
30,35
29,08
28,02
27,01
27,25
28,22
26,63
29,35
29,83
31,29
22
Jatibarang/Cemara/ Cepu
30,93
30,40
29,15
27,88
26,82
25,81
26,05
27,02
25,43
28,15
28,63
30,09
23
Kaji
32,34
31,81
30,56
29,29
28,23
27,22
27,46
28,43
26,84
29,56
30,04
31,50
24
Kerapu
31,09
32,81
30,85
26,59
25,58
25,34
27,01
29,20
27,89
30,12
29,76
30,01
25
Klamono
29,41
29,99
28,28
25,56
25,23
24,76
25,08
26,01
24,15
26,16
26,68
28,01
26
Komp.P.SIt/ Tap/ Jene Serdang
31,94
31,41
30,16
28,89
27,83
26,82
27,06
28,03
26,44
29,16
29,64
31,10
27
Lalang
31,99
31.46
30,21
28,94
27,88
26,87
27,11
28,08
26,49
29,21
29,69
31,15
28
Langsa
31,31
33.07
30,91
26,56
25,71
25,82
27,30
29,46
27,94
30,04
29,78
30,19
29
Link
31,83
31,30
30,05
28,78
27,72
26,71
26,95
27,92
26,33
29,05
29,53
30,99
30
Madura
31,12
32,82
30,76
26,38
25,56
25,91
27,39
29,46
27,90
29,71
29,88
30,33
31
Mudi
30,69
32,39
30,33
25,95
25,13
25,48
26,96
29,03
27,47
29,28
29,45
29,90
32
NSC/Katapa/Arbei
31,60
33,36
31,20
26,85
26,00
26,11
27,59
29,75
28,23
30,33
30,07
30,48
33
Pagerungan Kond.
30,65
32,51
30,55
26,05
25,11
25,21
26,51
28,68
27,37
29,39
29,28
29,78
34
Pam. Sanga-Sanga Mix
32,04
31,51
30,26
28,99
27,93
26,92
27,16
28,13
26,54
29,26
29,74
31,20
35
Ramba/Tempino
32,13
31,60
30,35
29,08
28,02
27,01
27,25
28,22
26,63
29,35
29,83
31,29
36
Rimau
31,84
31,31
30,06
28,79
27,73
26,72
26,96
27,93
26,34
29,06
29,54
31,00
37
Sangatta
31,94
31,41
30,16
28,89
27,83
26,82
27,06
28,03
26,44
29,16
29,54
31,10
38
Selat Panjang
31,84
31,41
30,16
28,89
27,83
26,82
27,06
28,03
26,44
29,16
29,64
31,10
39
Sembilang
31,74
31,21
29,96
28,69
27,63
26,62
26,86
27,83
26,24
28,96
29,44
30,90
40
Sep. Yak. Mix.
30,99
32,69
30,63
26,25
25,43
25,78
27,26
29,33
27,77
29,58
29,75
30,20
41
Tanjung
32,13
31,60
30,35
29,08
28,02
27,01
27,25
28,22
26,63
29,35
29,83
31,29
42
Walio Mix
31,74
31,21
29,96
28,69
27,63
26,62
26,86
27,83
26,24
28,96
29,44
30,90
Average
31,35
32,04
30,36
27,41
26,51
26,15
26,92
28,46
26,88
29,21
29,48
30,50
Source : Indonesia Oil and Gas Statistics, 2003, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
68
Table 3.3b Indonesian Crude Oil Prices by Type, 2004 (US$/Barrel) Months No
Crude Oil Jan
Feb
Mar
Apr
May
Jun
Jul
Aug
Sep
Oct
Nov
Dec
1
SLC
30.16
29.36
32.28
32.12
37.09
36.30
36.28
41.42
43.56
49.04
37.36
33.99
2
Arjuna
31.95
33.33
34.79
34.40
38.67
36.92
28.74
43.58
44.91
50.53
44.98
37.32
3
Attaka
32.49
33.73
35.48
35.10
39.37
37.61
40.04
46.43
47.81
52.53
46.91
38.88
4
Cinta
29.20
28.63
31.49
31.53
36.13
34.97
35.58
40.69
42.31
47.35
36.48
33.06
5
Duri
28.24
27.42
28.78
28.37
33.58
30.37
30.74
37.39
39.52
39.56
30.81
30.16
6
Widuri
29.25
28.65
31.52
31.53
36.18
35.00
35.58
40.68
42.32
47.39
36.60
33.10
7
Belida
32.22
33.45
35.14
34.75
38.90
37.25
39.75
46.11
47.10
52.06
46.35
38.52
8
Senipah Cond.
32.48
33.74
35.16
34.62
38.93
37.40
39.39
45.43
46.72
51.49
45.96
38.08
9
Anoa
32.89
34.13
35.88
35.41
39.77
38.01
40.44
46.83
48.21
52.93
47.31
39.28
10
Arun condensate
32.48
33.74
35.16
34.62
38.93
37.40
39.39
45.43
46.72
51.49
45.96
38.08
11
Arirnbi
30.80
32.18
33.64
33.25
37.52
35.77
37.59
42.43
43.76
49.38
43.83
36.17
12
Badak
32.49
33.73
35.48
35.01
39.37
37.61
40.04
46.43
47.81
52.53
46.91
38.88
13
Bekapai
32.49
33.73
35.48
35.01
39.37
37.61
40.04
46.43
47.81
52.53
46.91
38.88
14
Bentayan
28.20
27.40
30.32
30.16
35.13
34.34
34.32
39.46
41.60
47.08
35.40
32.03
15
Bontang R. Cond.
39.12
33.71
35.50
36.09
39.22
37.14
37.75
43.67
43.50
48.49
46.95
42.33
16
Bula
27.84
26.92
28.28
27.87
33.08
29.87
30.24
36.89
39.02
39.06
30.31
29.66
17
Bunyu
30.16
29.36
32.28
32.12
37.09
36.30
36.28
41.42
43.56
49.04
37.36
33.99
18
Camar
32.33
33.71
35.17
34.78
39.05
37.30
39.12
43.96
45.29
50.91
45.36
37.70
19
Geragai
30.35
29.55
32.47
32.31
37.28
36.49
36.47
41.61
43.75
49.23
37.55
34.18
20
Handil Mix
32.10
33.48
34.94
34.55
38.82
37.07
38.89
43.73
45.06
50.68
45.13
37.47
21
Jambi
30.35
29.55
32.47
32.31
37.28
36.49
36.47
41.61
43.75
49.23
37.55
34.18
22
Jatibarang/Cemara/ Cepu
29.15
28.35
31.27
31.11
36.08
35.29
35.27
40.41
42.55
48.03
36.35
32.98
23
Kaji
30.56
29.76
32.68
32.52
37.49
36.70
36.68
41.82
43.96
49.44
37.76
34.39
24
Kerapu
31.88
33.11
34.80
34.41
38.56
36.91
39.41
45.77
46.76
51.72
46.01
38.18
25
Klamono
27.84
26.92
28.28
27.87
33.08
29.87
30.24
36.89
39.02
39.06
30.31
29.66
26
Komp.P.SIt/Tap/ Jene/ Serdang
30.16
29.36
32.28
32.12
37.09
36.30
36.28
41.42
43.56
49.04
37.36
33.99
27
Lalang
31.21
29.41
32.33
32.17
37.14
36.35
36.33
41.47
43.61
49.09
37.41
34.04
28
Langsa
32.09
33.33
35.08
34.61
38.97
37.21
39.64
46.03
47.41
52.13
46.51
38.48
29
Lirik
30.05
29.25
32.17
32.01
36.98
36.19
36.17
41.31
43.45
48.93
37.25
33.88
30
Madura
32.08
33.46
34.92
34.53
38.80
37.05
38.87
43.71
45.04
50.66
45.11
37.45
31
Mudi
31.65
33.03
34.49
34.10
38.37
36.62
38.44
43.28
44.61
50.23
44.68
37.02
32
NSC/Katapa Arbei
32.38
33.62
35.37
34.90
39.26
37.50
39.93
46.32
47.70
52.42
46.80
38.77
33
Pagerungan Kond.
31.73
32.99
34.41
33.87
38.18
36.65
38.64
44.68
45.97
50.74
45.21
37.33
34
Pam. Sanga-Sanga Mix
30.26
29.46
32.38
32.22
37.19
36.40
36.38
41.52
43.66
49.14
37.46
34.09
35
Ramba/Tempino
30.35
29.55
32.47
32.31
37.28
36.49
36.47
41.61
43.75
49.23
37.55
34.18
36
Rimau
30.06
29.26
32.18
32.02
36.99
36.20
36.18
41.32
43.46
48.94
37.26
33.89
37
Sanggata
30.16
29.36
32.28
32.12
37.09
36.30
36.28
41.42
43.56
49.04
37.36
33.99
38
Selat Panjang
30.16
29.36
32.28
32.12
37.09
36.30
36.28
41.42
43.56
49.04
37.36
33.99
39
Sembilang
29.96
29.16
32.08
31.92
36.89
36.10
36.08
41.22
43.36
48.84
37.16
33.79
40
Sep. Yak. Mix.
31.95
33.33
34.79
34.40
38.67
36.92
38.74
43.58
44.91
50.53
44.98
37.32
41
Tanjung
30.35
29.55
32.47
32.31
37.28
36.49
36.47
41.61
43.75
49.23
37.55
34.18
42
Walio Mix
29.96
29.16
32.08
31.92
36.89
36.10
36.08
41.22
43.36
48.84
37.16
33.79
Average
30.97
30.96
33.16
32.89
37.53
36.12
37.10
42.61
44.31
49.21
40.63
35.51
Source: Indonesia Oil and Gas Statistics, 2004, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
69
Table 3.3c Indonesian Crude Oil Prices by Type, 2005 (US$/Barrel) Months No
Crude Oil Jan
Feb
Mar
Apr
May
Jun
Jul
Aug
Sep
Oct
Nov
Dec
1
SLC
41.48
44.13
53.29
55.22
49.50
53.60
55.11
60.35
60.36
57.10
52.80
62.74
2
Arjuna
43.78
46.94
54.21
56.24
49.68
54.12
57.60
63.24
62.76
60.05
55.51
56.72
3
Attaka
45.36
48.46
55.56
57.02
50.18
54.98
58.89
65.58
67.08
62.30
66.48
58.18
4
Cinta
40.23
42.10
51.67
51.92
48.66
51.37
52.44
57.24
58.06
54.93
60.97
52.11
5
Duri
38.51
38.36
43.52
47.89
41.40
46.28
49.03
53.25
53.66
50.55
48.81
48.22
6
Widuri
40.27
42.18
51.76
54.08
48.70
51.52
52.47
57.24
58.00
54.79
51.02
52.29
7
Belida
44.94
48.15
55.74
55.98
49.94
54.46
58.48
65.24
66.76
62.16
58.55
58.07
8
Senipah Condensate
43.95
46.94
54.49
54.90
48.42
52.61
55.58
62.58
64.56
59.88
55.11
56.46
9
Anoa
45.76
48.88
55.98
67.42
50.58
55.38
59.29
65.98
67.49
62.70
56.88
58.58
10
Arun Condensate
43.95
46.94
54.49
54.90
48.42
52.61
55.58
62.58
64.56
59.88
55.11
56.46
11
Arimbi
42.63
48.79
53.06
55.09
48.53
52.97
56.45
62.09
61.61
58.90
54.46
55.57
12
Badak
45.38
48.46
55.56
57.02
50.18
54.98
58.89
65.58
67.09
62.30
54.48
68.18
13
Bekapal
45.35
48.46
55.56
57.02
50.18
54.98
58.89
65.58
67.09
62.30
56.48
58.18
14
Bentayan
39.98
42.17
51.33
53.26
47.54
51.64
53.15
59.39
58.40
55.14
50.64
51.78
15
Bontang R. Cond.
40.61
43.69
50.06
49.51
44.44
45.36
49.07
67.07
61.65
57.55
53.26
63.12
16
Bula
38.01
34.86
43.02
47.19
40.90
45.78
48.53
52.75
53.16
50.05
45.11
47.72
17
Bunyu
41.94
44.13
63.29
65.22
49.50
53.60
55.11
60.35
60.36
57.10
52.60
53.74
18
Camar
44.16
47.32
54.69
56.62
50.08
54.50
57.98
63.62
63.14
60.43
55.99
57.10
19
Cepu
40.93
43.12
52.28
54.21
48.49
42.59
54.10
59.34
59.35
56.09
51.89
62.73
20
Geragal
42.13
44.32
53.48
55.41
49.69
53.79
55.30
60.54
60.55
57.29
52.79
53.93
21
Handil mix
43.93
47.09
54.36
56.39
49.83
54.27
57.75
63.39
62.91
60.20
55.76
56.87
22
Jambi
42.18
44.32
53.48
55.41
49.69
53.79
55.30
60.54
60.55
57.29
52.72
33.93
23
Jatibarang
41.94
44.13
53.29
55.22
49.50
53.60
55.11
60.35
60.36
57.10
52.60
53.74
24
Kaji
42.34
44.53
53.69
55.52
49.80
54.00
55.51
60.75
60.76
57.50
53.00
54.14
25
Kerapu
44.60
47.81
55.40
55.55
49.60
54.12
58.14
64.90
66.42
61.82
56.21
57.73
26
Klamono
38.01
34.88
43.02
47.19
40.90
45.78
48.53
52.75
53.18
50.05
46.11
47.72
27
Komp.PLB.SLT/TAP/ Jene/Serdang
41.94
44.13
53.29
55.22
49.50
53.60
55.11
60.35
60.36
57.10
52.60
53.74
28
lalang
41.99
44.18
53.34
55.27
49.55
53.65
55.16
60.40
60.41
57.15
52.65
53.79
29
Langsa
44.95
48.06
55.16
56.82
49.78
54.58
58.49
55.18
55.89
61.90
56.08
57.78
30
Lirik
41.83
44.02
53.18
55.11
49.39
53.49
55.00
60.24
60.25
58.99
52.49
53.63
31
Madura
43.91
47.07
54.34
56.37
49.81
54.25
57.73
63.37
62.89
60.18
56.74
56.85
32
Mudi
43.48
46.64
63.19
55.94
49.38
53.82
57.30
62.94
62.46
59.75
55.31
56.42
33
NSC/Katapa/Arbai
45.25
48.35
55.45
58.91
50.07
54.87
58.78
65.47
66.98
62.19
56.37
58.07
34
Pagerungan Cond.
43.20
46.19
53.74
54.15
47.67
51.86
54.83
61.83
63.81
59.13
54.38
55.71
35
Pam. sanga2 Mix
42.04
44.23
53.39
55.32
49.60
53.70
55.21
60.45
60.46
57.20
52.70
53.84
36
Ramba/Tempina
42.13
44.32
53.48
55.41
49.69
43.79
55.30
60.54
60.55
57.29
52.79
53.93
37
Rimau/Taruhan
41.84
44.03
53.19
55.12
49.40
53.50
55.01
60.25
60.26
57.00
52.60
53.64
38
Sangatta
41.94
44.13
23.29
55.22
46.50
53.60
55.11
60.35
60.36
57.10
52.60
53.74
39
Selat Panjang
41.94
44.13
53.29
55.22
49.50
53.60
55.11
60.35
60.36
57.10
52.60
53.74
40
Sembilang
41.74
43.93
53.09
55.02
46.30
53.40
54.91
60.15
60.16
56.90
52.40
53.54
41
Sep. Yakin Mix
43.78
46.94
54.21
56.24
49.68
54.12
57.60
63.24
62.76
60.05
55.61
56.72
42
Tanjung
42.13
44.32
53.48
55.41
46.69
53.79
55.30
60.54
60.55
57.29
52.79
53.93
43
Walio Mix
41.74
43.93
53.09
55.02
46.30
53.40
54.91
60.16
60.16
56.90
52.40
53.54
Average
42.39
44.74
53.00
54.88
48.72
52.92
55.42
61.09
61.36
58.11
53.96
54.64
Source: Ministry of Energy and Mineral Resources, www.esdm.go.id
70
Table 3.4
Domestic Fuel Prices, 2003-April 2006 (Rupiah/Liter)
Since
02.01.03
Avgas
Avtur
Pertamax Plus
n.a
n.a
2600
Pertamax
Premium
2300
1810
Kerosene 700
ADO
1890
IDO
1860
Fuel Oil 1560
1970 21.01.03
n.a
n.a
2600
2300
1810
700
Market Prices 1650
1650
1560
1800 01.12.03
n.a
n.a
2600
2300
1810
700
01.02.04
01.03.04
01.04.04
01.05.04
01.06.04
01.07.04
01.08.04
01.09.04
01.10.04
01.11.04
01.12.04
19.12.04
03.01.05
01.02.05
01.03.05
-
-
-
-
-
5,808
6,215
6,380
6,391
6,237
6,248
*
*
*
*
*
-
-
-
-
-
3,014
3,047
3,179
3,542
3,674
4,070
*
*
*
*
*
2600
2600
2750
2750
2750
2750
2750
2750
2750
2750
2750
2750
4200
4200
4200
4200
2300
2300
2450
2450
2450
2450
2450
2450
2450
2450
2450
2450
4000
4000
4000
4000
Subsidies Prices Market Prices
1650
1650
1560
1800 01.01.04
Subsidies Prices
Subsidies Prices Market Prices
1810
1800
1650
1650
1560
Subsidies Prices
2100
2200
2100
2050
1560
Market Prices
1810
1800
1650
1650
1560
Subsidies Prices
2100
2200
2100
2050
1560
Market Prices
1810
1800
1650
1650
1560
Subsidies Prices
2100
2200
2100
2050
1560
Market Prices
1810
1800
1650
1650
1560
Subsidies Prices
2100
2200
2100
2050
1560
Market Prices
1810
1800
1650
1650
1560
Subsidies Prices
2100
2200
2100
2050
1590
Market Prices
1810
1800
1650
1650
1560
Subsidies Prices
2100
2200
2100
2050
1600
Market Prices
1810
1800
1650
1650
1560
Subsidies Prices
2100
2200
2100
2050
1600
Market Prices
1810
1800
1650
1650
1560
Subsidies Prices
2100
2200
2100
2050
1600
Market Prices
1810
1800
1650
1650
1560
Subsidies Prices
2100
2200
2100
2050
1600
Market Prices
1810
1800
1650
1650
1560
Subsidies Prices
2100
2200
2100
2050
1600
Market Prices
1810
1800
1650
1650
1560
Subsidies Prices
2100
2200
2100
2050
1600
Market Prices
1810
1800
1650
1650
1560
Subsidies Prices
2100
2200
2100
2050
1600
Market Prices
1810
1800
1650
1650
1560
Subsidies Prices
2100
2200
2100
2050
1600
Market Prices
1810
1800
1650
1650
1560
Subsidies Prices
2100
2200
2100
2050
1600
Market Prices
1810
1800
1650
1650
1560
Subsidies Prices
2100
2200
2100
2050
1600
Market Prices
2400
2200
2100
2300
2300
Subsidies Prices
2870
2790
2700
2660
2300
Market Prices
71
Table 3.4
Domestic Fuel Prices, 2003-April 2006 (Continued) (Rupiah/Liter)
Since
14.03.05
01.04.05
01.07.05
01.08.05
01.07.05
01.10.05
08.10.05
01.11.05
21.11.05
01.12.05
01.01.06
01.02.06
Avgas
Avtur
Pertamax Plus
Pertamax
*
*
4200
4000
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
*
4200
4200
4200
5900
5900
5900
5900
5600
5600
n.a
n.a
4000
4000
4000
5700
5700
5700
5700
5400
5400
ADO
Fuel Oil
Premium
Kerosene
2400
2200
2100
2300
2160
Subsidies Prices
2870
2790
2700
2660
2300
Market Prices
2400
2200
2100
2300
2360
Subsidies Prices
2870
2790
2700
2660
2360
Market Prices
2400
2200
2100
2300
2360
Subsidies Prices
4060
4940
4740
4560
2900
Market Prices
2400
2200
2100
2300
2600
Subsidies Prices
4640
5490
5480
5240
3150
Market Prices
2400
2200
2100
2300
2600
Subsidies Prices
5160
5600
5350
5130
3150
Market Prices
4500a)
2000a)
4300a)
-
Subsidies Prices
3150
Market Prices
-
Subsidies Prices
3810
Market Prices
-
Subsidies Prices
3870
Market Prices
-
Subsidies Prices
3870
Market Prices
-
Subsidies Prices Market Prices
5160
5600
5350
4500a)
2000a)
4300a)
6290
6400
6000
4500a)
2000a)
4300a)
IDO
5130 5780 -
5890
6480
6170
4500a)
2000a)
4300a)
5890
6480
6170
4500a)
2000a)
4300a)
5150
6480
5340
5180
3680
4500a)
2000a)
4300a)
-
-
4780
5320
5180b)
5020b)
3640b)
4950c)
4810c)
3480c)
4300a)
-
-
n.a
4500a)
2000a)
4930
5740
n.a
5440b)
5940 5940 -
5020
3640
Subsidies Prices Market Prices Subsidies Prices Market Prices
5200c)
01.03.06
*
*
n.a
4500a)
2000a)
4898.69
5747.96
n.a
4300a) 5273.19b)
4900.4
3603.83
Subsidies Prices Market Prices
5043.92c)
01.04.06
*
*
n.a
4500a)
2000a)
5098.57
5507.06
n.a
4300a) 5362.31b)
4983.1
3672.74
Subsidies Prices Market Prices
5129.16c)
* not single price a) Premium, Kerosene and ADO Prices based on Perpres No. 55/2005 b) Transportation c) Industry Sources : Patra Propen Volume XXXI-February 2002 Indonesia Oil and Gas Statistics 2001-2002, Directorate General of Oil and Gas. Ministry of Energy and Mineral Resources Ministry of Energy and Mineral Resources, www.esdm.go.id PT Pertamina (Persero), www.pertamina.com
72
Table 3.5a Domestic Avgas Selling Prices, 2005 (Rupiah per Liter)
No
Location/Airport
Jan
Feb
Mar
Apr
May
Jun
Jul
Aug
Sep
Oct
Nov
Dec
1
Polonia
9,328
9,350
10,461
11,748
12,309
11,451
12,045
13,156
14,025
16,511
14,641
13,002
2
S. M. Badarudin II
8,624
8,635
9,746
11,022
11,572
10,714
11,308
12,397
13,266
15,719
13,849
12,232
3
Halim PK
9,537
9,548
10,659
11,957
12,518
11,660
12,254
13,376
14,245
16,742
14,861
13,222
4
Achmad Yani
8,822
8,833
9,955
11,231
11,781
10,923
11,517
12,617
13,486
15,950
14,069
12,452
5
Juanda
8,624
8,635
9,746
11,022
11,572
10,714
11,308
12,397
13,266
15,719
13,849
12,232
6
Iswahyudi
8,921
8,932
10,054
11,330
11,880
11,033
11,627
12,727
13,596
16,060
14,190
12,562
7
Ngurah Rai
9,328
9,350
10,461
11,748
12,309
11,451
12,045
13,156
14,025
16,511
14,641
13,002
8
Eltari
9,537
9,548
10,659
11,957
12,518
11,660
12,254
13,376
14,245
16,742
13,739
13,222
9
Instalasi Surabaya Group
8,525
8,525
9,647
10,923
11,462
10,604
11,198
12,298
13,156
15,609
14,410
12,111
10
Supadio
9,130
9,141
10,252
11,539
12,100
11,242
11,836
12,936
13,816
16,291
14,410
12,782
11
Depot Pontianak
9,130
9,141
10,252
11,539
12,100
11,242
11,308
12,936
13,816
16,291
13,849
12,782
12
Sepinggan
8,624
8,635
9,746
11,022
11,572
10,714
11,627
12,397
13,266
15,719
14,190
12,232
13
Syamsuddin Noor
8,921
8,932
10,054
11,330
11,880
11,033
12,045
12,727
13,596
16,060
14,641
12,562
14
Juwata
9,328
9,350
10,461
11,748
12,309
11,451
11,836
13,156
14,025
16,511
14,410
13,002
15
Termindung
9,130
9,141
10,252
11,539
12,100
11,242
11,836
12,936
13,816
16,291
13,739
12,782
16
Depot Balikpapan
8,525
8,525
9,647
10,923
11,462
10,604
11,198
12,298
13,156
15,609
13,959
12,111
17
Instalasi Makassar
8,723
8,734
9,845
11,121
11,671
10,813
11,407
12,507
13,376
15,840
14,861
12,342
18
Depot Jayapura
9,537
9,548
10,659
11,957
12,518
11,660
12,254
12,376
14,245
16,742
15,081
13,222
19
Depot Manokwari
9,735
9,757
10,868
12,155
12,727
11,869
12,474
13,585
14,456
16,973
16,973
13,442
Tax included Source: www.pertamina.com
73
Table 3.5b International Avgas Selling Prices, 2005 (US$ Cent per Liter)
No
LocationAirport
Jan
Feb
Mar*
Apr*
May*
Jun*
Jul
Aug
Sep
Oct
Nov
Dec
1
Polonia
92.08
91.39
112.83
125.114
128.799
119.658
113.75
121.75
128.82
145.50
130.26
117.20
2
S. M. Badarudin II
85.08
84.39
105.13
117.414
121.099
111.958
106.75
114.75
121.82
138.50
123.26
110.20
3
Halim PK
94.08
93.39
115.03
127.314
130.999
121.858
115.75
123.75
130.82
147.50
132.26
119.20
4
Achmad Yani
87.08
86.39
107.33
119.614
123.299
114.158
108.75
116.75
123.82
140.50
125.26
112.20
5
Juanda
85.08
84.39
105.13
117.414
121.099
111.958
106.75
114.75
121.82
138.50
123.26
110.20
6
Iswahyudi
88.08
87.39
108.43
120.714
124.399
115.258
109.75
117.75
124.82
141.50
126.26
113.20
7
Ngurah Rai
92.08
91.39
112.83
125.114
128.799
119.658
113.75
121.75
128.82
145.50
130.26
117.20
8
Eltari
94.08
93.39
115.03
127.314
130.999
121.858
115.75
123.75
130.82
147.50
132.26
119.20
9
Instalasi Surabaya Group
84.08
83.39
104.03
116.314
119.999
110.858
105.75
113.75
120.82
137.50
122.26
109.20
10
Supadio
90.08
89.39
110.63
122.914
126.599
117.458
111.75
119.75
126.82
143.50
128.26
115.20
11
Depot Pontianak
90.08
89.39
110.63
112.914
126.599
117.458
106.75
119.75
126.82
143.50
128.26
115.20
12
Sepinggan
85.08
84.39
105.13
117.414
121.099
111.958
109.75
114.75
121.82
138.50
123.26
110.20
13
Syamsuddin Noor
88.08
87.39
108.43
120.714
124.399
115.258
113.75
117.75
124.82
141.50
126.26
113.20
14
Juwata
92.08
91.39
112.83
125.114
128.799
119.658
111.75
121.75
128.82
145.50
130.26
117.20
15
Termindung
90.08
89.39
110.63
122.914
126.599
117.458
111.75
119.75
126.82
143.50
128.26
115.20
16
Depot Balikpapan
84.08
83.39
104.03
116.314
119.999
110.858
105.75
113.75
120.82
137.50
122.26
109.20
17
Instalasi Makassar
86.08
85.39
106.23
118.514
122.199
113.058
107.75
115.75
122.82
138.50
124.26
111.20
18
Depot Jayapura
94.08
93.39
115.03
127.314
130.999
121.858
115.75
123.75
130.82
147.50
132.26
119.20
19
Depot Manokwari
96.08
95.39
117.23
129.514
133.199
124.658
117.75
125.75
132.82
149.50
134.26
121.20
* Tax included Source: www.pertamina.com
74
Table 3.6a Pertamina Domestic Avtur Selling Prices, 2005 (Rupiah per Liter) No 1
2
Location Region 1
Region 2
Airport Polonia, Sultan Iskandar Muda, Tabing, Simpang Tiga, Ranai
Jan
Feb
Mar
Apr
May
Jun
Jul
Aug
Sep
Oct
Nov
Dec
3,960
3,465
3,707
4,510
4,950
4,609
4,752
5,038
5,379
6,149
6,028
5,247
Pinang Kampai
3,520
3,432
3,674
4,488
4,917
4,576
4,719
5,005
4,346
6,545
6,424
5,775
Hang nadim
3,230
3,150
3,370
4,100
4,500
4,190
4,320
4,580
4,890
5,590
5,480
4,770
Pangkal Pinang, Sultan Thaha, Padang Kemiling
3,564
1,476
3,380
4,521
4,961
4,620
4,763
5,049
5,390
6,149
5,480
SMB II
3,520
3,432
3,340
4,488
4,917
4,576
4,719
5,005
5,346
6,545
6,424
3,586
3,498
3,400
4,543
4,983
4,631
4,785
5,071
5,412
6,094
5,973
5,269
3
Region 3
Halim PK, Husien Sastranegara, Pondok Cabe Soekarno Hatta
3,531
3,432
3,320
4,488
4,928
4,576
4,719
5,016
5,357
6,545
5,973
5,214
4
Region 4
Ahmad Yani, Adi Sucipto, Adi Sumarmo
3,553
3,465
3,370
4,510
4,950
4,609
4,752
5,038
5,379
6,314
6,424
5,214
Tunggul Wulung
3,553
3,465
3,370
4,510
4,950
4,609
4,752
5,038
5,379
6,545
6,204
5,775
Region 5
Sumbawa Besar, M Salahudin, Mau Hau, Wai Oti, Eltari, Selaparang, H Aroeboesman
3,608
3,509
3,410
4,565
5,005
4,653
5,016
5,313
5,742
6,776
6,644
5,324
5
6
Region 6
7
Region 7
8
Region 8
5,775
Iswahyudi
3,608
3,509
3,410
4,565
5,005
4,653
5,016
5,313
5,742
6,776
5,973
5,775
Ngurah Rai
3,542
3,454
3,360
4,499
4,939
4,598
4,741
5,027
5,368
6,094
5,973
5,214
Juanda
3,553
3,465
3,370
4,510
4,950
4,609
4,752
5,038
5,379
6,094
6,204
5,214
Syamsuddin Noor, Supadio, Juwata, Tjilik Riwut, Temindung, Iskandar
3,597
3,498
3,410
4,554
4,994
4,642
4,796
5,082
5,423
6,314
5,904
5,346
Sepinggan
3,520
3,432
3,340
4,499
4,917
4,576
4,719
5,005
5,346
6,094
5,973
5,214
3,608
3,509
3,410
4,565
5,005
4,653
4,807
5,093
5,434
6,149
6,182
5,379
3,630
3,531
3,430
4,587
5,027
4,675
5,016
5,313
5,786
6,435
6,314
5,544
6,776
6,644
5,775
Hasanuddin, Mutiara, Lalos, Bubung, Jlaludin, Sam Ratulangi, Wolter Mongisidi Sentani, Rendani, Mopah, Frans kaiseipo, Paniai, Dumatubun, Pattimura, Babullah, Sorong Daratan, Utarom
All Depot Non DPPU Tax included 9
Source: www.pertamina.com
75
Table 3.6b International Avtur Selling Prices, 2005 (US$ Cent per Liter)
International Avtur Retail Price Tax 10% (Exept Batam)
1
2
Jan
Feb
Mar
Apr
May
Jun
Jul
37.55
39.32
38.79
46.18
49.60
46.21
46.21
39.95
42.67
50.80
54.56
50.83
Aug
Sep
Oct
Nov
Dec
Regional 1-4 & Reg.6
47.32
49.12
51.37
54.63
54.15
46.98
Region 5
49.32
51.12
53.37
56.63
56.15
48.98
Region 7
48.32
50.12
52.37
55.63
55.15
47.98
Region 8
50.32
52.12
52.37
37.63
57.15
49.98
Ngurah Rai
47.32
49.12
52.37
54.63
54.15
47.18
Juanda
47.32
49.12
52.37
54.63
54.15
46.98
Sukarno Hatta Retail Price
38.49
45.88
49.30
Tax 10%
42.34
50.47
54.23
47.28
Source: www.pertamina.com
76
Table 3.7
Fuel Oil Subsidy, 1995-2005 (Billion Rupiah)
Note : (a) (b) (c) (d)
Year
Oil Subsidy
1995/1996
0
1996/1997
1,416.10
1997/1998
9,814.20
1998/1999
27,534.0 (a)
1999/2000
37,572.7 (b)
2000
53,635.2 (c)
2001
68,380.8 (d)
2002
31,161.70
2003
30,037.90
2004
72,884.22
2005
99,487.66
: include oil : include oil : include oil : include oil
subsidy deficit fiscal year 1997/1998 subsidy deficit fiscal year 1999/1999 subsidy deficit fiscal year 1999/2000 subsidy deficit fiscal year 2000
Sources : th Oil and Gas Data Information, 6 Ed., 2002, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources Indonesia Oil and Gas Statistics 2003, Directorate General Oil and Gas, Ministry of Energy and Mineral Resources Directorat General Oil and Gas, Ministry of Energy and Mineral Resources
Table 3.8
Gas Domestic Prices, Jan 2006 US$/MMBTU
Gas Prices FUEL Electricity
2.1 - 2.9
Industry
3
Refinery
1.7 - 2
FEEDSTOCK Fertilizer
1.5 - 2.75
Methanol Plant
1.42 - 2
DISTRIBUTION
2.16-3
Source: Directorate General Oil and Gas, Ministry of Energy and Mineral Resources (Processed)
77
Table 3.9a International Coal Price Trend 60 53
Coal Price (US$/ton)
50 45 40.85 39.85 38.9
40
40.3
40.3 37.65
36.35
34.5
34.5
34.35
30
29.95
28.75
28.75
26.75
20
10
0 1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001 2002 2003 2004 2005
Year For 6700 Kcal/kg (GAD-Gross Air Dried) Source : Barlow-Jonker
Table 3.9b Indonesian Coal Export Price Trend
60
50.40
Coal Price (US$/ton)
50
42.97
40
38.53 38.06 37.15
38.49 38.49 34.72
35.96 32.81
32.28
30
27.94
26.68
28.90
27.02 25.80
20
10
0 1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001 2002
2003 2004 2005
Year For 6300 Kcal/kg (GAD-Gross Air Dried) Source : Ditjen MinerbaPabum, 2005
78
Table 3.10
Averaged Generation Cost of PLN Power Plants, 1993-2005 (Rupiah/kWh) Hydro Power Plant
Year
Steam Power Plant
Diesel Power Plant
Gas Power Plant
Geothermal Power Plant
Gas-Steam Power Plant
Average
1993/1994
16.01
59.29
151.35
170.06
61.86
103.36
73.03
1994
18.82
53.17
155.46
78.88
62.49
83.39
67.14
1995
20.13
55.87
157.05
131.52
83.44
69.76
74.82
1996
17.19
56.80
156.11
179.94
96.16
69.49
68.37
1997
18.39
69.47
186.16
253.11
120.48
95.73
87.43
1998
20.03
106.93
211.50
247.91
257.50
233.02
152.20
1999
29.55
116.08
221.36
224.38
275.26
192.63
146.79
2000
32.61
109.79
231.92
324.29
262.00
204.51
148.33
2001
36.31
149.09
408.15
592.06
319.95
265.36
203.71
2002
208.53
236.73
849.60
875.02
368.90
316.32
329.74
2003
128.81
265.47
701.89
791.29
400.42
362.88
339.29
2004
123.26
273.46
673.34
862.66
415.62
370.27
351.34
2005
114.71
316.72
925.18
953.79
514.70
560.78
469.78
2000: not included maintenance cost Source: PLN Statistics, 1993-2005, PT PLN (Persero)
Table 3.11
Averaged Selling Price of Electricity by Type of Customer, 1992-2005 (Rupiah/kWh)
Year
Residential
Industrial
Business
Social
Government Office Building
Public Street Lighting
1992
128.85
122.83
237.81
106.88
180.93
131.42
1993
144.53
135.35
253.56
119.21
208.36
153.52
1994
146.57
137.75
255.49
122.78
214.25
154.25
1995
156.83
144.79
264.00
128.16
224.73
167.70
1996
158.91
146.16
266.04
130.60
225.63
169.05
1997
161.65
149.70
270.35
130.34
232.07
172.82
1998
184.40
201.01
305.83
193.32
294.02
238.97
1999
193.80
208.56
313.47
215.29
316.61
266.07
2000
207.34
302.52
380.51
231.50
491.93
439.08
2001
253.65
361.67
451.91
272.47
596.68
484.17
2002
392.79
442.94
592.77
421.28
692.33
515.37
2003
522.48
530.32
661.41
538.09
725.90
594.98
2004
557.76
559.15
682.32
568.65
712.47
638.99
2005
563.05
569.87
694.71
569.90
730.32
628.72
Source: PLN Statistics, 2004-2005, PT PLN (Persero)
79
Table 3.12
Price of Fuels for Electricity, 1992-2005
Oil (Rp/Liter)*)
Year HSD
IDO
MFO
Average
Coal (Rp/Ton)
Natural Gas (Rp/MMSCF)
Geothermal (Rp/kWh)
1992
360.56
317.78
240.97
306.44
65.24
6,392.61
49.28
1993
384.59
376.83
255.30
338.91
68.66
4,951.88
69.02
1994
386.99
368.66
258.25
337.97
70.34
5,578.41
90.15
1995
401.86
372.23
257.45
343.85
72.91
6,288.19
90.15
1996
399.24
417.08
256.82
357.71
69.41
6,878.80
108.88
1997
388.07
371.65
256.82
338.85
60.02
6,874.79
99.12
1998
430.66
457.33
328.85
405.61
74.88
26,414.80
253.99
1999
553.59
509.21
378.27
480.36
140.73
21,065.44
246.19
2000
593.35
538.39
382.15
504.63
153.79
21,787.67
221.56
2001
878.52
797.01
654.72
776.75
199.60
26,073.78
269.54
2002
1,406.79
1,331.77
1,127.05
1,288.54
219.75
23,496.92
310.36
2003
1,740.91
1,705.10
1,595.15
1,680.39
230.82
21,550.40
316.28
2004
1,829.11
1,694.11
1,697.70
1,740.31
230.75
21,258.05
297.39
2005
2,819.15
2,485.99
2,418.19
2,574.44
251.55
25,323.76
461.70**)
*) including the transportation cost **) Refer to Indonesia Power fuesl price Source: PLN Statistics, 2004-2005, PT PLN (Persero)
80
ENERGY RESERVES AND POTENTIALS
IV. ENERGY RESERVES AND POTENTIALS OF INDONESIA
PENGKAJIAN ENERGI UNIVERSITAS INDONESIA
81
82
Table 4.1
Oil and Gas Reserves, 1995-2005
Year
Oil
Gas
(Billion Barrel Oil)
(Trillion Cubic Feet)
Proven
Potential
Total
Proven
Potential
Total
1995
4.98
4.12
9.10
72.26
51.31
123.57
1996
4.73
4.25
8.98
77.19
58.73
135.92
1997
4.87
4.22
9.09
76.17
61.62
137.79
1998
5.10
4.59
9.69
77.06
59.39
136.45
1999
5.20
4.62
9.82
92.48
65.78
158.26
2000
5.12
4.49
9.61
94.75
75.56
170.31
2001
5.10
4.66
9.75
92.10
76.05
168.15
2002
4.72
5.03
9.70
90.30
86.29
176.59
2003
4.73
4.40
9.13
91.17
86.96
178.13
2004
4.30
4.31
8.61
97.81
90.53
188.34
2005
4.19
4.44
8.63
97.26
88.54
185.80
Sources : th Data, Information Oil and Gas 6 Ed., 2002, (pages : 34), Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources Oil and Gas Statistics of Indonesia 1999-2003, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources Oil and Gas Statistics of Indonesia 2000-2004, Directorate of Oil and Gas Ministry of Energy and Mineral Resources Directorate of Oil and Gas Ministry of Energy and Mineral Resources
83
Table 4.2
Coal Reserves by Province, 2005
Quality No
1
2
3
4
5
6
7
8
9
Class
Criteria (Cal/gr, adb)
Medium Calories High Calories
51006100 6100 7100
Province
Banten
Central
Low Calories
<5100
East java
Medium Calories
51006100
Nangroe Aceh Darussalam
Low Calories Medium Calories
North Sumatra
Riau
West Sumatra
Jambi
Bengkulu
Low Calories Medium Calories Low Calories Medium Calories High Calories Medium Calories High Calories Very High Calories Low Calories Medium Calories High Calories Low Calories Medium Calories High Calories Very High Calories
Resource (million Ton) Hypothetic 5.47
Inferred 2.78
Indicated
Measured
0.00
2.09
Total
Reserve (million Ton)
10.34
0.00
0.00
2.97
0.00
0.00
2.97
0.00
5.47
5.75
0.00
2.09
1,331.00
0.00
0.00
0.82
0.00
0.00
0.82
0.00
0.00
0.82
0.00
0.00
0.82
0.00
0.00
0.08
0.00
0.00
0.08
0.00
0.00
0.08
0.00
0.00
0.08
0.00
<5100
0.00
20.92
6.70
64.14
91.76
0.00
51006100
0.00
325.43
6.70
26.26
358.39
0.00
0.00
346.35
13.40
90.40
450.15
0.00
0.00
0.00
0.00
19.97
19.97
0.00
<5100 51006100 <5100 5100 6100 6100 7100 51006100 61007100 >7100
<5100 5100 6100 6100 7100 <5100 51006100 61007100 >7100
0.00
7.00
0.00
0.00
7.00
0.00
0.00
7.00
0.00
19.97
26.97
0.00
0.00
1,345.69
0.00
268.06
1,613.75
0.00
0.00
30.62
0.00
51.57
82.19
0.00
12.79
359.60
0.00
16.99
389.38
16.54
12.79
1,735.91
0.00
336.62
2,085.32
16.54
19.19
284.36
42.72
22.97
369.24
2.83
5.76
164.58
0.00
144.20
314.60
19.24
0.00
27.00
0.00
14.00
41.00
14.00
24.95
475.94
42.72
181.20
7,243.00
36.07
0.00
51.13
0.00
0.00
51.10
0.00
190.84
1,200.09
36.32
90.20
1,517.40
18.00
0.00
210.81
0.00
82.90
293.77
0.00
190.84
1,462.03
363.00
173.20
18,623.00
18.00
0.00
11.34
0.00
10.58
21.92
0.00
0.00
0.81
0.00
5.86
6.67
3.79
15.15
100.62
8.11
45.49
16,937.00
1,733.00
0.00
0.32
0.00
37.00
0.69
0.00
15.15
113.09
8.11
6,230.00
198.65
21.12
84
Table 4.2
Coal Reserves by Province, 2005 (Continued)
Quality No
Province Class
10
11
12
13
14
15
16
17
South Sumatra
Lampung
West Kalimantan
Central Kalimantan
South Kalimantan
East Kalimantan
South Sulawesi
Central Sulawesi
Low Calories Medium Calories High Calories High Calories Medium Calories High Calories Very High Calories Low Calories Medium Calories High Calories Very High Calories Low Calories Medium Calories High Calories Very High Calories Low Calories Medium Calories High Calories Very High Calories Medium Calories High Calories Low Calories
Criteria (Cal/gr, adb) <5100 51006100 61007100 61007100 5100 6100
Resource (million Ton) Hypothetic
Inferred
Indicated
Measured
Total
Reserve (million Ton)
326.55
7,400.27
2,300.07
1,358.00
11,384.89
2,426.00
198.93
1,629.28
9,139.87
366.01
11,334.10
186.00
0.00
31.00
433.89
14.00
478.89
67.00
525.48
906,055.00
11,873.83
1,738.01
23,197.88
2,679.00
0.00
92.95
0.00
0.00
92.95
0.00
0.00
14.00
0.00
0.00
14.00
0.00
0.00
106.95
0.00
0.00
106.95
0.00
6100 7100
42.12
378.60
0.00
0.00
420.72
0.00
>7100
0.00
104.00
1.32
1.48
106.80
0.00
42.12
48,160.00
132.00
1.48
52,752.00
0.00
0.00
483.92
0.00
0.00
483.92
0.00
0.00
296.75
5.08
44.36
354.80
4.05
114.11
262.72
0.00
72.6A
449.47
0.00
0.00
247.62
0.00
77.02
324.64
44.54
114.11
1,291.01
5.08
194.02
161,183.00
4,859.00
0.00
370.87
0.00
600.99
971.86
53,633.00
0.00
4,793.13
301.36
2,526.46
7,620.95
1,287.01
0.00
336.19
33.12
109.64
478.95
4,436.00
0.00
17.62
0.00
12.00
29.62
0.14
0.00
5,517.81
334.48
3,249.09
910,138.00
1,867.84
0.00
201.93
13.76
89.83
30,532.00
0.00
2,285.84
10,630.35
121.61
2,609.46
15,682.72
941.62
502.96
2,611.07
191.77
1,558.62
4,918.92
1,064.82
90.11
60.84
4.48
14.40
169.82
941.62
2,878.90
13,504.19
331.62
4,271.31
21,076.98
2,071.68
0.00
131.03
32.31
53.10
216.44
0.06
<5100 5100 6100 6100 7100 >7100
<5100 5100 6100 6100 7100 >7100
<5100 51006100 61007100 >7100
51006100 61007100 <5100
0.00
13.90
0.78
0.00
14.68
0.00
0.00
144.93
33.09
53.10
231.12
0.06
0.00
1.98
0.00
0.00
1.98
0.00
0.00
1.98
0.00
0.00
1.98
0.00
85
Table 4. 2
Coal Reserves by Province, 2005 (Continued) Quality
No
18
19
Class
Criteria (Cal/gr, adb)
Low Calories
<5100
Province
North Maluku
West Papua
Medium Calories High Calories Very High Calories Total
1. 2.
5100 6100 6100 7100 >7100
Resource (million Ton) Hypothetic
Inferred
Indicated
Measured
Total
Reserve (million Ton)
0.00
2.13
0.00
0.00
2.13
0.00
0.00
2.13
0.00
0.00
2.13
0.00
89.40
30.95
0.00
0.00
120.35
0.00
0.00
5.38
0.00
0.00
5.38
0.00
0.00
25.53
0.00
0.00
25.53
0.00
89.40
61.86
0.00
0.00
151.26
0.00
3,899.22
34,323.06
12,679.98
10,371.74
61,273.99
6,756.90
Depth measured until 100 m Coal quality based on Calorie Value (Keppres No. 13 Tahun 2000 renewed by PP No. 45 Tahun 2003) a. Low Calorie < 5100 kal/gr b. Medium Calorie < 5100 - 6100 kal/gr c. High Calorie > 6100 - 7100 kal/gr d. Very High Calorie > 7100 kal/gr
Source: Directorate of Mineral Resources Inventory, Directorate General of Geology and Mineral Resources, Ministry of Energy Mineral Resources
86
Table 4.3
Potential and Installed Capacities of Geothermal Energy in Sumatra, December 2004 Resources (MWe)
No
Area
Reserve (MWe)
Speculative
Hypothetic
Possible
Probable
Proven
Installed (MWe)
Regency/ City
Nangroe Aceh Darussalam 1
Lho Pria Lacrt
Sabang
30
-
-
-
-
-
2
Kaneke
Safoang
50
-
-
-
-
-
3
Iboih-Jaboi
Sataang
-
123
-
-
-
-
4
le Seum-Krueng Raya
Aceh Besar
-
63
-
-
-
-
5
Seulawah Agam
Aceh Besar
-
-
282
-
-
-
6
Alur Canang
Pidie
25
-
-
-
-
-
7
Alue Long-Bangga
Pidie
100
-
-
-
-
-
8
Tangse
Pidie
25
-
-
-
-
-
9
Rimba Raya
Central Aceh
100
-
-
-
-
-
10
G. Geureudong
Central Aceh
-
120
-
-
-
-
11
Simpang Balik
Central Aceh
100
-
-
-
-
-
12
Silih Nara
Central Aceh
100
-
-
-
-
-
13
Meranti
East Aceh
25
-
-
-
-
-
14
Brawang Buaya
East Aceh
25
-
-
-
-
-
15
Kafi
Southeast Aceh
25
-
-
-
-
-
16
Gunung Kembar
Southeast Aceh
-
92
-
-
-
-
17
Dolok Perkirapan
Southeast Aceh
25
-
-
-
-
-
North Sumatera 18
Beras Tepu
Karo
-
-
-
-
-
-
19
Lau Detauk-DebukSibayak
Karo
-
70
131
-
39
2
20
Marike
Karo
25
-
-
-
-
-
21
Dolok Marawa
Simalungun
225
-
-
-
-
-
22
Pusuk Bukrt-Danau Toba
North Tapanuli
225
-
-
-
-
-
23
Sirnbolon-Samosir
North Tapanuli
225
-
-
-
-
-
24
Pagaran
North Tapanuli
225
-
-
-
-
-
25
Helatoba
North Tapanuli
25
-
-
-
-
-
26
Sipaholon Ria-Ria
North Tapanuli
225
-
-
-
-
-
27
Sarula
North Tapanuli
-
100
200
-
80
-
28
Sibual-Buali
South Tapanuli
-
-
556
-
-
-
29
Namora llangit
North Tapanuli
-
-
-
-
210
-
30
Sibutauhan
South Tapanuli
100
-
-
-
-
-
31
Sorik Marapi
South Tapanuli
-
-
420
-
-
-
32
Sampuraga
South Tapanuli
225
-
-
-
-
-
33
Roburan
South Tapanuli
-
-
320
-
-
-
West Sumatera 34
Simisioh
Pasaman
100
-
-
-
-
-
35
Cubadak
Pasaman
100
73
-
-
-
-
36
Talu
Pasaman
50
-
-
-
-
-
37
Panti
Pasaman
150
-
-
-
-
-
38
Lubuk Sikaping
Pasaman
100
-
-
-
-
-
39
Situjuh
Lima Puluh Koto
25
-
-
-
-
-
40
Bonjol
Pasaman
100
-
-
-
-
-
41
Kota Baru-Marapi
Bukit Tinggi
50
-
-
-
-
-
42
Maninjau
Agam
25
-
-
-
-
-
43
Sumani
Solok
25
-
-
-
-
-
44
Priangan
Tanah Datar
25
-
-
-
-
-
45
Bukit Kili
Solok
-
-
58
-
-
-
87
Table 4.3
Potential and Installed Capacities of Geothermal Energy in Sumatra, December 2004 (Continued) Resources (MWe)
No
Area
Reserve (MWe)
Regency/ City Speculative
Hypothetic
Possible
Probable
Proven
Installed (MWe)
West Sumatera 46
Surian
Solok
75
-
-
-
-
-
47
Gunung Talang
Solok
-
-
94
-
-
-
48
Muaralabuh
Solok
-
-
194
-
-
-
49
Liki-Pinangawan
Solok
-
-
412
-
-
-
51
Gunung Kapur
Kerinci
25
-
-
-
-
-
52
Gunung Kaca
Kerinci
25
-
-
-
-
-
53
Sungai Betung
Kerinci
100
-
-
-
-
-
54
Semurup
Kerinci
-
-
208
-
-
-
55
Lempur
Kerinci
-
-
150
15
40
-
56
Air Dikit
Merangin
225
-
-
-
.
-
57
Graho Myabu
Merangin
-
185
-
-
-
-
58
Sungai Tenang
Sorolangun
-
74
-
-
-
-
Jambi
Bengkulu 59
Tambang Sawah
Rejang Lebong
-
73
100
-
-
-
60
Bukit Gedang-Hulu Lais
Rejang Letaong
-
150
500
-
-
-
61
Suban Gergok
Rejang Lebong
225
-
-
-
-
-
62
Lebong Simpang
Rejang Lebong
225
-
-
-
-
-
Bangka Belitung 63
Sungai Liat
Bangka
25
-
-
-
-
-
64
Pangkal Pinang
Bangka
25
-
-
-
-
-
65
Air Tembaga
Bangka
25
-
-
-
-
-
South Sumatera 66
Tanjungsakti
Lahat
50
-
-
-
-
-
67
Rantau Dadap-Segamrt
Muara Enim
225
-
-
-
-
-
68
Bukit Lumut Balai
Ogan Komering Ulu
-
235
600
-
-
-
69
Ulu Danau
Ogan Komering Ulu
225
6
-
-
-
-
70
Marga Bayur
Ogan Komering Ulu
-
145
194
-
-
-
71
Wai Selabung
Ogan Komering Ulu
225
6
-
-
-
-
-
Lampung 72
Wai Umpu
North Lampung
100
-
-
-
-
73
Danau Ranau
West Lampung
-
185
222
-
-
-
74
Purunan
West Lampung
25
-
-
-
-
-
75
Gunung Sekincau
West Lampung
-
100
130
-
-
-
76
Bacingot
West Lampung
225
-
-
-
-
-
77
Suoh-Antatai
West Lampung
-
163
300
-
-
-
78
Fajar Bulan
West Lampung
100
-
-
-
-
-
79
Natar
South Lampung
25
-
-
-
-
-
80
Ulubelu
Tanggamus
-
156
380
-
20
-
81
Lempasing
South Lampung
225
-
-
-
-
-
82
Wai Ratal
South Lampung
-
194
-
-
-
-
83
Kaiianda
South Lampung
-
40
40
-
-
-
84
Pematang Belirang
South Lampung
225
-
-
-
-
-
Source: Directorate of Mineral resources Inventory, Directorate general of Geology and Mineral Resources, Ministry of Energy Mineral Resources, December 2004
88
Table 4.4
Potential and Installed Capacity of Geothermal Energy in Java, December 2004 Resources (MWe)
No
Area
Reserve (MWe)
Regency/ City Speculative
Hypothetic
Possible
Probable
Proven
Installed (MWe)
Banten 85
Rawa Dano
Serang
-
-
115
-
-
-
86
Gunung Karang
Serang
-
-
170
-
-
-
87
Gunung Pulosari
Serang
-
100
-
-
-
-
88
Gunung Endut
Lebak
225
-
-
-
-
-
89
Pamancalan
Lebak
225
-
-
-
-
-
West Java 90
Kawah Ratu
Sukabumi
-
-
72
30
-
91
Kiarataeres
Sukabumi
225
-
-
-
-
-
92
Awi Bengkok
Bogor
-
-
115
-
485
330
93
Ciseeng
Bogor
-
100
-
-
-
-
94
Bujal-Jasinga
Bogor
25
-
-
-
-
-
95
Cisukarame
Sukabumi
-
-
83
-
-
-
96
Selabintana
Sukabumi
25
-
-
-
-
-
97
Cisolok
Sukataumi
-
50
50
-
-
-
98
Gunung Pancar
Bogor
50
-
-
-
-
-
99
Jampang
Sukabumi
225
-
-
-
-
-
100
Tanggeung-Cibungur
Cianjur
100
-
-
-
-
-
Saguling
Bandung
25
-
-
-
-
-
102
Cilayu
Garut
100
-
-
-
-
-
103
Kawah Cibuni
Bandung
-
-
140
-
-
-
104
Gunung Patuha
Bandung
-
65
247
-
170
-
105
Kawah Ciwidey
Bandung
-
84
140
-
-
-
106
Maribaya
Bandung
25
-
-
-
-
-
107
Tangkuban Parahu
Bandung
-
100
90
-
-
-
108
Sagalaherang
Subang
-
185
-
-
-
-
109
Ciarinem
Garut
25
-
-
-
-
-
110
Gunung Papandayan
G£rut
225
-
-
-
-
-
111
Gunung MasigitGuntur
Garut
-
-
70
-
-
-
112
Kamojang
Garut
-
-
-
73
260
140
113
Darajat
Garut
-
-
-
70
362
145
114
Gunung Tampomas
Sumedang
-
-
100
-
-
-
115
Cipacing
Bandung
25
-
-
-
-
-
116
Gunung WayangWlndu
Bandung
-
75
-
135
250
110
117
Gunung Talagabodas
Tasikmalaya
-
75
120
80
-
-
118
Gunung Galunggung
Tasikmalaya
100
-
-
-
-
-
119
Ciheuras
Tasikmalaya
25
-
-
-
-
-
120
Cigunung
Tasikmalaya
25
-
-
-
-
-
121
Cibalong
Tasikmalaya
25
-
-
-
-
-
122
Gunung Karaha
Tasikmalaya
-
50
70
100
30
-
123
Gunung Sawal
Tasikmalaya
25
-
-
-
-
-
124
Cipanas-Ciawi
Tasikmalaya
50
-
-
-
-
-
125
Gunung Cakrabuana
Tasikmalaya
25
-
-
-
-
126
Gunung Kromong
Majalengka
25
-
-
-
-
-
127
Sangkan-Urip
Kuningan
50
-
-
-
-
-
128
Subang
Kuningan
50
-
-
-
-
-
129
Cibinbin
Kuningan
25
-
-
-
-
-
89
Table 4.4 Potential and Installed Capacity of Geothermal Energy in Java, December 2004 (Continued) Resources (MWe) No
Area
Reserve (MWe)
Speculative
Hypothetic
Possible
Probable
Proven
Installed (MWe)
-
Regency/ City
Central Java 130
Banyugaram
Cilaeap
100
-
-
-
-
131
Bumiayu
Banyumas
25
-
-
-
-
-
132
Baturaden
Banyumas
-
-
185
-
-
-
133
Guci
Pemalang
-
-
100
-
-
-
134
Mangunan-Wanayasa
Banjarnegara
-
-
92
-
-
-
135
Candradimuka
Wonosotao
25
-
-
-
-
-
136
Dieng
Wonosobo
-
200
185
115
280
60
137
Krakal
Kebumen
25
-
-
-
-
-
138
Panulisan
Cilacap
25
-
-
-
-
-
139
Gunung Ungaran
Semarang
-
50
52
-
-
-
140
Candi UmbulTelomoyo
Semarang
-
92
-
-
-
-
141
Kuwuk
Grobogan
25
-
-
-
-
-
142
Gunung Lawu
Karang Anyar
25
-
-
-
-
-
143
Kiepu
Semarang
25
-
-
-
-
-
East Java 145
Melati
Pacitan
25
-
-
-
-
-
146
Rejosari
Pacitan
25
-
-
-
-
-
147
Telaga Ngebel
Ponorogo
-
148
Gunung Pandan
Madiun
149
Gunung ArjunoWelirang
Mojokerto
-
-
120
-
.
50
-
-
-
-
-
-
38
92
-
-
-
150
Cangar
Malang
-
-
100
-
-
-
151
Songgorrti
Malang
25
-
-
-
-
-
152
Tirtosari
Sumenep
12.5
-
-
-
-
-
153
lyang-Argopuro
Protaolinggo
-
110
185
-
-
-
154
Tiris
Probolinggo
-
55
92
-
-
-
155
Blawan-ljen
Banyuwangi
-
92
185
-
-
-
Source: Directorate of Mineral Resources Inventory, Directorate General of Geology and Mineral Resources, Ministry of Energy Mineral Resources, December 2004
90
Table 4.5
No
Potential and Installed Capacity of Geothermal Energy in East Region of Indonesia, December 2004
Area
Regency/ City
Resources (MWe)
Reserve (MWe)
Speculative
Hypothetic
Possible
Probable
Proven
Installed (MWe) -
Bali 156
Banyuwedang
Buleleng
12.5
-
-
-
-
157
Seririt
Buleleng
12.5
-
-
-
-
-
158
Batukao
Tabanan
25
-
-
-
-
-
159
Penebel
Tabanan
25
-
-
-
-
-
160
Buyan-Bratan
Buleleng
-
-
226
-
-
-
East Husa Tenggara 164
Wai Sano
Manggarai
-
90
33
-
-
-
165
Ulumbu
Manggarai
-
-
187.5
-
12.5
-
166
Wai Pesi
Manggarai
-
-
54
-
-
-
167
Gou-lnelika
Ngada
-
28
-
-
-
-
168
Mengeruda
Ngada
-
5
-
-
-
-
169
Mataloko
Ngada
-
10
63.5
-
1.5
-
170
Komandaru
Ende
-
11
-
-
-
-
171
Ndetusoko
Ende
-
-
10
-
-
-
172
Sukoria
Ende
-
145
25
-
-
-
173
Jopu
Ende
-
-
5
-
-
-
174
Lesugolo
Ende
-
-
45
-
-
-
175
Oka - He Ange
East Flares
-
-
40
-
-
-
176
Atadei
Lembata
-
-
40
-
-
-
177
Bukapiting
Alor
-
-
27
-
-
-
178
Roma-Ujelewung
Lembata
-
16
6
-
-
-
179
Oyang Barang
East Flares
-
-
37
-
-
-
180
Sirung(lsiabang-Kuriali)
Alor
100
48
-
-
-
-
181
Adum
Lembata
182
Alor Timur
Alor
-
-
36
-
-
-
190
-
-
-
-
-
West Kalimantan 183
Sibetuk
Sintang
25
-
-
-
-
184
Jagoi Babang
Sintang
12.5
-
-
-
-
-
185
Meromoh
Bengkayang
12.5
-
-
-
-
-
North Sulawesi 186
Air Madidi
Minahasa
25
-
-
-
-
-
187
Lahendong
Minahasa
-
125
-
110
65
20
188
Tompaso
Minahasa
-
-
130
-
-
-
189
Gunung Amtaang
Bolaang Mongondow
-
-
225
-
-
-
190
Kotamobagu
Bolaang Mongondow
-
-
185
-
-
-
Gorontalo 191
Gorontalo
Gorontalo
-
-
15
-
-
-
192
Pentadio
Boalemo
25
-
-
-
-
-
Central Sulawesi 193
Maranda
Poso
25
-
-
-
-
-
194
Sapo
Donggala
25
-
-
-
-
-
195
Langkapa
Poso
25
-
-
-
-
-
196
Napu
Poso
25
-
-
-
-
-
197
Torire
Poso
25
-
-
-
-
-
198
Toare
Donggala
25
-
-
-
-
-
199
Patalogumba
Donggala
25
-
-
-
-
-
200
Marana
Donggala
-
-
40
-
-
-
201
Bora
Donggala
-
-
8
-
-
-
202
Pulu
Donggala
-
-
58
-
-
-
203
Sedoa
Donggala
25
-
-
-
-
204
Wliasa
Poso
25
-
-
-
-
-
205
Watuneso
Poso
25
-
-
-
-
-
206
Papanpulu
Poso
25
-
-
-
-
-
91
Table 4.5 Potential and Installed Capacity of Geothermal Energy in East Region of Indonesia, December 2004 (Continued) No
Area
Regency/ City
Resources (MWe)
Reserve (MWe) Possible
Probable
Proven
Installed (MWe)
-
-
-
-
-
-
30
-
-
-
-
-
-
-
Speculative
Hypothetic
25 -
South Sulawesi 207
Limbong
Luwu
208
Pararra
North Luwu
209
Mambosa
Mamuju
25
-
210
Somba
Majene
25
-
-
-
-
211
Mamasa
Polewali Mamasa
-
-
2
-
-
-
212
Bituang
Tana Toraja
-
-
17
-
-
-
213
Sangala
Tana Toraja
25
-
-
-
-
-
214
Sengkang
Sindenreng Rappang
25
-
-
-
-
-
215
Sulili
Pinrang
25
-
-
-
-
-
216
Malawa
Pangkajene
25
-
-
-
-
-
217
Baru
Baru
25
-
-
-
-
-
218
Watampone
Bone
25
-
-
-
-
-
219
Todong
Bone
25
-
-
-
-
-
220
Sinjai
Sinjai
25
-
-
-
-
-
221
Masepe
Sindenreng Rappang
25
-
-
-
-
-
222
Danau Tempe
Wajo
25
-
-
-
-
-
South-East Sulawesi 223
Mangolo
Kolaka
-
-
14
-
-
-
224
Parora
Kendari
25
-
-
-
-
-
225
Puriala
Kendari
25
-
-
-
-
-
226
Amoloha
Kendari
25
-
-
-
-
-
227
Loanti
Kendari
25
-
-
-
-
-
228
Laenia
Kendari
-
-
36
-
-
-
229
Torah
Buton
25
-
-
-
-
-
230
Kalende
Buton
25
-
-
-
-
-
231
Kanale
Buton
25
-
-
-
-
-
232
Wonco
Buton
25
-
-
-
-
-
233
Gonda Baru
Bau-Bau
-
-
1
-
-
-
234
Kabungka
Buton
25
-
-
-
-
-
235
Sampolawa
Buton
25
-
-
-
-
-
North Maluku 236
Mamuya
North Halmahera
-
7
-
-
-
-
237
Ibu
West Halmahera
25
-
-
-
-
-
238
Akelamo
North Halmahera
25
-
-
-
-
-
239
Jallolo
West Halmahera
-
-
42
-
-
-
240
Keibesi
West Halmahera
25
-
-
-
-
-
241
Akesahu
Tidore
25
-
-
-
-
-
242
Indari
South Halmahera
25
-
-
-
-
-
243
Labuha
South Halmahera
25
-
-
-
-
-
244
Tonga Wayaua
South Halmahera
-
110
-
-
-
-
Maluku 245
Larike
Ambon
25
-
-
-
-
-
246
Taweri
Ambon
25
-
-
-
-
-
247
Tolehu
Ambon
-
-
100
-
-
-
248
Oma Haruku
Central Maluku
25
-
-
-
-
-
249
Saparua
Central Maluku
25
-
-
-
-
-
250
Nusa Laut
Central Maluku
25
-
-
-
-
-
Papua 251
Makbau
Sorong
25
-
-
-
-
-
252
Ransiki
Manokwari
25
-
-
-
-
-
Source: Directorate of Mineral Resources Inventory, Directorate General of Geology and Mineral Resources, Ministry of Energy Mineral Resources, December 2004
92
Table 4.6
Potential of Microhydro Energy > 20 kVA (15 kW) (measured by PLN) (kW)
No
Location
Province
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 37 38 39 40 41 42 43 44 45 46 47
Blangkejeren Tangse Sepakat Arul Ralem Sibundong-2 Letter W Hinas Kanan Lubuk Buntak Purui Merasap Muara Kedihin Baras Tamako/U-Peliang Poigar Lobong Kolondom Kembera Toni Tawaeli Talise Mongango Wining Bambalo/Poso Kalumpang Hanga-hanga-2 Rongi Mikuasi Enrekang/Lewaja Mamasa/Bala Palangka Bonelemo Cennae Usu Malili Batu Sitanduk Kadundung Rante Balla Hatu Teminabuan Wamena-3 Werba Tatui Santong Roa/Ende Lokomboro/Waikabubak Banjar Cahyana Tapen
Aceh Aceh Aceh Aceh North Sumatera West Sumatera South Sumatera South Sumatera South Sumatera West Kalimantan South Kalimantan East Kalimantan North Sulawesi North Sulawesi North Sulawesi North Sulawesi North Sulawesi North Sulawesi North Sulawesi North Sulawesi North Sulawesi North Sulawesi Central Sulawesi Central Sulawesi Central Sulawesi Central Sulawesi Central Sulawesi South Sulawesi South Sulawesi South Sulawesi South Sulawesi South Sulawesi South Sulawesi South Sulawesi South Sulawesi South Sulawesi Maluku Papua Papua Papua Papua East Nusa Tenggara East Nusa Tenggara East Nusa Tenggara Central Java Central Java
Number of Units 1 2 2 1 2 1 1 2 1 1 1 1 1 2 2 2 1 1 1 1 1 2 1 1 2 1 2 1 1 1 1 1 2 1 2 1 1 1 2 1 2 1 1 1 1 1 Total Potential
Potential 2,050 1,250 1,750 378 2337 5,000 520 2,210 210 1,160 500 200 1,090 2,500 1,500 2,000 430 300 1,270 1,200 900 1,600 2,610 700 1,670 845 1,060 440 340 1,500 1,340 590 3,750 1,750 1,443 612 528 150 1,000 1,650 1,182 545 700 860 1,490 730 57,840
Measuring Institution PLN Region I PLN Region I PLN Region I PLN Region I PLN Region II PLN Region III PLN Region IV PLN Region IV PLN Region IV PLN Region V PLN Region VI PLN Region VI PLN Region VII PLN Region VII PLN Region VII PLN Region VII PLN Region VII PLN Region VII PLN Region VII PLN Region VII PLN Region VII PLN Region VIII PLN Region VII PLN Region VII PLN Region VII PLN Region VII PLN Region VII PLN Region VIII PLN Region VIII PLN Region VIII PLN Region VIII PLN Region VIII PLN Region VIII PLN Region VIII PLN Region VIII PLN Region VIII PLN Region IX PLN Region X PLN Region X PLN Region X PLN Region X PLN Region XI PLN Region XI PLN Region XI PLN Region XI PLN Region XI
Source : Rencana Induk Pengembangan Energi Baru dan Terbarukan 1997, Directorate General of Electricity and Energy Development, Ministry of Energy and Mineral Resources
93
Table 4.7
Potential of Microhydro Energy > 20 kVA (15 kW) (measured by non PLN) in Sumatera and Java (kW)
No
River
Location
Sub District
Regency
Province
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50
Samalanga Kr. Inong Kr. Sabet Bt. Kumal Marpinggan Rantaupuran Batang Gadis A. Pasariran Hutapungkut I. Eho I. Gomo Indano Moi Aek Raisan Aek Silang Sungai Putih Ludang Bayang Bungo Muara sako Bt. Bayang Bt. Sumani Bt. Gumanti Bt. Balangir Bt. Sangir Bt. A. Guntung Sikarbau Patimah ~ A. Tenang Selabung Selabung Selabung Campang Rarem Ilahan Klingi Klingi Air Lang Blimbing Ketaun Cawang Kiri Padang Guci Mana Seluma Sindur Palik Lais Lubuk Banyau Merangin Bt. Air Batu Sampean
Samalanga Jim-jim Sabet Padang Bulan Siponggol Gunung Tua-2 Batang Gadis Sipenggang Alahan Kae I. Eho I. Gomo Indano Moi Raisan-3 Silang-2 Sungai Putih Sawah Kerambil Koto Baharu Muara Sako Bayang Sani Sumani Pinti Kayu Balangir Kubang Gajah Guntung Sikarbau Patimah Batu Hampar Bedegung Banding Agung 1 Banding Agung 2 Banding Agung 3 Mutar Alam Sinar Mulia Way Ilahan Klingi 1 Klingi 2 Kepala Curup 2 Cinta Mandi Suka Negeri Bungin Tambun Talang Genting Pulau Timun Seluma Talang Alai Aur Gading Kuro Tidur Lubuk Banyau Penetay Perentak Sampean Baru
Samalanga Bandar Baru Lamo Pdg. Sidempuan Pdg. Sidempuan Penyambungan Batang Toru Batang Toru Kota Nopan Teluk Dalam Teluk Dalam Perw. kec. Moi Pandan Dolok Sanggul Bayang Terusan Bayang Pancung Soal Bayang Gunung Talang Lembah Gumanti Sangir Sangir Palupuh Lembah Melati Bonjol Bonjol Tanjung Agung Banding Agung Banding Agung Banding Agung Sumber Jaya Bukit Kemuning Pulau Panggung P. Ulak Tanding P. Ulak Tanding P. Ulak Tanding Perw. Kb. Agung Pw. R. Pengadang Kaur Utara Kaur Utara Pino Manna Perw. Sukaraja Kirkap Lais Lais Sungai Manau Sungai Manau Prajekan
North Aceh Pidie West Aceh South Tapanuli South Tapanuli South Tapanuli South Tapanuli South Tapanuli South Tapanuli Nias Nias Nias North Tapanuli North Tapanuli Pesisir Selatan Pesisir Selatan Pesisir Selatan Pesisir Selatan Pesisir Selatan Solok Solok Solok Solok Agam Pasaman Pasaman Pasaman Muara Enim Oku Oku Oku North Lampung North Lampung South Lampung Rejang Lebong Rejang Lebong Rejang Lebong Rejang Lebong Rejang Lebong South Bengkulu South Bengkulu South Bengkulu South Bengkulu South Bengkulu North Bengkulu North Bengkulu North Bengkulu Sarko Sarko Bondowoso
Aceh Aceh Aceh North Sumatera North Sumatera North Sumatera North Sumatera North Sumatera North Sumatera North Sumatera North Sumatera North Sumatera North Sumatera North Sumatera West Sumatera West Sumatera West Sumatera West Sumatera West Sumatera West Sumatera West Sumatera West Sumatera West Sumatera West Sumatera West Sumatera West Sumatera West Sumatera South Sumatera South Sumatera South Sumatera South Sumatera Lampung Lampung Lampung Bengkulu Bengkulu Bengkulu Bengkulu Bengkulu Bengkulu Bengkulu Bengkulu Bengkulu Bengkulu Bengkulu Bengkulu Bengkulu Jambi Jambi East Java Total Potential
Potential 1,130.00 458.40 1,274.00 684.00 240.00 809.60 900.00 1,200.00 1,248.00 712.30 467.30 672.00 1,280.00 1,152.00 1,113.60 411.80 499.20 3,880.40 644.00 600.00 8,840.00 480.00 7,488.00 624.00 770.00 860.00 608.00 968.00 3,194.40 3,194.50 2,881.10 750.00 1,044.00 1,700.00 480.00 998.00 1,792.00 1,850.00 2,306.00 3,404.80 1,489.60 4,059.20 358.40 777.60 1,854.00 1,315.20 773.60 841.60 518.40 2,486.90 78,083.90
Source : Rencana Induk Pengembangan Energi Baru dan Terbarukan 1997, Directorate General of Electricity and Energy Development, Ministry of Energy and Mineral Resources
94
Table 4.8
Potential of Microhydro Energy > 20 kVA (15 kW) (measured by non PLN) in Kalimantan and Sulawesi (kW)
No
River
Location
Sub District
Regency
Province
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50
Mempawah Kalompe Kalis Tapin Barabai Pisap Purui Waruk Bawan Mating Remayo Karau Sampulan Raung Sholuhan Suko Bumban Munthe Munthe Munthe Susua Lakambula Tindaki Dolago ~ ~ Tamunggu Pondo Pameki Ampana Kanori Tomasa Wimbi Mongono Tanggar Mamuju Tangkok Urupai Mayamba Maiting Lengkeme Biyalo Sallu Kokkang Dolok Mata Allo Matama Mumbi Susua Lakambula
Tiang Aping Kalompe Kalis Rarahim Hinas Kanan Kaitan Purui Menarung Long Bawan 1 Long Bawan 2 Pa'Betung Rudok Muara Tuhup Kuala Kurun 1 Kuala Kurun 2 Puruh Cahu 1 Puruh Cahu 2 Tincep 1 Tincep 2 Tincep 3 Rate Limbong 2 Olondoro Tindaki Dolago Banggai Salumpaka Nupabomba Boboya Mantilayo Sansarino Malewa Pandiri Sawidago 2 Solan Tombolo Mamuju Manipi Labole Paumah Kabiraan Langkeme Biyalo Kendenan Tombang Suddu Bilajen Talogo Kalimamang Rate Limbong 2 Olondoro
Mempawah Mempawah Mandai Piani Batu Benawa Awayan Jaro Br. Tongkok Kerayan Kerayan Kerayan Dusun Tengah Muara Laung Kuala Kurun Kuala Kurun Puruk Cahu Saripoi Sonder Sonder Sonder Lasusua Teomokale Parigi Parigi Walatang Banawa Tawaeli Palu Timur Sigi Biromaku Ampana Kota Tojo Lage Pamona Utara Klintom Malino Mamuju Sinjai Barat Lamuru Sendana Malunda Mario Riwawu Bulukumba Makale Salluputti Alla Alla Tutallu Tutallu Lasusua Teomokale
Pontianak Pontianak Kapuas Hulu Tapin H1. Sungai Teng. H1. Sungai Teng. Tabalong Kutai Bulungan Bulungan Bulungan Buntok Barito Utara Kapuas/Gng. Mas Kapuas North Barito North Barito Minahasa Minahasa Minahasa Kolaka Buton Donggala Donggala Donggala Donggala Donggala Donggala Donggala Poso Poso Poso Poso Banggai Tanjung Moncong Mamuju Sinjai Bone mejene Mejene Soppeng Donggala Tator Tator Enrekang Enrekang Polmas Polmas Kolaka Buton
West Kalimantan West Kalimantan West Kalimantan South Kalimantan South Kalimantan South Kalimantan South Kalimantan East Kalimantan East Kalimantan East Kalimantan East Kalimantan Central Kalimantan Central Kalimantan Central Kalimantan Central Kalimantan Central Kalimantan Central Kalimantan North Sulawesi North Sulawesi North Sulawesi North Sulawesi North Sulawesi Central Sulawesi Central Sulawesi Central Sulawesi Central Sulawesi Central Sulawesi Central Sulawesi Central Sulawesi Central Sulawesi Central Sulawesi Central Sulawesi Central Sulawesi Central Sulawesi South Sulawesi South Sulawesi South Sulawesi South Sulawesi South Sulawesi South Sulawesi South Sulawesi South Sulawesi South Sulawesi South Sulawesi South Sulawesi South Sulawesi South Sulawesi South Sulawesi South East Sulawesi South East Sulawesi Total Potential
Potential 530.00 121.60 1,428.20 324.00 249.20 1,950.70 220.00 240.00 200.00 36.00 504.00 2,112.00 80.00 24.00 48.00 346.00 228.00 605.00 1,100.00 2,200.00 712.80 441.60 515.20 768.00 816.00 231.60 319.20 399.40 1,500.00 554.40 404.90 2,756.00 436.80 1,523.50 1,230.00 648.00 5,616.00 1,090.00 106.60 157.00 145.60 360.00 194.90 432.00 224.60 2,820.80 562.80 547.00 712.80 441.60 39,215.80
Source : Rencana Induk Pengembangan Energi Baru dan Terbarukan 1997, Directorate General of Electricity and Energy Development, Ministry of Energy and Mineral Resources
95
Table 4.9
Potential of Microhydro Energy > 20 kVA (15 kW) (measured by non PLN) in East Region of Indonesia (kW)
No
River
Location
Sub District
Regency
Province
Potential
1
Ira
Ira
Galela
North Maluku
Maluku
370.60
2
Akelamo
Goal
Sahu
North Maluku
Maluku
800.00
3
Memekan
Memekan
Kao
North Maluku
Maluku
52.80
4
Ngaoli
Ngaoli
Kao
North Maluku
Maluku
345.60
5
Wae Toni
Saunullu
Tehoru
Central Maluku
Maluku
240.00
6
~
Teminabuan
Teminabuan
Sorong
Papua
400.00
7
~
Sorpehee
Sorpehee
Fak Fak
Papua
340.00
8
~
Hamerhu
Hamerhu
Fak Fak
Papua
640.00
9
Iborengeh
Masi 1
Warware
Monokwari
Papua
668.80
10
Masi
Masi 2
Warware
Monokwari
Papua
436.80
11
Ransiki
Ransiki
Ransiki
Monokwari
Papua
1,364.40
12
Wambiadi
Wambiadi
Wambiadi
Manokwari
Papua
450.00
13
Mariarotu
Mariarotu
Yapen Selatan
Yapen Waropen
Papua
1,443.20
14
Waelega
Bonar
Rutteng
Manggarai
East Nusa Tenggara
2,600.00
15
Bijeli
Bijeli
Molo Selatan
Central Timor
East Nusa Tenggara
4,532.60
16
~
Oe Hala
Molo Selatan
Central Timor
East Nusa Tenggara
92.50
17
~
Fulur
Tasifato
Belu
East Nusa Tenggara
200.00
18
Lowo Mego
Wolodesa
Perw. Paga
Sika
East Nusa Tenggara
288.00
19
Wae Musur
Sita 1
Mborong
Manggarai
East Nusa Tenggara
2,400.00
20
Wae Laku
Sita 2
Satar Mese
Manggarai
East Nusa Tenggara
608.00
21
~
Tjuruk
Ruteng
Manggarai
East Nusa Tenggara
760.00
22
Wae Naong
Barang
Cibal
Manggarai
East Nusa Tenggara
680.00
23
Wae Purang
Purang
Lembor
Manggarai
East Nusa Tenggara
714.00
24
Kali Putih
Mbulilo
Wolowaru
Ende
East Nusa Tenggara
130.00
25
Wai Wutu
Piga
Pwk. Bajawa
Ngada
East Nusa Tenggara
321.60
26
Utan
Utan
Utan
Sumbawa
East Nusa Tenggara
330.00
27
Lowo Roga
Masabewa
Paga
Sikka
East Nusa Tenggara
306.00
28
Wai Buntal
Taen Terong
Riung
Ngada
East Nusa Tenggara
416.00
29
Wai Pua
Were 2
Golewa
Ngada
East Nusa Tenggara
98.00
30
Wai Boa
Aimere
Aimere
Ngada
East Nusa Tenggara
193.10
31
Amor-amor
Sami Jengkel
Bayan
West Lombok
East Nusa Tenggara
180.00
32
Nae
Dompu
Dompu
Bima
West Nusa Tenggara
680.00 1,050.20
33
Babak
Babak
Narmada
Central Lombok
West Nusa Tenggara
34
Brang Marenteh
Marenteh
Alas
Sumba Besar
West Nusa Tenggara
215.00
35
Mamak
Mamak
Lape Lapok
Sumbawa
West Nusa Tenggara
560.00
36
~
Batujai
Batujai
Central Lombok
West Nusa Tenggara
168.00
37
Pengga
Pengga
Pengga
Central Lombok
West Nusa Tenggara
448.00
38
Segare
Pekatan
Tanjung
West Lombok
West Nusa Tenggara
468.00
39
Delo
Paradowane
Monta
Bima
West Nusa Tenggara
216.70
40
Brang Jereweh
Jereweh
Delo
Sumbawa Besar
West Nusa Tenggara
121.00
41
Lampe
Lampe
Rasanae
Bima
West Nusa Tenggara
216.70
Total Potential
26,545.60
Source : Rencana Induk Pengembangan Energi Baru dan Terbarukan 1997, Directorate General of Electricity and Energy Development, Ministry of Energy and Mineral Resources
96
Table 4.10
Potential of Solar Energy
No
Regency
Province
Year of Measurement
Average Radiation (kWh/m2)
Measured by
1
Banda Aceh
Aceh
1980
4.10
LSDE
2
Palembang
South Sumatera
1979-1981
4.95
BMG
3
Menggala
Lampung
1972-1979
5.23
DGEED/BMG
4
Rawasragi
Lampung
1965-1979
4.13
DGEED/BMG
5
Jakarta
Jakarta
1965-1981
4.19
DGEED/BMG
6
Bandung
West Java
1980
4.15
LSDE
7
Lembang
West Java
1980
5.15
LSDE
West Java
1980
4.32
LSDE
West Java
1980
2.56
LSDE
West Java
1991-1995
4.45
LSDE
8 9 10
Citius, Tangerang Darmaga, Bogor Serpong, Tangerang
11
Semarang
Central Java
1979-1981
5.49
BMG
12
Surabaya
East Java
1980
4.30
LSDE
13
Kenteng, Yogyakarta
Yogyakarta
1980
4.50
LSDE
14
Denpasar
Bali
1977-1979
5.26
DGEED/BMG
15
Pontianak
1991-1993
4.55
LSDE
16
Banjarbaru
1979-1981
4.80
BMG
17
Banjarmasin
1991-1995
4.57
LSDE
18
Samarinda
1991-1995
4.17
LSDE
19
Menado
1991-1995
4.91
LSDE
20
Palu
1991-1994
5.51
LSDE
21
Kupang
1975-1978
5.12
DGEED/BMG
22
Waingapu, Sumba Timur
1991-1995
5.75
LSDE
23
Maumere
1992-1994
5.72
LSDE
West Kalimantan South Kalimantan South Kalimantan East Kalimantan North Sumatera South East Sulawesi West Nusa Tenggara East Nusa Tenggara East Nusa Tenggara
Source : Rencana Induk Pengembangan Energi Baru dan Terbarukan 1997, Directorate General of Electricity and Energy Development, Ministry of Energy and Mineral Resources
97
Table 4.11
Potential of Wind Energy in West Region of Indonesia measured by BMG) (m/sec)
No
Village/Sub District/Regency
Province
Year of Measurement
Average Velocity at Elevation of 24 m 2.73
1
Sabang
Aceh
1994
2
Meulaboh
Aceh
1994
3.33
3
Polonia Medan
North Sumatera
1994
3.68
4
Sei Dadap Kisaran
North Sumatera
1994
3.06
5
Binaka
North Sumatera
1994
3.06
6
Sicincin
West Sumatera
1994
3.86
7
KP. Laing
West Sumatera
1992
3.72
8
Depati Darbo
Jambi
1994
4.01
9
Simpang Tiga Pakanbaru
Riau
1994
3.97
10
Kijang
Riau
1994
4.22
11
Japura Rengat
Riau
1994
2.83
12
Ranai
Riau
1994
2.45
13
Pangkal Pinang
South Sumatera
1992
3.68
14
Buluh Tumbang Tanjung Pandan
South Sumatera
1995
5.56
15
Serang Banten
West Java
1992
3.01
16
Curug Tangerang
West Java
1994
2.70
17
Tanjung Priok
Jakarta
1993
4.45
18
Cengkareng
Jakarta
1994
3.55
19
Semarang Maritim
Central Java
1992
2.94
20
Kledung
Central Java
1994
4.08
21
Adi Sumarmo Surakarta
Central Java
1995
2.39
22
Iswahyudi Madiun
East Java
1994
5.57
23
Suranaya AURI
East Java
1994
4.65
24
Surabaya Perak
East Java
1994
2.61
25
Kalianget
East Java
1994
5.40
26
Sangkapura Bawean
East Java
1994
2.96
27
Surabaya Maritim
East Java
1994
3.37
28
Ploso
East Java
1991
2.39
29
Kp. Tiekung
East Java
1994
2.55
Bali
1992
2.39
30 • • •
Denpasar Small Scale Medium Scale Large Scale
: 2 – 3 (m/sec) : 3 – 4 (m/sec) : > 4 (m/sec)
Source : Rencana Induk Pengembangan Energi Baru dan Terbarukan 1997, Directorate General of Electricity and Energy Development, Ministry of Energy and Mineral Resources
98
Table 4.12
Potential of Wind Energy in East Region of Indonesia (measured by BMG) (m/sec)
No.
Village/Sub District/Regency
Province
Year of measurement
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36
Banjar Baru Balik Papan Tarakan Tanjung Redep Palangkaraya Panarung Muara Teweh Pangkalan Bun Pangkalan Bun Bubung Luwuk Samratulangi Menado Meteo Bitung Rembiga Ampenen Sengkol Sumbawa Besar Bima Kupang Maumere Lasiana Lekunik Tardamu Satar Tacik Ruteng Ternate Tual Saumlaki Geser Sanana Nalea Labuha Genyem Biak Kaimana Manokwari Sentani Serui Wamena Timika
South Kalimantan East Kalimantan East Kalimantan East Kalimantan Central Kalimantan Central Kalimantan Central Kalimantan Central Kalimantan South East Sulawesi North Sulawesi North Sulawesi West Nusa Tenggara West Nusa Tenggara West Nusa Tenggara West Nusa Tenggara East Nusa Tenggara East Nusa Tenggara East Nusa Tenggara East Nusa Tenggara East Nusa Tenggara East Nusa Tenggara Maluku Maluku Maluku Maluku Maluku Maluku Maluku Papua Papua Papua Papua Papua Papua Papua Papua
1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 1991 1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 1994 1992 1994 1994 1994 1994 1990 1990 1994
• • •
Small Scale Medium Scale Large Scale
Average Velocity at Elevation of 24 m 2.55 3.49 3.06 2.58 2.96 2.95 3.01 3.01 3.01 3.21 2.80 3.14 2.45 3.92 2.83 5.51 3.46 3.62 3.93 5.11 3.88 2.90 2.70 4.72 3.37 3.01 3.86 2.62 2.89 3.81 3.80 4.21 3.18 3.42 2.96 3.06
: 2 – 3 (m/sec) : 3 – 4 (m/sec) : > 4 (m/sec)
Source : Rencana Induk Pengembangan Energi Baru dan Terbarukan 1997, Directorate General of Electricity and Energy Development, Ministry of Energy and Mineral Resources
99
Table 4.13
No
1 2 3
Province
Aceh North Sumatera West Sumatera
Potential of Biomass Energy Energy from rice waste (kWh)
Energy from corn waste (kWh)
Energy From cassava waste (kWh)
Energy from wood waste (kWh)
Energy from bagasse waste (kWh)
Energy from coconut waste (kWh)
Energy from palm waste (kWh)
Total potential (kWh)l
Total potential (kW)
4,389,706
431,095
258,504
6,049,213
n.a
219,280
205,280
11,553,080
1,318.84
10,195,593
2,314,892
871,309
5,355,260
64,490
235,701
1,683,820
20,721,068
2,365.42
5,098,375
246,795
199,979
3,948,58
0.0
161,697
137,843
9,793,277
1,117.95
4
Riau
1,983,752
257,553
169,647
9,615,760
0.0
796,550
928,015
13,751,279
1,569.78
5
Jambi
2,367,450
128,522
616,022
5,425,444
0.0
298,997
214,169
9,050,605
1,033.17
6
Bengkulu
1,347,523
295,034
159,077
1,053,227
0.0
29,925
52,813
2,937,601
335.34
7
South Sumatera
5,430,242
328,720
755,798
9,138,553
57,921
63,780
259,221
16,034,238
1,830.39
8
Lampung
5,479,526
4,099,255
4,031,337
1,200,435
260,241
436,210
37,483
15,544,489
1,774.49
9
Jakarta
62,007
722
1,470
2,698
0.0
0.0
0.0
66,899
7.64
10
West Java
25,217,219
1,884,996
3,632,919
1,374,134
113,359
476,541
22,076
32,721,246
3,735.30
11
Central Java
19,274,685
8,091,226
5,868,925
1,517,684
293,198
422,761
0.0
35,468,481
4,048.91
12
Yogyakarta
7,577
180
22
33,155
28,236
113,149
0.0
182,322
20.81
13
East Java
21,090,156
16,558,311
6,713,419
2,124,634
856,306
519,077
0.0
47,861,905
5,463.69
4,225,297
245,497
391,479
14,598,861
0.0
119,163
135,369
19,715,669
2,250.65
14 15 16 17
West Kalimantan Central Kalimantan South Kalimantan East Kalimantan
2,327,557
41,242
122,772
23,747,448
0.0
73,314
8,194
26,320,528
3,004.63
5,021,574
245,908
199,243
4,370,927
45,814
122,838
16,445
10,022,752
1,144.15
1,723,811
182,263
294,074
25,932,474
0.0
66,050
45,775
28,244,449
3,224.25
18
North Sulawesi
1,250,948
1,117,723
138,926
3,173,349
16,505
755,977
0.0
6,453,431
736.69
19
Central Sulawesi
1,979,301
282,321
352,967
7,040,892
0.0
408,941
8,814
10,073,238
1,149.91
20
South Sulawesi
11,037,629
5,659,932
1,236,409
3,555,232
71,889
349,818
44,929
21,955,841
2,506.37
21
South East Sulawesi
1,036,020
644,745
358,275
5,506,430
0.0
97,876
0.0
7,643,349
872.53
22
Bali
1,965,806
661,104
206,987
34,745
0.0
174,551
0.0
3,043,195
347.40
23
West Nusa Tenggara
3,487,425
457,785
227,621
1,120,737
0.0
97,299
0.0
5,390,869
615.40
24
East Nusa Tenggara
2,033,010
3,974,166
1,876,283
2,153,199
0.0
127,297
0.0
10,163,957
1,160.27
25
Maluku
322,707
473,766
433,506
7,789,331
0.0
558,270
0.0
9,577,581
1,093.33
26
Papua
213,204
58,504
78,470
59,271,453
0.0
31,545
40,354
59,693,532
6,814.33
27
East Timor
279,675
1,018,650
438,906
566,083
0.0
24,896
0.0
2,328,212
265.78
138,847,782
49,700,918
29,634,361
205,699,957
1,807,964
6,781,514
3,840,607
436,313,106
49,807.43
Total Potential
Source : Rencana Induk Pengembangan Energi Baru dan Terbarukan 1997, Directorate General of Electricity and Energy Development, Ministry of Energy and Mineral Resources
100
Table 4.14
No
Potential of Biogas Energy
Province
Energy from cow waste (kWh)
Energy from buffalo waste (kWh)
Energy from pig waste (kWh)
Total potential (kWh)
Total potential (kW)
1
Aceh
176,518,754
196,136,857
181,220
372,836,831.00
42,561.28
2
North Sumatera
74,363,081
132,422,738
203,169,016
409,954,835.00
46,798.50
3
West Sumatera
126,698,243
98,229,921
3,407,275
228,335,439.00
26,065.69
4
Riau
36,120,418
21,630,728
22,834,799
80,585,945.00
9,199.31
5
Jambi
38,478,295
38,231,613
1,238,582
77,948,490.00
8,898.23
6
Bengkulu
30,164,863
48,092,009
113,785
78,370,657.00
8,946.42
7
South Sumatera
144,011,035
69,914,662
21,079,697
235,005,394.00
26,827.10
8
Lampung
108,170,057
22,692,458
7,308,835
138,171,350.00
15,772.99
9
Jakarta
1,671,636
296,479
4,436,556
6,404,671.00
731.13
10
West Java
93,668,568
252,258,353
5,272,717
351,199,638.00
40,091.28
11
Central Java
405,853,632
131,878,374
13,902,080
551,634,086.00
62,971.93
12
Yogyakarta
61,485,351
5,222,260
1,091,497
67,799,108.00
7,739.62
13
East Java
1,018,223,467
78,446,300
6,142,490
1,102,812,257.00
125,891.81
47,469,518
2,977,066
102,917,667
153,364,251.00
17,507.33
14,886,698
4,426,575
13,901,453
33,214,726.00
3,791.64
47,219,493
26,031,288
1,251,422
74,502,203.00
8,504.82
22,933,519
11,013,426
9,209,247
43,156,192.00
4,926.51
14 15 16 17
West Kalimantan Central Kalimantan South Kalimantan East Kalimantan
18
North Sulawesi
83,926,641
2,414,049
54,189,247
140,529,937.00
16,042.23
19
Central Sulawesi
121,577,567
21,287,126
23,807,187
166,671,880.00
19,026.47
20
South Sulawesi
201,287,881
119,742,352
42,624,867
363,655,100.00
41,513.14
21
South East Sulawesi
80,296,106
6,233,922
1,388,381
87,918,409.00
10,036.35
22
Bali
153,772,988
5,378,353
120,413,566
279,564,907.00
31,913.80
138,391,872
106,098,407
2,640,116
247,130,395.00
28,211.23
245,128,428
90,774,249
160,980,602
496,883,279.00
56,721.84
23 24
West Nusa Tenggara East Nusa Tenggara
25
Maluku
30,020,918
10,427,830
9,620,437
50,069,185.00
5,715.66
26
Papua
17,244,574
372,072
64,499,908
82,116,554.00
9,374.04
27
East Timor
10,374,345
25,986,128
42,923,212
79,283,685.00
9,050.65
Total Potential
3,529,957,948
1,528,615,595
940,545,861
5,999,119,404
684,830.98
Source : Rencana Induk Pengembangan Energi Baru dan Terbarukan 1997, Directorate General of Electricity and Energy Development, Ministry of Energy and Mineral Resources
101
Table 4.15
Potential of Peat Energy Quality
No
Location
Province Ash (%)
S (%)
Average Thickness (m)
Area (ha)
Dry Weight (million tons)
Average Calorific Value (MJ/kg dry weight)
Total Calorific Value (109 MJ)
1
Alue Bilie
Aceh
21.00
0.20
1.50
20,000.00
91.05
11.99
1,091.69
2
Tanjung Medan
North Sumatera
2.50
0.30
2.50
26,000.00
73.10
20.91
1,528.52
3
Siak Kiri
Riau
1.50
0.15
1.50
206,000.00
396.00
20.51
8,121.96
4
Siak Kanan
Riau
1.50
0.17
4.80
110,000.00
423.20
21.65
9,162.28
5
P. Bengkalis
Riau
3.50
0.42
3.00
66,410.00
360.00
24.00
8,640.00
6
P. Rangsang
Riau
3.50
0.42
3.00
76,000.00
200.00
19.70
3,940.00
7
Tembilahan
Riau
4.00
0.90
2.40
112,000.00
330.00
19.31
6,372.30
8
P. Rupat
Riau
2.80
0.37
3.10
38,100.00
143.28
19.71
2,824.05
9
Kumpeh
Jambi
5.10
0.70
3.00
17,700.00
31.86
18.12
577.30
10
Air Hitam
Jambi
3.10
0.19
6.00
157,50.00
977.60
18.96
18,535.30
11
Dendang
Jambi
4.00
0.50
4.00
25,000.00
70.00
20.71
1,449.70
12
Air Sugihan
South Sumatera
23.10
0.0
1.50
7,200.00
9.72
15.29
148.61
13
Bayung Lincir
South Sumatera
5.60
0.25
3.50
45,000.00
59.33
20.91
1,240.59
14
Tulung Selapan
South Sumatera
0.0
0.0
3.50
12,000.00
292.80
18.00
5,270.40
15
Paloh
West Kalimantan
2.40
0.70
2.00
11,500.00
27.60
19.08
526.61
16
Sakura
West Kalimantan
1.70
0.60
3.00
17,500.00
99.97
18.19
1,818.45
17
Rasau Jaya/Pinang
West Kalimantan
2.10
0.30
3.40
44,000.00
165.00
20.89
3,446.85
18
Ketapang
West Kalimantan
3.20
0.80
2.10
75,000.00
240.00
20.88
5,011.20
19
Sungairaya
West Kalimantan
3.00
0.48
5.00
64,635.00
262.00
19.58
5,129.96
20
Kendawangan
West Kalimantan
5.60
0.90
1.50
77,000.00
14.25
19.86
283.01
21
Maraban
South Kalimantan
0.30
0.17
3.00
12,600.00
12.30
24.00
295.20
4.50
0.80
2.50
57,000.00
92.50
19.24
1,779.70
2.20
0.10
3.50
1,071.00
3.94
15.89
62.61
3.80
0.51
3.00
36,895.00
139.40
18.48
2,576.11
1.60
0.12
3.00
4,280.00
15.36
20.82
319.80
4.10
0.45
4.70
78,750.00
377.30
19.17
7,232.84
2.50
0.37
2.00
3,600.00
5.40
20.47
110.54
1.70
0.15
2.00
4,000.00
7.20
20.82
149.90
Central Kalimantan Central Kalimantan Central Kalimantan Central Kalimantan Central Kalimantan Central Kalimantan Central Kalimantan
22
Kanamit
23
Sampit
24
Sekajang
25
Kelampangan
26
Baung
27
Kota Besi
28
Berengbengkel
29
Muarakaman
East Kalimantan
10.50
0.90
2.00
5,579.00
16.85
15.06
253.76
30
Malangke
Sulawesi
3.10
0.31
0.50
1,250.00
1.25
20.71
25.89
133.5
12.23
86.5
1,256,070.06
4,938.26
582.91
97,925.13
Total Potential Indonesia
Note : Values of MJ/kg dry weight and MJ are those of thermal energy Sources : Rencana Induk Pengembangan Energi Baru dan Terbarukan 1997, Directorate General of Electricity and Energy Development, Ministry of Energy and Mineral Resources
102
ENERGY PRODUCTION AND CONSUMPTION V. ENERGY PRODUCTION AND CONSUMPTION IN INDONESIA
PENGKAJIAN ENERGI UNIVERSITAS INDONESI
103
104
Table 5.1
Production of Energy, 1997-2005
Type of Production
Unit
Crude Oil & Condensate
1997
1998
1999
2000
2001
2002
2003
2004
2005
Thousand barrel
576,962.57
568,782.26
545,579.06
517,488.69
489,306.41
456,944.00
418,593.46
347,356.42
341,904.43
Gas
MMSCF
3,166,034.90
2,978,851.90
3,068,349.06
2,901,378.73
2,807,149.95
3,041,872.71
3,155,243.12
3,030,132.06
2,985,340.96
LNG
tons
27,136,671.20
27,179,907.30
29,812,374.60
27,321,019.90
24,343,678.00
26,184,740.50
26,077,444.47
25,237,867.67
23,676,764.80
LPG
tons
2,786,651.80
2,343,944.20
2,263,518.10
2,087,669.10
2,187,676.70
2,113,881.00
1,927,318.28
2,016,001.24
1,818,899.82
Coal
tons
54,822,000.00
61,931,000.00
73,777,000.00
77,040,000.00
92,540,000.00
103,372,000.00
114,278,000.00
132,352,000.00
149,665,233.34
Sources: -
th
Directorate General of Oil & Gas, Oil & Gas Data Information, 6 Ed.,2002 Embassy of the United States of America Jakarta, Petroleum Report Indonesia : 2002-2003, March 2004 Indonesia Oil & Gas Statistics, 1995-2005 Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources Indonesia Mineral & Coal Statistics, 2000-2004, Directorate of Mineral and Coal Enterprises, Ministry of Energy and Mineral Resources Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources http:// dpmb.esdm.go.id
105
Table 5.2
Energy Supply by Type of Primary Energy, 1990-2004 (Thousand BOE)
Year
Crude Oil
1990
297,434.57
1991
307,149.74
1992 1993
%
Gas
%
Coal
%
Hydro
%
Geo
44.63
127,603.63
19.15
24,390.00
3.66
21,678.30
3.25
2,185.30
43.63
152,419.78
21.65
24,683.23
3.51
21,222.30
3.01
2,231.20
339,310.51
44.52
163,685.27
21.48
30,129.50
3.95
27,465.90
3.60
339,952.70
43.62
173,142.36
22.22
35,122.90
4.51
26,301.80
3.37
1994
348,163.40
42.23
207,075.78
25.12
35,135.21
4.26
25,737.50
1995
367,779.07
42.06
230,037.44
26.31
38,666.49
4.42
26,349.50
1996
401,355.42
43.26
239,484.78
25.81
46,090.80
4.97
1997
423,921.16
44.44
233,232.25
24.45
56,842.80
5.96
1998
393,762.49
43.11
207,184.27
22.68
61,000.80
1999
409,777.72
43.18
202,201.78
21.31
83,958.93
%
Biomass
%
Total
0.33
193,190.59
28.99
666,482.39
0.32
196,353.58
27.89
704,059.83
2,045.70
0.27
199,486.74
26.18
762,123.63
2,169.40
0.28
202,654.63
26.00
779,343.79
3.12
3,000.00
0.36
205,264.26
24.90
824,376.15
3.01
4,200.00
0.48
207,404.32
23.72
874,436.82
27,120.60
2.92
4,545.30
0.49
209,219.61
22.55
927,816.51
20,691.60
2.17
5,424.10
0.57
213,843.95
22.42
953,955.86
6.68
26,912.80
2.95
7,435.20
0.81
217,168.62
23.77
913,464.19
8.85
25,972.90
2.74
7,501.70
0.79
219,564.74
23.14
948,977.77
2000
451,235.18
44.78
204,633.82
20.31
93,831.55
9.31
25,111.40
2.49
9,179.10
0.91
223,613.99
22.19
1,007,605.03
2001
450,538.77
42.26
232,584.73
21.82
115,029.25
10.79
29,380.30
2.76
11,795.10
1.11
226,840.46
21.28
1,066,168.60
2002
464,507.34
41.79
251,431.61
22.62
122,879.41
11.06
29,843.80
2.68
12,199.99
1.10
230,641.23
20.75
1,111,503.38
2003
465,802.09
41.25
246,132.55
21.80
128,763.35
11.40
30,696.00
2.72
23,372.00
2.07
234,423.57
20.76
1,129,189.56
2004
510,349.41
44.87
181,277.82
15.94
151,524.50
13.32
32,401.20
2.85
24,856.40
2.19
237,065.44
20.84
1,137,474.77
Source: Handbook of Indonesia’s Energy Economy Statistics, 2005, Center for Energy Information, Department of Energy and Mineral Resources (Processed by PE UI using INOSYD)
106
Table 5.3
Energy Consumption by Type of Final Energy, 1990 – 2004 (Thousand BOE)
Year
Petroleum Fuels
%
Gas
%
Coal
%
LPG
%
Electricity
%
Biomassa
%
Total
1990
173,135.83
39.24
43,936.37
9.96
9,411.70
2.13
2,705.85
0.61
18,788.30
4.26
193,190.59
43.79
441,168.63
1991
184,874.13
40.19
43,491.56
9.45
11,058.08
2.40
3,082.43
0.67
21,167.64
4.60
196,353.58
42.68
460,027.42
1992
201,743.83
41.39
46,190.88
9.48
12,266.40
2.52
3,527.92
0.72
24,260.64
4.98
199,486.74
40.92
487,476.42
1993
218,904.86
42.59
48,164.84
9.37
13,940.96
2.71
4,133.57
0.80
26,132.07
5.08
202,654.63
39.43
513,930.92
1994
227,550.18
43.04
49,468.86
9.36
14,419.88
2.73
4,984.42
0.94
27,054.70
5.12
205,264.26
38.82
528,742.29
1995
245,233.21
43.92
52,562.90
9.41
16,924.33
3.03
5,862.35
1.05
30,366.46
5.44
207,404.32
37.15
558,353.58
1996
261,441.21
44.83
55,157.60
9.46
15,785.89
2.71
6,774.11
1.16
34,825.51
5.97
209,219.61
35.87
583,203.92
1997
275,272.59
44.94
61,007.99
9.96
16,395.21
2.68
6,977.41
1.14
39,022.44
6.37
213,843.95
34.91
612,519.58
1998
271,925.68
44.58
55,217.13
9.05
18,215.03
2.99
6,966.04
1.14
40,539.55
6.65
217,168.62
35.60
610,032.05
1999
290,414.95
43.73
75,420.40
11.36
27,425.06
4.13
7,517.14
1.13
43,764.31
6.59
219,564.74
33.06
664,106.60
2000
307,580.86
43.33
84,004.53
11.83
36,950.29
5.21
8,127.72
1.14
49,569.53
6.98
223,613.99
31.50
709,846.91
2001
319,170.37
43.48
89,628.48
12.21
38,269.63
5.21
8,280.44
1.13
51,840.99
7.06
226,840.46
30.90
734,030.36
2002
328,089.76
43.49
93,986.35
12.46
39,589.17
5.25
8,745.06
1.16
53,417.90
7.08
230,641.23
30.57
754,469.47
2003
330,623.73
43.44
90,734.74
11.92
40,954.11
5.38
8,910.36
1.17
55,472.80
7.29
234,423.57
30.80
761,119.31
2004
354,274.20
42.53
114,651.10
13.76
56,437.25
6.78
9,159.10
1.10
61,352.90
7.37
237,065.44
28.46
832,939.98
Source: Handbook of Indonesia’s Energy Economy Statistics, 2005, Center for Energy Information, Department of Energy and Mineral Resources (Processed by PE UI using INOSYD)
107
Table 5.4
Final Energy Consumption by Sector, 1990 – 2004 (Thousand BOE)
Year
Industry
%
Commercial
%
Residential
%
Transportation
%
Others
%
total
1990
72,563.39
33.25
6,218.00
2.85
45,997.00
21.08
76,183.17
34.91
17,242.12
7.90
218,203.67
1991
75,464.00
32.56
7,224.00
3.12
47,568.00
20.53
82,585.86
35.64
18,907.61
8.16
231,749.46
1992
85,822.25
33.75
8,317.00
3.27
49,221.00
19.36
91,208.57
35.87
19,695.17
7.75
254,264.00
1993
93,897.11
34.11
9,911.00
3.60
51,159.00
18.58
96,713.16
35.13
23,616.71
8.58
275,296.97
1994
104,488.85
35.67
10,834.00
3.70
53,443.00
18.24
98,186.85
33.52
25,992.16
8.87
292,944.86
1995
114,698.42
36.03
12,063.00
3.79
56,395.00
17.72
105,866.94
33.26
29,309.74
9.21
318,333.10
1996
115,294.09
34.16
13,538.00
4.01
59,451.00
17.62
116,188.58
34.43
33,018.47
9.78
337,490.14
1997
125,067.83
34.59
14,847.00
4.11
64,368.00
17.80
122,833.39
33.98
34,405.54
9.52
361,521.76
1998
123,833.29
34.78
14,961.00
4.20
68,154.00
19.14
123,558.40
34.71
25,493.37
7.16
356,000.05
1999
160,372.39
39.93
15,955.00
3.97
71,142.00
17.71
128,833.84
32.07
25,363.12
6.31
401,666.35
2000
184,118.43
41.81
17,176.00
3.90
75,542.00
17.15
137,440.30
31.21
26,138.12
5.93
440,414.85
2001
197,893.44
42.48
17,755.00
3.81
79,739.00
17.12
143,624.41
30.83
26,859.70
5.77
465,871.55
2002
197,932.16
41.57
18,394.00
3.86
83,160.00
17.47
149,107.28
31.32
27,525.35
5.78
476,118.79
2003
189,526.41
39.44
19,725.00
4.10
86,582.00
18.02
156,827.33
32.63
27,939.83
5.81
480,600.57
2004
241,152.26
43.82
21,698.00
3.94
89,087.00
16.19
169,788.99
30.85
28,597.21
5.20
550,323.47
Source: Handbook of Indonesia’s Energy Economy Statistics, 2005, Center for Energy Information, Department of Energy and Mineral Resources (Processed by PE UI using INOSYD)
108
Table 5.5
Petroleum Fuel Consumption by Sector, 1990 – 2004 (Thousand BOE)
Year
Industry
Commercial
Residential
Transportation
Others
Electricity
Total
1990
37,840.00
2,394.00
39,490.00
76,170.00
17,242.00
30,095.99
203,231.99
1991
40,384.00
3,028.00
39,997.00
82,557.00
18,908.00
34,104.65
218,978.65
1992
46,488.00
3,880.00
40,503.00
91,178.00
19,695.00
38,507.81
240,251.81
1993
52,551.00
4,970.00
41,104.00
96,663.00
23,617.00
41,905.06
260,810.06
1994
56,093.00
5,491.00
41,860.00
98,114.00
25,992.00
25,066.95
252,616.95
1995
61,525.00
5,962.00
42,655.00
105,781.00
29,310.00
19,713.88
264,946.88
1996
62,349.00
6,499.00
43,491.00
116,084.00
33,018.00
22,118.26
283,559.26
1997
64,836.00
6,854.00
46,469.00
122,711.00
34,406.00
30,436.03
305,712.03
1998
68,312.00
5,749.00
48,976.00
123,396.00
25,493.00
27,329.84
299,255.84
1999
79,719.00
5,824.00
50,847.00
128,662.00
25,363.00
31,077.57
321,492.57
2000
85,239.00
6,134.00
52,794.00
137,275.00
26,138.00
33,195.15
340,775.15
2001
87,507.00
6,226.00
55,094.00
143,484.00
26,860.00
35,676.09
354,847.09
2002
87,363.00
6,320.00
57,906.00
148,976.00
27,525.00
46,035.27
374,125.27
2003
79,434.00
6,414.00
60,137.00
156,698.00
27,940.00
50,308.36
380,931.36
2004
88,651.00
6,511.00
60,856.00
169,659.00
28,597.00
56,208.71
410,482.71
Source: Handbook of Indonesia’s Energy Economy Statistics, 2005, Center for Energy Information, Department of Energy and Mineral Resources (Processed by PE UI using INOSYD )
109
Table 5.6
Gas Consumption by Sector, 1990 – 2004 (Thousand BOE)
Year
Industry
Commercial
Residential
Transportation
Electricity
Total
1990
14,027.00
92.00
39.00
3.00
2,388.86
16,549.86
1991
11,407.00
103.00
40.00
18.00
2,296.72
13,864.72
1992
12,287.00
117.00
40.00
20.00
2,296.72
14,760.72
1993
11,975.00
131.00
41.00
40.00
10,465.47
22,652.47
1994
18,670.00
152.00
49.00
63.00
28,862.62
47,796.62
1995
19,639.00
172.00
58.00
74.00
39,517.75
59,460.75
1996
18,308.00
194.00
68.00
89.00
52,830.78
71,489.78
1997
23,462.00
208.00
74.00
103.00
40,996.93
64,843.93
1998
17,940.00
186.00
76.00
140.00
39,881.08
58,223.08
1999
32,117.00
194.00
74.00
147.00
42,495.52
75,027.52
2000
37,752.00
203.00
82.00
138.00
41,099.30
79,274.30
2001
47,891.00
206.00
89.00
111.00
39,946.81
88,243.81
2002
45,859.00
209.00
96.00
99.00
34,649.69
80,912.69
2003
44,211.00
212.00
104.00
97.00
33,101.00
77,725.00
2004
68,661.00
215.00
111.00
97.00
31,687.91
100,771.91
Source: Handbook of Indonesia’s Energy Economy Statistics, 2005, Center for Energy Information, Department of Energy and Mineral Resources (Processed by PE UI using INOSYD )
110
Table 5.7
Coal Consumption by Sector, 1990-2004 (Thousand BOE)
Year
Industry
Commercial
Residential
Transportation
Others
Electricity
Total
1990
9,243.00
0.00
0.00
0.00
0.00
14,013.66
23,256.66
1991
10,860.00
0.00
0.00
0.00
0.00
15,763.70
26,623.70
1992
12,047.00
0.00
0.00
0.00
0.00
15,763.70
27,810.70
1993
13,690.00
0.00
2.00
0.00
0.00
14,505.16
28,197.16
1994
14,151.00
0.00
13.00
0.00
0.00
16,949.10
31,113.10
1995
16,601.00
0.00
24.00
0.00
0.00
17,143.22
33,768.22
1996
15,473.00
0.00
36.00
0.00
0.00
24,417.00
39,926.00
1997
16,056.00
0.00
55.00
0.00
0.00
30,532.41
46,643.41
1998
17,829.00
0.00
72.00
0.00
0.00
32,593.65
50,494.65
1999
26,862.00
0.00
86.00
0.00
0.00
34,983.07
61,931.07
2000
36,215.00
0.00
88.00
0.00
0.00
40,259.25
76,562.25
2001
37,508.00
0.00
91.00
0.00
0.00
42,993.54
80,592.54
2002
38,802.00
0.00
94.00
0.00
0.00
43,075.26
81,971.26
2003
40,140.00
0.00
97.00
0.00
0.00
46,771.31
87,008.31
2004
55,344.00
0.00
99.00
0.00
0.00
47,238.50
102,681.50
Source: Handbook of Indonesia’s Energy Economy Statistics, 2005, Center for Energy Information, Department of Energy and Mineral Resources (Processed by PE UI using INOSYD )
111
Table 5.8a Petroleum Fuel Sales in Residential Sector, 2000-2005 2000 Volume (kl)
2001 Percent (%)
Volume (kl)
2002
Percent (%)
Volume (kl)
2003 Percent (%)
Volume (kl)
2004 Percent (%)
Volume (kl)
2005 Percent (%)
Volume (kl)
Percent (%)
Premium
0
0.00
0
0.00
0
0.00
0
0.00
0
0.00
0
0.00
Kerosene
12,409,142
100.00
8,172,429
100.00
11,622,937
100.00
11,704,403
100.00
11,787,354
100.00
11,294,676
100.00
Automotive Diesel Oil
0
0.00
0
0.00
0
0.00
0
0.00
0
0.00
0
0.00
Intermediate Diesel Oil
0
0.00
0
0.00
0
0.00
0
0.00
0
0.00
0
0.00
Fuel Oil
0
0.00
0
0.00
0
0.00
0
0.00
0
0.00
0
0.00
12,409,142
100
8,172,429
100
11,622,937
100
11,704,403
100
11,787,354
100
11,294,676
100
TOTAL
Source: Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources (Processed)
Table 5.8b Petroleum Fuel Sales in Transportation Sector, 2000-2005 2000 Volume (kl) Premium & Special Premium Kerosene Automotive Diesel Oil Intermediate Diesel Oil Fuel Oil TOTAL
2001 Percent (%)
Volume (kl)
2002 Percent (%)
Volume (kl)
2003 Percent (%)
Volume (kl)
2004 Percent (%)
Volume (kl)
2005 Percent (%)
Volume (kl)
Percent (%)
12,874,043
50.71
11,490,034
49.06
14,096,529
51.76
14,647,489
54.77
17,027,444
56.51
17,828,528
58.81
0
0.00
0
0.00
0
0.00
0
0.00
0
0.00
0
0.00
12,152,821
47.87
9,774,706
41.73
12,675,523
46.54
12,108,939
43.95
12,816,785
42.54
12,132,616
40.02
139,530
0.55
1,960,756
8.37
122,517
0.45
85,878
0.31
51,995
0.17
71,814
0.24
221,365
0.87
196,933
0.84
339,230
1.25
267,803
0.97
233,982
0.78
281,316
0.93
25,387,759
100
23,422,429
100
27,233,798
100
27,553,352
100
30,130,206
100
30,314,274
100
Source: Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources (Processed)
112
Table 5.8c Petroleum Fuel Sales in Industry Sector, 2000-2005 2000 Volume (kl)
2001 Percent (%)
Volume (kl)
2002 Percent (%)
Volume (kl)
2003 Percent (%)
Volume (kl)
2004 Percent (%)
Volume (kl)
2005 Percent (%)
Volume (kl)
Percent (%)
Premium
0
0.00
0
0.00
0
0.00
0
0.00
0
0.00
0
0.00
Kerosene
48,634
0.40
2,339,809
21.10
52,953
0.43
48,440
0.48
58,765
0.44
90,906
0.77
Automotive Diesel Oil
6,674,515
54.95
5,104,186
46.02
7,010,072
57.18
5,682,776
56.57
8,956,069
66.37
8,505,760
72.11
Intermediate Diesel Oil
1,308,278
10.77
1,566,295
14.12
1,198,555
9.78
1,063,634
10.59
1,007,715
7.47
807,141
6.84
4,115,835
33.88
2,081,063
18.76
3,997,918
32.61
3,251,247
32.36
3,472,210
25.73
2,391,854
20.28
12,147,262
100
11,091,353
100
12,259,498
100
10,046,097
100
13,494,759
100
11,795,661
100
Fuel Oil TOTAL
Source: Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources (Processed)
Table 5.8d Petroleum Fuel Sales in Electricity Sector, 2000-2005 2000 Volume (kl) Premium Kerosene Automotive Diesel Oil Intermediate Diesel Oil Fuel Oil TOTAL
0
2001
Percent (%) 0.00
Volume (kl)
2002 Percent (%)
0
Volume (kl)
0.00
0
2003
2004
Percent (%)
Volume (kl)
Percent (%)
0.00
0
0.00
Volume (kl) 0
2005
Percent (%) 0.00
Volume (kl) 0
Percent (%) 0.00
0
0.00
0
0.00
0
0.00
0
0.00
0
0.00
0
0.00
3,244,920
64.79
9,836,012
89.42
4,589,987
70.09
5,122,023
65.23
4,589,987
70.09
6,832,053
75.89
24,360
0.49
26,394
0.24
38,474
0.59
33,720
0.43
38,474
0.59
16,255
0.18
1,739,012
34.72
1,137,735
10.34
1,920,478
29.33
2,696,366
34.34
1,920,478
29.33
2,154,715
23.93
5,008,292
100
11,000,141
100
6,548,939
100
7,852,109
100
6,548,939
100
9,003,023
100
Source: Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources (Processed)
113
Table 5.9a Petroleum Fuel Sales per Region, 2003 KiloLiter
No 1
2
UPMS I
4
UPMS IV
UPMS V
UPMS VI
UPMS VII
UPMS VIII
TOTAL
1,791,598
996,157
5,047,512
1,889,029
2,897,290
863,052
944,000
218,851
14,647,489
a. Transportation
1,791,598
996,157
5,047,512
1,889,029
2,897,290
863,052
944,000
218,851
14,647,489
Kerosene
1,485,584
773,161
3,881,577
1,503,017
2,376,466
803,523
673,729
256,052
11,753,109
a. Residential
1,484,357
771,619
3,855,972
1,493,208
2,369,530
803,142
671,411
255,164
11,704,403
1,227
1,542
25,605
9,809
6,936
115
2,318
888
48,440
Automotive Diesel Oil
4,440,567
2,178,744
5,368,028
2,498,723
4,316,072
3,254,999
1,227,407
779,918
24,064,458
a. Residential
2,091,808
1,146,818
3,125,551
1,395,132
2,398,340
1,042,750
712,853
195,687
12,108,939
b. Industry
1,317,189
5,143
1,809,604
336,657
72,295
1,542,526
213,561
385,801
5,682,776
c. Electricity
1,031,570
405,352
432,873
766,934
1,316,148
669,723
300,993
198,430
5,122,023
Intermediate Diesel Oil
46,828
51,017
721,889
62,197
224,236
8,501
68,810
1,183,478
a. Residential
11,562
6,315
24,438
4,790
32,480
782
5,511
85,878
b. Industry
35,266
22,235
690,336
53,269
191,756
7,473
63,299
1,063,634
22,467
7,115
4,138
1,018,800
233,714
2,523,460
799,454
1,487,101
41,105
111,782
19,561
1,967
117,341
14,644
96,700
7,331
10,259
267,803
b. Industry
568,185
158,212
1,663,441
284,483
515,940
33,774
27,212
3,251,247
c. Electricity
431,054
73,535
742,678
500,327
874,461
74,311
2,696,366
8,783,377
4,232,793
17,542,466
6,752,420
11,301,165
c. Electricity Fuel Oil 5
UPMS III
Premium
b. Industry
3
UPMS II
a. Residential
TOTAL
-
-
33,720
4,971,180
3,025,728
150
1,254,971
6,215,566
57,864,100
Source: Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
114
Table 5.9b Petroleum Fuel Sales per Region, 2004 KiloLiter
No 1
2
UPMS I
UPMS II
UPMS III
UPMS IV
UPMS V
Premium
2,086,945
1,172,962
5,490,179
2,197,943
3,163,435
992,303
1,056,125
258,124
16,418,016
a. Transportation
1,791,598
996,157
5,047,512
1,889,029
2,897,290
863,052
944,000
218,851
14,647,489
Kerosene
1,472,827
764,692
3,885,584
1,534,633
2,451,421
807,805
674,425
254,732
11,846,119
a. Residential
1,471,105
759,889
3,857,708
1,526,907
2,440,564
806,489
671,929
252,763
11,787,354
1,722
4,803
27,876
7,726
10,857
1,316
2,496
1,969
58,765
Automotive Diesel Oil
4,865,958
2,522,241
5,987,186
2,805,216
4,452,888
3,666,160
1,341,500
846,602
26,487,751
a. Residential
2,216,996
1,331,509
3,147,180
1,533,987
2,262,171
1,190,294
747,565
387,083
12,816,785
b. Industry
1,441,144
778,411
2,524,151
1,251,695
663,174
1,793,934
261,373
242,187
8,956,069
c. Electricity
1,207,818
412,321
315,855
19,534
1,527,543
681,932
332,562
217,332
4,714,897
41,188
56,879
675,162
58,527
192,451
10,882
58,325
0
1,093,414
8,914
5,851
140
7,228
23,802
167
5,893
0
51,995
32,274
23,852
668,494
51,299
168,649
10,715
52,432
0
1,007,715
0
27,176
6,528
0
0
0
0
0
33,704
936,155
230,115
2,411,564
713,817
1,269,018
77,048
116,790
0
5,754,507
19,698
3,824
76,126
14,543
104,777
5,410
9,604
0
233,982
b. Industry
534,879
215,042
1,491,160
699,274
422,019
71,638
38,198
0
3,472,210
c. Electricity
381,578
11,249
844,278
0
742,222
0
68,988
0
2,048,315
9,403,073
4,746,889
18,449,675
7,310,136
11,529,213
5,554,198
3,247,165
1,359,458
61,599,807
b. Industry
3
Intermediate Diesel Oil 4
a. Residential b. Industry c. Electricity Fuel Oil
5
a. Residential
TOTAL
UPMS VI
UPMS VII
UPMS VIII
TOTAL
Source: Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
115
Table 5.9c Petroleum Fuel Sales per Region, 2005 KiloLiter
No 1
2
UPMS I
UPMS II
UPMS III
UPMS IV
UPMS V
UPMS VI
UPMS VII
UPMS VIII
Premium
2,258,790
1,266,535
5,940,065
2,289,072
3,334,077
1,042,826
1,078,367
270,595
17,480,327
a. Transportation
1,791,598
996,157
5,047,512
1,889,029
2,897,290
863,052
944,000
218,851
14,647,489
Kerosene
1,375,586
768,711
3,765,451
1,450,594
2,382,302
778,884
625,702
238,353
11,385,582
a. Residential
1,372,295
761,068
3,738,166
1,444,133
2,363,974
777,191
607,057
230,793
11,294,676
3,291
7,643
27,285
6,461
18,328
1,693
18,646
7,560
90,906
Automotive Diesel Oil
4,880,971
2,377,763
6,078,870
2,769,377
5,235,136
3,860,891
1,486,372
781,050
27,470,430
a. Residential
2,240,741
1,121,411
3,061,296
1,503,323
2,330,795
1,061,353
676,341
137,356
12,132,616
b. Industry
1,308,615
1,114,924
1,924,863
388,844
760,654
2,084,373
505,371
418,116
8,505,760
c. Electricity
1,331,615
141,428
1,092,711
877,210
2,143,687
715,164
304,660
225,578
6,832,053
Intermediate Diesel Oil
36,659
34,796
590,118
53,598
150,425
10,692
18,923
0
895,210
a. Residential
10,245
3,259
16,455
5,330
30,610
993
4,922
0
71,814
b. Industry
26,414
20,324
572,913
43,976
119,815
9,699
14,001
0
807,141
0
11,213
750
4,292
0
0
0
0
16,255
824,692
204,491
1,787,696
628,083
1,205,791
32,352
144,780
0
4,827,884
25,979
15,240
99,444
11,357
90,751
10,603
27,942
0
281,316
b. Industry
311,725
188,701
1,276,568
189,760
337,329
21,748
66,022
0
2,391,854
c. Electricity
486,988
550
411,683
426,966
777,712
0
50,816
0
2,154,715
9,376,698
4,652,296
18,162,199
7,190,724
12,307,732
5,725,643
3,354,144
1,289,997
62,059,433
b. Industry
3
4
c. Electricity Fuel Oil 5
a. Residential
TOTAL
TOTAL
Source: Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
116
Table 5.10 Crude Oil Production by Production Schemes, 1995 – 2005 (Barrel)
Year Annually 1995
Daily Average Annually
1996
Daily Average Annually
1997
Daily Average Annually
1998
Daily Average Annually
1999
Daily Average Annually
2000
Daily Average Annually
2001
Daily Average Annually
2002
Daily Average Annually
2003
Daily Average Annually
2004
Daily Average Annually
2005
Daily Average
Pertamina
Production Sharing Contractors
Total
20,656,779.00
464,193,521.00
484,850,300.00
56,594.00
1,271,763.00
1,328,357.00
37,577, 840.00
447,995,960.00
485,573,800.00
102,670.00
1,224,030.00
1,326,700.00
38,942,558.00
445,398,042.00
484,340,600.00
106,692.00
1,220,269.00
1,326,961.00
43,570,517.00
436,539,183.00
480,109,700.00
119,371.00
1,195,998.00
1,315,369.00
40,984,592.00
399,476,972.00
440,461,564.00
112,287.00
1,094,457.00
1,206,744.00
45,726,352.00
419,699,983.00
465,426,335.00
124,935.00
1,146,721.00
1,271,657.00
46,101,364.00
395,072,849.00
441,174,213.00
129,882.00
1,082,391.00
1,212,273.00
42,569,440.00
364,952,958.00
407,522,398.00
118,904.00
999,871.00
1,118,775.00
41,512,127.00
328,053,059.00
369,565,186.00
113,731.85
898,775.50
1,012,507.36
41,010,652.00
306,148,281.00
347,158,933.00
112,358.00
838,762.00
951,120.00
41,877,493.00
299,325,102.00
341,202,595.00
114,733.00
820,069.00
934,802.00
Sources : Indonesia Oil and Gas Statistics, 1995-2005 Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources Oil & Gas Statistics of Indonesia 2000-2004, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
117
Table 5.11
Condensate Production by Production Scheme, 1995 – 2005 (Barrel)
Year
1995
1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
Annually Daily Average Annually Daily Average Annually Daily Average Annually Daily Average Annually Daily Average Annually Daily Average Annually Daily Average Annually Daily Average Annually Daily Average Annually Daily Average Annually Daily Average
Pertamina
Production Sharing Contractors
Total
349,597.00
61,776,824.00
62,126,421.00
958
169,252.00
170,210.00
59,560.00
63,014,920.00
63,074,480.00
160
172,640.00
172,800.00
46,465.00
59,365,544.00
59,412,009.00
127
162,645.00
162,772.00
137,596.00
54,644,672.00
54,782,268.00
377
149,711.00
150,048.00
209,168.00
53,972,181.00
54,181,349.00
573
147,869.00
148,442.00
720,149.00
51,400,608.00
52,120,757.00
1,968.00
140,439.00
142,407.00
214,828.00
47,917,367.00
48,132,195.00
589
131,280.00
131,869.00
99,525.00
48,002,723.00
48,102,248.00
273
131,514.00
131,787.00
103,200.00
48,742,844.00
48,846,044.00
282.74
133,542.04
133,824.78
197,489.00
46,975,415.00
47,172,904.00
539.59
128,348.13
128,887.72
701,838.00
45,749,079.00
46,450,917.00
1,923.00
125,340.00
127,263.00
Sources : Oil & Gas Statistics of Indonesia 2000-2004, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources Oil & Gas Statistics of Indonesia 2000-2004, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
118
Table 5.12
Production of Naphtha and LSWR by Refinery, 1996 – 2005 (Barrel)
Refinery Year
1996 1997 1998 1999 2000 2001 2002 2003 2004 2005
Products Naphtha LSWR Naphtha LSWR Naphtha LSWR Naphtha LSWR Naphtha LSWR Naphtha LSWR Naphtha LSWR Naphtha LSWR Naphtha LSWR Naphtha LSWR
Sub Total Naphtha Sub Total LSWR Total Non-Fuels Products
P.Brandan
Kasim
Total
Dumai
S.Pakning
Musi
Cilacap
Balikpapan
Balongan
Cepu
259,462 0 242,164 0 70,761 0 614,776 0 667,074 0 73,338 0 0 0 20,295 0
291,271 3,689,236 396,644 9,826,160 227,506 4,767,558 399,559 5,509,723 620,226 5,693,507 213,870 4,855,527 0 2,560,153 0 2,618,638
0 5,066,437 0 4,805,368 0 3,483,279 0 2,581,395 0 3,333,620 0 2,860,161 0 3,051,234 0 3,885,279
23,339 16,340,893 36,733 16,106,174 87,336 9,673,835 95,346 7,650,353 135,714 3,827,181 2,634,839 6,957 0 488,043 4,299,733 2,302,857
9,586,766 1,055,438 3,035,678 914,340 2,305,760 657,337 4,998,137 1,056,766 9,023,638 1,177,562 10,332,709 2,716,652 0 439,179 9,668,298 1,624,280
4,453,184 23,255,328 4,475,643 21,504,036 3,359,049 22,275,944 3,058,849 21,912,179 6,172,462 24,585,961 6,925,713 22,919,190 31,033 21,106,172 4,165,440 20,737,635
0 0 0 0 0 2,234,290 0 0 0 0 0 0 0 0 0 0
0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
0 0 0 0 0 239,751 40,752 0 28,240 0 0 866,586 0 717,730 0 1,016,373
14,614,022 49,407,332 8,186,862 53,156,078 6,050,412 43,331,994 9,207,419 38,710,416 16,647,354 38,617,831 20,180,469 34,225,073 31,033 28,362,511 18,153,766 32,185,062
314,654 0 2,262,524 0 2,262,524
0 1,935,875 0 0 2,149,076 41,456,377 43,605,453
0 4,385,352 965,725 7,829,198 965,725 41,281,323 42,247,048
3,601,827 802,850 4,511,650 276,891 15,426,517 57,476,034 72,902,551
8,204,852 2,081,510 10,185,687 1,378,815 67,341,525 13,101,879 80,443,404
6,671,033 18,921,161 5,238,579 18,539,881 44,550,985 215,757,487 260,308,472
0 0 0 0 0 2,234,290 2,234,290
0 0 0 0 0 0 0
0 1,061,869 0 939,856 68,992 4,842,165 4,911,157
18,477,712 29,188,617 21,216,295 28,964,641 132,765,344 376,149,555 508,914,899
Sources : Indonesia Oil & Gas Statistics 1996-2002, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources, 2006
119
Table 5.13a Production of various Fuels by Refinery, 2003 (Barrel)
Refineries Fuels Products
Total P.Brandan
Dumai
S.Pakning
Musi
Cilacap
Balikpapan
Balongan
Cepu
Kasim
1. JP-5
0
0
0
0
0
0
0
0
0
0
2. Avgas
0
0
0
72,351
0
0
0
0
0
72,351
3. Avtur
0
2,528,517
0
687,185
3,363,683
4,124,217
0
0
0
10,703,602
4. Premium
0
8,670,509
0
6,984,283
23,220,352
13,660,366
16,510,633
0
526,987
69,573,130
5. Kerosene
336,449
6,160,934
2,274,871
5,815,385
23,124,978
16,202,299
3,911,199
174,348
555,627
58,556,090
6. Gas Oil/ ADO/ HSD
174,503
24,559,224
2,834,910
8,341,619
23,201,178
25,777,277
8,654,278
220,764
744,983
94,508,736
0
1048
0
443,232
5,426,958
611,918
1,311,961
0
0
7,795,117
52,046
54,167
0
8,431,800
23,179,382
340
2,159,718
0
0
33,877,453
9. Pertamax plus
0
0
0
0
0
0
495,861
0
0
495,861
10.Pertamax
0
0
0
232,200
0
30,640
2,357,879
0
0
2,620,719
562,998
41,974,399
5,109,781
31,008,055
101,516,531
60,407,057
35,401,529
395,112
1,827,597
278,203,059
7. Diesel Oil/ IDO/ MDF 8. Fuel Oil/ DCO/ IFO/ MFO
Sub Total Converted from kiloLiter
Source : Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
120
Table 5.13b Production of various Fuels by Refinery, 2004 (Barrel)
Refineries Fuels Products
Total P.Brandan
Dumai
S.Pakning
Musi
Cilacap
Balikpapan
Balongan
Cepu
Kasim
1. JP-5
0
0
0
0
0
0
0
0
0
0
2. Avgas
0
0
0
32,248
0
0
0
0
0
32,248
3. Avtur
0
2,625,419
0
621,005
3,185,872
4,783,701
0
0
0
11,215,997
4. Premium
0
8,791,612
0
7,775,338
22,747,609
15,151,474
16,952,659
0
523,462
71,942,154
5. Kerosene
281,846
5,739,851
2,653,849
5,818,757
19,617,295
17,018,205
4,963,520
168,623
562,465
56,824,412
6. Gas Oil/ ADO/ HSD
159,088
24,362,779
2,943,891
7,730,101
23,993,524
28,123,212
10,372,352
221,854
745,681
98,652,481
16,058
82
0
445,878
8,112,892
496,058
1,132,151
0
0
10,203,119
8. Fuel Oil/ DCO/ IFO/ MFO
0
648
0
8,143,901
20,961,727
4,164
1,854,101
0
0
30,964,541
9. Pertamax plus
0
0
0
0
0
0
303,162
0
0
303,162
10. Pertamax
0
0
0
351,895
0
151,502
2,534,047
0
0
3,037,445
456,992
41,520,391
5,597,740
30,919,122
98,618,919
65,728,316
38,111,993
390,477
1,831,609
283,175,558
7. Diesel Oil/ IDO/ MDF
Sub Total Converted from kiloLiter
Source : Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
121
Table 5.13c Production of various Fuels by Refinery, 2005 (Barrel)
Refineries Total
Fuels Products P.Brandan
Dumai
S.Pakning
Musi
Cilacap
Balikpapan
Balongan
Cepu
Kasim
1. JP-5
0
0
0
0
0
0
0
0
0
0
2.
0
0
0
33,814
0
0
0
0
0
33,814
3. Avtur
0
2,583,548
0
691,664
2,802,628
4,609,052
0
0
0
10,686,892
4. Premium
0
7,861,068
0
8,033,855
20,166,508
16,831,920
17,660,576
0
464,634
71,018,560
5. Kerosene
340,523
5,920,639
2,629,382
6,062,436
17,075,738
16,461,482
4,552,991
187,078
494,517
53,724,786
6. Gas Oil/ ADO/ HSD
163,497
23,158,704
2,835,008
6,410,558
22,761,491
28,180,373
10,186,847
221,024
722,767
94,640,268
16,058
138
0
255,234
7,088,768
246,585
968,711
0
0
8,575,494
8. Fuel Oil/ DCO/ IFO/ MFO
0
296
0
6,036,214
20,143,040
4,220
1,570,494
0
0
27,754,265
9. Pertamax plus
0
0
0
0
0
0
431,870
0
0
431,870
10. Pertamax
0
0
0
110,342
0
87,523
1,502,023
0
0
1,699,888
520,078
39,524,392
5,464,390
27,634,117
90,038,173
66,421,156
36,873,512
408,101
1,681,918
268,565,837
Avgas
7. Diesel Oil/ IDO/ MDF
Sub Total Converted from kiloLiter
Source : Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
122
Table 5.14a Production of Oil and Gas by Refinery, 2003
Crude Oil
Condensate
Imported Crude Oil
Thousand Barrel
Thousand Barrel
Thousand Barrel
LNG Billion BTU
LPG Thousand Barrel
Thousand ton
Thousand Barrel
51.50
553.625
A. OIL REFINERY P. Brandan
961.64
0
0.00
0
0
Dumai
45,945.78
0
0.00
0
0
Sei Pakning
17,140.15
0
0.00
0
0
Musi
41,102.46
0
0.00
0
0
102.97
1106.8738
Cilacap
37,213.18
0
88,080.88
0
0
162.72
1749.2508
Balikpapan
42,213.44
0
46,035.71
0
0
128.42
1380.472
Balongan
36,259.88
0
462.68
0
0
333.34
3583.3728
778.94
8373.5943
822.13
0
0.00
0
0
3,091.30
0
0.00
0
0
224,749.94
0.00
134,579.28
0
0
Arun
0
0
0
328,312.49
87,878.08
0.00
Badak
0
0
0
1,019,036.44
273,346.69
843.39
Mundu
0
0
0
0
0
12.55
Tanjung Santan
0
0
0
0
0
155.38
Jabung
0
0
0
0
0
67.26
Arjuna
0
0
0
0
0
25.80
Arar
0
0
0
0
0
0.77
Sumbagut
0
0
0
0
0
38.90
SUB TOTAL
0
0
0
1,347,348.93
361,224.76
1,148.38
TOTAL
0
0
0
1,347,348.93
361,224.76
1,927.32
Cepu Kasim SUB TOTAL B. GAS REFINERY
Sources : Indonesia Oil and Gas Statistics, 2003, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
123
Table 5.14b Production of Oil and Gas by Refinery, 2004
Crude Oil
Condensate
Imported Crude Oil
Thousand Barrel
Thousand Barrel
Thousand Barrel
LNG Billion BTU
LPG Thousand Barrel
Thousand ton
Thousand Barrel
63.25
679.937
A. OIL REFINERY P. Brandan
961.64
0
0.00
0
0
Dumai
45,945.78
0
0.00
0
0
Sei Pakning
17,140.15
0
0.00
0
0
Musi
41,102.46
0
0.00
0
0
134.28
1,443.47
Cilacap
37,213.18
0
88,080.88
0
0
148.11
1,592.21
Balikpapan
42,213.44
0
46,035.71
0
0
120.32
1,293.39
Balongan
36,259.88
0
462.68
0
0
430.44
4,627.24
896.40
9,636.25
822.13
0
0.00
0
0
3,091.30
0
0.00
0
0
224,749.94
0.00
134,579.28
0
0
Arun
0
0
0
292,928.27
78,406.92
0.00
0.00
Badak
0
0
0
1,010,988.93
271,188.02
854.14
9,886.19
Mundu
0
0
0
0
0
9.46
101.66
Tanjung Santan
0
0
0
0
0
0.00
0.00
Jabung
0
0
0
0
0
68.98
859.52
Arjuna
0
0
0
0
0
147.22
1,736.01
Arar
0
0
0
0
0
1.47
18.36
Sumbagut
0
0
0
0
0
38.34
412.12
SUB TOTAL
0
0
0
1,303,917.20
349,594.94
1,119.61
13,013.40
TOTAL
0
0
0
1,303,917.20
349,594.94
2,016.00
22,649.64
Cepu Kasim SUB TOTAL B. GAS REFINERY
Sources : Indonesia Oil and Gas Statistics, 2004, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
124
Table 5.14c Production of Oil and Gas by Refinery, 2005
Crude Oil
Condensate
Imported Crude Oil
Thousand Barrel
Thousand Barrel
Thousand Barrel
LNG Billion BTU
LPG Thousand Barrel
Thousand ton
Thousand Barrel
71.37
767.23
A. OIL REFINERY P. Brandan
896.97
0
0
0
0
Dumai
42,087.33
0
0
0
0
Sei Pakning
17,888.34
0
0
0
0
Musi
36,399.54
0
0
0
0
139.68
1,501.56
Cilacap
24,095.05
1,090.38
85,372.98
0
0
118.39
1,272.68
Balikpapan
45,785.15
2,406.96
42,030.25
0
0
99.14
1,065.74
Balongan
41,795.67
0
193.84
0
0
404.14
4,344.49
832.72
8,951.71
903.96
0
0.00
0
0
2,843.29
0
0.00
0
0
212,695.29
3,497.34
127,597.07
0
0
Arun
0
0
0
217,529.28
58,225.18
0.00
0.00
Badak
0
0
0
1,005,610.72
269,745.36
770.20
8,961.84
Mundu
0
0
0
0
0
5.96
64.06
Tanjung Santan
0
0
0
0
0
127.36
1,503.66
Jabung
0
0
0
0
0
56.24
700.41
Arjuna
0
0
0
0
0
0.00
0.00
Arar
0
0
0
0
0
0.00
0.00
Sumbagut
0
0
0
0
0
26.43
284.10
SUB TOTAL
0
0
0
1,223,140.00
327,970.55
995.10
11,514.07
TOTAL
0
0
0
1,223,140.00
327,970.55
1,827.81
20,465.78
Cepu Kasim SUB TOTAL B. GAS REFINERY
Source: Indonesia Oil and Gas Statistics, 2005, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
125
Table 5.15
Natural Gas Production by Production Scheme, 1995 – 2005
(Barrel)
Year 1996
1997
1998
1999
2000
2001
2002
2003
2004
2005
Pertamina Annually Daily Average Annually Daily Average Annually Daily Average Annually Daily Average Annually Daily Average Annually Daily Average Annually Daily Average Annually Daily Average Annually Daily Average Annually Daily Average
Pertamina-JOB
Pertamina-TAC
PSC
Total
279,163,623
35,114,369
28,303,436
2,821,434,761
3,164,016,189
764,832
96,204
77,544
7,729,958
8,668,538
279,511,569
34,783,553
26,154,729
2,825,585,041
3,166,034,892
765,785
95,297
71,657
7,741,329
8,674,068
270,329,833
37,613,772
29,460,354
2,641,447,914
2,978,851,873
740,630
103,051
80,713
7,236,844
8,161,238
259,131,635
34,239,136
34,213,979
2,740,764,314
3,068,349,064
709,950
93,806
93,737
7,508,943
8,406,436
285,691,770
33,186,444
27,604,880
2,554,895,640
2,901,378,734
782,717
90,922
75,630
6,999,714
7,948,983
276,790,580
32,675,517
37,243,630
2,460,440,226
2,807,149,953
758,330
89,522
102,037
6,740,932
7,690,822
258,012,265
36,999,407
39,733,464
2,707,127,571
3,041,872,707
706,883
101,368
108,859
165,915,572
166,832,682
264,658,030
32,376,560
203,016,436
2,819,735,938
3,319,786,964
725,090
88,703
556,209
7,725,304
9,095,307
301,856,580
27,544,471
54,470,370
2,655,764,844
3,039,636,265
827,004
75,464
149,234
7,276,068
8,327,771
308,000,980
23,962,781
37,293,334
2,605,729,121
2,974,986,216
843,838
65,652
130,542
7,138,984
8,179,016
Source : Indonesia Oil and Gas Statistics, 1995-2002, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources, 2006
126
Table 5.16
Production and Utilization of Natural Gas, 1999-2005 (MMSCF)
1999
2000
2001
2002
2003
2004
2005
Gas Production
3,066,349.00
2,901,302.00
2,807,150.00
3,041,852.00
3,073,482.00
3,030,132.06
2,985,340.96
Utilization (incl. Export)
2,575,131.00
2,728,172.00
2,623,725.00
2,856,637.00
2,900,581.00
2,678,791.43
2,592,511.71
0.84
0.94
0.93
0.94
0.94
385,887
397,163
382,583
372,446
353,612
311,869.35
315,067.71
8,253
14,936
10,397
26,901
28,141
34,098.78
24,578.61
41,911
32,227
29,437
30,879
22,995
20,496.73
16,154.70
238,797
255,178
230,140
268,129
254,222
196,150.83
196,775.08
2,048
2,822
3,411
2,737
2,884
175,334
223,564
254,237
199,765
182,573
46,944
62,560
86,295
148,957
158,921
131,990
155,357
102,915
64,824
125,815
1,543,967
1,584,365
1,524,310
1,741,999
1,771,418
60%
58%
58%
61%
61%
1,031,164
1,143,807
1,099,415
1,114,638
1,129,163
40%
42%
42%
39%
39%
458,184
137,671
179,371
154,943
172,901
15%
5%
6%
5%
6%
( % Utilization ) - Own use - LPG/ Lex Plant - Refinery - Fertilizer/ Petrochemical - Cement Industry - Electricity - PT PGN (Persero) - Others Industry Exports ( % Exports ) Domestic Utilization (% Domestic Utilization) Losses/ Flared ( % Losses )
283,381.65
594,666.90
131,786
157,532
Source: Oil & Gas Statistics of Indonesia 1999 – 2005, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
127
Table 5.17
Production of LNG, 1999 – 2005 Year
Refinery
Unit 1999 Barrel MMSCF
ARUN
3
m
MMBtu ton Barrel MMSCF BADAK
3
m
MMBtu Ton Barrel MMSCF Total
3
m
MMBtu Ton
158,142,836.48
2000 92,892,616.35
2001 41,553,057.00
2002 86,427,144.65
2003 87,878,075.48
2004 78,406,924.51
2005 58,225,181.06
529,462.22
311,004.48
139,120.00
289,508.74
294,215.80
262,506.38
194,937.91
25,144,711.00
14,769,926.00
6,606,936.00
13,749,071.00
13,972,614.00
12,466,701.00
9,257,803.79
590,821,637.09
347,046,814.69
155,242,219.00
323,059,932.43
328312490
292,928,270.02
217,529,276.44
11,416,606.73
6,706,079.73
2,999,788.00
6,242,574.69
6,344,071.29
5,660,332.39
4,203,377.21
254,818,169.81
285,558.150.94
295,655,566.00
276,238,880.50
273,346,685.54
271,188,018.87
269,745,364.93
249,028.60
951,451.20
985,095.00
920,400.33
910,763.82
903,571.36
898,764.58
40,516,089.00
45,403,746.00
47,009,235.00
43,921,982.00
43,462,123.00
43,118,895.00
42,889,513.02
949,962,137.05
1,064,560,786.72
1,102,203,950.00
1,029,818,546.52
1,019,036,443.67
1,010,988,934.34
1,005,610,720.45
18,395,767.38
20,614,940.15
21,343,890.00
19,942,165.79
19733373.2
19,577,535.28
19,473,387.59
412,961,006.29
378,450,767.29
337,208,623.00
362,666,025.15
361,224,761.02
349,594,943.38
327,970,545.99
1,378,490.88
1,262,455.68
1,124,215.00
1,209,909.07
1204979.618
1,166,077.74
1,093,702.49
65,660,800.00
60,173,672.00
53,616,171.00
57,671,053.00
57,434,737.00
55,585,596.00
52,147,316.81
1,540,783,774.14
1,411,607,601.41
1,257,446,169.00
1,352,878,478.95
1347348934
1,303,917,204.36
1,223,139,996.89
29,812,374.12
27,321,019.88
24,343,678.00
26,184,740.48
26,077,444.47
25,237,867.67
23,676,764.80
Source : Indonesia Oil and Gas Statistics, 1999-2002, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
128
Table 5.18
Production of LPG, 2001 – 2005 (tons)
Type of Refinery
Products
2001
2002
2003
2004
2005
A. Gas Refinery Arun
Badak
Butane
0.00
0.00
0.00
0.00
0.00
Propane
0.00
0.00
0.00
0.00
0.00
Butane
510,553.00
381,872.12
409,490.13
440,857.69
369,832.86
Propane
552,469.00
441,561.02
433,902.17
413,278.35
400,364.56
0.00
0.00
0.00
57,227.53
0.00
114,101.00
162,171.99
25,797.00
89,996.65
0.00
67,792.00
67,262.40
61,652.80
57,227.53
48,394.41
105,703.00
105,262.80
93,722.50
89,996.65
78,963.98
Butane
0.00
68,929.68
67,261.95
68,978.02
56,240.01
Propane
0.00
0.00
0.00
0.00
0.00
9,314.00
9,533.00
12,548.00
9,457.00
5,959.00
Propane
0.00
0.00
0.00
0.00
0.00
Butane
0.00
0.00
0.00
0.00
0.00
Butane Arjuna
Propane Butane
Santan
Jabung
Propane
Butane Mundu
Arar Propane Butane Sumbagut
Propane
4,072.00
677.53
772.00
1,474.00
0.00
51,531.00
48,308.00
38,900.00
38,337.00
26,428.00
0.00
0.00
0.00
0.00
0.00
Butane
639,190.00
506,975.52
594,185.61
625,791.06
515,768.97
Propane
776,345.00
709,673.34
554,193.67
504,749.00
479,328.54
Sub Total B. Oil Refinery Dumai
Butane
60,810.00
43,416.00
51,500.00
63,250.00
71,370.00
Musi
Butane
101,963.00
121,070.00
102,965.00
134,276.00
139,680.00
Cilacap
Butane
146,347.00
144,768.00
162,721.00
148,113.00
118,389.00
Balikpapan
Butane
94,513.00
104,437.00
128,416.00
120,315.00
99,139.00
Exor-1 Balongan
Butane
368,510.00
400,486.00
333,337.00
430,441.00
404,139.00
Sub Total
Butane
772,143.00
814,177.00
778,939.00
896,395.00
832,717.00
Butane
1,411,333.00
1,321,152.52
1,373,124.61
1,522,186.06
1,348,485.97
776,345.00
709,673.34
554,193.67
504,749.00
479,328.54
Total Propane
Sources : Indonesia Oil and Gas Statistics, 1999-2002, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
129
Table 5.19
Gas Sales of PT. PGN (Persero) by Sector, 1995 – 2005
Years
Production LPG (ton)
1995
Natural Gas (103 m3) Number of Consumers Natural Gas (103 m3)
1996
LPG (ton)
1998
1999
2000
2001
1,249,497
5,316
8,331
38,554
1,715
40,269
8,884
1,505,961
1,514,844
4,337
7,237 43,512
Natural Gas (103 m3)
9,548
1,835,355
1,844,904
LPG (ton)
2,634
3,459
6,093
Number of Consumers
45,640
1,882
47,522
Natural Gas (103 m3)
10,659
1,561,107
1,571,766
LPG (ton)
2,417
2,303
4,720
Number of Consumers
49,361
1,945
51,306
Natural Gas (103 m3)
11,729
1,612,104
1,623,834,588
2,398
2,276
4,674
LPG (ton) Number of Consumers
52,290
2,113
54,403
Natural Gas (103 m3)
12,742
1,907,882
1,920,625
2,847
1,997
4,484
LPG (ton) Number of Consumers
56,704
2,217
58,928
Natural Gas (103 m3)
13,510
2,116,602
2,130,113
LPG (ton)
1,955
1,766
3,721
692,757 n.a
27,813 n.a
64,463 2,131,137
LPG (ton)
n.a
n.a
3,796
Number of Consumers
n.a
n.a
64,463
Natural Gas (10 m )
n.a
n.a
2,684,224
LPG (ton)
n.a
n.a
3,364
Number of Consumers
n.a
n.a
77,075
Natural Gas (10 m )
n.a
n.a
2,937,681
LPG (ton)
n.a
n.a
0
Number of Consumers
n.a
n.a
894,856
3
3
3
2004
1,224,621
3,015
1,861
3
Natural Gas (10 m )
2003
28,876
Total
2,900
Number of Consumers 2002
Industry & Commercial
41,651
Number of Consumers 1997
Households
3
3
Source : Indonesia Oil and Gas Statistics,1995-2004 ,Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources.
130
Table 5.20 Coal Production by Company, 1999-June 2006 (Thousand ton) No.
Company
1999
2000
2001
2002
2003
2004
2005
2006*
Government Company (PT Tambang Batubara Bukit Asam) 1
- Bukit Asam
2
- Ombilin
3
- Tanjung Enim : Steam Coal
4
- Tanjung Enim : Antrachite Sub Total
-
-
1,091
737
559
362
10
10,043
9,984
9,612
9,077
10,013
73
25
41
11,207
10,746
10,21 2
43 9,482
4 10,027
8,559 69
-
-
8,638 8,707
3,742
48
0 -
-
-
8,607
3,743
Coal Contractor 5
PT Adaro Indonesia
13,601
15,481
17,708
20,819
22,523
24,331
26,686
16,746
6
PT Allied Indo Coal
426
132
121
164
52
185
-
-
7
PT Antang Gunung Meratus
150
257
447
465
507
1,130
1,029
-
8
PT Arutmin Indonesia
8,653
7,708
9,532
10,557
13,615
15,019
16,757
7,919
9
PT Bahari Cakrawala Sebuku
1,548
1,521
1,968
2,065
1,964
2,531
3,000
850
10
PD Baramarta
0
246
177
637
719
1,049
-
23
11
PT Baramulti Suksessarana
0
0
0
14
39
73
1,286
-
12
PT Bentala Coal Mining
188
166
83
0
0
0
27
-
13
PT Berau Coal
3,261
4,877
6,750
7,123
7,360
9,103
9,197
4,472
14
PT BHP Kendilo Coal Indonesia
1,027
1,038
933
769
0
0
-
-
15
Borneo Indobara
-
-
-
-
-
-
-
232
16
PT Gunung Bayan Pratama Coal
1,048
1,345
1,970
2,602
3,326
3,360
4,330
1,333
17
PT Indominco Mandiri
3,058
3,705
4,435
5,335
6,327
7,103
7,449
1,617
714
1,128
2,599
2,293
2,891
2,801
3,029
1,014
0
101
40
0
0
0
167
-
18
PT Jorong Barutama Greston
19
PT Kadya Caraka Mulia
20
PT Kalimantan Energi Lestari
21
PT Kaltim Prima Coal
22
PT Kartika Selabumi Mining
23
PT Kideco Jaya Agung
24
PT Lanna Harita Indonesia
25
Mahakam Sumber Jaya
26
PT Mandiri Inti Perkasa
27
PT Marunda Graha Mineral
28
PT Multi Harapan Utama
29
PT Riau Bara Harum
30
PT Sumber Kurnia Buana
31
PT Tanito Harum
32
PT Tanjung Alam Jaya
33
PT Trubaindo Coal Mining Sub Total
13,974
13,099
15,528
17,577
16,203
21,280
601
-
27,641
14,550
0
0
0
0
302
736
1,035
342
7,302
8,037
10,381
11,500
14,056
16,927
18,125
7,717
0
0
99
945
1,235
1,700
1,887
704
1,694
-
0
602
1,082
279
0
458
824
250
1,644
1,221
1,301
973
1,620
1,521
897
509
167
-
0
609
406
847
932
757
870
-
1,011
1,036
1,571
1,807
2,179
2,256
2,403
217
0
0
483
586
450
250
751
286
1,610
-
57,605
61,707
76,532
87,078
96,301
113,171
132,544
59,062
13
11
Cooperative Unit 34
KOP Karya Merdeka
25
52
0
0
0
0
35
KOP Teratai Putih
26
53
0
0
0
0
36
KUD Bina Bersama
12
0
0
0
0
0
37
KUD Karya Maju
7
20
0
0
0
0
38
KUD Karya Murni
2
0
5
17
0
0
39
KUD Karya Nata
0
0
10
0
0
0
40
KUD Maduratna
121
29
0
0
0
0
41
KUD Makmur
30
0
0
0
0
0
42
KUD Penerus Baru
17
0
0
0
0
0
43
KUD Toddopuli
0
0
0
0
0
0
131
Table 5.20 Coal Production by Company, 1999-June 2006 (Continued) (Thousand ton) No.
Company
44
KUD Usaha Karya Cempaka
45
KUD Markulin
46
KUD Nusantara
47
KUD Tani Jaya Murni Sub Total
1999
2000
17
2001
45
2002
2003
0
0
2004
2005
0
0
0
686
2006*
182 99 257
199
0
0
15
17
0
967
0
0
2,475
3,413
13
11
Mining Authorization Holder 48
PT Alhasanie
49
PT Amanah Anugerah Adimulya
50
PT Anugerah Bara Kaltim
51
CV Balangan Putera
52
CV Bara Pinang Corporation
53
PT Baradinamika Muda Sukses
54
PT Berkelindo Jaya Pratama
55
PT Bina Mitra Sumberarta
56
PT Bukit Baiduri Enterprise
57
117
0
0 0
113 47
1,580
-
3,395
-
64
-
69 0
222
159
113
300
455
328
-
36
0
0
0
0
0
1,689
1,994
2,013
1,980
2,417
1,430
1,690
1,179
PT Bukit Bara Utama
140
83
103
76
102
96
88
27
58
PT Bukit Sunur
640
498
342
245
114
155
91
23
59
PT Bumi Dharma Kencana
271
60
PT Cenco International
180
169
61
PT Danau Mas Hitam
273
64
0
33
88
178
54
62
PT Fajar Bumi Sakti
187
155
297
100
50
153
328
491
121
306
268
55
63
PT Kalimantan Energi Utama
64
PT Karbindo Abesyapradi
65
PT Kimco Armindo
66
PT Kitadin Corporation
67
PT Kusuma Raya Utama
11
-
681 34
-
963 865
1,259
2,359
1,922
2,291
1,768
1,604
-
31
68
PT Mahakarya Ekaguna
186
-
69
PT Manunggal Inti Arthamas
308
-
70
PT Multi Prima Energi
71
PT Nusa Riau Kencana Coal
72
PT Restu Kumala Jaya
73
PT Sari Andara Persada
74
PT Satui Bara Tama
75
PT Surya Kencana Jorong Mandiri
76
PT Surya Sakti Darma Kencana
77
PT Tri Bhakti Sarimas Sub Total Grand Total
94 148
44
0
13
0
80
57
14
0
0
259
-
338
-
0 0 441 27 328 24
4,708
4,388
5,781
6,795
7,951
9,507
9,762
1,239
73,777
77,040
92,540
103,372
114,278
132,352
150,925
64,054
*until June 2006 Sources : Indonesia Mineral & Coal Statistics 2004, Directorate of Mineral and Coal Enterprises, Ministry of Energy and Mineral Resources Directorate of Mineral and Coal Enterprises, http://portal.dpmb.esdm.go.id
132
Table 5.21
Domestic Coal Sales by Company , 1998 -2004 (Thousand ton)
No
Company
1999
2000
2001
2002
2003
2004
2005
2006*
State Owned (Bukit Asam, PT) Bukit Asam 1 2 3
-
Ombilin Mine Tanjung Enim Mine (Steam) Tanjung Enim Mine (Anthracite) Sub Total
2
7,151.01
3,370.17
620
591
430
303
26
93
41.76
1.62
8,920
8,442
7,825
7,290
7,631
7,117 -
-
-
67
32
21
28
4
9,607
9,065
8,276
7,621
7,661
7,210
-
-
4,720
6,608
8,356
9,306
9,314
7,858
156
121
200
118
193
110
224
463
479
498
613
416.86
108
16
257
495
245
920
4,576.81
211
230
291
289
106
110
-
695
1,047
398.14
-
-
49
57
24.87
-
7,192.77
3,371.79
Contractor 4
PT Adaro Indonesia
5
9
PT Allied Indo Coal PT Antang Gunung Meratus PT Arutmin Indonesia PT Bahari Cakrawaia Sebuku PD Baramarta
-
10
PT Baramulti Suksessarana
-
11
PT BerauCoal
6 7 8
12 13 14
15
Borneo Indobara PT Gunung Bayan Pratama Coal, PT lndominco Mandirt PT Jorong Barutama Greston PT Kadya Caraka Mulia
-
1,197
1,429 -
54 -
18
PT Lanna Harita Indonesia
-
19
PT Mandiri Intiperkasa
-
21
PT Multi Harapan Utama Riau Bara Harum
-
22
PT Sumber Kurnia Buana
-
23
PT Tanito Harum
24
PT Tanjung Alam Jaya
-
PT Trubaindo Coal Mining
-
1,798 97
38
149
625
2,864 936 -
423 38
4,499 -
901
-
558 -
-
848
706 -
406
130
115
28
483
82
2,594.06
95
46.79
1,053.51 -
840.53 167.42
551 837
905.07
5,251
5,743
1,007.31
342.40
79
57
6,353.88
2,584.59
423
299
242.32 68.40
-
587
497.65
-
16
-
216.47 -
284
-
451
-
-
-
-
-
-
-
18,302
20,549
22,047
26,620
-
-
-
174
158
-
-
-
-
-
-
-
-
-
-
232
679.12
-
9.13 282
12,679
8,739
1,379.25 213.62
3,343
-
Sub Total
-
3,752.96
1,040
932
-
138.46
572
847
-
-
-
688
4,588.54 -
-
2,971 -
-
1,255
647
1,662 -
38
-
-
2,324 -
-
1,142 -
512
828
1,813 -
54
268
-
17
177 -
-
PT Kaltim Prima Coal PT Kartika Selabumi Mining, PT Kideco Jaya Agung
16
-
8,776.61 -
-
187.59
-
1,171.44
544.51
32,856.35
11,928.06
3
-
-
-
69
-
-
-
222
-
-
-
-
Mining Authorization
29
PT Anugerah Bara Kaltim/Shawindo, C V Balangan Putra, C V Bara Pinang Corporation PT Baradinamika Muda Sukses PT Bukit Baiduri Enterprise
22
-
122
30
PT Bukit Bara Utama
2
-
5
31
PT Bukit Sunur
6
-
4
25 26 27 28
455
369
75 -
44 -
8
-
-
-
-
-
-
-
1
-
-
32
PT Bumi Dharma Kencana
-
-
-
-
-
271
-
33
PT Cenco International
-
-
-
-
-
180
-
34
PT Danau Mashitam
-
-
-
9
32
-
101.30
-
133
Table 5.21
Domestic Coal Sales by Company , 1998 -2004 (Continued) (Thousand ton)
No
Company
35
-
37
PT Fajar Bumi Sakti PT Kalimantan Energi Utama PT Karbindo Abesyapradhi
38
PT Kilisuci Paramita
-
39
PT Kitadin Corporation
36
1999
2000
137
2001
86
95
253
115
206
36
10 63
2004
77
76
188.17 681
-
2005
-
107
103
2003
62 -
68
2002
-
-
266
78
-
56.43
-
2006*
-
-
-
PT Maharya Eka Guna
-
-
-
-
-
40
Nusa Riau Kencana Coal
-
-
-
-
-
41
PT Kusuma Raya Utama
-
-
-
-
-
-
-
-
42
PT Restu Kumala Jaya
-
-
-
-
43
PT Satui Bara Tama PT Suiya Kencana Jorong Mandiri PT Surya Sakti Darma Kemcana Sub Total
44 45
148
44
13
18
185.56
-
150.85
-
-
-
-
-
-
441
-
-
-
-
-
-
-
27
-
-
-
-
-
-
-
328
-
-
645
380
727
980
950
2,319
1,309.66
10.50
Cooperative Unit 46
KOP Kary a Merdeka
47
KUD Karya Mumi
48
KUD KaryaNata
-
2
30
-
-
-
5
-
10
-
-
-
-
-
-
-
-
-
-
-
-
-
-
17
10.50
49
KUD Makmur
-
-
-
-
50
KUD Markufin
-
-
-
-
-
686
-
-
51
KUD Nusantara
-
-
-
-
-
182
-
-
52
KUD Tani Jaya Mumi
-
-
-
Sub Total
32
Total *until June 2006
19,023
22,124
15
17
27,320
29,167
-
107
-
-
-
975
-
-
41,358.78
15,310.35
30,658
37,125
Sources : Indonesia Mineral & Coal Statistics 2004, Directorate of Mineral and Coal Enterprises, Ministry of Energy and Mineral Resources Directorate of Mineral and Coal Enterprises, http://portal.dpmb.esdm.go.id
134
Table 5.22 Domestic Coal Sales by Industry, 1998-2004 (Thousand ton) 2001
2002
2003
2004
13,576.45
17,977.00
18,414.47
22,995.61
22,882.19
n.a
488.15
568.44
568.00
554.31
1,200.03
1,213.17
1,153.97
1,057.56
1,142.65
1,090.77
CFPP Freeport
n.a
n.a
646.09
557.95
669.33
593.65
CFPP Newmont Minahasa
n.a
n.a
38.97
28.08
24.00
3.65
CFPP Newmont Nusa Tenggara
n.a
n.a
406.13
477.61
480.00
482.58
1. Coal-Fired Power Plant CFPP Asam-Asam CFPP Bukit Asam
CFPP Ombilin (Sijantang)
1998
1999
10,622.94 n.a
137.43
125.1
374.89
105.36
229.58
182.64
CFPP Paiton
2,151.93
3,368.92
6,276.10
8,300.75
9,060.89
9,310.01
CFPP Suralaya
7,133.54
8,869.25
10,172.03
8,950.79
10,821.16
10,664.59
2. Cement Industry
1265.12
2032.34
5143.27
5911.06
4,773.62
5,549.31 169.85
PT Basowa Cement
n.a
30.27
247.51
152.98
251.01
PT Indocement Cibinong
42.91
88.35
1352.14
1019.87
0.00
0.00
PT Indocement Cirebon
7.68
80.78
380.4
294.22
313.50
385.95
PT Indocement Citeureup
n.a
n.a
0
1019.87
800.92
1,184.56
PT Indocement Tarjun
n.a
n.a
341.51
370.12
269.56
368.41
PT Kodeco Cement
67.19
456.42
0
0
0.00
0.00
PT Semen Andalas
59.21
19.52
35.64
47.05
168.00
185.34
PT Semen Baturaja
68.7
62.37
71.34
103.36
94.01
129.08
PT Semen Cibinong
577.61
452.15
602.77
897.67
885.64
811.58
75.83
99.98
912.03
862.61
715.17
1,063.64
0
0
0
0
5.64
12.82
14.85
177.26
0
0
0.00
0.00
262.72
469.75
474.96
680.64
692.39
454.21
88.43
95.5
724.96
462.7
577.78
783.87
144.91
194.21
181.7
208.72
201.91
119.18
PT Semen Gresik PT Semen Kupang PT Semen Nusantara PT Semen Padang PT Semen Tonasa 3. Metallurgy PT Antam Tbk.
32.77
20.78
13.6
120
62.27
46.27
PT Inco Tbk.
74.17
75.51
123.5
77.87
109.51
51.16
PT Kobatin
0
1.2
30.23
2.19
10.00
7.32
PT Newmont Sumbawa
0
70.97
0
0
0.00
0.00
PT Kobatin
24.52
16.94
0
0
0.00
0.00
PT Timah Tbk.
13.46
8.82
14.37
8.66
20.12
14.43
4. Pulp Industry
702.88
829.09
822.82
499.59
1,704.50
1,160.91
PT Indah Kiat
167.63
198.23
163.28
7.51
1,198.00
369.42
PT Indorayon Utama
21.35
2.27
0
8.36
PT Jaya Kertas
10.32
23.7
20.88
27.83
32.55
54.50
PT Tjiwi Kimia
503.57
604.9
638.65
455.88
473.95
728.63
0
0
0
0
0.00
0.00
29.96
38.3
31.27
24.71
24.98
17.96
2,600.55
2,573.35
1,593.06
3,792.48
957.32
6,347.71
15,366.36
19,243.75
25,749.12
28,851.02
30,657.94
36,077.26
5. Small Industry 6. Briquette 7. Others* Total
8.36
Source : Indonesia Mineral & Coal Statistics 2004, Directorate of Mineral and Coal Enterprises, Ministry of Energy and Mineral Resources
135
Table 5.23 Coal Quality by Company Parameter Calorific Value Company (Kcal/Kg)
Total Moisture Reference
Suphur
Ash
(%-adb)
(%-adb)
(%-ar)
STATE OWNED COMPANY Tambang Batubara Bukit Asam Tbk. PT Suralaya Coal (SRC)
5500-6500
0.15-1.47
3-15
18.28
Lumut Coal (LMC)
6500-7500
0.24-155
4-10
8-17
PTBA.2005 PTBA,2005
Antracite Coal (ANC)
7500-8000
0.57-179
6-20
2-8
PTBA.2005
Ombilin (OMB)
6800-7000
0.5
8
14 Max
PTBA, 2005
CONTRACTOR 1. Adaro Indonesia, PT Paringin
5900
0.1
1
23.5
OR IV, 2002
Tutupan
5850
0.1
0.8
24.5
QR IV, 2002
Wara
4395
0.15
1.4
34.1
QR IV, 2002
6900-7200
0.8
10
4
WP&B 2003
2. Allied Indo Coal, PT 3. Antang Gunung Meratut, PT F.Tanjung
6500-6800
0.5-1
10-15
9-15
WP&B 2003
F.Warukin
5000-5500
0.1-0.5
10-15
9-15
WP&B 2003
Asam-asam
5000
0.15
3.9
23
Arutmin, 2002
Sarongga
6720
0.8
10
4.95
Arutmin, 2002
Satui
6800
0.8
8
7
Arutmin, 2002
Senakin Barat
6700
0.8-1.4
12
4.5
Arutmin, 2002
Senakin Timur
6700
0.8-1.4
12
4.5
Arutmin, 2002
5. Bahari Cakrawala Sebuku, PT
6260
0.83
8.97
7-12
WP&B 2003
6. Baramarta, PD
6400-7200
0.3-1.2
1-4
2-7
WP&B 2003
7. Baramulti Suksessarana, PT
5900-6500
0.4-1.3
1-4
3-8
WP&B 2003
4. Arutmin Indonesia, PT
8. Berau Coal, PT Lati
5400
1
5
26
WP&B 2003
Binuang Blok 5 & 6
5900
0.6
5
18
WP&B 2003 WP&B 2003
Binuang Blok 7
5559
0.7
4,3
22.5
SambarataBlokA
6000
0.7
5
15
WP&B 2003
Birang
5550
0.99
4.43
18
Berau, 2002
5373-7870
0.25-2.70
1.8-18.22
4.20-9.90
QR I, 2002
9. Gunung Bayan Pratama, PT Tlaga & Rusuh 10.lndominco Mandiri, PT Seam O
6475
0.22
2.1
10.9
QR III, 2002
Seam l
5982
0.26
9.3
11.1
QR III, 2002
Seam 2 Selatan Barat
6250
0.19
1.9
11.7
QR III, 2002
Seam 4 Selatan Timur
6144
0.27
3
13.5
QR III, 2002
Seam 6 Selatan Timur
5993
0.28
2.4
15.9
QR III, 2002
Seam 11 Selatan Timur
6144
2.11
3
8
QR III, 2002
11. Jorong Barutama Greston, PT
5617
0.25
4.5
30.5
QR III, 2002
12. Kaltim Prima Coal,PT Melawan West
5610
0.22
2.1
21.2
QR III, 2002
Melawan East
5610
0.22
2.1
21.2
QR III, 2002
Bendili
5940
0.21
3.2
7.2
QR III, 2002
Surya Pit
5940
0.21
3.2
7.2
QR III, 2002
Source: Indonesia Mineral & Coal Statistics 2004, Directorate of Mineral and Coal Enterprises, Ministry of Energy and Mineral Resources
136
Table 5.24 Electricity Production by Type of Power Plant of PLN, 1992 – 2005 (GWh)
Own Generated Year
Purchased
Total
40,878.83
837.42
41,716.25
-
45,468.59
1,057.62
46,526.21
4,599.00
-
50,066.42
1,411.94
51,478.36
2,210.03
4,921.96
-
58,210.81
1,193.42
59,404.23
23,043.91
2,352.35
5,410.31
-
65,730.25
1,656.29
67,386.54
1,731.49
27,320.82
2,605.28
5,774.73
745.98
74,799.65
1,819.92
76,619.57
30,512.37
1,395.50
24,940.78
2,616.80
5,306.55
543.61
74,964.61
2,938.76
77,903.37
9,370.08
33,999.53
1,555.04
27,045.52
2,727.73
5,325.86
472.96
80,496.72
4,279.08
84,775.80
2000
9,109.94
38,428.70
1,251.63
26,396.74
2,648.54
5,667.97
686.63
84,190.15
9,135.14
93,325.29
2001
10,651.02
39,376.31
1,459.39
27,366.18
2,982.12
5,752.43
767.27
88,354.72
13,299.21
101,653.93
2002
8,833.57
39,031.98
2,228.75
28,802.77
3,186.98
5,984.59
1,224.60
89,293.24
19,066.61
108,359.85
2003
8,472.16
42,178.01
2,486.25
28,409.31
2,958.63
5,541.39
2,435.17
92,480.92
20,538.76
113,019.68
2004
8,942.79
41,645.42
3,179.33
30,700.30
3,146.54
5,498.34
3,078.45
96,191.17
24,053.14
120,244.31
2005
9,830.96
42,268.13
6,039.08
31,271.97
3,005.51
5,761.20*)
3,105.25
101,282.09
26,087.70
127,369.82
Gas
Combined
Turbine
Cycle
22,565.72
2,688.91
7,858.66
21,784.23
1994
7,042.75
1995
Hydro
Steam
Geothermal
Diesel*
Rented
1992
8,787.64
1,775.27
1,083.74
3,977.55
-
1993
2,609.44
7,794.75
1,090.00
4,331.51
21,581.41
1,013.13
14,228.37
1,601.76
7,528.72
22,775.27
1,470.46
19,304.37
1996
8,118.17
25,506.45
1,299.06
1997
5,148.72
31,472.63
1998
9,649.00
1999
Sub Total
*) Include Gas Micro scale Power Plant, from 2004
Source: PLN Statistics, 2004, PT. PLN (Persero)
137
Table 5.25 Fuel Consumption for PLN Power Plant, 1989-2005 Natural Gas
HSD
IDO
(MMSCF)
(Thousand liter)
(Thousand liter)
MFO
Coal
(Thousand liter)
(ton)
Year 1989/90
11,815
1,233,814
40,758
1,890,516
3,970,559
1990/91
13,301
1,666,565
70,776
2,817,275
4,572,306
1991/92
12,788
1,897,178
57,165
3,206,929
5,143,300
1992/93
12,788
2,478,317
82,245
3,267,068
5,143,300
1993/94
58,271
3,251,686
68,526
3,021,545
4,732,669
1994
160,705
1,882,862
45,041
1,865,637
5,530,066
1995
220,032
1,817,598
8,238
1,157,591
5,593,402
1996
433,003
2,220,784
15,505
1,111,006
7,966,656
1997
228,268
2,982,319
33,635
1,590,122
9,961,959
1998
78,547
2,856,272
26,440
1,253,285
10,634,490
1999
236,612
3,253,219
20,941
1,429,003
11,414,098
2000
228,883
3,141,917
23,145
1,858,568
13,135,583
2001
222,421
3,575,348
30,457
1,793,283
14,027,713
2002
192,927
4,625,521
40,682
2,300,603
14,054,377
2003
184,304
5,024,362
31,573
2,557,546
15,260,305
2004*)
176,436
6,299,706
36,935
2,502,598
15,412,738
2005*)
143,050
7,626,201
27,581
2,258,776
16,900,972
*) Include Gas Micro scale Power Plant, from 2004
Source: PLN Statistics 2004-2005, PLN (Persero)
Table 5.26 Own-Uses, Losses, and Factors in PLN Electricity, 1993-2005 Own Year
Uses (GWh)
Transmission
Distribution
Load
Capacity
Demand
Losses (GWh)
Losses (GWh)
Factor (%)
Factor (%)
Factor (%)
1993/94
1,901.22
1,188.96
4,667.05
74.88
38.17
33.54
1994
1,990.87
1,416.93
4,957.59
68.01
39.89
38.06
1995
2,260.91
1,698.58
5,626.12
66.82
44.34
29.28
1996
2,588.33
1,825.40
5,882.49
68.59
47.75
29.46
1997
3,230.30
1,818.68
7,069.91
70.08
46.15
46.79
1998
3,218.68
1,755.24
7,462.54
68.90
43.21
46.63
1999
3,224.35
2,116.56
7,862.40
67.60
44.63
49.41
2000
3,416.13
2,307.77
8,175.10
69.54
46.29
49.31
2001
3,709.87
2,336.56
10,924.80
71.13
47.90
49.04
2002
3,767.51
2,706.61
14,521.74
72.10
48.28
49.11
2003
4,039.82
2,686.10
15,715.54
71.88
49.78
49.21
2004
5,824.43
2,711.49
10,420.45
72.64
51.14
49.36
2005
5,302.43
2,794.43
11,442.77
74.26
52.15
48.26
Source: PLN Statistics, 2004-2005, PT. PLN (Persero)
138
Table 5.27
Industrial Sector
Residential Sector
Commercial Sector
Social Buildings
Government Buildings
Public Lighting
Number of customers
47,847
20,696,261
770,920
442,302
76,196
16,799
21,980,325
Energy Sales(MVA)
27,948.89
19,550.83
6,225.67
1,203.99
1,314.79
687.84
56,932.01
Income (million Rp)
4,085,015.00
3,106,917.00
1,656,290.00
157,244.00
296,656.00
116,275.00
9,418,397.00
50,748
23,162,538
793,355
535,083
79,093
19,770
24,640,587
30,768.81
22,698.27
7,249.62
1,403.41
1,355.93
835.48
64,311.52
4,606,116.00
3,669,230.00
1,959,951.00
182,925.00
314,665.00
144,390.00
10,877,278.00
43,088
24,902,763
847,940
537,589
80,609
21,500
26,433,489
27,995.54
24,865.45
8,655.96
1,417.41
1,383.28
943.77
65,261.41
5,627,407.00
4,585,295.00
2,647,255.00
274,019.00
406,714.00
225,532.00
13,766,222.00
42,514
25,825,088
982,281
568,480
81,343
24,846
27,524,552
31,337,57
26,874,78
9,330.31
1,468.82
1,343.54
977.05
71,332.07
6,535,846
5,208,334
2,924,805
316,216
425,382
259,968
15,670,552
44,337
26,769,675
1,062,955
582,811
79,453
29,174
28,595,405
34,013.22
30,563.42
10,575.97
1,643.52
1,297.83
1,070.85
79,164.81
10,289,533
6,337,009
4,024,216
380,484
638,447
470,194
22,139.88
46,014.00
27,885,612
1,172,247
608,713
79,746
35,396
29,827,728
35,593.25
33,339.78
11,395.35
1,781.55
1,281.63
1,128.82
84,520.38
12,872,975
8,456,684
5,149,643
485,425
764,718
546,538
28,275,983
46,824
28,903,325
1,245,709
633,114
80,954
43,993
30,953,919
36,831.30
33,993.56
11,845.04
1,842.89
1,281.49
1,294.47
87,088.75
16,313,885
13,352,473
702,137
776,371
887,275
667,088
32,699,229
46.818
29.997.554
1.310.686
659.034
83.81
53.514
32.151.416
36.497
35.753
13.224
2.022
1.433
1.512
90.441
19.355.351
18.680.109
8.746.392
1.087.806
1.040.349
899.629
49.809.637
46.52
31.095.970
1.382.416
686.851
87.187
67.502
33.366.446
40.324
38.588
15.258
2.238
1.645
2.045
100.097
22.547.351
21.523.164
10.410.620
1.272.560
1.171.832
1.306.466
58.232.002
46,475
32,174,922
1,455,797
716,194
89,533
76,432
34,559,353
42,448
41,184
17,023
2,430
1,726
2,221
107,032
24,189,890
23,188,785
11,825,952
1,384,770
1,260,284
1,396,542
63,246,221
Year
1996
1997
Number of customers Energy Sales(MVA) Income (million Rp)
1998
Number of customers Energy Sales(MVA) Income (million Rp)
1999
2000
Number of customers Energy Sales(MVA) Income (million Rp) Number of customers Energy Sales(MVA) Income (million Rp)
2001
Number of customers Energy Sales(MVA) Income (million Rp)
2002
Number of customers Energy Sales(MVA) Income (million Rp)
2003
Number of customers Energy Sales(MVA) Income (million Rp)
2004
Number of customers Energy Sales(MVA) Income (million Rp)
2005
Electricity Sold by PLN by Sector, 1996-2005
Number of customers Energy Sales(MVA) Income (million Rp)
Total
Source: PLN Statistics, 2004-2005, PT. PLN (Persero)
139
Tabel 5.28a Load Balance of PLN Electricity, 2003 (MW) PLN Unit/Province Region of Naggroe Aceh. D
Installed Capacity
Load Capacity
Peak Load 60.50
137.30
88.50
Regionof North Sumatera
0.40
0.40
0.30
Region of West Sumatera
41.60
33.10
30.10
Region of Riau
188.80
173.80
117.50
Region of South Sumatera, Jambi & Bengkulu North Sumatera
79.70
50.10
30.90
- South Sumatera
35.60
19.30
11.80
- Jambi
22.50
22.50
12.40
- Bengkulu
21.70
8.30
6.80
Region of Bangka Belitung
76.20
34.60
49.80
Regionof Lampung Region of West Kalimantan
12.50
5.10
10.70
232.20
162.40
176.60
Region of South & Central Kalimantan
381.50
290.90
286.30
- Central Kalimantan
310.20
237.50
232.80
71.30
53.40
53.50
Region of East Kalimantan
310.70
192.10
213.60
Region North, Central Sulawesi & Gorontalo
321.50
262.90
232.00
- North Sulawesi
155.80
148.00
134.50
39.50
34.80
26.10
- Central Sulawesi
126.20
80.20
71.30
Region of South & Southeast Sulawesi
461.50
384.70
472.10
- South Sulawesi
435.80
361.80
452.90
25.70
22.80
19.20
Region of Maluku
145.60
64.00
52.10
- Maluku
102.10
41.50
34.50
43.50
22.50
17.60
136.50
100.20
84.30
- South Kalimantan
- Gorontalo
- South East Sulawesi
- North Maluku Region of Papua Distribution of Bali
4.10
2.20
1.30
Region of West Nusa Tenggara
146.00
99.10
101.10
Region of East Nusa Tenggara
125.40
69.20
57.40
PT PLN Batam
115.80
96.40
116.10
G & T Nothern Part of Sumatera
1,470.00
1,161.60
1,180.10
G & T Southern Part of Sumatera
1,328.70
1,201.40
990.40
Total Non Java
5,715.90
4,403.30
4,263.20 3.00
Distribution East Java
10.50
8.70
Distribution Central Java
0.60
0.50
0.20
- Central Java
0.40
0.30
0.20
- Yogyakarta
0.30
0.20
-
Distribution West Java
0.80
0.70
0.60
- West Java
0.60
0.60
-
- Banten
0.20
0.20
-
-
-
-
PT Indonesia Power
8,980.00
8,327.00
-
PT PJB
6,495.50
6,039.00
-
-
-
13,682.00
Distribution Jaya & Tangerang
P3B Total Java
15,490.40
14,375.90
13,685.80
Total Indonesia
21,206.30
18,779.20
17,949.10
Source : PLN Statistics, 2003 PT.PLN (Persero)
140
Tabel 5.28b Load Balance of PLN Electricity, 2004 (MW) PLN Unit/Province Region of Naggroe Aceh. D
Installed Capacity
Load Capacity
Peak Load 48.37
142.30
73.08
Regionof North Sumatera
0.44
0.40
0.28
Region of West Sumatera
43.42
33.40
30.09
Region of Riau
187.52
176.70
171.32
Region of South Sumatera, Jambi & Bengkulu North Sumatera
78.25
53.84
34.51
- South Sumatera
34.08
24.99
12.48
- Jambi
22.52
16.25
13.46
- Bengkulu
21.65
12.60
8.57
Region of Bangka Belitung
85.24
63.21
56.57
Regionof Lampung
7.68
3.67
9.60
239.51
239.67
230.50
Region of South & Central Kalimantan
396.28
280.27
235.05
- Central Kalimantan
312.50
220.42
191.62
83.78
59.85
43.42
Region of East Kalimantan
336.34
223.28
213.62
Region North, Central Sulawesi & Gorontalo
343.81
271.83
242.02
- North Sulawesi
178.08
156.58
136.79
39.49
31.56
26.84
- Central Sulawesi
126.24
83.69
78.39
Region of South & Southeast Sulawesi
463.64
364.72
530.76
- South Sulawesi
384.69
308.32
482.84
78.95
56.40
47.92
Region of Maluku
169.82
82.15
52.12
- Maluku
116.44
55.39
34.51
53.38
26.76
17.61
139.23
98.71
90.16
Region of West Kalimantan
- South Kalimantan
- Gorontalo
- South East Sulawesi
- North Maluku Region of Papua Distribution of Bali
4.08
3.71
1.52
Region of West Nusa Tenggara
147.70
103.06
101.10
Region of East Nusa Tenggara
127.96
68.86
63.57
PT PLN Batam
137.50
78.80
130.50
PT PLN Tarakan G & T Nothern Part of Sumatera
31.22
28.00
20.44
1,520.87
1,212.24
1,203.70
G & T Southern Part of Sumatera
1,370.04
1,180.04
1,028.39
Total Non Java
5,972.85
4,570.78
4,494.17
13.66
11.12
2.99
Distribution East Java Distribution Central Java
0.64
0.21
- Central Java
0.38
0.20
- Yogyakarta
0.26
Distribution West Java
0.93
0.89
- West Java
0.71
0.71
- Banten
0.22
0.18
PT Indonesia Power
9,005.19
7,643.87
PT PJB
6,477.14
5,817.21
Total Java
15,497.56
13,473.09
14,401.84
Total Indonesia
21,470.41
18,043.87
18,896.01
0.01 0.64
Distribution Jakarta Raya & Tangerang
P3B
14,398.00
Source : PLN Statistics, 2004 PT.PLN (Persero)
141
Table 5.28c Load Balance of PLN Electricity, 2005 PLN Unit/Province Region of Naggroe Aceh. D
Installed Capacity
Load Capacity
(MW) Peak Load 39.77
143.92
78.23
Regionof North Sumatera
0.44
0.37
0.28
Region of West Sumatera
43.06
28.84
25.18
Region of Riau
161.27
121.88
99.96
Region of South Sumatera, Jambi & Bengkulu
79.13
48.28
33.02
- South Sumatera
36.38
24.77
8.50
- Jambi
16.65
13.42
14.88
- Bengkulu
26.11
10.09
9.64
Region of Bangka Belitung
94.59
55.66
57.25
7.25
4.30
9.96
283.69
166.63
191.40
Region of South & Central Kalimantan
398.72
334.18
323.40
- Central Kalimantan
313.57
262.29
218.97
85.15
71.89
45.23
Region of East Kalimantan
297.61
205.76
250.71
Region North, Central Sulawesi & Gorontalo
353.78
258.56
249.42
- North Sulawesi
181.94
147.68
140.49
41.00
26.49
27.73
- Central Sulawesi
130.84
84.39
81.20
Region of South & Southeast Sulawesi
496.08
364.18
313.78
- South Sulawesi
416.99
306.83
276.89
79.08
57.35
36.89
Region of Maluku
207.34
114.18
77.60
Region of Papua
184.67
93.10
79.05
5.58
3.60
1.99
Region of West Nusa Tenggara
147.46
105.13
117.98
Region of East Nusa Tenggara
151.71
77.31
66.59
PT PLN Batam
137.50
83.30
150.60
Regionof Lampung Region of West Kalimantan
- South Kalimantan
- Gorontalo
- South East Sulawesi
Distribution of Bali
PT PLN Tarakan
31.64
24.80
25.50
G & T Nothern Part of Sumatera
1,524.05
1,215.24
1,203.70
G & T Southern Part of Sumatera
1,410.05
1,147.31
1,121.43
0.00
0.00
0.00
6,159.54
5,311.52
4,438.57 2.99
P3B Sumatra Total Non Java Distribution East Java
13.65
13.12
Distribution Central Java
0.64
0.00
0.21
- Central Java
0.38
0.00
0.20
- Yogyakarta
0.26
0.00
0.01
Distribution West Java
0.93
0.93
0.64
- West Java
0.71
0.71
0.00
- Banten
0.22
0.22
0.00
Distribution Jakarta Raya & Tangerang
0.00
0.00
0.00
PT Indonesia Power
9,005.19
7,574.53
0.00
PT PJB
6,477.14
5,778.28
0.00
0.00
0.00
0.00
P3B Java-Bali Muara Tawar
858.00
858.00
14,821.00
Total Java
16,355.55
14,224.86
14,824.84
Total Indonesia Source : PLN Statistics, 2005 PT.PLN (Persero)
22,515.09
19,536.38
19,263.40
142
EXPORTS AND IMPORTS OF ENERGY
VI. EXPORTS AND IMPORTS OF ENERGY IN INDONESIA
PENGKAJIAN ENERGI UNIVERSITAS INDONESIA 143
144
Table 6.1
Type of Export Crude Oil and Condensate
Refined Product
LNG
Piping Gas
LPG
Coal -
Export of Energy, 1997 – 2005
Unit
1997
1998
1999
2000
2001
2002
2003*
2004*
2005
Thousand Barrel
289,093.20
280,364.60
285,399.70
223,500.00
240,170.30
217,274.00
189,094.82
178,869.41
159,702.82
Million US$
5,479.90
3,444.90
4,949.50
6,282.50
5,619.20
4,929.00
5,401.60
6,472.98
8,194.66
Thousand Barrel
71,785.40
58,897.00
56,496.20
67,084.50
56,686.10
55,490.00
63,502.59
52,390.00
40,861.25
Million US$
1,291.10
695.4
912.2
1,675.90
1,241.90
1,060.00
1,606.82
1,751.41
2,050.40
MMBTU
1,387,548,990
1,387,548,990
1,501,935,830
1,400,024,020.00
1,238,784,870.00
1,035,543,000.00
1,369,603,250.00
1,369,603,250.00
1,369,603,250.00
Million US$
4,735.00
3,389.80
4,489.10
6,802.10
5,375.30
5,595.00
6,586.42
7,721.97
9,132.23
MMBTU
-
-
-
-
122,183,750.00
216,171,250.00
216,171,250.00
216,171,250.00
216,171,250.00
ton
2,132,917
1,761,304
1,745,383
1,306,318.00
1,484,484.00
1,268,000.00
1,106,424.23
1,034,270.06
1,066,391.80
Million US$
516.2
257.1
339.2
393.70
388.60
412.00
329.48
356.81
475.11
58,460.00
65,281.00
74,177.93
85,681.00
93,758.81
106,206.74
Thousand 41,726.00 47,626.00 55,301.00 ton Unaudited: export 2005 (except coal) Unaudited: export refined product 2003 Export LNG value in Million US$ from 2001 not included exporting by pipeline
Sources: Embassy of the United States of America Jakarta, Petroleum Report Indonesia : 2002-2003, March 2004 Indonesia Oil & Gas Statistics, 1995-2005 Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources - Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources Directorate of Mineral and Coal Enterprises, http://www.dpmb.esdm.go.id Energy News, http://www.usembassyjakarta.org
145
Table 6.2
Import of Energy, 1995 – 2005
Type of Import
Crude Oil
Petroleum Fuels
Unit
1995
1996
1997
1998
1999
2000
2001
2002
2003*
2004*
2005*
Thousand Barrels
68,326.90
71,791.00
62,881.90
72,475.90
84,692.00
79,978.10
112,878.10
124,147.70
137,126.65
148,489.59
118,302.86
Million US$
1,229.10
1,506.70
1,291.90
985.7
1,501.20
2,303.50
2,852.30
n.a
4,118.21
5,802.40
6,503.76
Thousand Barrels
45,019.20
60,905.80
94,994.20
54,053.80
79,902.00
87,001.60
89,622.10
106,927.60
101,598.51
122,598.45
158,625.33
Million US$
978.8
1,576.90
2,296.80
803.4
1,656.30
2,889.90
2,577.40
n.a
3,317.94
5,750.80
10,353.91
n.a : not available * unaudited
Sources: th Directorate General of Oil & Gas, Oil & Gas Data Information, 6 Ed.,2002 Embassy of the United States of America Jakarta, Petroleum Report Indonesia : 2002-2003, March 2004 Indonesia Oil & Gas Statistics, 1995-2002, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources - Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
146
Table 6.3
Import of Crude Oil by Type, 2000 – 2005 (Barrel)
No.
Products
2000
2001
2002
2003
2004
2005
36,182,304
40,005,584
34,472,549
41,339,170
37,879,588
39,370,973
3,384,571
7,510,042
1
ALC
2
Azeri
3
Bach Ho
3,025,964
6,518,473
3,548,095
4
Badin
2,406,380
385,893
1,505,789
5
Basrah
4,986,874
2,004,092
6
BBT
0
1,310,526
0
7
Bebatik
0
0
649,803
8
Bintulu
467,938
2,532,932
0
9
BIS
0
183,453
0
10
Ben Chamas
11
BLC
1,971,959
0
3,889,780
12
Bonny Light
0
10,443,068
7,786,978
13
Borrow Island
0
0
0
14
Brass River
0
925,751
6,568,639
15
Brunei LC/ Manis
599,590
0
0
16
Buanga Kekwa
17
Cham
0
601,527
0
0
0
0
1,170,657
0
0
18
Champion
19
Cooper Basin
20
Cossack
21
Daihung
22
Dulang
23
Escravos/ Forcados
3,631,646
4,929,038
8,021,350
5,476,107
3,840,495
5,681,711
7,699,300
2,775,547
1,017,610 346,330
588,013
2,088,406
6,948,114
1,273,288
1,304,837
3,745,959
947,142
0
0
0
12,784,351
1,797,312
3,827,392
947,148
9,554,088
1,354,504
1,309,311
1,888,712
0
24
Gippsland
0
0
0
25
Harriet/Varanus
0
0
0
26
ILC
3,667,594
5,538,619
0
27
Jabiru
0
0
0
28
Kitina
0
0
1,887,294
29
Kutubu
0
0
1,878,834
3,134,773
1,245,513
601,649
30
Labuan
2,222,325
0
5,203,485
6,345,155
2,903,545
1,745,498
31
LBN
1,754,336
0
0
32
Legendre
0
548,884
661,934
3,660,083
1,927,817
33
Marib Light
1,939,917
0
34
Masa
35
Miri
36
MLC
37
Mutineer Exeter
38
Nanhai
39
Nemba
40
Nice Blend
41
Nile Blend
0
0
1,979,636
470,683
0
0
4,618,839
3,168,133
1,746,697
0
0
0
630,523 1,284,970
5,983,017
6,573,363
6,682,148
3,644,653
0
2,943,342
7,720,215
579,618
2,380,711 0
0
42
North W.S. Cond
0
0
0
43
Odudu
0
7,625,225
9,446,665
44
Oman
0
0
2,096,636
810,351 622,146 10,486,526
0
147
Table 6.3
No.
Import of Crude Oil by Type, 2000 – 2005 (Continued)
Products
2000
2001
2002
2003*
45
Palanca
46
Palm
0
989,121
0
47
PPT
0
479,466
0
48
QIB
0
4,740,697
0
49
Quaiboe/ Nile Blend
919,072
1,405,184
15,307,383
11,344,121
50
Rang dong
472,428
0
0
51
Ruby
470,849
0
674,655
52
Saharan
0
7,857,493
53
Sarir
0
0
54
Seria
0
0
55
Skua/ Griffin
56
Tantawan/Benchmas
57
Tapis
58
Thevarnard
(Barrel) 2005
2004 995,309
10,444,373
7,595,669
3,954,424
962,668
2,422,147
1,026,698
1,102,195
5,492,300
8,068,368
4,500,062
993,838
989,185
3,646,681
0
1,037,908
659,917
3,674,660
5,229,287
13,459,632
0
0
0
2,544,149
4,474,390
4,182,342
627,904
0
0
0
0
9,393,365
59
Var
0
362,023
0
60
Wenchang
0
0
1,657,497
2,250,787
4,208,933
4,033,511
61
Xijiang
0
1,813,251
1,169,666
4,699,339
6,586,741
4,502,359
62
Zafiro
0
0
1,939,918
1,938,925
6,821,381
Total
81,732,435
110,908,272
125,905,217
137,126,653
147,299,540
118,302,860
Sources: Indonesia Oil and Gas Statistics, 1997-August 2003, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources - Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
148
Table 6.4
Import of Refinery Products, 2000 – 2005 (Barrel)
Products
2000
2001
2002
Gas Oil
45,079,337
1,346,006
60,609,566
DPK
16,732,380
0
0
IDO
1,794,410.00
-
-
12,477,236
58,649
0
0
0
0
HSFO Inco Fuel
2003
2004
2005
77,604,755
90,817,486
-
-
-
IFO
12,712,611
189,615
0
Kerosene
19,624,012
17,219,590
17,100,258
14,284,537
13,594,785
16,378,352
Pygas
755,002.99
479,263.19
387,730.24
80,825.97
307,702
-
Fuel Oil
12,712,613
7,556,859
8,863,108
7,892,099
9,370,389
8,380,045
Avtur
-
199,422
1,234,605
1,582,777
3,622,078
4,112,632
Avgas
-
0
6,478
0
0
0
Premium
11,464,533
4,121,905
15,790,121
22,253,020
31,136,209
38,936,818
58,904,934.93
46,589,870.52
60,609,566.03
55,586,079.83
64,874,990.44
90,817,486.43
HOMC 90
-
2,579,433.50
574,303.96
200,000.00
-
-
HOMC 92
-
4,397,958.96
2,028,530.00
4,111,473.44
678,070.20
3,036,698.31
HOMC 93
-
-
8,472.00
HOMC 95
-
3,545,501.37
1,437,503.00
1,874,430.00
712,426.00
-
HOMC 97
-
105,000.00
-
-
95,133.00
-
LPG
-
-
-
1,881,808.94
369,011.08
250,509.08
ADO
-
-
-
Sources: Indonesia Oil and Gas Statistics, 2000-2005, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources - Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
149
Table 6.5
Export of Crude Oil by Destination Country, 1997 – 2005 (Barrel)
Country Arab Saudi
1997
1998
1999
2000
2001
2002
2003
2004
2005
0
210,011
0
532,649
0
0
0
Australia
33,724,756
51,689,282
42,740,670
20,539,899
32,147,225
33,274,233
20,034,470
17,927,840
18,034,151
China
44,433,187
28,321,078
30,842,831
33,781,103
18,850,028
21,408,856
28,867,632
25,426,105
28,467,433
India
0
0
0
0
3,907,416
682,616
0
Japan
94,966,831
80,229,153
88,180,203
74,807,184
70,231,383
51,077,628
44,479,013
44,120,310
37,186,844
Korea
32,637,329
32,076,840
38,629,225
37,407,522
46,623,836
38,185,209
30,273,558
30,232,519
27,842,982
0
0
0
0
1,301,167
3,967,194
0
2,439,322
1,507,387
Malaysia New Zealand
550,109
778,169
670,336
164,992
760,003
1,063,899
0
285,010
2,020,667
Philippines
2,937,395
1,013,748
420,006
1,110,426
1,145,719
410,338
0
278,005
0
Singapore
12,212,537
15,249,484
8,237,064
15,655,585
14,933,556
7,859,108
5,973,731
3,838,302
4,589,206
Taiwan
11,354,434
10,150,280
9,056,796
9,156,889
7,663,153
6,042,385
5,527,515
6,029,097
2,639,440
8,470,324
2,684,514
5,549,786
9,932,728
3,876,493
6,089,605
5,858,688
6,293,551
5,721,285
20,705,014
24,843,784
26,576,697
14,152,826
15,034,016
15,863,909
13,100,997
11,929,831
5,988,356
261,991,916
247,246,343
250,903,614
217,241,803
216,473,995
185,924,980
154,115,604
148,799,892
133,997,751
Thailand USA TOTAL
Sources: Indonesia Oil and Gas Statistics, 1997- 2004, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources - Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
150
Table 6.6
Export of Condensate by Destination Country, 1997 – 2005 (Barrel)
Country
1997
1998
1999
2000
2001
2002
2003
2004
China
0
659,764
725,303
n.a
180,044
656,060
1,950,705
Japan
3,856,579
5,745,706
6,540,241
n.a
7,634,672
10,673,893
8,463,790
USA
2005 842,186
7,919,959
6,441,355
0
0
262,462
n.a
314,997
0
0
Australia
3,076,121
283,498
662,672
n.a
3,416,633
1,194,532
2,160,068
2,502,397
1,760,278
267,503
Singapore
9,977,857
6,334,122
3,868,560
n.a
5,583,269
6,789,116
5,178,246
4,922,662
3,023,117
Korea
12,265,505
8,423,329
4,814,470
7,243,867
n.a
5,341,220
5,791,506
9,832,321
11,877,862
Thailand
454,490
355,003
1,052,351
n.a
1,619,498
4,468,747
5,036,350
2,847,039
Philippines
151,483
0
0
n.a
0
0
144,073
Taiwan
0
0
1,378,306
n.a
504,003
980,670
0
Arab Saudi
0
0
237,891
n.a
0
0
0
Malaysia
0
0
n.a
543,625
0
0
Vietnam TOTAL
0
0
0
n.a
0
545,762
0
25,939,859
18,192,563
21,971,653
n.a
25,137,961
30,554,524
32,765,553
199,981
30,069,919
24,799,925
n.a. : not available Sources: - Indonesia Oil and Gas Statistics, 1997-2004, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources - Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
151
Table 6.7
Products Avtur
Benzene
Decant Oil
Gas Oil
Green Coke
IFO
JP-5
Light Fuel Oil
LOMC
LSWR
Lube Oil
Mixed Oil
Mogas
Naphtha
Paraxylene
Propylene
PTA Slack
Wax
Total
Export of Refinery Product, 1999– 2005
Unit Thousand Barrel Million US$ Thousand Barrel Million US$
1999 0.00
2000 n.a
2001 0.00
2002
2003
2004
0.00
2005* n.a
0.00
n.a
0.00
0.00
207.61
n.a
783.91
714.20
787.29
277.90
n.a 54.71
20.22
121.12
1.32
n.a
25.86
23.69
3,782.41
n.a
3,104.69
0.00
3,253.54
48.49
n.a
49.32
0.00
136.89
Thousand Barrel
0.00
n.a
0.00
0.00
n.a
Million US$
0.00
n.a
0.00
0.00
1,135.06
n.a
2,622.42
1,654.38
2,638.35
2,589.62
2,014.20
Million US$
5.70
n.a
16.75
13.89
22.19
22.76
26.59
Thousand Barrel
0.00
n.a
0.00
0.00
Million US$
0.00
n.a
0.00
0.00
n.a
246.89
n.a
0.00
0.00
n.a
Thousand Barrel Million US$
Thousand Barrel
Thousand Barrel
12.80
n.a
n.a
Million US$
5.11
n.a
0.00
0.00
Thousand Barrel
0.00
n.a
0.00
3,253.18
2,813.23
4,939.94
n.a
77.98
103.32
n.a
Million US$ Thousand Barrel Million US$ Thousand Barrel
0.00
n.a
0.00
56.78
517.34
n.a
611.50
0.00
10.61
n.a
14.41
0.00
17,420.82
n.a
32,831.22
35,938.03
n.a
n.a n.a 34,651.74
42,287.22
31,320.52
Million US$
267.24
n.a
707.99
640.62
928.71
1,091.84
1,389.59
Thousand Barrel
461.40
n.a
147.47
417.33
673.89
512.50
306.65
14.77
n.a
6.34
10.32
31.24
23.10
21.66
Thousand Barrel
0.00
n.a
0.00
0.00
n.a
Thousand US$
0.00
n.a
0.00
0.00
n.a
Thousand Barrel
0.00
n.a
0.00
0.00
n.a
Million US$
0.00
n.a
0.00
0.00
8,772.29
n.a
13,448.37
10,993.31
18,715.00
11,763.13
6,531.06
Million US$
145.33
n.a
330.76
235.42
528.08
361.22
305.47
Thousand Barrel
522.36
n.a
759.74
120.15
571.61
282.60
18.28
n.a
40.59
5.40
41.66
30.15
Thousand Barrel
0.00
n.a
0.00
0.00
Million US$
0.00
n.a
0.00
0.00
69.34
n.a
738.56
689.69
552.78
367.98
620.99
45.61
38.10
49.05
Million US$
Thousand Barrel
Million US$
Thousand Barrel Million US$ Thousand Barrel Million US$ Thousand Barrel Million US$
3.66
n.a
45.48
0.00
146.57
n.a
10.26
0.00
n.a
n.a n.a
0.28
n.a
10.57
0.00
33,282.09
n.a
55,058.14
53,780.28
60,832.28
63,309.90
44,450.68
520.79
n.a
1,248.06
986.11
1,688.52
1,702.21
1,972.19
Sources : Indonesia Oil and Gas Statistics, 1999 – 2004 Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
152
Table 6.8
Country Japan USA Korea Singapore Taiwan Australia Italy Thailand Malaysia India Pakistan China Bangladesh Vietnam France New Zealand Netherland Total
Export of Refinery Product by Destination Country, 1999 –2005
Unit Thousand Barrel Thousand US$ Thousand Barrel Thousand US$ Thousand Barrel Thousand US$ Thousand Barrel Thousand US$ Thousand Barrel Thousand US$ Thousand Barrel Thousand US$ Thousand Barrel Thousand US$ Thousand Barrel Thousand US$ Thousand Barrel Thousand US$ Thousand Barrel Thousand US$
2000
2001
2002
2003*
2004*
2005
16,153.07
13,838.41
9,918.86
11,184.91
21,305.87
25,244.87
419,959.44
n.a
n.a
420,016.92
743,660.00
1,101,949.00
2,315.99
1,452.22
386.93
3,012.90
2,198.40
405.91
56,191.33
n.a
n.a
63,535.11
64,642.80
21,656.00
17,807.07
15,903.10
10,140.84
6,870.05
6,390.16
3,938.87
441,836.05
n.a
n.a
210,131.36
204,859.29
156,020.00
14,485.86
10,936.61
9,308.49
12,957.83
10,544.23
9,593.35
310,946.70
n.a
n.a
311,725.76
358,890.66
403,858.00
2,785.83
2,828.62
1,620.77
820.02
1,743.80
997.99 44,791.00
83,640.60
n.a
n.a
33,100.35
62,538.52
1,251.40
1,843.90
1,892.46
3,019.26
418.90
426.36
34,433.79
n.a
n.a
14,641.31
17,144.12
12,959.00
3,722.94
-
2,813.54
4,047.29
2,432.60
n.a
108,329.93
79.94
52.75
168.14
741.01
89,388.22 2,267.70
910.93
72,923.06
n.a
n.a
11,659.29
48.59
1,268.40
1,401.61
380.51
3,113.91
667.80
668.90 17,761.00
43,733.65
n.a
n.a
13,016.63
23,126.49
5,026.20
3,260.54
3,657.31
4,290.52
1,880.55
120,635.01
122,909.79
n.a
n.a
Thousand Barrel
0.00
170.87
124.86
47.80
Thousand US$
0.00
n.a
n.a
Thousand Barrel
0.00
2,641.23
1,542.14
5,625.52
3,927.78
1,867.05
Thousand US$
0.00
n.a
n.a
156,214.73
126,749.11
78,720.00
20.58 0.66
Thousand Barrel
0.00
14.02
21.25
Thousand US$
0.00
n.a
0.99
Thousand Barrel
0.00
16.48
667.68
Thousand US$
0.00
n.a
15,523.15
124.86
Thousand Barrel
0.00
Thousand US$
0.00
n.a
Thousand Barrel
0.00
63.25
Thousand US$
0.00
n.a
Thousand Barrel
0.00
252.12
Thousand US$
0.00
2.55
Thousand Barrel
Thousand US$ n.a : Not Available * unaudited
67,084.46
81,945.40
42,058.53
58,356.63
52,390.83
1,675,962.63
n.a
n.a
1,615,592.03
1,771,849.99
Source : Indonesia Oil and Gas Statistics, 1999-2003, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources - Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
153
Table 6.9
Year
1995
1996
1997
1998
1999
2000
2001
Export of LNG by Destination Country, 1995 –2005
Unit
Japan
Taiwan
Korea
Total
MMBTU
833,187,850
103,696,260
350,051,820
1,286,935,930
Thousand US$
2,416,501.20
338,865.10
1,100,894.80
3,856,261.10
MMBTU
955,771,780
78,551,700
335,741,450
1,370,064,930
Thousand US$
3,245,789,90
296,632,80
1,187,732.60
1,187,732.60
MMBTU
936,317,800
78,987,070
372,244,120
1,387,548,990
Thousand US$
3,155,947.60
289,587,50
1,289,390.60
4,445,338.20
MMBTU
927,140,940
97,152,800
371,646,440
1,395,940,180
Thousand US$
2,228,695.70
262,750.90
898,348.90
3,389,795.50
MMBTU
958,654,880
110,519,060
423,761,890
1,492,935,830
Thousand US$
2,850,981.50
395,085.90
1,243,022.90
4,489,090.30
MMBTU
933,859,920
145,398,470
320,765,630
1,400,024,020
Thousand US$
4,532,123.50
781,701.25
1,488,294.53
6,802,119.28
MMBTU
870,978,110
212,323,430
155,483,330
1,238,784,870
n.a
n.a
n.a
n.a
929,302,080
260,145,510
170,845,150
1,360,292,740
n.a
n.a
n.a
n.a
MMBTU
923,706,740
182,881,450
263,015,060
1,369,603,250
Thousand US$
4,330,218.65
964,364.13
1,291,839.80
6,586,422.58
MMBTU
841,968,900
205,826,130
274,620,250
1,322,415,280
Thousand US$
4,623,436.50
1,388,643.68
1,709,887.43
7,721,967.60
MMBTU
738,644,920
186,263,540
292,920,730
1,217,829,190
Thousand US$
4,945,590.08
1,682,790.65
250,384.90
9,132,229.78
Thousand US$ MMBTU
2002
2003*
2004*
2005*
Thousand US$
* unaudited Sources : Indonesia Oil and Gas Statistics, 1995-August 2003, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources Indonesia Oil and Gas Statistics, 1995-August 2003, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
154
Table 6.10
Export of LPG by Destination Country, 2000 – 2005
Country
Unit
2000
2001
2002
2003
2004
2005
Japan
Thousand ton
944.00
1,169.10
880.30
882.31
891.59
865.65
Million US$
290.33
n.a
n.a
266.27
308.29
392.69
Taiwan
Thousand ton
1.75
93.53
10.65
3.65
0.00
8.81
Million US$
0.48
n.a
n.a
0.83
0.00
3.12
China
Million US$
151.76
21.76
243.35
81.97
45.76
85.58
41.88
n.a
n.a
23.80
15.06
34.39
Hong Kong
Thousand ton
90.47
35.75
0.00
0.00
0.00
0.00
Million US$
25.11
n.a
n.a
0.00
0.00
Thousand ton
0.00
30.45
51.79
8.45
6.98
9.18
4.65
Thousand ton
Australia
Malaysia
Singapore
Philippines Papua New Guinea
Million US$
8.47
n.a
n.a
1.91
2.91
2.09
Thousand ton
0.00
18.19
16.52
21.71a)
0.00a)
0.00a)
Million US$
0.00
n.a
n.a
5.482a)
0.00a)
0.00a)
Thousand ton
3.48
13.30
1.62
-
-
-
-
-
-
Million US$
1.06
n.a
n.a
Thousand ton
31.47
17.12
57.26
Million US$
10.33
n.a
n.a
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
Thousand ton Million US$
0.00
n.a
n.a
Thousand ton
0.00
3.31
1.75
Vietnam
Million US$
0.00
n.a
n.a
Domestic
Million US$
TOTAL
Million US$
Thousand ton
Thousand ton
0.05
60.56
50.70
72.75
52.49
0.00
16.04
n.a
n.a
20.24
17.77
0.00
1,253.25
1,484.50
1,269.71
1,106.42
1,034.27
1,066.39
393.71
n.a
n.a
329.48
356.81
475.11
n.a : not available * unaudited a) Malaysia and Singapore Sources: Indonesia Oil and Gas Statistics, 1998 – August 2003, Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources - Directorate General of Oil and Gas, Ministry of Energy and Mineral Resources
155
Table 6.11 No.
Coal Export by Company, 1999 – 2005 Company
1999
2000
2001
2002
2003
2004
2005
2006*
Government Company 1
PT Tambang Batubara Bukit Asam - Bukit Asam - Ombilin - Tanjung Enim
2,492 502
172
34
0
1,738
1,971
1,861
1,855
432
38
0
0
0
0
27
460
-
2,239
2,712
1,409
-
-
-
-
Coal Contractors 2
PT Allied Indo Coal
3
PD Baramarta
0
0
-
0
0
1,049
4
PT Adaro
10,048
9,671
11,446
12,688
15,187
15,099
17,317
11,919
5
PT Arutmin Indonesia
7,089
9,303
9,247
9,858
13,772
13,796
12,517
7,125
6
PT Bahari Cakrawala Sebuku
1,379
1,328
1,584
1,715
1,885
2,696
2,823
7
PD Baramarta
719
1,049
95
8
PT Bentala Coal Mining
77
0
7
0
9
PT Berau Coal
2,091
3,344
4,835
5,072
5,349
6,160
5,763
10
PT BHP Kendilo Coal Indonesia
1,118
1,032
883
817
374
11
PT Gunung Bayan Pratama Coal
12
PT Indominco Mandiri
13
PT Jorong Barutama Greston
14
PT Kaltim Prima Coal
15
PT Kideco Jaya Agung
16
PT Lanna Harita Indonesia
971 2,645
-
450
1,447
1,810
2,609
3,539
2
1,324
197
3,212
3,863
4,371
5,334
4,887
6,584
8,902
1,807
836
897
1,330
1,060
1,961
1,826
2,139
711
13,390
12,743
15,079
16,629
16,034
22,404
26,622
14,504
6,433
6,525
7,321
6,750
8,942
10,966
11,831
5
0
0
99
831
1,194
1,480
1,733
696
17
PT Mandiri Intiperkasa
-
352
1,021
204
18
PT Marunda Graha Minera
-
295
788
295
19
PT Multi Harapan Utama
20
PT Tanito Harum
21
PT Tanjung Alam Jaya
22
PT Trubaindo Coal Mining
875
621
580
448
1,159
1,002
648
419
1,005
934
1,053
1,629
2,104
3,217
4,984
600
0
0
0
636
0 -
34
-
-
389
1,034
Mining Authorisation Holder 23
PT Anugerah Bara Kaltim
0
0
0
1449
24
PT Anugerah Buana Bahari Abadi
0
0
48
0
25
PT Berkelindo Jaya Pratama
27
0
0
0
26
PT Berkelindo Jaya Pratama
308
249
0
0
27
PT Bukit Baiduri Enterprise
1663
1888
1998
28
PT Bukit Bara Utama
126
89
71
29
PT Bukit Sunur
642
460
30
PT Danau Mas Hitam
272
31
PT Fajar Bumi Sakti
35
32
PT Karbindo Abesyapradi
33
PT Kitadin - Tandung Mayang
34
PT Kitadin Corporation
35
PT Nusa Riau Kencana Coal
36
PT Restu Kumala Jaya
2,317
1,479
1,502
1963
2,459
1,255
1,626
47
108
83
74
24
245
268
155
130
85
22
154
0
27
49
81
16
0
4
232
73
128
155
0
339
0
0
1,934
785
815
1515
1859
28
113
100
0
-
197
1,230
84
-
200
-
-
864
7 -
1,047
-
76
241
-
93,759
106,767
-
-
-
15
Cooperative Unit 37
KOP Teratai Putih
3
27
0
0
38
KOP Karya Merdeka
3
27
0
0
54,884
58,191
65,628
74,174
Total
85,681
51,231
Sources : Indonesia Mineral & Coal Statistics, 1997-2005 Directorate of Mineral and Coal Enterprises, Ministry of Energy and Mineral Resources Directorate of Mineral and Coal Enterprises, http://portal.dpmb.esdm.go.id
156
Table 6.12
Coal Export by Destination Country, 1999 – 2005 (Thousand ton)
Country
1999
2001
2002
2003
ASIA Arab Saudi China
43,678 0 15
47,164 0 629
60,236 38 2,858
66,158 68 520
Hong Kong
2,510
4,662
5,564
2,345 13,170
3,130 15,216
1,960
India Japan Korea Malaysia Pakistan Philippines Singapore South Korea Srilangka Taiwan Thailand Turkey EUROPE Bulgaria Croatia Denmark Finland France Germany Greece Israel Ireland Italy Netherlands New Zealand Portugal Scotland Slovenia Spain Switzerland United Kingdom
2004 -
2005 -
2006* -
1,219
1,227
766
9,178
8,230
8,970
4,605
4,586 16,530
6,700 17,992
5,465 19,013
2,098
6,239
3,823
2,800 101 5,308 0 13,554 1,916 0 6,882 29 0 0 0 0 101 216
1,980 71 5,552 0 11,507 2,318 0 10,227 0 0 0 132 0 502 0
2,018 489 5,633 27 13,100 3,155 0 9,936 0 642 297 130 248 557 213
2,118 488 6,966 40 14,144 4,075 46 12,787 0 420 0 120 0 661 220
4,315 41 2,352 684 9,690 8 16,678 2,217
8,740 24,237 9,964 3,977 251 2,655 1,280
5,207 9,543 4,254 1,842 280 1,090 373
14,524 4,256
8,474 1,884
18 370 2,041
455 1,584 2,410
295 2,096 1,515
0 4,669 284
0 0 550 2,872 562
948 0 563 3,203 379
444 0 71 3,001 357
231 0 0 2,926 2,266
0 199 0
65
-
254 62
350
63
466 0 2,704 350 709
484 2,780 1,076 963
307 1,570 1,773 544
0 230 3,007 4,039
405 3,653 4,287
287 1,921 1,356
1,141
1,772
1,037
439 0 326
146 887
-
-
125
50
70
990
Australia-America Australia Brazilian Canada Chile Peru
2,596 0 398 0 1,099 0
2,161 160 284 36 642 0
2,555 0 356 0 554 535
3,118 386 344 0 271 72
USA
1,098
1,039
1,110
2,045
2,110
1,931
1,406
2,161 55,318
5,730 65,281
1,451 74,178
3,618 85,681
7,809 93,759
8,425 107,306
2,143 51,496
Others Total
772
-
Sources : Indonesia Mineral & Coal Statistics, 1997-2004, Directorate of Mineral and Coal Enterprises, Ministry of Energy and Mineral Resources Directorate of Mineral and Coal Enterprises, http://portal.dpmb.esdm.go.id
157
158
INFRASTRUCTURE OF ENERGY
VII. INFRASTRUCTURE OF ENERGY IN INDONESIA
PENGKAJIAN ENERGI UNIVERSITAS INDONESIA
159
160
Table 7.1
Installed Capacities of Oil Refinery Plants, 1999 – 2005 (Barrel/Day)
Refinery Plant
1999
2000
2001
2002
2003
2004
2005
5,000
5,000
5,000
5,000
5,000
5,000
5,000
120,000
120,000
170,000
120,000
120,000
120,000
120,000
50,000
50,000
50,000
50,000
50,000
50,000
50,000
Musi
135,200
135,200
133,700
135,200
135,200
135,200
135,200
Cilacap
348,000
348,000
348,000
348,000
348,000
348,000
348,000
Balikpapan
260,000
260,000
260,000
260,000
260,000
260,000
260,000
3,800
3,800
3,800
3,800
3,800
3,800
3,800
125,000
125,000
125,000
125,000
125,000
125,000
125,000
Pangkalan Brandan Dumai Sungai Pakning
Cepu Exor-1 Balongan Kasim Total
10,000
10,000
10,000
10,000
10,000
10,000
10,000
1,057,000
1,057,000
1,105,500
1,105,500
1,105,500
1,105,500
1,105,500
Sources: Oil & Gas Data & Information 2001, Directorate General of Oil & Gas, Department of Energy and Mineral Resources Pertamina Annual Report 1996/1997 CIC Magazine No. 218,26 January 1999 Directorate General of Oil & Gas, Department of Energy and Mineral Resources
Table 7.2a
Fuel Oil Sales & Distribution Channels of Pertamina and Partner
No.
Distribution Channel
Unit
1
SPBU - Public Gas Station
2659
2
SPBI - Gas Fuel Distribution for Industry
3
SPBA - Fuel Distributor for Armed Forces
4
Kerosene Distributor
5
SPBB - Fuel Distributor for Bunkers
6
PSPD - Premium Solar Packed Dealer
130
7
APMS - Automotive Diesel Oil Distributor
286
8
SPDN - Diesel Oil Dealer for Fisheries
8 189 2728 58
30
Source: PERTAMINA Annual Report, 2003
161
Table 7.2b
Non-Fuel Oil Sales & Distribution Channels of Pertamina and Partners
Distribution Channel
No.
Unit
1
Lubricans Distributors
224
2
Private lubricant Packages Factories
3
LPG Distributor
4
Asphalt Distributor
22
5
Tank Asphalt Distributor
50
6
Wax Distributor
32
7
Industrial Chemical Products Distributor
8
SPBG - LNG Filling Pump
28
9
LPG Station
18
10
SPBE - Bulk Elpiji Station & Transporter
44
6 457
136
Source: PERTAMINA Annual Report, 2003
Table 7.3
Oil Fuel Pipeline
Location
Distance (km)
Diameter
Balongan - Jakarta
210
16” & 16” & 16”
Cilacap - Tasikmalaya
127
10” & 16”
Tasikmalaya - Padalarang
131
10” & 16”
Tasikmalaya – Ujung Berung
91
10” & 10”
Cilacap - Maos
20
10” & 12”
Maos - Rewulu
161
8” & 12”
Source: PT Pertamina (Persero)
162
Table 7.4
Number of Oil Fuels Public Station and Kerosene Agents OIL FUEL PUBLIC STATION
LOCATION Aceh
KEROSENE AGENT
PRIVATE
PERTAMINA
TOTAL
AGENT
TNI / POLRI
TOTAL
(Unit)
(Unit)
(Unit)
(Unit)
(Unit)
(Unit)
49
0
49
29
0
29
154
0
154
329
0
329
Riau
64
1
65
70
0
70
West Sumatra
54
0
54
112
0
112
321
1
322
540
0
540
66
0
67
69
0
69
North Sumatra
Sub Total UPPDN I South Sumatra Jambi
30
0
30
19
0
19
Bengkulu
14
0
14
3
0
3
Lampung
66
0
66
49
0
49
Bangka Belitung
15
0
15
13
0
13
Sub Total UPPDN II
191
0
192
153
0
153
DKI.Jakarta
165
19
184
136
34
170
Banten
98
1
99
57
0
57
West Java
404
6
410
325
20
345
Sub Total UPPDN III
667
26
693
518
54
572
Central Java
225
0
225
196
0
196
Yogyakarta
97
0
97
77
0
77
Sub Total UPPDN IV
322
0
322
273
0
273
East Java
384
1
385
0
0
0
79
0
79
0
0
0
Bali West Nusa Tenggara
18
1
19
0
0
0
East Nusa Tenggara
21
0
21
0
0
0
Sub Total UPPDN V
502
2
504
0
0
0
35
0
35
0
0
0
East Kalimantan South Kalimantan
33
0
33
0
0
0
Central Kalimantan
18
0
18
0
0
0
West Kalimantan Sub Total UPPDN VI
31
0
31
0
0
0
117
0
117
0
0
0
South Sulawesi
95
2
97
91
0
91
South East Sulawesi
10
0
10
17
0
17
Central Sulawesi
26
0
26
31
0
31
North Sulawesi
31
0
31
36
0
36
162
2
164
175
0
175
8
0
8
25
0
25
4
1
5
8
0
8
15
2
17
46
0
46
Sub Total UPPDN VII Maluku North Maluku Papua Sub Total UPPDN VIII Grand Total
27
3
30
79
0
79
2,309
34
2,344
1,738
54
1,792
Source : PT Pertamina (Persero)
163
Table 7.5
Oil Fuel Storage Tanks of PT PERTAMINA (Persero) in Sumatera and Java
Location
TOTAL Number of Tank Total Capacity (Unit) (Kilo Liter)
UPPDN I Medan - Transit Terminal
53
- Instalasi
30
447,520 145,700
- Seafed Depot
92
188,391
- Inland Depot
29
24,322
- DPPU
52
17,730
- Third Party
19
78809
Sub Total UPPDN I
275
902,472
- Seafed Depot
40
85,224
- Inland Depot
38
77,759
- DPPU
19
1,529
- Third Party
11
4,171
Sub Total UPPDN II
108
168,683
- Transit Terminal
21
338,638
- Instalasi
13
126,417
- Seafed Depot
33
412,884
- Inland Depot
35
191,781
- DPPU
23
81,917
- Third Party
12
232,200
Sub Total UPPDN III
137
1,383,837
- Transit Terminal
13
231,811
- Instalasi
22
94,580
- Inland Depot
63
196,794
- DPPU
18
1,423
- Third Party
8
126,000
124
650,608
17
147,278
UPPDN II Palembang
UPPDN III Jakarta
UPPDN IV Semarang
Sub Total UPPDN IV
UPPDN V Surabaya - Transit Terminal - Instalasi
74
466,196
- Seafed Depot
123
221,045
- Inland Depot
35
23,400
- DPPU
41
1,102
- Third Party
37
325,573
Sub Total UPPDN V
327
1,184,594
Source : PT Pertamina (Persero)
164
Table 7.6
Oil Fuel Storage Tanks of PT PERTAMINA (Persero) in Kalimantan, Sulawesi, and Papua TOTAL Number of Tank (Unit)
Location
Total Capacity (Kilo Liters)
UPPDN VI Balikpapan - Seafed Depot
90
176,981
- Inland Depot
10
11,177
- DPPU
33
4,475
2
4,600
135
197,233
- Third Party Sub Total UPPDN VI
UPPDN VII Makassar - Instalasi - Seafed Depot - DPPU
20
55,409
123
130,378
25
2,705
7
71,308
175
259,800
12
137,217
142
131,913
- Third Party Sub Total UPPDN VII
UPPDN VIII Jayapura - Transit Terminal - Seafed Depot - DPPU
31
200
- Third Party
691
Sub Total UPPDN VIII Sub Total Directorate PPDN Sub Total Third Party Grand Total
185
270,021
1,466
5,017,248
96
843,352
1,562
5,860,600
Source : PT Pertamina (Persero)
Table 7.7 No.
Distribution Gas Pipeline of PT PGN (Persero)
Location
Length (km)
Capacity (MMSCFD)
1
Medan
418
195
2
Palembang
72
0.8
3
Cirebon
331
6
4
Surabaya
509
212
5
Bogor
408
36
6
Jakarta
810
467
Source : PT Perusahaan Gas Negara (Persero), www.pgn.co.id
165
Table 7.8
No.
Gas Pipeline Diameter (inch)
Pipe Name
Length (km)
Capacity (MMSCFD)
Location
Remark
Gathering Line 1.
Offshore-Lhok Seumawe
2.
Onshore-Lhok Seumawe/Arun
3.
Badak-Bontang
4.
Field-Badak-Bontang
30
109
1,000
Aceh
LNG Plant
16-42
30-34
200-2,000
Aceh
LNG Plant/Industries
42
57
2,000
East Kalimantan
LNG Plant
20-36
10-70
300-1,500
East Kalimantan
Gas Processing
5.
Offshore-West Java
16-26
20-70
200-600
West Java
Proc. Platform
6.
Grissik Fields
16-26
13-50
200-600
South Sumatra
To Sales Line
16-26
10-55
200-600
North of Java
Power Plant
24
220
500
West Java
Industries
Sales Line 7.
Offshore-T. Priok/Muara Karang
8.
Cilamaya-Cilegon
9.
Pagerungan-Gresik
24-28
3-370
500-700
East Java
Power Plant/Industries
10.
Prabumulih-Palembang
20-28
15-50
300-500
South Sumatra
Power Plant/Industries
11.
Grissik-Duri
28
550
700
12.
Natuna-Singapore
16-28
10-470
200-700
Sumatra
Duri Steam Flood
South China Sea
Export/Power Plant
13.
Grissik-Sakeman
28
135
700
Riau
Transmission
14.
Sakeman-Batam-Singapore
28
335
700
Sumatra
Export/Power Plant
Source : Directorate General of Oil & Gas, Ministry of Oil and Gas
Table 7.9
Transacted Gas Pipeline Project in 2005 & 2006
No
Projects
Length
Status
1
East kalimantan to Java gas transmision pipeline
1220 km
Tendered on 29-12-2005
2
Semarang to Cirebon gas Transmission pipeline
230 km
Tendered on 2-7-2005
3
Semarang to Gresik gas transmission pipeline
250 km
Tendered on 2-7-2005
4
Duri-Dumai to Medan gas Transmission pipeline
529 km
To be tendered in mid 2006
5
Cirebon to Muara Bekasi gas tranmission pipeline
220 km
To be tendered in mid 2007
6
Sengkang to Mkassar gas transmision pipeline
274 km
To be tendered at the end of 2006
Source: Petrominer, March 15 2006
166
Table 7.10
Design and Production Capacities of LNG Plant (Million ton/year)
Arun LNG Refinery Plant Capacity Design Production 1,552 2,142 1,552 2,142 1,552 2,142 1,552 2,142 1,552 2,142 1,552 2,142
Train 1 2 3 4 5 6
Total
Badak LNG Refinery Plant Capacity Train Design Production A 1,842 2,622 B 1,842 2,622 C 1,842 2,622 D 1,842 2,622 E 1,842 2,731 F 1,842 2,731 G 1,842 2,742 H 1,842 2,950 18,088 21,642 27,400 34,294
9,312 12,852 Total Design Capacity Total Production Capacity
Source : Directorate General of Oil and Gas, 2003, Ministry of Energy and Mineral Resources
Table 7.11
Main Coal Harbor
Terminal
Location
Operator
Maximum Vessel (DWT)
Stockyard (Thousand M. ton)
50,000
Sumatera Kertapati
South Sumatera
PT TB Bukit Asam
7,000
Pulau Bai
South Sumatera
Government of Indonesia
40,000
n.a
Tarahan
South Sumatera
PT TB Bukit Asam
40,000
310,000
Teluk Bayur
West Sumatera
PT TB Bukit Asam
35,000
90,000
Kalimantan Tanjung Bara
East Kalimantan
PT Kaltim Prima Coal
180,000
500,000
Tanah Merah
East Kalimantan
PT Kideco
60,000
260,000
North Pulau Laut
South Kalimantan
PT Arutmin
150,000
500,000
Balikpapan
East Kalimantan
PT Dermaga Perkasa Pratama
80,000
800,000
Tanjung Redeb
East Kalimantan
PT Berau Coal
5,000
50,000
Beloro
East Kalimantan
PT Multi Harapan Utama
8,000
75,000
Loa Tebu
East Kalimantan
PT Tanito Harum
8,000
50,000
Tanjung Pemancingan
South Kalimantan
PT Arutmin
60,000
1,500,000
Sembilang
South Kalimantan
PT Arutmin
7,500
200,000
Air Tawar
South Kalimantan
PT Arutmin
7,500
200,000
Satui
South Kalimantan
PT Arutmin
5,000
150,000
Banjarmasin
South Kalimantan
Government of Indonesia
5,000
n.a
Kelanis
South Kalimantan
PT Adaro
8,000
150,000
Indonesian Bulk Terminal
South Kalimantan
PT IBT
200,000
1,600,000
West Java
n.a
6,000
50,000
Java Terminal Batubara Indah n.a : not available
Source : Directorate General Mineral and Coal Enterprise, Ministry of Energy and Mineral Resources
167
Table 7.12
Number of PLN Power Plants, 1992 – 2005 (Unit)
Year
Hydro
Steam
Gas Turbine
Combined Cycle
Geothermal
Diesel*)
Total
1992
142
34
44
0
0
2,976
3,196
1993
149
34
45
12
3
3,126
3,369
1994
146
35
49
30
6
3,400
3,666
1995
154
36
41
33
6
3,646
3,916
1996
143
38
45
40
23
3,479
3,768
1997
154
38
50
40
6
3,683
3,971
1998
170
39
49
33
7
3,664
3,962
1999
177
39
49
50
7
3,731
4,053
2000
182
39
47
54
7
3,685
4,014
2001
186
41
47
54
8
3,837
4,173
2002
184
41
47
55
8
4,431
4,766
2003
185
40
47
56
8
4,543
4,879
2004
190
41
55
51
8
4,778
5,123
2005
191
41
60
51
8
4,859
5,210
*) Include Gas Micro scale Power Plant, from 2004 Source: PLN Statistics, 2004-2005, PT PLN (Persero)
168
Table 7.13
Installed and Rated Capacities of PLN Power Plants, 1992 – 2005 (MW) Hydro
Steam
Gas Turbine
Combined Cycle
Geothermal
Diesel*)
Total
%
Year Installed
Rated
Installed
Rated
Installed
Rated
Installed
Rated
Installed
Rated
Installed
Rated
Installed
Rated
Rated
1992
2,178.71
2,158.34
3,940.60
3,718.00
1,222.76
774.70
1,392.33
1,265.28
140.00
140.00
2,062.17
1,448.25
10,936.57
9,504.57
87%
1993
2,178.76
2,129.30
4,690.60
4,535.20
995.92
662.60
3,411.31
3,243.35
195.00
195.00
2,128.46
1,464.20
13,600.05
12,229.65
90%
1994
2,178.27
2,054.05
4,755.60
4,580.51
982.37
732.80
3,942.11
3,661.86
305.00
305.00
2,164.12
1,502.44
14,327.47
12,836.66
90%
1995
2,178.27
1,989.50
4,820.60
4,530.95
1,002.47
758.65
4,414.48
4,397.41
305.00
305.00
2,265.36
1,564.08
14,986.18
13,545.59
90%
1996
2,184.03
2,170.78
5,020.60
4,242.50
1,093.31
885.80
5,053.31
4,719.25
308.75
306.37
2,447.84
2,005.18
16,107.84
14,329.88
89%
1997
2,436.34
2,409.01
6,770.60
6,107.00
1,371.12
992.25
5,588.89
5,563.54
362.50
360.00
2,416.39
1,792.09
18,945.84
17,223.89
91%
1998
3,006.76
2,994.64
6,770.60
6,700.40
1,347.41
1,086.86
6,560.97
6,463.09
360.00
360.00
2,535.02
1,649.36
20,580.76
19,254.35
94%
1999
3,013.99
2,985.10
6,770.00
6,671.50
1,516.11
997.81
6,281.70
6,264.09
360.00
360.00
2,649.94
1,890.45
20,591.74
19,168.95
93%
2000
3,015.24
2,747.42
6,770.00
6,508.31
1,203.37
901.90
6,836.22
6,456.13
360.00
360.00
2,549.85
1,692.64
20,734.68
18,666.40
90%
2001
3,105.76
2,952.45
6,900.00
6,502.28
1,224.72
1,054.82
6,863.22
6,306.19
380.00
379.62
2,585.12
1,694.48
21,058.82
18,889.84
90%
2002
3,155.17
2,836.16
6,900.00
6,144.17
1,224.72
861.99
6,863.22
6,074.35
380.00
379.88
2,589.12
1,657.33
21,112.23
17,953.88
85%
2003
3,167.93
3,122.93
6,900.00
6,185.50
1,224.72
1,457.00
6,863.22
5,923.40
380.00
360,00
2,670.42
1,730.41
21,206.29
18,779.25
2004
3,199.44
2,991.63
6,900.00
5,934.52
1,481.57
1,435.89
6,560.97
5,609.65
395.00
359,16
2,933.43
1,713/02
21,470.41
18,043.87
2005
3,220.96
3,079.53
6,900.00
5,657.07
2,723.63
2,829.11
6,280.97
5,854.39
395.00
339.86
2,994.54
1,776.42
22,515.09
19,536.38
*) Include Gas Micro scale Power Plant, from 2004 Source: PLN Statistics, 2004-2005, PT PLN (Persero)
169
Tabel 7.14a Captive Power Plants, 2003
PLN Unit/Province Region of Naggroe Aceh. D Region of North Sumatera Region of West Sumatera Region of Riau Region of South Sumatera, Jambi & Bengkulu - South Sumatera - Jambi - Bengkulu Region of Bangka Belitung Regionof Lampung Region of West Kalimantan Region of South & Central Kalimantan - South Kalimantan - Central Kalimantan Region of East Kalimantan Region North, Central Sulawesi & Gorontalo - North Sulawesi - Gorontalo - Central Sulawesi Region of South & Southeast Sulawesi - South Sulawesi - South East Sulawesi Region of Maluku - Maluku - North Maluku Region of Papua Distribution of Bali Region of West Nusa Tenggara Region of East Nusa Tenggara PT PLN Batam Distribution East Java Distribution Central Java - Central Java - Yogyakarta Distribution West Java - West Java - Banten Distribution Jaya & Tangerang Total Indonesia
Number of Captive Power Plants/CP (Unit)
Installed Capacity (kVA)
Reserved CP
Total
95
167
262
515.718,00
54.718,00
569.900,00
26.381,00
70
76
146
116.575,00
116.575,00
212.073,00
210.265,00
141
97
238
134.541,40
134.541,40
190.390,50
134.571,00
404
69
473
106.358,60
106.358,60
869.911,60
69.272,00
210
296
506
183.768,20
183.768,20
1.074.733,80
183.601,20
114 63 33
143 81 72
257 144 105
117.145,00 54.588,00 12.035,20
117.145,00 54.588,00 12.035,00
728.088,00 299.246,00 47.399,00
139.914,50 35.437,70 8.249,00
19
35
54
5.853,00
5.853,00
11.956,00
9.571,50
109
113
222
114.179,25
114.179,25
254.559,35
82.315,00
93
102
195
64.253,00
64.253,00
211.737,00
41.628,00
194
300
494
196.407,00
196.407,00
410.551,00
114.962,00
117 77
226 74
343 151
168.824,00 27.583,00
168.824,00 27.583,00
327.634,00 82.917,00
100.750,00 14.212,00
71
139
210
103.734,00
103.734,00
853.587,50
99.504,70
56
246
302
52.397,00
52.397,00
91.762,00
46.093,00
15 7 34
123 26 97
138 33 131
36.120,00 5.313,00 10.964,00
36.120,00 5.313,00 10.964,00
48.590,00 23.028,00 20.144,00
33.933,00 4.923,00 7.237,00
96
312
408
68.086,00
68.086,00
96.958,00
67.240,00
65 31 19 21
241 71 99 51 48 146 330
306 102 99 51 48 165 351
58.248,00 9.838,00 16.711,67 12.015,62 4.696,05 20.402,70 199.873,50
58.248,00 9.838,00 16.711,67 12.015,62 4.696,05 20.402,70 199.873,50
81.988,00 14.970,00 16.711,67 12.015,62 4.696,05 41.443,03 208.138,50
59.042,00 8.198,00 18,96 15,38 3,58 19.140,10 177.649,55
110
90
200
15.038,30
15.038,30
26.295,70
12.836,90
Main CP
Reserved CP
kVA from PLN Connected to Reserved CP
Main CP
Total
9
64
73
5.520,00
5.520,00
7.060,00
2.987,45
35 264
309
35 573
171.173,05
427.373,68
122.115,00 598.546,73
1.856.417,40
59
940
999
378.618,30
830.856,00
1.209.474,30
746.304,90
46 13 351 260 91
814 126 1.228 1.218 10
860 139 1.579 1.478 101
374.895,30 3.723,00 1.242.306,00 776.424,00 465.882,00
747.790,00 83.066,00 1.359.482,00 1.353.257,00 6.225,00
1.122.685,30 86.789,00 2.601.788,00 2.129.681,00 472.107,00
676.406,60 69.898,30 1.359.482,00 1.353.257,00 6.225,00
51
750
801
111.237,00
1.348.471,00
1.459.708,00
1.711.672,00
2.458
5.762
8.22
5.693.761,05
5.404.196,60
11.097.957,65
6.952.773,56
Source: PLN Statistics, 2003, PT PLN (Persero)
170
Tabel 7.14b Captive Power Plants, 2004
PLN Unit/Province Region of Naggroe Aceh. D Region of North Sumatera Region of West Sumatera Region of Riau Region of South Sumatera, Jambi & Bengkulu - South Sumatera - Jambi - Bengkulu Region of Bangka Belitung Regionof Lampung Region of West Kalimantan Region of South & Central Kalimantan - South Kalimantan - Central Kalimantan Region of East Kalimantan Region North, Central Sulawesi & Gorontalo - North Sulawesi - Gorontalo - Central Sulawesi Region of South & Southeast Sulawesi - South Sulawesi - South East Sulawesi Region of Maluku - Maluku - North Maluku Region of Papua Distribution of Bali Region of West Nusa Tenggara Region of East Nusa Tenggara PT PLN Batam PT PLN Tarakan Distribution East Java Distribution Central Java - Central Java - Yogyakarta Distribution West Java - West Java - Banten Distribution Jaya & Tangerang Total Indonesia
Number of Captive Power Plants/CP (Unit) Main Reserved Total CP CP
Installed Capacity (kVA) Main CP
Reserved CP
Total
kVA from PLN Connected to Reserved CP
95
167
262
522.78
54,718.00
55,240.78
26,381.00
65
64
129
67,876.00
144,858.00
212,734.00
210,265.00
77
222
299
53,094.50
75,244.50
128,339.00
141,414.00
485
0
485
832,827.90
0.00
832,827.90
0.00
147
188
335
497,280.10
137,323.00
634,603.10
123,360.08
92 42 13
108 59 21
200 101 34
368,541.00 110,410.00 18,329.10
89,513.35 42,335.50 5,474.00
458,054.35 152,745.50 23,803.10
85,626.93 33,309.50 4,423.65
19
35
54
6,103.00
5,852.60
11,955.60
9,571.50
126
50
176
118,219.00
47,106.00
165,325.00
103,109.50
73
102
175
143,577.00
64,253.00
207,830.00
41,628.00
194
300
494
214,144.00
196,407.00
410,551.00
114,962.00
117 77
226 74
343 151
158,810.00 55,334.00
168,824.00 27,583.00
327,634.00 82,917.00
100,750.00 14,212.00
71
139
210
749,853.50
103,734.00
853,587.50
99,504.70
78
249
327
40,885.00
50,359.00
91,244.00
46,093.00
43 8 27
140 35 74
183 43 101
12,944.00 18,250.00 9,691.00
37,396.00 4,511.50 8,451.50
50,340.00 22,761.50 18,142.50
33,933.00 4,923.00 7,237.00
90
330
420
26,507.00
75,444.45
101,951.45
63,926.98
65 25 0 0 0 0 21
251 79 99 51 48 404 330
316 104 99 51 48 404 351
23,940.00 2,567.00 0.00 0.00 0.00 8,265.00
62,211.45 13,233.00 16,711.67 12,015.62 4,696.05 191,935.00 199,873.50
86,151.45 15,800.00 16,711.67 12,015.62 4,696.05 191,935.00 208,138.50
62,828.10 1,098.88 13,085.80 9,760.60 3,325.20 19,140.10 177,649.55
110
90
200
11,257.40
15,038.30
26,295.70
12,836.90
11
117
128
4,740.00
6,798.60
11,538.60
3,574.00
113 6 262
0 25 332
113 31 594
112,511.00 10,281.60 514,024.00
0.00 3,613.40 493,499.00
112,511.00 13,895.00 1,007,523.00
0.00 6,878.51 232,314.50
59
940
999
378,618.30
830,856.00
1,209,474.30
746,304.90
46 13 1,228 1,218 10
814 126 1,579 1,478 101
860 139 2,807 2,696 111
374,895.30 3,723.00 1,359,482.00 1,353,257.00 6,225.00
747,790.00 83,066.00 2,601,787.50 2,129,680.50 472,107.00
1,122,685.30 86,789.00 3,961,269.50 3,482,937.50 478,332.00
676,406.60 69,898.30 1,359,482.00 1,353,257.00 6,225.00
51
750
801
111,237.00
1,348,471.00
1,459,708.00
1,711,672.00
3,381
6,108
9,489
5,261,306.08
6,471,948.52
11,733,254.60
5,244,013.42
Source: PLN Statistics, 2004, PT PLN (Persero)
171
Table 7.14c Captive Power Plants, 2005
PLN Unit/Province Region of Naggroe Aceh. D Region of North Sumatera Region of West Sumatera Region of Riau Region of South Sumatera, Jambi & Bengkulu - South Sumatera - Jambi - Bengkulu Region of Bangka Belitung Region of Lampung Region of West Kalimantan Region of South & Central Kalimantan - South Kalimantan - Central Kalimantan Region of East Kalimantan Region North, Central Sulawesi & Gorontalo - North Sulawesi - Gorontalo - Central Sulawesi Region of South & Southeast Sulawesi - South Sulawesi - South East Sulawesi Region of Maluku - Maluku - North Maluku Region of Papua Distribution of Bali Region of West Nusa Tenggara Region of East Nusa Tenggara PT PLN Batam PT PLN Tarakan Total Non Java Distribution East Java Distribution Central Java & Yogyakarta - Central Java - Yogyakarta Distribution West Java & Banten - West Java - Banten Distribution Jaya & Tangerang Total Java Total Indonesia
Number of Captive Power Plants/CP (Unit) Main Reserved CP CP Total
Installed Capacity (kVA) Main CP
Reserved CP
Total
kVA from PLN Connected to Reserved CP
232
48
280
456,172.00
0.00
456,172.00
0.00
65
64
129
95,498.00
116,575.00
212,073.00
210,265.00
0
0
0
53,094.50
92,416.50
145,511.00
0.00
107
481
588
830,159.00
118,273.00
948,432.00
118,273.00
210
296
506
890,965.00
183,768.20
1,074,733.20
0.00
114 63 33
143 81 72
257 144 105
610,943.00 244,658.00 35,364.60
117,145.00 54,588.00 12,035.20
728,088.00 299,246.00 47,399.80
0.00 0.00 0.00
0
0
0
0.00
0.00
0.00
0.00
0
95
95
0.00
131,031.00
131,031.00
46,073.00
0
0
0
0.00
0.00
0.00
0.00
0
0
0
0.00
0.00
0.00
0.00
0 0
0 0
0 0
0.00 0.00
0.00 0.00
0.00 0.00
0.00 0.00
71
139
210
749,853.50
103,734.00
853,587.50
99,504.70
78
249
327
40,885.00
50,359.00
91,244.00
0.00
43 8 27
140 35 74
183 43 101
12,944.00 18,250.00 9,691.00
37,396.00 4,511.50 8,451.50
50,340.00 22,761.50 18,142.50
0.00 0.00 0.00
90
325
415
27,152.00
77,037.00
104,189.00
1,166,143.80
65 25 0 0 0 0 21
246 79 108 60 48 0 330
311 104 108 60 48 0 351
24,585.00 2,567.00 0.00 0.00 0.00 0.00 8,265.00
63,804.00 13,233.00 16,840.17 12,015.62 4,824.55 0.00 199,873.50
88,389.00 15,800.00 16,840.17 12,015.62 4,824.55 0.00 208,138.50
64,016.80 1,102,127.00 16,840.17 12,015.62 4,824.55 0.00 177,649.55
52
78
130
17,245.12
15,205.30
32,450.42
0.00
12
118
130
1,870.00
8,586.50
10,456.50
3,512.50
103 3 1,044 266
59 33 2,423 995
162 36 3,467 1,261
161,187.00 3,211.60 3,335,558.32 512,000.00
55,925.30 18,198.50 1,187,822.97 793,000.00
217,112.30 21,410.10 4,523,381.29 1,305,000.00
0.00 0.00 1,838,261.72 799,000.00
0
0
0
0.00
0.00
0.00
0.00
0 0
0 0
0 0
0.00 0.00
0.00 0.00
0.00 0.00
0.00 0.00
0
0
0
0.00
0.00
0.00
0.00
0 0
0 0
0 0
0.00 0.00
0.00 0.00
0.00 0.00
0.00 0.00
51
750
801
111,237.00
1,348,471.00
1,459,708.00
1,711,672.00
317 1,361
1,745 4,168
2,062 5,529
623,237.00 3,958,795.32
2,141,471.00 3,329,293.97
2,764,708.00 7,288,089.29
2,510,672.00 4,348,933.00
Source: PLN Statistics, 2005, PT PLN (Persero)
172
SELECTED WORLD ENERGY STATISTICS VIII. SELECTED WORLD ENERGY STATISTICS
PENGKAJIAN ENERGI UNIVERSITAS INDONESIA
173
174
Table 8.1
World Oil Proven Reserves; 1985, 1995, 2004, 2005 (Thousand Million Barrels)
USA Canada Mexico Total North America Argentina Brazil Colombia Ecuador Peru Trinidad & Tobago Venezuela Other S. & Cent. America Total S. & Cent. America Azerbaijan Denmark Italy Kazakhstan Norway Romania Russian Federation Turkmenistan United Kingdom Uzbekistan Other Europe & Eurasia Total Europe & Eurasia Iran Iraq Kuwait Oman Qatar Saudi Arabia Syria United Arab Emirates Yemen Other Middle East Total Middle East Algeria Angola Chad Rep. of Congo (Brazzaville) Egypt Equatorial Guinea Gabon Libya Nigeria Sudan Tunisia Other Africa Total Africa Australia Brunei China India Indonesia Malaysia Thailand Vietnam Other Asia Pacific Total Asia Pacific TOTAL WORLD
at end 1985 36.4 9.6 55.6 101.5 2.2 2.2 1.2 1.1 0.6 0.6 54.5 0.5 62.9 n.a 0.4 0.6 n.a 5.6 1.4 n.a n.a 5.6 n.a 65.0 78.6 59.0 65.0 92.5 4.1 4.5 171.5 1.5 33.0 0.1 0.2 431.3 8.8 2.0 0.8 3.8 0.7 21.3 16.6 0.3 1.8 1.0 57.0 2.9 1.4 17.1 3.8 9.2 3.5 0.1 1.1 39.1 770.4
at end 1995 29.8 10.5 48.8 89.0 2.4 6.2 3.0 3.4 0.8 0.7 66.3 1.1 83.8 n.a 0.9 0.7 n.a 10.8 1.0 n.a n.a 4.5 n.a 63.6 81.5 93.7 100.0 96.5 5.2 3.7 261.5 2.6 98.1 0.1 0.1 661.5 10.0 3.1 1.3 3.8 0.6 1.5 29.5 20.8 0.3 0.4 0.7 72.0 4.0 1.1 16.3 5.5 5.0 5.2 0.3 0.8 1.0 39.2 1027.0
at end 2004 29.3 16.5 14.8 60.6 2.3 11.2 1.5 5.1 1.1 0.8 79.7 1.3 103.0 7.0 1.3 0.8 39.6 9.7 0.5 72.4 0.5 4.0 0.6 2.2 138.7 132.7 115.0 101.5 5.6 15.2 264.3 3.2 97.8 2.9 0.1 738.2 11.8 9.0 0.9 1.8 3.6 1.8 2.2 39.1 35.9 6.4 0.7 0.6 113.8 4.0 1.1 16.0 5.6 4.3 4.3 0.5 3.1 0.8 39.8 1194.1
at end 2005 29.3 16.5 13.7 59.5 2.3 11.8 1.5 5.1 1.1 0.8 79.7 1.3 103.5 7.0 1.3 0.7 39.6 9.7 0.5 74.4 0.5 4.0 0.6 2.2 140.5 137.5 115.0 101.5 5.6 15.2 264.2 3.0 97.8 2.9 0.1 742.7 12.2 9.0 0.9 1.8 3.7 1.8 2.2 39.1 35.9 6.4 0.7 0.6 114.3 4.0 1.1 16.0 5.9 4.3 4.2 0.5 3.1 1.0 40.2 1200.7
2005 Share of Total 2.4% 1.4% 1.1% 5.0% 0.2% 1.0% 0.1% 0.4% 0.1% 0.1% 6.6% 0.1% 8.6% 0.6% 0.1% 0.1% 3.3% 0.8% 6.2% 0.3% 0.2% 11.7% 11.5% 9.6% 8.5% 0.5% 1.3% 22.0% 0.2% 8.1% 0.2% 61.9% 1.0% 0.8% 0.1% 0.1% 0.3% 0.1% 0.2% 3.3% 3.0% 0.5% 0.1% 9.5% 0.3% 0.1% 1.3% 0.5% 0.4% 0.3% 0.3% 0.1% 3.4% 100.0%
R/P Ratio 11.8 14.8 10.0 11.9 8.7 18.8 7.3 25.6 27.1 13.0 72.6 24.8 40.7 42.4 9.3 17.0 79.6 8.9 11.3 21.4 7.8 6.1 12.9 12.9 22.0 93.0 * * 19.6 38.0 65.6 17.5 97.4 18.3 4.6 81.0 16.6 19.9 14.3 19.3 14.6 13.6 25.8 63.0 38.1 46.3 25.2 12.0 31.8 20.0 14.9 12.1 20.7 10.4 13.9 5.2 21.8 13.2 13.8 40.6
Source : BP Statistical Review of World Energy June 2006
175
Table 8.2
World Oil Production, 2000 – 2005 (Thousand barrels daily)
2000 2001 2002 2003 2004 USA 7,733 7,669 7,626 7,400 7,228 Canada 2,721 2,677 2,858 3,004 3,085 Mexico 3,450 3,560 3,585 3,789 3,824 Total North America 13,904 13,906 14,069 14,193 14,137 Argentina 819 830 818 806 754 Brazil 1,268 1,337 1,499 1,555 1,542 Colombia 711 627 601 564 551 Ecuador 409 416 401 427 535 Peru 100 98 98 92 94 Trinidad & Tobago 138 135 155 164 152 Venezuela 3,239 3,141 2,916 2,607 2,972 Other S. & Cent. America 130 137 152 153 144 Total S. & Cent. America 6,813 6,721 6,640 6,367 6,745 Azerbaijan 281 300 311 313 317 Denmark 363 348 371 368 390 Italy 88 79 106 107 105 Kazakhstan 744 836 1,018 1,111 1,297 Norway 3,346 3,418 3,333 3,264 3,188 Romania 131 130 127 123 119 Russian Federation 6,536 7,056 7,698 8,544 9,287 Turkmenistan 144 162 182 202 193 United Kingdom 2,667 2,476 2,463 2,257 2,028 Uzbekistan 177 171 171 166 152 Other Europe & Eurasia 466 466 501 509 496 Total Europe & Eurasia 14,942 15,443 16,281 16,965 17,572 Iran 3,818 3,730 3,414 3,999 4,081 Iraq 2,583 2,376 2,035 1,339 2,010 Kuwait 2,104 2,070 1,995 2,329 2,481 Oman 959 961 900 823 785 Qatar 855 854 783 917 990 Saudi Arabia 9,511 9,263 8,970 10,222 10,588 Syria 548 581 545 562 529 United Arab Emirates 2,626 2,534 2,324 2,611 2,656 Yemen 450 455 457 448 420 Other Middle East 48 47 48 48 48 Total Middle East 23,501 22,871 21,471 23,296 24,588 Algeria 1,578 1,562 1,680 1,852 1,946 Angola 746 742 905 885 986 Cameroon 88 81 75 68 62 Chad 24 168 Rep. of Congo (Brazzaville) 275 271 258 243 240 Egypt 781 758 751 749 721 Equatorial Guinea 117 173 210 234 329 Gabon 327 301 295 240 235 Libya 1,469 1,421 1,374 1,486 1,607 Nigeria 2,155 2,274 2,103 2,263 2,502 Sudan 174 211 233 255 325 Tunisia 78 71 75 68 72 Other Africa 56 53 63 71 75 Total Africa 7,844 7,918 8,022 8,438 9,266 Australia 809 733 731 624 541 Brunei 193 203 210 214 211 China 3,252 3,306 3,346 3,401 3,481 India 780 780 801 798 816 Indonesia 1,456 1,389 1,288 1,183 1,152 Malaysia 754 748 785 831 857 Thailand 164 174 191 223 220 Vietnam 328 350 354 364 427 Other Asia Pacific 200 195 193 195 186 Total Asia Pacific 7,936 7,877 7,899 7,832 7,890 TOTAL WORLD 74,941 74,736 74,382 77,091 80,198 Includes crude oil, shale oil, oil sands and NGLs (natural gas liquids - the liquid content of natural gas where this is recovered separately).
2005 6,830 3,047 3,759 13,636 725 1,718 549 541 111 171 3,007 142 6,964 452 377 118 1,364 2,969 114 9,551 192 1,808 126 463 17,534 4,049 1,820 2,643 780 1,097 11,035 469 2,751 426 48 25,119 2,015 1,242 58 173 253 696 355 234 1,702 2,580 379 74 72 9,835 554 206 3,627 784 1,136 827 276 392 199 8,000 81,088
Source : BP Statistical Review of World Energy June 2006
176
Table 8.3
World Oil Consumption, 2000 – 2005 (Thousand barrels daily)
USA Canada Mexico Total North America Argentina Brazil Chile Colombia Ecuador Peru Venezuela Other S. & Cent. America Total S. & Cent. America Austria Azerbaijan Belarus Belgium & Luxembourg Bulgaria Czech Republic Denmark Finland France Germany Greece Hungary Iceland Republic of Ireland Italy Kazakhstan Lithuania Netherlands Norway Poland Portugal Romania Russian Federation Slovakia Spain Sweden Switzerland Turkey Turkmenistan Ukraine United Kingdom Uzbekistan Other Europe & Eurasia Total Europe & Eurasia Iran Kuwait Qatar Saudi Arabia United Arab Emirates Other Middle East Total Middle East
2000
2001
2002
2003
2004
2005
19,701 1,937 1,884 23,522 431 1,855 236 232 129 155 496 1,126 4,661 244 123 143 702 84 169 215 224 2,007 2,763 406 145 19 170 1,956 158 49 897 201 427 324 203 2,583 73 1,452 318 263 677 79 255 1,697 138 402 19,564 1,319 202 44 1,536 255 1,379 4,735
19,649 2,023 1,899 23,571 405 1,896 230 245 132 148 545 1,138 4,739 265 81 149 669 87 178 205 222 2,023 2,804 411 142 18 185 1,946 186 56 942 213 415 327 217 2,566 68 1,508 318 281 645 83 273 1,697 135 427 19,743 1,331 206 54 1,551 292 1,421 4,854
19,761 2,067 1,837 23,665 364 1,853 228 222 131 147 594 1,149 4,688 271 74 145 691 88 174 200 226 1,967 2,714 414 140 19 182 1,943 193 53 952 208 420 338 226 2,606 76 1,526 317 267 656 86 278 1,693 130 453 19,726 1,429 222 79 1,572 320 1,425 5,047
20,033 2,132 1,885 24,050 372 1,785 229 222 137 140 479 1,173 4,537 293 86 152 748 98 185 193 239 1,965 2,664 404 132 18 178 1,927 183 51 962 219 435 317 199 2,645 71 1,559 332 259 668 95 286 1,717 148 475 19,903 1,513 238 77 1,684 333 1,394 5,238
20,732 2,248 1,898 24,877 394 1,776 244 223 144 152 525 1,188 4,647 285 92 153 785 102 203 189 224 1,978 2,634 435 136 20 185 1,873 188 54 1,003 210 460 322 230 2,714 68 1,593 319 258 688 103 293 1,764 155 482 20,195 1,575 266 84 1,805 355 1,407 5,492
20,655 2,241 1,978 24,875 421 1,819 257 230 148 139 553 1,208 4,776 294 103 137 809 109 211 189 233 1,961 2,586 429 151 19 196 1,809 208 57 1,071 213 478 320 240 2,753 73 1,618 315 262 650 110 294 1,790 161 502 20,350 1,659 280 98 1,891 376 1,436 5,739
177
Table 8.3
World Oil Consumption, 2000 – 2005 (Continued)
(Thousand barrels daily) 2000
2001
2002
2003
2004
2005
Algeria Egypt South Africa Other Africa Total Africa Australia Bangladesh China China Hong Kong SAR India Indonesia Japan Malaysia New Zealand Pakistan Philippines Singapore South Korea Taiwan Thailand Other Asia Pacific Total Asia Pacific
192 564 475 1,226 2,458 837 66 4,772 201 2,254 1,049 5,577 441 134 373 348 654 2,229 816 725 363 20,839
200 548 488 1,239 2,475 845 80 4,872 243 2,284 1,088 5,435 448 136 366 347 716 2,235 819 701 383 20,998
222 534 501 1,254 2,511 846 80 5,288 268 2,374 1,115 5,359 489 141 357 332 699 2,282 844 766 406 21,644
231 550 513 1,274 2,568 851 78 5,803 269 2,420 1,132 5,455 480 148 321 330 668 2,300 868 836 400 22,359
240 567 523 1,315 2,646 856 80 6,772 314 2,573 1,150 5,286 493 150 325 336 748 2,283 880 913 427 23,586
254 616 529 1,363 2,763 884 82 6,988 285 2,485 1,168 5,360 477 152 353 314 826 2,308 884 946 445 23,957
TOTAL WORLD
75,779
76,379
77,280
78,655
81,444
82,459
Source : BP Statistical Review of World Energy June 2006
178
Table 8.4
World Oil Refinery Capacities, 2000 – 2005 Thousand barrels daily 1997
1998
1999
2000
2001
2002
2003
2004
2005
15,711
16,261
16,512
16,595
16,785
16,757
16,894
17,125
17,335
Canada
1,811
1,844
1,861
1,861
1,917
1,923
1,959
1,915
1,927
Mexico
1,449
1,449
1,449
1,481
1,481
1,463
1,463
1,463
1,463
18,971
19,554
19,822
19,937
20,183
20,143
20,316
20,503
20,725
USA
Total North America Argentina Brazil Neth. Antilles & Aruba Venezuela
653
650
645
626
614
611
611
611
611
1,739
1,750
1,845
1,863
1,823
1,868
1,940
1,940
1,940
545
545
545
545
545
545
545
545
570
1,192
1,199
1,222
1,280
1,277
1,277
1,277
1,277
1,357
Other S. & Cent. America
2,269
2,180
2,224
2,230
2,219
2,266
2,240
2,254
2,285
Total S. &. Cent. America
6,398
6,324
6,481
6,544
6,478
6,567
6,613
6,627
6,763
698
732
736
770
785
803
805
782
778
France
1,872
1,918
1,933
1,984
1,961
1,987
1,967
1,977
1,978
Germany
2,170
2,206
2,240
2,262
2,274
2,286
2,304
2,314
2,322
403
403
403
403
412
412
412
412
412
Italy
2,243
2,271
2,294
2,294
2,294
2,294
2,294
2,294
2,294
Netherlands
1,196
1,196
1,212
1,212
1,233
1,237
1,237
1,239
1,242
308
310
323
318
307
310
310
310
310
Russian Federation
5,929
5,533
5,399
5,351
5,304
5,372
5,407
5,412
5,412
Spain
Belgium
Greece
Norway
1,265
1,247
1,247
1,247
1,247
1,333
1,333
1,358
1,363
Sweden
422
422
422
421
422
422
422
421
422
Turkey
713
713
713
713
713
713
713
693
613
1,823
1,848
1,777
1,778
1,769
1,785
1,813
1,843
1,848
United Kingdom Other Europe and Eurasia
6,135
6,090
5,996
5,890
5,901
5,975
6,038
6,015
6,036
Total Europe and Eurasia
25,177
24,889
24,695
24,643
24,622
24,929
25,055
25,070
25,030
Iran
1,387
1,492
1,574
1,574
1,574
1,574
1,584
1,624
1,684
Iraq
634
634
634
639
644
644
644
644
644
Kuwait
880
895
895
690
745
770
905
905
915
1,704
1,762
1,838
1,846
1,861
1,861
1,911
2,061
2,061
Saudi Arabia United Arab Emirates
298
235
290
440
674
711
645
620
620
Other Middle East
1,164
1,169
1,175
1,173
1,164
1,254
1,255
1,255
1,255
Total Middle East
6,067
6,187
6,406
6,362
6,662
6,814
6,944
7,109
7,179
Total Africa
2,928
2,881
2,983
3,034
3,217
3,294
3,313
3,311
3,311
890
906
924
924
916
933
860
867
813
4,559
4,592
5,401
5,407
5,643
5,479
5,487
6,289
6,587
Australasia China India
1,236
1,356
2,190
2,219
2,261
2,289
2,333
2,513
2,558
Indonesia
1,015
1,095
1,118
1,126
1,126
1,091
1,056
1,056
1,056
Japan
5,056
5,144
5,087
5,010
4,705
4,728
4,645
4,531
4,531
Singapore
1,246
1,246
1,246
1,255
1,255
1,255
1,255
1,255
1,255
South Korea
2,598
2,598
2,598
2,598
2,598
2,598
2,598
2,598
2,598
Taiwan
732
732
732
732
874
1,159
1,159
1,159
1,159
Thailand
824
863
872
872
872
874
860
876
876
Other Asia Pacific
1,107
1,152
1,233
1,292
1,386
1,351
1,313
1,259
1,261
Total Asia Pacific
19,263
19,684
21,401
21,435
21,636
21,757
21,566
22,403
22,694
TOTAL WORLD
78,804
79,519
81,788
81,955
82,798
83,504
83,807
85,023
85,702
Source : BP Statistical Review of World Energy June 2006
179
Table 8.5
World Natural Gas Proven Reserves; 1985, 1995, 2004, 2005 (Trillion cubic meter)
USA Canada Mexico Total North America Argentina Bolivia Brazil Colombia Peru Trinidad & Tobago Venezuela Other S. & Cent. America Total S. & Cent. America Azerbaijan Denmark Germany Italy Kazakhstan Netherlands Norway Poland Romania Russian Federation Turkmenistan Ukraine United Kingdom Uzbekistan Other Europe & Eurasia Total Europe & Eurasia Bahrain Iran Iraq Kuwait Oman Qatar Saudi Arabia Syria United Arab Emirates Yemen Other Middle East Total Middle East Algeria Egypt Libya Nigeria Other Africa Total Africa Australia Bangladesh Brunei China India Indonesia Malaysia Myanmar Pakistan Papua New Guinea Thailand Vietnam Other Asia Pacific Total Asia Pacific TOTAL WORLD
at end 1985 5.41 2.78 2.17 10.37 0.68 0.13 0.09 0.11 + 0.32 1.73 0.24 3.32 n.a 0.09 0.30 0.26 n.a 1.86 0.57 0.10 0.27 n.a n.a n.a 0.65 n.a 40.37 44.45 0.21 13.99 0.82 1.04 0.22 4.44 3.69 0.12 3.15 + 27.67 3.35 0.26 0.63 1.34 0.59 6.16 0.77 0.35 0.24 0.87 0.48 1.98 1.49 0.27 0.62 0.02 0.22 0.00 0.25 7.57 99.54
at end 1995 4.62 1.93 1.92 8.47 0.62 0.13 0.15 0.22 0.20 0.35 4.06 0.23 5.96 n.a 0.12 0.22 0.30 n.a 1.82 1.81 0.15 0.41 n.a n.a n.a 0.70 n.a 57.64 63.16 0.15 19.35 3.36 1.49 0.45 8.50 5.54 0.24 5.86 0.43 + 45.37 3.69 0.65 1.31 3.47 0.81 9.93 1.28 0.27 0.40 1.67 0.68 1.95 2.27 0.27 0.60 0.43 0.18 0.15 0.41 10.54 143.42
at end 2004 5.45 1.59 0.42 7.46 0.55 0.76 0.33 0.12 0.33 0.53 4.29 0.17 7.07 1.37 0.08 0.20 0.18 3.00 1.45 2.39 0.11 0.30 47.80 2.90 1.11 0.53 1.86 0.46 63.73 0.09 26.74 3.17 1.57 1.00 25.78 6.83 0.31 6.06 0.48 0.05 72.09 4.55 1.87 1.49 5.23 1.17 14.30 2.52 0.44 0.34 2.20 0.92 2.77 2.46 0.50 0.80 0.43 0.35 0.24 0.38 14.35 179.00
at end 2005 5.45 1.59 0.41 7.46 0.50 0.74 0.31 0.11 0.33 0.55 4.32 0.17 7.02 1.37 0.07 0.19 0.17 3.00 1.41 2.41 0.11 0.63 47.82 2.90 1.11 0.53 1.85 0.46 64.01 0.09 26.74 3.17 1.57 1.00 25.78 6.90 0.31 6.04 0.48 0.05 72.13 4.58 1.89 1.49 5.23 1.20 14.39 2.52 0.44 0.34 2.35 1.10 2.76 2.48 0.50 0.96 0.43 0.35 0.24 0.37 14.84 179.83
2005 Share of Total 3.0% 0.9% 0.2% 4.1% 0.3% 0.4% 0.2% 0.1% 0.2% 0.3% 2.4% 0.1% 3.9% 0.8% 0.1% 0.1% 1.7% 0.8% 1.3% 0.1% 0.3% 26.6% 1.6% 0.6% 0.3% 1.0% 0.3% 35.6% 0.1% 14.9% 1.8% 0.9% 0.6% 14.3% 3.8% 0.2% 3.4% 0.3% 40.1% 2.5% 1.1% 0.8% 2.9% 0.7% 8.0% 1.4% 0.2% 0.2% 1.3% 0.6% 1.5% 1.4% 0.3% 0.5% 0.2% 0.2% 0.1% 0.2% 8.3% 100.0%
R/P Ratio 10.4 8.6 10.4 9.9 11.1 71.1 27.3 16.7 * 18.8 * 87.7 51.8 * 6.5 11.8 14.0 * 22.3 28.3 25.3 48.6 80.0 49.3 58.7 6.0 33.2 47.0 60.3 9.1 * * * 56.9 * 99.3 57.3 * * 26.7 * 52.2 54.4 * * * 88.3 67.9 30.7 28.3 47.0 36.2 36.3 41.4 38.5 32.2 * 16.5 45.6 34.7 41.2 65.1
Source : BP Statistical Review of World Energy June 2006
180
Table 8.6
World Natural Gas Production, 1997 – 2005 (Billion cubic metres)
USA Canada Mexico Total North America Argentina Bolivia Brazil Colombia Trinidad & Tobago Venezuela Other S. & Cent. America Total S. & Cent. America Azerbaijan Denmark Germany Italy Kazakhstan Netherlands Norway Poland Romania Russian Federation Turkmenistan Ukraine United Kingdom Uzbekistan Other Europe & Eurasia Total Europe & Eurasia Bahrain Iran Kuwait Oman Qatar Saudi Arabia Syria United Arab Emirates Other Middle East Total Middle East Algeria Egypt Libya Nigeria Other Africa Total Africa Australia Bangladesh Brunei China India Indonesia Malaysia Myanmar New Zealand Pakistan Thailand Vietnam Other Asia Pacific Total Asia Pacific TOTAL WORLD
1997 543.1 165.8 31.7 740.6 27.4 2.7 6.0 5.9 7.4 30.8 2.4 82.5 5.6 7.9 17.1 19.3 7.6 67.1 43.0 3.6 15.0 532.6 16.1 17.4 85.9 47.8 13.4 899.1 8.0 47.0 9.3 5.0 17.4 45.3 3.8 36.3 3.3 175.4 71.8 11.6 6.0 5.1 4.9 99.4 29.8 7.6 11.7 22.7 23.0 67.2 38.6 1.5 5.2 15.6 15.2 0.5 3.5 242.2 2239.3
1998 549.2 171.3 34.3 754.8 29.6 2.8 6.3 6.3 8.6 32.3 2.5 88.4 5.2 7.6 16.7 19.0 7.4 63.6 44.2 3.6 14.0 551.3 12.4 16.8 90.2 51.1 12.4 915.5 8.4 50.0 9.5 5.2 19.6 46.8 4.3 37.1 3.2 184.0 76.6 12.2 5.8 5.1 5.0 104.8 30.4 7.8 10.8 23.3 24.7 64.3 38.5 1.8 4.6 16.0 16.3 0.9 3.6 242.7 2290.1
1999 541.6 177.4 37.2 756.2 34.6 2.3 6.7 5.2 11.7 27.4 2.1 90.0 5.6 7.8 17.8 17.5 9.3 59.3 48.5 3.4 14.0 551.0 21.3 16.9 99.1 51.9 11.5 934.9 8.7 56.4 8.6 5.5 22.1 46.2 4.5 38.5 3.4 193.8 86.0 14.7 4.7 6.0 5.4 116.9 30.8 8.3 11.2 25.2 25.9 71.0 40.8 1.7 5.3 17.3 17.7 1.3 3.6 260.1 2351.9
2000 550.6 183.2 35.8 769.6 37.4 3.2 7.2 5.9 14.1 27.9 2.2 97.9 5.3 8.1 16.9 16.2 10.8 57.3 49.7 3.7 13.8 545.0 43.8 16.7 108.4 52.6 11.3 959.5 8.8 60.2 9.6 8.7 23.7 49.8 4.2 38.4 3.4 206.8 84.4 18.3 5.3 12.5 5.9 126.5 31.2 10.0 11.3 27.2 26.9 68.5 45.3 3.4 5.6 18.8 18.6 1.6 3.7 272.0 2432.3
2001 565.8 186.8 35.3 787.9 37.1 4.7 7.6 6.1 15.2 29.6 2.3 102.6 5.2 8.4 17.0 15.2 10.8 61.9 53.9 3.9 13.6 542.4 47.9 17.1 105.9 53.5 11.0 967.7 9.1 66.0 8.5 14.0 27.0 53.7 4.1 39.4 3.0 224.8 78.2 21.5 5.6 14.9 6.6 126.8 32.5 10.7 11.4 30.3 27.2 66.3 46.9 7.2 5.9 19.8 18.0 2.0 3.9 282.2 2492.1
2002 544.3 187.8 35.3 767.4 36.1 4.9 9.2 6.2 17.3 28.4 2.3 104.4 4.8 8.4 17.0 14.6 10.6 59.9 65.5 4.0 13.2 555.4 49.9 17.4 103.6 53.8 11.3 989.4 9.5 75.0 8.0 15.0 29.5 56.7 5.0 43.4 2.6 244.7 80.4 22.7 5.6 14.2 6.8 129.6 32.6 11.4 11.5 32.7 28.7 70.4 48.3 8.4 5.6 20.6 18.9 2.4 5.5 297.0 2532.6
2003 551.4 182.7 36.4 770.5 41.0 6.4 10.0 6.1 24.7 25.2 2.2 115.7 4.8 8.0 17.7 13.7 12.9 58.4 73.1 4.0 13.0 578.6 55.1 17.7 102.9 53.6 10.7 1024.4 9.6 81.5 9.1 16.5 31.4 60.1 5.2 44.8 1.8 259.9 82.8 25.0 5.8 19.2 6.9 139.7 33.2 12.3 12.4 35.0 29.9 72.8 51.8 9.6 4.3 23.2 19.6 2.4 6.7 313.1 2623.3
2004 539.4 183.6 37.4 760.4 44.9 8.5 11.0 6.4 28.1 28.1 2.8 129.7 4.7 9.4 16.4 13.0 20.6 68.8 78.5 4.4 12.8 591.0 54.6 19.1 96.0 55.8 11.0 1055.9 9.8 84.9 9.7 17.2 39.2 65.7 5.3 46.3 2.5 280.4 82.0 26.9 6.5 21.8 7.0 144.3 35.3 13.3 12.2 41.0 30.1 75.4 53.9 10.2 3.8 26.9 20.3 4.2 6.5 333.0 2703.8
2005 525.7 185.5 39.5 750.6 45.6 10.4 11.4 6.8 29.0 28.9 3.5 135.6 5.3 10.4 15.8 12.0 23.5 62.9 85.0 4.3 12.9 598.0 58.8 18.8 88.0 55.7 9.8 1061.1 9.9 87.0 9.7 17.5 43.5 69.5 5.4 46.6 3.4 292.5 87.8 34.7 11.7 21.8 7.0 163.0 37.1 14.2 12.0 50.0 30.4 76.0 59.9 13.0 3.7 29.9 21.4 5.2 7.3 360.1 2763.0
Source : BP Statistical Review of World Energy June 2006
181
Table 8.7
World Natural Gas Consumption, 1997 – 2005
USA
1997
1998
1999
2000
2001
2002
(Billion cubic metres) 2003 2004 2005
653.2
642.2
644.3
669.7
641.4
661.6
643.1
645.0
633.5
Canada
83.8
85.0
83.1
83.0
82.8
85.6
92.2
92.7
91.4
Mexico
32.3
35.4
37.4
38.5
39.0
42.7
45.8
48.6
49.6
769.3
762.6
764.8
791.2
763.2
789.9
781.1
786.3
774.5
28.5
30.5
32.4
33.2
31.1
30.3
34.6
37.9
40.6
Brazil
6.0
6.3
7.1
9.3
11.7
14.4
15.9
19.0
20.2
Chile
2.8
3.3
4.6
5.2
6.3
6.5
7.1
8.3
7.6
Colombia
5.9
6.2
5.2
5.9
6.1
6.1
6.0
6.3
6.8
Ecuador
0.1
0.1
0.1
0.1
0.2
0.1
0.1
0.2
0.2
Total North America Argentina
Peru Venezuela
0.2
0.4
0.4
0.3
0.4
0.4
0.5
0.9
1.6
30.8
32.3
27.4
27.9
29.6
28.4
25.2
28.1
28.9
Other S. & Cent. America
8.5
10.0
11.3
11.9
13.6
14.4
15.9
17.1
18.3
Total S. & Cent. America
82.9
89.1
88.5
94.0
98.9
100.7
105.3
117.7
124.1
Austria
8.1
8.3
8.5
8.1
8.6
8.5
9.4
9.5
10.0
Azerbaijan
5.6
5.2
5.6
5.4
7.8
7.8
8.0
8.6
8.8
Belarus
14.8
15.0
15.3
16.2
16.1
16.6
16.3
18.5
18.9
Belgium & Luxembourg
12.5
13.8
14.7
14.9
14.6
14.8
16.0
16.5
16.8
Bulgaria
4.1
3.5
3.0
3.3
3.0
2.7
2.8
2.9
3.2
Czech Republic
8.5
8.5
8.6
8.3
8.9
8.7
8.7
8.7
8.5
Denmark
4.4
4.8
5.0
4.9
5.1
5.2
5.2
5.2
5.0
Finland
3.2
3.7
3.7
3.7
4.1
4.0
4.5
4.3
4.0
France
34.6
37.0
37.7
39.7
41.7
41.7
43.3
44.5
45.0
Germany
79.2
79.7
80.2
79.5
82.9
82.6
85.5
85.9
85.9
Greece
0.2
0.8
1.4
1.9
1.9
2.0
2.3
2.5
2.5
Hungary
10.8
10.9
11.0
10.7
11.9
12.0
13.1
13.0
13.4
Iceland
-
-
-
-
-
-
-
-
-
3.1
3.1
3.3
3.8
4.0
4.1
4.1
4.1
3.9
53.2
57.2
62.2
64.9
65.0
64.6
70.9
73.6
79.0
Kazakhstan
7.1
7.3
7.9
9.7
10.1
11.1
13.3
15.4
17.8
Lithuania
2.6
2.3
2.4
2.7
2.8
2.9
3.1
3.1
3.2
39.1
38.7
37.9
39.2
39.1
39.3
40.3
41.1
39.5
Republic of Ireland Italy
Netherlands Norway
3.7
3.8
3.6
4.0
3.8
4.0
4.3
4.6
4.5
Poland
10.5
10.6
10.3
11.1
11.5
11.2
11.2
13.1
13.6
0.1
0.8
2.3
2.4
2.6
2.8
3.0
3.1
3.0
Portugal Romania Russian Federation Slovakia
20.0
18.7
17.2
17.1
16.6
17.2
18.3
17.5
17.3
350.4
364.7
363.6
377.2
372.7
388.9
392.9
401.9
405.1
6.3
6.4
6.4
6.5
6.9
6.5
6.3
6.1
5.9
12.3
13.1
15.0
16.9
18.2
20.8
23.6
27.4
32.3
Sweden
0.8
0.9
0.8
0.7
0.7
0.8
0.8
0.8
0.8
Switzerland
2.5
2.6
2.7
2.7
2.8
2.8
2.9
3.0
3.1
Spain
Turkey
9.4
9.9
12.0
14.1
16.0
17.4
20.9
22.1
27.4
Turkmenistan
10.1
10.3
11.3
12.6
12.9
13.2
14.6
15.5
16.6
Ukraine
74.3
68.8
73.0
73.1
70.9
69.8
68.0
72.9
72.9
United Kingdom
84.5
87.9
92.5
96.9
96.4
95.1
95.3
97.0
94.6
Uzbekistan
45.4
47.0
49.3
47.1
51.1
52.4
47.2
44.8
44.0
Other Europe & Eurasia
14.7
14.6
12.9
13.5
14.7
13.8
14.2
14.4
15.3
Total Europe & Eurasia
936.1
959.9
981.3
1013.0
1025.4
1045.2
1070.6
1101.2
1121.9
182
Table 8.7
World Natural Gas Consumption, 1997 – 2005 (Continued)
Iran
1997
1998
1999
2000
2001
2002
(Billion cubic metres) 2003 2004 2005
47.1
51.8
58.4
62.9
70.2
79.2
82.9
86.5
Kuwait
9.3
9.5
8.6
9.6
8.5
8.0
9.1
9.7
9.7
Qatar
14.5
14.8
14.0
9.7
11.0
11.1
12.2
14.9
15.9
88.5
Saudi Arabia
45.3
46.8
46.2
49.8
53.7
56.7
60.1
65.7
69.5
United Arab Emirates
29.0
30.4
31.4
31.4
32.3
36.4
37.9
40.2
40.4
Other Middle East
19.6
20.5
21.5
22.1
22.8
23.6
23.9
25.3
27.0
Total Middle East
164.9
173.7
180.1
185.4
198.4
215.1
226.1
242.3
251.0
Algeria
20.2
20.9
21.3
19.8
20.5
20.2
21.4
22.0
24.1
Egypt
11.6
12.0
14.3
18.3
21.5
22.7
24.6
26.2
25.5
South Africa
-
-
-
-
-
-
-
-
-
Other Africa
14.4
14.9
15.2
17.0
17.1
17.2
19.2
20.4
21.6
Total Africa
46.1
47.7
50.9
55.2
59.1
60.1
65.2
68.6
71.2
Australia
21.4
22.4
23.2
23.9
24.5
25.2
26.1
25.3
25.7
7.6
7.8
8.3
10.0
10.7
11.4
12.3
13.3
14.2
19.0
19.7
20.9
23.8
26.8
28.6
33.2
39.0
47.0
2.6
2.5
2.7
2.5
2.5
2.4
1.5
2.2
2.2
23.0
24.7
25.9
26.9
27.2
28.7
29.9
32.7
36.6
Bangladesh China China Hong Kong SAR India Indonesia
31.9
27.8
31.8
32.3
33.5
34.5
33.4
36.9
39.4
Japan
66.0
68.7
71.7
74.9
76.6
75.2
82.6
78.7
81.1
Malaysia
16.7
17.4
16.1
24.3
25.8
26.8
31.8
33.9
34.9
5.1
4.5
5.2
5.5
5.7
5.5
4.1
3.7
3.6
15.6
16.0
17.3
18.8
19.8
20.6
23.2
26.9
29.9
^
^
^
^
0.1
1.8
2.7
2.4
3.0
New Zealand Pakistan Philippines Singapore South Korea Taiwan Thailand Other Asia Pacific Total Asia Pacific TOTAL WORLD
1.5
1.5
1.5
1.7
4.5
4.9
5.3
6.6
6.5
16.4
15.4
18.7
21.0
23.1
25.7
26.9
31.5
33.3
5.1
6.4
6.2
6.7
7.4
8.5
8.7
10.2
10.7
14.2
15.1
16.4
19.2
22.2
23.9
26.3
27.4
29.9
4.3
4.7
5.0
5.1
5.2
5.3
5.6
7.8
8.9
250.4
254.3
270.9
296.7
315.7
329.0
353.8
378.5
406.9
2249.7
2287.3
2336.5
2435.4
2460.8
2540.0
2601.9
2694.7
2749.6
Source : BP Statistical Review of World Energy June 2006
183
Table 8.8
World Coal Proven Reserves by Type, 2005
USA Canada
Sub-bituminous and Lignite
Total
111,338
135,305
246,643
0
240
3,471
3,107
6,578
0
101
Mexico Total North America
860
351
1,211
0
121
115,669
138,763
254,432
0
231
-
10,113
10,113
0
*
6,230
381
6,611
0
112 56
Brazil Colombia
(Million tonnes) Share of total R/P ratio
Anthracite and bituminous
Venezuela
479
-
479
0
Other S. & Cent. America
992
1,698
2,690
0
*
Total S. & Cent. America
7,701
12,192
19,893
0
269
Bulgaria Czech Republic
4
2,183
2,187
0
83
2,094
3,458
5,552
0
90
France
15
-
15
183
6,556
6,739
0
-
3,900
3,900
0
54
198
3,159
3,357
0
351
Kazakhstan
28,151
3,128
31,279
0
362
Poland
14,000
-
14,000
0
88
22
472
494
0
16
49,088
107,922
157,010
0
*
200
330
530
0
27
Germany Greece Hungary
Romania Russian Federation Spain Turkey Ukraine
25 33
278
3,908
4,186
0
68
16,274
17,879
34,153
0
436
0
370
United Kingdom
220
-
220
Other Europe & Eurasia
1,529
21,944
23,473
Total Europe & Eurasia
112,256
174,839
287,095
0
241
48,750
-
48,750
0
198 126
South Africa
11
Zimbabwe
502
-
502
0
Other Africa
910
174
1,084
0
Middle East
419
-
419
493 399
Total Africa & Middle East
50,581
174
50,755
0
200
Australia
38,600
39,900
78,500
0
213
China
62,200
52,300
114,500
0
52
India
90,085
2,360
92,445
0
217
Indonesia
740
4,228
4,968
0
Japan
359
-
359
New Zealand
33
538
571
0
111
North Korea
300
300
600
0
20
Pakistan
-
3,050
3,050
0
South Korea
-
80
80
Thailand
-
1,354
1,354
Vietnam
150
-
150
5
Other Asia Pacific
97
215
312
25
Total Asia Pacific
192,564
104,325
296,889
0
92
TOTAL WORLD Less than 0.05% * More than 500 years
478,771
430,293
909,064
1
155
37 323
* 28
0
64
Source : BP Statistical Review of World Energy June 2006
184
Table 8.9
World Coal Production, 1995-2005 (Million Ton Oil Equivalent) 1997
USA
1998
1999
2000
2001
2002
2003
2004
2005
580.3
598.4
579.7
565.6
587.3
565.6
549.3
567.9
576.2
Canada
43.0
40.8
39.2
37.1
37.6
34.9
32.2
34.9
34.4
Mexico
4.5
4.8
4.9
5.4
5.4
5.2
4.6
4.7
4.8
627.8
644.0
623.8
608.1
630.3
605.7
586.0
607.4
615.3
2.1
2.0
2.1
2.9
2.1
1.9
1.8
2.0
2.2
Colombia
21.0
21.9
21.3
24.9
28.5
25.7
32.5
34.9
38.4
Venezuela
3.9
4.7
4.8
5.8
5.6
5.9
5.1
5.9
6.2
Other S. & Cent. America
1.1
0.4
0.5
0.5
0.5
0.4
0.3
0.2
0.5
Total S. & Cent. America
28.1
29.1
28.7
34.0
36.8
33.9
39.7
43.0
47.3
Total North America Brazil
Bulgaria Czech Republic France Germany
4.9
5.0
4.2
4.4
4.4
4.4
4.6
4.5
4.4
27.9
26.0
23.1
25.0
25.4
24.3
24.2
23.5
23.5
4.3
3.6
3.3
2.3
1.5
1.1
1.3
0.4
0.2
66.9
61.3
59.4
56.5
54.1
55.0
54.1
54.7
53.2
Greece
7.7
8.1
8.0
8.2
8.5
9.1
9.5
9.6
9.6
Hungary
3.3
3.0
3.1
2.9
2.9
2.7
2.8
2.3
2.0
Kazakhstan
37.3
36.0
30.0
38.5
40.7
37.8
43.3
44.4
44.0
Poland
92.1
79.6
77.0
71.3
71.7
71.3
71.4
70.5
68.7
7.4
5.7
5.1
6.4
7.1
6.6
7.0
6.7
6.5
109.3
103.9
112.0
115.8
121.5
114.8
124.9
128.6
137.0
Spain
9.8
9.3
8.6
8.0
7.6
7.2
6.8
6.7
6.4
Turkey
13.1
13.9
13.3
13.9
14.2
11.5
10.5
10.5
12.8
Ukraine
39.8
39.9
41.3
42.2
43.8
43.0
41.5
41.9
40.7
United Kingdom
29.4
25.0
22.5
19.0
19.4
18.2
17.2
15.3
12.5
Other Europe & Eurasia
15.9
16.7
13.4
14.0
14.3
15.2
15.6
15.6
14.6
Total Europe & Eurasia
469.2
437.0
424.3
428.6
437.3
422.2
434.6
435.2
436.2
Romania Russian Federation
Total Middle East
0.6
0.6
0.7
0.6
0.5
0.4
0.6
0.6
0.6
124.6
127.1
125.6
126.6
126.0
124.1
133.9
136.9
138.9
Zimbabwe
3.4
3.5
3.2
2.8
2.9
2.6
2.0
2.4
2.6
Other Africa
1.2
1.4
1.3
1.2
1.2
1.3
1.2
1.3
1.3
South Africa
Total Africa
129.2
132.0
130.1
130.7
130.0
128.0
137.0
140.6
142.8
Australia
148.1
149.8
160.6
166.2
179.8
184.0
189.5
197.0
202.4
China
690.0
628.7
645.9
656.7
697.6
733.7
868.4
1007.3
1107.7
India
149.6
150.3
147.4
157.0
160.3
168.1
175.9
191.0
199.6
33.7
38.3
45.3
47.4
56.9
63.6
69.4
81.4
83.2
Japan
2.4
2.0
2.2
1.7
1.8
0.8
0.7
0.7
0.6
New Zealand
2.0
2.0
2.1
2.2
2.4
2.7
3.2
3.2
3.2
Pakistan
1.4
1.5
1.5
1.4
1.5
1.6
1.5
1.5
1.6
South Korea
2.0
2.0
1.9
1.9
1.7
1.5
1.5
1.4
1.3
Thailand
6.9
6.1
5.7
5.1
5.6
5.7
5.3
5.6
5.9
Vietnam
6.4
6.4
4.9
6.5
7.5
9.2
10.8
14.7
18.3
Indonesia
Other Asia Pacific
17.2
15.7
18.0
19.3
19.7
19.0
19.5
20.4
21.2
Total Asia Pacific
1059.7
1002.7
1035.5
1065.5
1134.8
1189.9
1345.6
1524.2
1644.9
TOTAL WORLD
2314.5
2245.5
2243.1
2267.4
2369.8
2380.0
2543.6
2751.0
2887.2
Source : BP Statistical Review of World Energy June 2006
185
Table 8.10
World Coal Consumption, 1997-2005 (Million Ton Oil Equivalent)
USA
1997
1998
1999
2000
2001
2002
2003
2004
2005
540.4
545.8
544.9
569.1
552.3
552.0
562.5
566.2
575.4
Canada
26.8
28.1
27.8
29.4
32.0
31.0
30.6
30.5
32.5
Mexico
5.7
5.9
6.0
6.2
6.8
7.6
8.6
7.0
6.0
573.0
579.7
578.7
604.6
591.1
590.6
601.7
603.7
613.9
Total North America Argentina Brazil
0.8
0.8
0.9
0.8
0.6
0.5
0.7
0.8
0.8
11.5
11.4
11.9
12.5
12.2
11.5
11.8
12.8
13.5
Chile
4.2
3.7
3.9
3.0
2.3
2.4
2.3
2.9
2.4
Colombia
3.0
2.8
2.4
2.7
2.7
2.5
2.4
2.0
2.3
-
-
-
-
-
-
-
-
-
0.4
0.4
0.5
0.5
0.4
0.4
0.5
0.6
0.6 0.1
Ecuador Peru Venezuela
^
^
0.1
^
^
0.1
0.1
0.1
Other S. & Cent. America
0.4
0.5
0.6
0.6
0.7
0.9
1.3
1.4
1.4
Total S. & Cent. America
20.3
19.7
20.2
20.2
19.0
18.2
19.0
20.4
21.1
3.1
3.0
3.2
3.2
2.9
3.0
2.9
2.4
2.5
-
-
-
-
^
^
^
^
^
Belarus
0.6
0.4
0.1
0.1
0.1
0.1
0.1
0.1
0.1
Belgium & Luxembourg
7.5
7.9
6.9
7.6
7.6
6.7
6.5
6.4
6.4
Bulgaria
7.8
8.2
6.6
6.3
6.9
6.5
7.3
7.7
7.4
22.8
20.5
19.0
21.0
21.2
20.6
20.8
20.5
20.5
Denmark
6.7
5.6
4.7
4.0
4.2
4.2
5.7
4.6
3.6
Finland
4.5
3.4
3.6
3.5
4.0
4.4
5.8
5.3
2.5
France
13.4
16.1
14.3
13.9
12.1
12.4
13.3
12.8
13.3
Germany
Austria Azerbaijan
Czech Republic
86.8
84.8
80.2
84.9
85.0
84.6
87.2
85.4
82.1
Greece
7.6
8.8
9.1
9.2
9.3
9.8
9.4
9.0
9.0
Hungary
3.7
3.4
3.4
3.2
3.4
3.1
3.4
3.1
2.7
Iceland
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
Republic of Ireland
2.0
1.9
1.6
1.9
1.9
1.7
1.8
1.8
1.9
Italy
11.0
11.6
11.6
13.0
13.7
14.2
15.3
17.1
16.9
Kazakhstan
22.4
22.9
19.8
23.2
22.5
22.8
25.2
26.5
27.2
Lithuania
0.1
0.1
0.1
0.1
0.1
0.1
0.2
0.2
0.2
Netherlands
9.5
9.4
7.7
8.6
8.5
8.9
9.1
9.1
8.7
Norway
0.6
0.7
0.7
0.7
0.6
0.5
0.5
0.6
0.5
Poland
70.1
63.8
61.0
57.6
58.0
56.7
57.7
57.3
56.7
Portugal
3.6
3.6
3.6
4.5
3.7
4.1
3.8
3.9
3.8
Romania
8.4
7.0
6.7
7.0
7.2
7.6
7.8
7.4
7.1
106.3
100.0
104.1
106.0
109.0
103.9
109.4
106.8
111.6
Russian Federation Slovakia
4.7
4.5
4.3
4.0
4.1
4.0
4.2
4.1
4.3
17.7
17.7
20.5
21.6
19.5
21.9
20.5
21.0
21.4
Sweden
2.1
2.0
2.0
1.9
2.0
2.2
2.2
2.3
2.2
Switzerland
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
0.1
22.3
24.0
22.6
25.5
21.8
21.2
21.8
23.0
26.1
Spain
Turkey Turkmenistan
-
-
-
-
-
-
-
-
-
Ukraine
38.0
36.9
38.5
38.8
39.4
38.3
39.0
38.1
37.4
United Kingdom
39.6
39.7
35.6
36.7
40.0
36.6
38.8
38.1
39.1
1.2
1.2
0.9
1.0
1.1
1.0
1.0
1.2
1.1
Other Europe & Eurasia
21.3
21.7
17.0
18.0
17.3
19.0
20.1
20.9
21.3
Total Europe & Eurasia
545.8
530.8
509.6
527.3
527.2
520.5
540.8
536.7
537.5
Uzbekistan
186
Table 8.10
World Coal Consumption, 1997-2005 (Continued) (Million Ton Oil Equivalent)
Iran
1997
1998
1999
2000
2001
2002
2003
2004
2005
0.9
1.0
1.0
1.1
1.1
1.1
1.1
1.1
1.1
Kuwait
-
-
-
-
-
-
-
-
-
Qatar
-
-
-
-
-
-
-
-
-
Saudi Arabia
-
-
-
-
-
-
-
-
-
United Arab Emirates
-
-
-
-
-
-
-
-
-
Other Middle East
5.4
5.8
5.7
6.2
7.2
7.6
7.9
8.0
7.9
Total Middle East
6.3
6.8
6.7
7.3
8.3
8.7
9.0
9.1
9.0
Algeria
0.3
0.5
0.5
0.5
0.6
0.9
0.8
0.8
0.9
Egypt South Africa
0.8
0.8
0.6
0.6
0.7
0.7
0.5
0.5
0.5
84.3
83.4
82.3
81.9
80.6
83.5
89.3
94.5
91.9
Other Africa
6.8
7.0
6.5
6.4
7.4
7.2
6.6
7.0
7.0
Total Africa
92.3
91.6
89.9
89.4
89.3
92.3
97.2
102.9
100.3
Australia
45.1
47.3
47.9
48.3
49.6
52.3
50.9
52.4
52.2
Bangladesh China China Hong Kong SAR India Indonesia Japan
0.3
0.1
^
0.3
0.4
0.4
0.4
0.4
0.4
700.2
651.9
656.2
667.4
681.3
713.8
853.1
978.2
1081.9
3.5
4.4
3.9
3.7
4.9
5.4
6.6
6.6
7.2
160.2
159.8
158.9
169.1
172.1
181.7
188.4
203.7
212.9
8.2
9.3
11.6
13.7
16.7
18.0
17.9
22.1
23.5
89.8
88.4
91.5
98.9
103.0
106.6
112.2
120.8
121.3
Malaysia
1.7
1.6
1.8
1.9
2.6
3.6
4.2
5.7
6.3
New Zealand
1.2
1.1
1.2
1.1
1.3
1.3
1.9
2.0
2.1
Pakistan
2.1
2.1
2.1
2.0
2.1
2.4
2.9
3.5
4.1
Philippines
2.4
2.7
2.9
4.3
4.5
4.7
4.7
5.0
5.9
Singapore
-
-
-
-
-
-
-
-
-
South Korea
34.8
36.1
38.2
43.0
45.7
49.1
51.1
53.1
54.8
Taiwan
21.9
23.8
24.9
28.9
30.8
32.9
35.3
36.8
38.2
8.7
7.3
7.9
7.8
8.8
9.2
9.4
10.6
11.8
19.9
18.4
19.1
21.7
22.5
22.0
22.5
25.4
25.7
1100.0
1054.3
1068.2
1112.2
1146.5
1203.2
1361.5
1526.2
1648.1
2337.7
2282.9
2273.2
2360.9
2381.3
2433.5
2629.2
2798.9
2929.8
Thailand Other Asia Pacific Total Asia Pacific TOTAL WORLD
Source : BP Statistical Review of World Energy June 2006
187
Table 8.11 World Primary Energy Production by Source, 1980-2004
Natural Year
Coal
Gas
Natural Gas Crude Oil 2
1
Plant Liquids
Nuclear Electric Power
3
Hydroelectric Power
3
Geothermal 3 and Other 4
1980
71.24
54.73
128.04
[R]
5.1
7.58
17.9
2.94
1981
71.63
55.56
120.11
[R]
5.37
[R]
8.53
18.26
3.1
1982
74.25
55.49
114.45
[R]
5.35
[R]
9.51
18.71
3.27
1983
74.25
56.12
113.97
5.36
[R]
10.72
19.69
1984
78.38
61.78
116.88
[R]
5.73
[R]
12.99
20.19
[R]
1985
82.2
64.22
115.37
[R]
5.83
[R]
15.3
20.42
1986
84.28
65.32
120.18
[R]
6.15
[R]
16.25
20.89
1987
86.08
68.48
121.07
[R]
6.35
[R]
17.64
20.9
[R]
1988
87.94
71.8
125.84
[R]
6.65
[R]
19.23
21.48
[R]
1989
89.43
74.24
127.83
[R]
6.69
[R]
19.74
21.53
[R]
4.34
1990
90.93
75.87
129.35
[R]
6.87
[R]
20.36
22.35
[R]
3.93
1991
86.29
76.69
128.73
[R]
7.12
[R]
21.18
22.83
[R]
1992
86.05
[R]
76.9
128.93
[R]
7.36
[R]
21.28
22.71
1993
84.28
[R]
78.41
128.72
[R]
7.66
[R]
22.01
23.94
1994
86.27
79.18
130.56
[R]
8.27
[R]
22.41
1995
88.87
[R]
80.24
133.32
8.55
[R]
23.26 24.11
25.79
[R]
4.81
[R]
372.98
[R]
8.94
[R]
23.88
26.07
[R]
4.91
[R]
380.75
[R]
9.17
[R]
24.32
26.06
[R]
4.89
[R]
384.39
[R]
9.47
[R]
25.09
[R]
26.56
[R]
5.09
[R]
385.32
[R]
397.13
[R] [R]
[R]
282.56
[R]
[R]
281.05
[R]
3.56
[R]
283.68
[R]
3.7
[R]
299.65
[R]
[R]
3.78
[R]
307.13
[R]
[R]
3.78
[R]
316.85
[R]
3.79
[R]
324.33
[R]
3.96
[R]
336.9
[R]
[R]
343.8
[R]
[R]
349.66
[R]
4.03
[R]
346.86
[R]
[R]
4.29
[R]
347.53
[R]
[R]
4.31
[R]
349.32
[R]
24.15
[R]
4.49
[R]
355.32
[R]
25.34
[R]
4.64
[R]
364.23
[R]
88.92
83.99
[R]
136.61
1997
92.15
[R]
84.29
[R]
140.52
1998
90.86
[R]
85.95
[R]
143.14
1999
90.43
[R]
87.89
2000
91.36
[R]
91.34
[R]
146.55
[R]
9.87
[R]
25.66
[R]
27.01
[R]
5.35
[R]
2001
96.89
[R]
93.74
[R]
145.32
[R]
10.32
[R]
26.39
[R]
26.39
[R]
5.25
[R]
404.3
2002
97.05
[R]
96.72
[R]
143.11
[R]
10.53
[R]
26.68
[R]
26.44
[R]
5.58
[R]
406.12
[R]
2003
104.61
[R]
98.93
[R]
147.97
[R]
11.02
[R]
26.45
[R]
26.83
[R]
5.9
[R]
421.71
[R]
2004P
113.3
1 2 3 4
[R]
140.79
154.79
8.76
287.53
1996
102.19
[R]
[R]
Total
11.48
27.47
27.53
6.33
443.1
Dry production. Includes lease condensate Net generation, i.e., gross generation less plant use. Includes net electricity generation from wood, waste, solar, and wind. Data for the United States also include other renewable energy.
R=Revised. P=Preliminary.
Source: Energy Information Agency, www.eia.doe.gov
188
Table 8.12
World Primary Energy Consumption, 1997-2005 (Million Ton Oil Equivalent)
USA
1997
1998
1999
2000
2001
2002
2003
2004
2005
2207.6
2222.0
2260.3
2312.0
2258.4
2291.1
2298.6
2344.7
2336.6
Canada
285.5
282.6
284.2
289.8
289.9
296.7
302.8
311.4
317.5
Mexico
122.2
128.2
131.7
135.8
135.3
135.3
140.4
143.8
147.2
2615.4
2632.8
2676.1
2737.6
2683.5
2723.1
2741.8
2799.9
2801.3
Total North America Argentina Brazil
55.8
58.1
57.5
58.9
57.7
54.3
58.7
62.2
66.8
160.6
166.9
171.3
176.9
174.1
177.9
180.3
187.0
194.5
Chile
22.1
21.6
22.5
22.8
23.5
23.9
24.2
26.5
27.0
Colombia
27.8
27.3
25.2
25.4
26.3
25.7
26.0
26.8
27.8
Ecuador
8.1
8.2
7.7
7.7
7.7
7.7
7.8
8.2
8.4
Peru
10.9
11.3
11.7
11.9
11.7
11.8
11.7
12.4
12.8
Venezuela
61.1
63.8
59.8
61.9
65.2
66.1
58.5
65.4
69.2
Other S. & Cent. America
79.0
82.0
83.7
85.0
85.5
87.8
91.1
92.7
95.0
Total S. & Cent. America
425.5
439.2
439.4
450.4
451.7
455.2
458.3
481.2
501.4
Austria
30.7
31.6
32.3
32.2
33.3
33.3
34.2
33.7
34.6
Azerbaijan
11.1
11.1
11.1
11.5
11.3
11.1
12.0
12.9
13.7
Belarus
22.7
22.5
21.4
21.7
21.9
22.1
22.2
24.2
23.8
Belgium & Luxembourg
60.3
63.0
64.1
66.4
64.0
64.9
68.6
71.1
72.7
Bulgaria
20.7
20.7
18.0
17.8
18.4
18.2
18.9
19.6
20.3
Czech Republic
41.7
39.9
38.5
40.0
41.5
41.5
43.6
44.3
44.4
Denmark
21.7
20.6
19.9
18.8
18.6
18.4
19.6
18.3
17.2
Finland
25.1
25.6
25.7
26.0
26.4
26.7
28.9
28.6
25.6
France
241.0
247.2
251.5
254.9
258.4
256.7
259.8
263.4
262.1
Germany
337.8
334.5
328.5
330.5
336.2
330.1
332.1
330.7
324.0
Greece
27.2
28.6
30.1
31.8
31.7
32.7
32.3
33.8
33.5
Hungary
23.8
23.8
23.7
23.0
24.1
23.5
23.8
23.8
24.9
Iceland
2.1
2.2
2.3
2.4
2.5
2.6
2.6
2.7
2.6
11.6
12.4
13.2
13.9
14.6
14.5
14.2
14.6
14.9
163.9
168.5
173.7
176.4
177.2
175.9
181.2
184.3
183.9
40.7
39.4
35.4
41.0
42.3
44.1
47.9
51.2
55.2
8.6
9.2
7.8
7.0
8.1
8.6
9.1
9.2
8.3
84.7
84.5
83.2
86.4
88.3
89.0
90.4
93.1
94.7
Republic of Ireland Italy Kazakhstan Lithuania Netherlands Norway
39.3
40.4
41.5
45.9
41.0
42.9
38.3
39.0
45.2
Poland
98.6
94.1
91.1
88.4
88.6
87.1
88.5
90.9
91.7
Portugal
20.5
22.7
23.3
24.8
25.0
24.7
25.3
24.3
23.0
Romania
45.2
41.3
36.9
37.0
37.3
38.6
37.8
39.0
39.8
610.9
611.4
621.1
636.0
637.5
646.6
656.9
670.5
679.6
Russian Federation Slovakia
17.1
17.6
17.5
18.1
18.6
18.7
18.1
17.6
18.2
111.7
118.1
122.7
129.2
133.0
134.7
141.2
145.5
147.4
Sweden
50.4
51.6
51.6
48.6
52.1
48.5
46.2
48.4
49.7
Switzerland
28.9
29.1
30.1
29.4
31.5
29.5
29.4
29.0
27.9
Turkey
69.6
72.1
70.7
76.3
71.5
75.1
79.9
85.3
89.7
Turkmenistan
12.1
12.6
13.8
14.9
15.3
15.8
17.4
18.5
19.8
Ukraine
138.9
133.7
136.5
136.7
135.9
134.1
134.2
139.9
139.7
United Kingdom
Spain
220.4
223.5
221.6
223.5
227.0
221.7
225.1
227.0
227.3
Uzbekistan
50.5
51.9
53.5
51.4
54.8
56.2
52.4
50.5
50.1
Other Europe & Eurasia
74.1
74.0
67.6
67.0
68.2
70.1
73.5
75.7
78.1
2763.7
2779.2
2780.0
2828.8
2856.0
2858.2
2905.4
2960.6
2984.0
Total Europe & Eurasia
189
Table 8.12
World Primary Energy Consumption, 1997-2005 (Continued) (Million Ton Oil Equivalent) 1997
1998
1999
2000
2001
2002
2003
2004
2005
106.1
108.2
114.7
122.0
128.6
142.2
149.7
156.2
162.0
Kuwait
15.3
17.7
18.1
19.0
18.2
18.6
20.3
22.5
23.1
Qatar
14.7
15.0
14.2
10.4
12.0
13.2
14.0
16.7
18.1
104.8
110.8
111.4
116.4
120.2
123.7
131.7
142.8
149.8
Iran
Saudi Arabia United Arab Emirates
43.9
41.7
42.0
41.1
43.7
48.6
50.4
53.5
54.6
Other Middle East
85.8
88.6
90.6
94.0
97.4
98.8
97.9
99.9
102.5
Total Middle East
370.6
382.0
390.9
402.9
420.1
445.1
464.0
491.7
510.2
Algeria
26.5
27.5
27.9
26.9
27.9
28.9
30.2
31.3
33.9
Egypt
39.9
41.9
44.7
47.5
49.4
49.5
51.5
54.0
55.8
109.4
108.8
107.9
108.4
107.0
110.9
117.3
123.6
120.5
South Africa Other Africa
85.4
88.4
91.8
93.1
95.2
96.8
99.0
102.7
106.3
Total Africa
261.2
266.7
272.2
275.8
279.5
286.2
298.0
311.7
316.5
Australia
105.2
108.1
110.5
111.2
113.4
116.6
116.3
117.6
118.7
10.6
11.0
11.0
12.7
14.1
14.8
15.5
16.4
17.4
960.9
916.9
934.1
966.7
1000.0
1057.8
1228.7
1423.5
1554.0
Bangladesh China China Hong Kong SAR India Indonesia
15.1
15.4
15.6
15.6
18.9
20.4
20.9
23.8
22.9
285.6
296.0
304.0
320.4
324.2
338.7
348.2
376.1
387.3
84.0
80.0
89.1
95.2
101.4
104.4
103.9
112.1
116.4
508.3
501.5
506.2
514.8
513.0
510.2
510.9
520.8
524.6
Malaysia
37.8
37.3
38.3
45.8
47.8
51.3
56.3
60.4
61.2
New Zealand
17.2
17.0
17.4
17.8
18.0
18.5
17.9
18.4
17.8
Pakistan
37.4
39.6
40.8
41.9
42.9
43.8
45.8
49.8
55.9
Philippines
22.6
22.9
22.7
22.6
22.7
23.5
24.4
24.9
25.2
Singapore
33.8
34.7
32.9
35.0
40.5
39.9
38.7
44.1
48.1
179.6
165.5
180.5
191.1
195.9
205.0
211.8
217.3
224.6
Taiwan
72.9
77.5
81.1
85.4
86.8
91.0
94.7
98.0
100.3
Thailand
60.9
57.4
58.8
61.2
63.3
68.8
74.7
80.6
85.6
Other Asia Pacific
45.0
45.1
47.2
51.8
54.5
55.0
56.1
61.9
63.8
2476.7
2426.0
2490.2
2589.5
2657.4
2759.5
2964.8
3245.9
3423.7
TOTAL WORLD 8913.2 8925.9 9048.8 9285.0 9348.2 * In this Review, primary energy comprises commercially traded fuels only.
9527.3
9832.2
10291.0
10537.1
Japan
South Korea
Total Asia Pacific
Source : BP Statistical Review of World Energy June 2006
190
Table 8.13
World Primary Energy Consumption by Fuel, 2004-2005 (Million tonnes oil equivalent) 2004 Oil
Natural Gas
2005 Hydro electric
Coal
Total
Oil
Natural Gas
Hydro electric
Coal
Total
USA
948.8
580.5
566.2
61.4
2,344.7
944.6
570.1
575.4
60.6
2,336.6
Canada
100.6
83.4
30.5
76.4
311.4
100.1
82.3
32.5
81.7
317.5
Mexico
85.2
43.8
7.0
5.7
143.8
87.8
44.6
6.0
6.3
147.2
1,134.6
707.7
603.7
143.5
2,799.9
1,132.6
697.1
613.9
148.6
2,801.3
Total North America Argentina
18.7
34.1
0.8
6.9
62.2
20.1
36.5
0.8
7.9
66.8
Brazil
81.9
17.1
12.8
72.6
187.0
83.6
18.2
13.5
77.0
194.5
Chile
11.3
7.5
2.9
4.8
26.5
11.9
6.8
2.4
5.9
27.0
Colombia
10.1
5.7
2.0
9.0
26.8
10.4
6.1
2.3
9.0
27.8
Ecuador
6.4
0.2
-
1.7
8.2
6.6
0.2
-
1.7
8.4
Peru
7.2
0.8
0.6
4.0
12.4
6.4
1.4
0.6
4.3
12.8 69.2
Venezuela
24.2
25.3
0.1
15.9
65.4
25.4
26.1
0.1
17.6
Other S. & Cent. America
58.1
15.4
1.4
17.8
92.7
58.8
16.4
1.4
18.3
95.0
Total S. & Cent. America
217.9
105.9
20.4
132.6
481.2
223.3
111.7
21.1
141.7
501.4
13.8
8.5
2.4
9.0
33.7
14.2
9.0
2.5
9.0
34.6
4.6
7.7
^
0.6
12.9
5.1
7.9
^
0.7
13.7
Austria Azerbaijan Belarus Belgium & Luxembourg
7.5
16.6
0.1
^
24.2
6.7
17.0
0.1
^
23.8
38.4
14.9
6.4
0.6
71.1
39.5
15.2
6.4
0.6
72.7 20.3
Bulgaria
4.7
2.6
7.7
0.7
19.6
5.0
2.9
7.4
0.8
Czech Republic
9.5
7.8
20.5
0.6
44.3
9.9
7.7
20.5
0.7
44.4
Denmark
9.1
4.7
4.6
^
18.3
9.1
4.5
3.6
^
17.2
Finland
10.6
3.9
5.3
3.4
28.6
11.0
3.6
2.5
3.1
25.6
France
94.0
40.1
12.8
14.7
263.4
93.1
40.5
13.3
12.8
262.1
Germany
124.0
77.3
85.4
6.2
330.7
121.5
77.3
82.1
6.3
324.0
Greece
21.3
2.2
9.0
1.2
33.8
20.9
2.3
9.0
1.3
33.5
Hungary
6.3
11.7
3.1
^
23.8
7.0
12.1
2.7
^
24.9
Iceland
1.0
-
0.1
1.6
2.7
0.9
-
0.1
1.6
2.6
Republic of Ireland
8.9
3.6
1.8
0.2
14.6
9.4
3.5
1.9
0.2
14.9
Italy
89.7
66.2
17.1
11.3
184.3
86.3
71.1
16.9
9.6
183.9
Kazakhstan
9.0
13.9
26.5
1.8
51.2
10.0
16.0
27.2
2.0
55.2
Lithuania
2.6
2.8
0.2
0.2
9.2
2.7
2.9
0.2
0.2
8.3
46.2
37.0
9.1
^
93.1
49.6
35.5
8.7
^
94.7 45.2
Netherlands Norway
9.6
4.1
0.6
24.7
39.0
9.8
4.0
0.5
30.9
Poland
21.1
11.8
57.3
0.8
90.9
21.9
12.2
56.7
0.9
91.7
Portugal
15.4
2.8
3.9
2.3
24.3
15.3
2.7
3.8
1.1
23.0
Romania Russian Federation Slovakia
10.9
15.7
7.4
3.7
39.0
11.3
15.6
7.1
4.6
39.8
128.5
361.7
106.8
40.8
670.5
130.0
364.6
111.6
39.6
679.6
3.2
5.5
4.1
1.0
17.6
3.5
5.3
4.3
1.1
18.2
Spain
77.6
24.7
21.0
7.8
145.5
78.8
29.1
21.4
5.2
147.4
Sweden
15.3
0.7
2.3
12.7
48.4
15.1
0.7
2.2
15.5
49.7
Switzerland
12.0
2.7
0.1
8.0
29.0
12.2
2.8
0.1
7.5
27.9
Turkey
32.0
19.9
23.0
10.4
85.3
30.0
24.6
26.1
9.0
89.7
Turkmenistan
4.6
13.9
-
-
18.5
4.9
14.9
-
-
19.8
Ukraine
13.9
65.6
38.1
2.7
139.9
13.9
65.6
37.4
2.8
139.7
United Kingdom
81.7
87.3
38.1
1.7
227.0
82.9
85.1
39.1
1.7
227.3
7.5
40.3
1.2
1.6
50.5
7.8
39.6
1.1
1.6
50.1
Other Europe & Eurasia
23.3
12.9
20.9
16.8
75.7
24.3
13.8
21.3
16.9
78.1
Total Europe & Eurasia
957.6
991.1
536.7
187.3
2,960.6
963.3
1,009.7
537.5
187.2
2,984.0
Uzbekistan
191
Table 8.13
World Primary Energy Consumption by Fuel, 2004-2005 (Continued) (Million tonnes oil equivalent) 2004 Oil
Natural Gas
2005 Hydro electric
Coal
Total
Oil
Natural Gas
Hydro electric
Coal
Total
Iran
74.6
77.9
1.1
2.7
156.2
78.4
79.6
1.1
2.8
162.0
Kuwait
13.7
8.7
-
-
22.5
14.4
8.7
-
-
23.1
Qatar
3.3
13.4
-
-
16.7
3.8
14.3
-
-
18.1
Saudi Arabia
83.7
59.1
-
-
142.8
87.2
62.6
-
-
149.8
United Arab Emirates
17.4
36.2
-
-
53.5
18.3
36.4
-
-
54.6
Other Middle East
68.1
22.8
8.0
1.1
99.9
69.2
24.3
7.9
1.1
102.5
Total Middle East
510.2
260.7
218.1
9.1
3.8
491.7
271.3
225.9
9.0
3.9
Algeria
10.6
19.8
0.8
0.1
31.3
11.2
21.7
0.9
0.1
33.9
Egypt
26.8
23.6
0.5
3.1
54.0
29.2
23.0
0.5
3.1
55.8
South Africa
24.8
-
94.5
0.8
123.6
24.9
-
91.9
0.8
120.5
Other Africa
61.9
18.3
7.0
15.4
102.7
64.0
19.4
7.0
15.9
106.3
Total Africa
124.2
61.8
102.9
19.4
311.7
129.3
64.1
100.3
19.9
316.5
38.8
22.8
52.4
3.6
117.6
39.7
23.1
52.2
3.7
118.7
3.9
12.0
0.4
0.3
16.4
4.0
12.8
0.4
0.3
17.4
318.9
35.1
978.2
80.0
1,423.5
327.3
42.3
1,081.9
90.8
1,554.0
Australia Bangladesh China China Hong Kong SAR India Indonesia
15.3
2.0
6.6
-
23.8
13.8
1.9
7.2
-
22.9
120.2
29.5
203.7
19.0
376.1
115.7
33.0
212.9
21.7
387.3
54.7
33.2
22.1
2.1
112.1
55.3
35.5
23.5
2.1
116.4
241.4
70.9
120.8
23.1
520.8
244.2
73.0
121.3
19.8
524.6
22.8
30.5
5.7
1.4
60.4
22.0
31.4
6.3
1.5
61.2
7.0
3.3
2.0
6.2
18.4
7.0
3.2
2.1
5.5
17.8
Pakistan
16.0
24.2
3.5
5.5
49.8
17.4
26.9
4.1
6.9
55.9
Philippines
15.8
2.1
5.0
1.9
24.9
14.7
2.7
5.9
1.9
25.2
Japan Malaysia New Zealand
Singapore South Korea
38.1
5.9
-
-
44.1
42.2
5.9
-
-
48.1
104.9
28.4
53.1
1.3
217.3
105.5
30.0
54.8
1.2
224.6
Taiwan
41.7
9.2
36.8
1.5
98.0
41.6
9.6
38.2
1.8
100.3
Thailand
44.0
24.6
10.6
1.4
80.6
45.6
26.9
11.8
1.3
85.6
Other Asia Pacific
20.3
7.0
25.4
9.3
61.9
21.1
8.0
25.7
8.9
63.8
1,103.6
340.6
1,526.2
156.5
3,245.9
1,116.9
366.2
1,648.1
167.4
3,423.7
TOTAL WORLD 3,798.6 2,425.2 2,798.9 643.2 10,291.0 3,836.8 2,474.7 2,929.8 668.7 * In this Review, primary energy comprises commercially traded fuels only. Excluded, therefore, are fuels such as wood, peat
10,537.1
Total Asia Pacific
Source : BP Statistical Review of World Energy June 2006
192
Table 8.14
World Hydroelectricity Consumption, 2000-2005 (Million tonnes oil equivalent) 2000
2001
2002
2003
2004
2005
USA
63.0
49.6
60.4
63.1
61.4
60.6
Canada
81.1
75.5
79.4
76.4
76.4
81.7
Mexico
7.5
6.4
5.6
4.5
5.7
6.3
151.6
131.5
145.4
144.0
143.5
148.6
Total North America Argentina Brazil
6.5
8.4
8.1
7.7
6.9
7.9
68.9
60.6
64.7
69.2
72.6
77.0
Chile
4.3
4.9
5.2
5.1
4.8
5.9
Colombia
6.9
7.1
7.6
8.1
9.0
9.0
Ecuador
1.7
1.6
1.7
1.6
1.7
1.7
Peru
3.7
4.0
4.1
4.2
4.0
4.3
14.2
13.7
13.5
13.7
15.9
17.6
Venezuela Other S. & Cent. America
18.5
17.0
17.9
18.2
17.8
18.3
Total S. & Cent. America
124.8
117.3
122.9
127.8
132.6
141.7
Austria
9.8
9.8
9.5
8.7
9.0
9.0
Azerbaijan
0.3
0.3
0.5
0.6
0.6
0.7
^
^
^
^
^
^
0.6
0.6
0.6
0.5
0.6
0.6
Belarus Belgium & Luxembourg Bulgaria
0.6
0.4
0.6
0.7
0.7
0.8
Czech Republic
0.5
0.6
0.6
0.4
0.6
0.7
^
^
^
^
^
^
Finland
3.3
3.1
2.4
2.1
3.4
3.1
France
Denmark
16.4
18.0
15.1
14.7
14.7
12.8
Germany
5.9
6.3
6.4
5.5
6.2
6.3
Greece
0.9
0.6
0.8
1.2
1.2
1.3
^
^
^
^
^
^
1.4
1.5
1.6
1.6
1.6
1.6
Hungary Iceland Republic of Ireland
0.3
0.2
0.3
0.2
0.2
0.2
11.5
12.2
10.7
10.0
11.3
9.6
Kazakhstan
1.7
1.8
2.0
2.0
1.8
2.0
Lithuania
0.1
0.2
0.2
0.2
0.2
0.2
^
^
^
^
^
^
32.2
27.4
29.4
24.0
24.7
30.9
Italy
Netherlands Norway Poland
0.9
1.0
0.9
0.7
0.8
0.9
Portugal
2.7
3.3
1.9
3.6
2.3
1.1
Romania
3.3
3.4
3.6
3.0
3.7
4.6
37.4
39.8
37.2
35.6
40.8
39.6
Slovakia
1.1
1.2
1.2
0.8
1.0
1.1
Spain
8.3
9.9
6.0
9.9
7.8
5.2
17.8
17.9
15.0
12.1
12.7
15.5
Russian Federation
Sweden Switzerland
8.7
9.7
8.3
8.3
8.0
7.5
Turkey
7.0
5.4
7.6
8.0
10.4
9.0
-
-
-
-
-
-
2.6
2.8
2.2
2.1
2.7
2.8 1.7
Turkmenistan Ukraine United Kingdom
1.8
1.5
1.7
1.3
1.7
Uzbekistan
1.3
1.2
1.6
1.7
1.6
1.6
Other Europe & Eurasia
15.9
15.4
15.1
16.0
16.8
16.9
Total Europe & Eurasia
194.5
195.3
183.1
175.8
187.3
187.2
193
Table 8.14
World Hydroelectricity Consumption, 2000-2005 (Continued) (Million tonnes oil equivalent) 2000
2001
2002
2003
2004
2005
0.9
0.9
1.8
2.2
2.7
2.8
Kuwait
-
-
-
-
-
-
Qatar
-
-
-
-
-
-
Saudi Arabia
-
-
-
-
-
-
United Arab Emirates
-
-
-
-
-
-
Other Middle East
1.0
1.0
1.1
1.1
1.1
1.1
Total Middle East
1.8
1.9
2.9
3.2
3.8
3.9
^
^
^
0.1
0.1
0.1
Egypt
3.2
3.3
3.2
2.9
3.1
3.1
South Africa
0.9
0.8
0.9
0.8
0.8
0.8
Other Africa
13.4
14.1
15.2
15.3
15.4
15.9
Total Africa
Iran
Algeria
17.6
18.2
19.3
19.1
19.4
19.9
Australia
3.7
3.7
3.6
3.7
3.6
3.7
Bangladesh
0.2
0.2
0.2
0.3
0.3
0.3
50.3
62.8
65.2
64.2
80.0
90.8
China China Hong Kong SAR India Indonesia Japan
-
-
-
-
-
-
17.4
16.3
15.5
15.7
19.0
21.7
2.3
2.6
2.3
2.1
2.1
2.1
20.7
20.8
21.1
23.3
23.1
19.8
Malaysia
1.7
1.5
1.2
1.3
1.4
1.5
New Zealand
5.6
5.1
5.7
5.4
6.2
5.5
Pakistan
4.0
4.1
4.6
5.8
5.5
6.9
Philippines
1.8
1.6
1.6
1.8
1.9
1.9
Singapore
-
-
-
-
-
-
1.3
0.9
1.2
1.6
1.3
1.2
South Korea Taiwan
2.0
2.1
1.4
1.6
1.5
1.8
Thailand
1.4
1.4
1.7
1.7
1.4
1.3
Other Asia Pacific
8.1
8.9
8.8
9.5
9.3
8.9
Total Asia Pacific
120.2
132.1
134.1
137.7
156.5
167.4
TOTAL WORLD
610.5
596.3
607.8
607.6
643.2
668.7
Source : BP Statistical Review of World Energy June 2006
194
Table 8.15
World Spot Crude Oil Prices, 1980 – 2005 US dollars per barrel
* + ++
Year
Dubai
Brent
Nigerian Forcados
West Texas Intermdiate
1980
35.69
36.83
36.98
37.96
1981
34.32
35.93
36.18
36.08
1982
31.80
32.97
33.29
33.65
1983
28.78
29.55
29.54
30.30
1984
28.06
28.78
28.14
29.39
1985
27.53
27.56
27.75
27.98
1986
13.10
14.43
14.46
15.10
1987
16.95
18.44
18.39
19.18
1988
13.27
14.92
15.00
15.97
1989
15.62
18.23
18.30
19.68
1990
20.45
23.73
23.85
24.50
1991
16.63
20.00
20.11
21.54
1992
17.17
19.32
19.61
20.57
1993
14.93
16.97
17.41
18.45
1994
14.74
15.82
16.25
17.21
1995
16.10
17.02
17.26
18.42
1996
18.52
20.67
21.16
22.16
1997
18.23
19.09
19.33
20.61
1998
12.21
12.72
12.62
14.39
1999
17.25
17.97
18.00
19.31
2000
26.20
28.50
28.42
30.37
2001
22.81
24.44
24.23
25.93
2002
23.74
25.02
25.04
26.16
2003
26.78
28.83
28.66
31.07
2004
33.64
38.27
38.13
41.49
2005
49.35
54.52
55.69
56.59
1972 - 1985 Arabian Light 1986 - 2005 Dubai dated 1976 -1983 Forties 1984 -2005 Brent dated 1976 -1983 Posted WTI prices 1984 -2005 Spot WTI (Cushing) prices
Source : BP Statistical Review of World Energy June 2006
195
Table 8.16
World Average Gas Prices, 1984 – 2005
LNG European
UK
USA
Canada
OECD
cif
Union cif
(Heren NBP Index) @
Henry Hub &
(Alberta) &
countries cif
1984
-
3.76
-
-
-
5.00
1985
5.23
3.83
-
-
-
4.75
1986
4.10
3.65
-
-
-
2.57
1987
3.35
2.59
-
-
-
3.09
1988
3.34
2.36
-
-
-
2.56
1989
3.28
2.09
-
1.70
-
3.01
1990
3.64
2.82
-
1.64
1.05
3.82
1991
3.99
3.18
-
1.49
0.89
3.33
1992
3.62
2.76
-
1.77
0.98
3.19
1993
3.52
2.53
-
2.12
1.69
2.82
1994
3.18
2.24
-
1.92
1.45
2.70
1995
3.46
2.37
-
1.69
0.89
2.96
1996
3.66
2.43
1.85
2.76
1.12
3.54
1997
3.91
2.65
2.03
2.53
1.36
3.29
1998
3.05
2.26
1.92
2.08
1.42
2.16
1999
3.14
1.80
1.64
2.27
2.00
2.98
2000
4.72
3.25
2.68
4.23
3.75
4.83
2001
4.64
4.15
3.22
4.07
3.61
4.08
2002
4.27
3.46
2.58
3.33
2.57
4.17
2003
4.77
4.40
3.26
5.63
4.83
4.89
2004
5.18
4.56
4.69
5.85
5.03
6.27
8.79
7.25
8.73
Year
Japan
(US dollars per million Btu) Crude Oil
Natural Gas
2005 6.05 6.28 6.69 @ Source: Heren Energy Ltd. & Source: Natural Gas Week Note: cif = cost+insurance+freight (average prices)
Source : BP Statistical Review of World Energy June 2006
196
Table 8.17
World Average Coal Prices, 1987 – 2005 (US dollars per tonne)
Northwest Europe marker price †
US Central Appalachian coal spot price index ‡
Japan coking coal import cif price
Japan steam coal import cif price
1987
31.30
-
53.44
41.28
1988
39.94
-
55.06
42.47
1989
42.08
-
58.68
48.86
1990
43.48
31.59
60.54
50.81
1991
42.80
29.00
60.45
50.30
1992
38.53
28.54
57.82
48.45
1993
33.68
29.85
55.26
45.71
1994
37.18
31.71
51.77
43.66
1995
44.50
26.98
54.47
47.58
1996
41.25
29.87
56.68
49.54
1997
38.92
29.76
55.51
45.53
1998
32.00
31.01
50.76
40.51
1999
28.79
31.28
42.83
35.74
2000
35.99
29.91
39.69
34.58
2001
39.29
49.75
41.33
37.96
2002
31.65
32.96
42.01
36.90
2003
42.52
38.49
41.57
34.74
2004
71.90
64.36
60.96
51.34
2005
61.07
70.82
89.33
62.91
† Source: McCloskey Coal Information Service ‡ Price is for CAPP 12,500 BTU, 1.2 SO2 coal. Source: Platts Note: cif = cost+insurance+freight (average prices)
Source : BP Statistical Review of World Energy June 2006
197
198
CURRENT AND FUTURE ENERGY TECHNOLOGY
IX. CURRENT AND FUTURE ENERGY TECHNOLOGY
PENGKAJIAN ENERGI UNIVERSITAS INDONESIA
199
200
Current and Future Energy Technology 9.1
Petroleum Technology Petroleum is an organic compound made up of a variety of hydrogen and carbon
atoms (hydrocarbons) that range from a light gas or methane to a number of heavy solids such as bitumen. Petroleum also contains small quantities of oxygen, nitrogen and sulphur. The main advantage of mineral oil compared to most other energy carriers is its high energy density that makes it easier to handle and transport in atmospheric tanks at reasonable cost. The calorific value of mineral oil is very high – around 42-43 MJ/kg. The ratio of hydrogen to carbon is typically around 2:1 – two hydrogen atoms per carbon atom. The typical emission of CO2 amounts to 73-75 grams per MJ. This is equivalent to some 3.1 kg of CO2 per kg of mineral oil. Exploration and Drilling. Seismic surveys are the most common exploration tool used in the search for oil and gas. Geophysicists record sound waves reflected back to the surface from structures kilometers below the seabed. They produce maps of the sub-surface showing the location of geological features such as sedimentary basins, faults and hopefully petroleum traps such as anticlines. Gravity and magnetic aerial surveys are also used to indicate the extent of sedimentary rocks over wide areas. Drilling is the only way to make sure whether a structure identified by seismic surveys actually contains hydrocarbons. Onshore, the drilling
process is relatively simple. A drill bit, made of either industrial diamonds or tungsten carbide, is attached to a length of drill pipe and rotated at high speed. Extra pipe lengths are added as the drill bit penetrates deeper into the rock. Specially prepared heavy mud is circulated through the pipe and drill bit, to cool and lubricate the drill bit and carry rock cuttings to the surface for analysis and to reduce the risk of high pressure petroleum blowing out at the surface. Offshore, the exploration drilling is more complicated because of the movement of the rig caused by swells and tides. Jack-up rigs are used in waters of less than 100 meters and semi-submersible rigs are designed for use in depths of up to 300 meters. They are most efficient in calm, protected waters. Drill ships are used extensively for deep water drilling in depths of more than 300 meters. Horizontal drilling is common these days, which enables increased production from thin reservoirs. Fields which previously was considered too small to be economically viable can now is tapped. A large field may require two or three production platforms, with up to 60 production wells from each platform. Wells can be drilled to over 5000 meters below the seabed. Some reach as far as eight kilometers from the platform. Refining. The petroleum refining industry is currently changing to meeting the environmental regulation on fuel quality. Building new refineries or revamping existing facilities in order to satisfy these regulations, mainly, reduction of benzene and aromatics in gasoline, reduction of sulfur in all liquid fuels, and synthesis of oxygenates. The challenge to go beyond these objectives is in catalyst science and technology. To reduce aromatics in gasoline, the need is to shift naphtha reforming to paraffin hydroisomerization, to achieve octane
201
requirements with less dependence on aromatics. In answer to environmental pressure, the need is to develop heterogeneous iso-butane alkylation catalysts to replace current liquid homogeneous catalysts, such as hydrogen fluoride and sulfuric acid. More effective catalysts for hydrodesulfurization and benzene removal are needed. To meet the demand for truly clean transportation fuels, fuel production will be integrated with lube oil and petrochemical production. The production of jet fuel and diesel fuel will surpass that of gasoline, and all of the products from the fuel–lube oil–petrochemical complex will be synthesized almost free of pollutants. The raw material used by the complex will be extended from crude oils to other resources, including natural gas, heavy oils, tar sands, shale oil, and coal. Process technologies will be developed to reduce the cost of production and to avoid the generation of pollutants except the emission of CO2. Facing the eventual displacement of internal combustion engines by transportation vehicles powered by hydrogen fuel cells, the oil industry may elect to provide hydrogen by producing it from hydrocarbons onboard the vehicle. In refining, several processes are involved such as: Distillation. Crude oil is a mixture of hydrocarbons with different boiling temperatures; it can be separated by distillation into groups of hydrocarbons that boil between two specified boiling points. Two types of distillation are performed: atmospheric and vacuum. Atmospheric distillation takes place in a distilling column at or near atmospheric pressure. The crude oil is heated to 350 - 400oC and the vapor and liquid are piped into the distilling column. The liquid falls to the bottom and the vapor rises, passing through a series of trays. Heavier hydrocarbons condense more quickly and settle on lower trays and lighter hydrocarbons remain as a vapor longer and condense on higher trays. Liquid fractions are drawn from the trays and removed. In this way the light gases, methane, ethane, propane and butane pass out the top of the column, petrol is formed in the top trays, kerosene and gas oils in the middle, and fuel oils at the bottom. Residue drawn of the bottom may be burned as fuel, processed into lubricating oils, waxes and bitumen or used as feedstock for cracking units. To recover additional heavy distillates from this residue, it may be piped to a second distillation column where the process is repeated under vacuum, called vacuum distillation. This allows heavy hydrocarbons with boiling points of 450oC and higher to be separated without them partly cracking into unwanted products such as coke and gas. The heavy distillates recovered by vacuum distillation can be converted into lubricating oils by a variety of processes (Figure 9.1). Reforming. Reforming is a process which uses heat, pressure and a catalyst to bring about chemical reactions which upgrade naphthas into high octane petrol and petrochemical feedstock. The naphthas are hydrocarbon mixtures containing many paraffin and naphthenes. This naphtha feedstock comes from the crude oil distillation or catalytic cracking processes, it also comes from thermal cracking and hydrocracking processes. Reforming converts a portion of these compounds to isoparaffins and aromatics, which are used to blend higher octane petrol. paraffins are converted to isoparaffins, naphthenes, and naphthenes are converted to aromatics
202
Figure 9.1 Crude oil distillation scheme
Cracking processes breakdown heavier hydrocarbon molecules (high boiling point oils) into lighter products such as petrol and diesel. These processes include catalytic cracking, thermal cracking and hydrocracking. Catalytic Cracking is used to convert heavy hydrocarbon fractions obtained by vacuum distillation into a mixture of more useful products such as petrol and light fuel oil. In this process, the feedstock undergoes a chemical breakdown, under controlled heat (450 - 500oC) and pressure, in the presence of a catalyst-a substance which promotes the reaction without itself being chemically changed. Silica-alumina or silica-magnesia has proved to be the most effective catalysts. The cracking reaction yields petrol, LPG, unsaturated olefin compounds, cracked gas oils, a liquid residue called cycle oil, light gases and a solid coke residue. Cycle oil is recycled to cause further breakdown and the coke, which forms a layer on the catalyst, is removed by burning. The other products are passed through a fractionator to be separated and separately processed. Fluid Catalytic Cracking uses a catalyst in the three phase fluidized flows. Feedstock entering the process immediately meets a stream of very hot catalyst and vaporizes. The resulting vapors keep the catalyst fluidized as it passes into the reactor, where the cracking takes place and where it is fluidized by the hydrocarbon vapor. The catalyst next passes to a steam stripping section where most of the volatile hydrocarbons are removed. It then passes to a regenerator vessel where it is fluidized by a mixture of air and the products of combustion which are produced as the coke on the catalyst is burnt off. The catalyst then flows back to the reactor. The catalyst thus undergoes a continuous circulation between the reactor, stripper and regenerator sections. The catalyst is usually a mixture of alumina and silica. Most recently, the introduction of synthetic zeolite catalysts has allowed much shorter reaction times and improved yields and octane numbers of the cracked gasolines. Thermal Cracking uses heat to breakdown the residue from vacuum distillation. The lighter elements produced from this process can be made into distillate fuels and petrol.
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Cracked gases are converted to petrol blending components by alkylation or polymerization. Naphtha is upgraded to high quality petrol by reforming. Gas oil can be used as diesel fuel or can be converted to petrol by hydrocracking. The heavy residue is converted into residual oil or coke which is used in the manufacture of electrodes, graphite and carbides. Hydrocracking can increase the yield of petrol components, as well as being used to produce light distillates. It produces no residues, only light oils. Hydrocracking is catalytic cracking in the presence of hydrogen. The extra hydrogen saturates, or hydrogenates, the chemical bonds of the cracked hydrocarbons and creates isomers with the desired characteristics. Hydrocracking is also a treating process, because the hydrogen combines with contaminants such as sulphur and nitrogen, allowing them to be removed. Gas oil feed is mixed with hydrogen, heated, and sent to a reactor vessel with a fixed bed catalyst, where cracking and hydrogenation take place. Products are sent to a fractionator to be separated. The hydrogen is recycled. Residue from this reaction is mixed again with hydrogen, reheated, and sent to a second reactor for further cracking under higher temperatures and pressures. In addition to cracked naphtha for making petrol, hydrocracking yields light gases useful for refinery fuel, or alkylation as well as components for high quality fuel oils, lube oils and petrochemical feedstock. Following the cracking processes it is necessary to build or rearrange some of the lighter hydrocarbon molecules into high quality petrol or jet fuel blending components or into petrochemicals. The former can be achieved by several chemical processes such as alkylation and isomerisation. Alkylation. Olefins such as propylene and butylene are produced by catalytic and thermal cracking. Alkylation refers to the chemical bonding of these light molecules with isobutane to form larger branched-chain molecules (isoparaffins) that make high octane petrol. Olefins and isobutane are mixed with an acid catalyst and cooled. They react to form alkylate, plus some normal butane, isobutane and propane. The resulting liquid is neutralized and separated in a series of distillation columns. Isobutane is recycled as feed and butane and propane sold as liquid petroleum gas (LPG). Isomerisation refers to chemical rearrangement of straight-chain hydrocarbons (paraffins), so that they contain branches attached to the main chain (isoparaffins). This is done for two reasons: they create extra isobutane feed for alkylation; they improve the octane of straight run pentanes and hexanes and hence make them into better petrol blending components. Isomerisation is achieved by mixing normal butane with a little hydrogen and chloride and allowed to react in the presence of a catalyst to form isobutane, plus a small amount of normal butane and some lighter gases. Products are separated in a fractionator. The lighter gases are used as refinery fuel and the butane recycled as feed. Pentanes and hexanes are the lighter components of petrol. Isomerisation can be used to improve petrol quality by converting these hydrocarbons to higher octane isomers. The process is the same as for butane isomerisation.
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Polymerisation. Under pressure and temperature, over an acidic catalyst, light unsaturated hydrocarbon molecules react and combine with each other to form larger hydrocarbon molecules. Such process can be used to react butenes (olefin molecules with four carbon atoms) with isobutane (branched paraffin molecules, or isoparaffins, with four carbon atoms) to obtain a high octane olefinic petrol blending component called polymer gasoline. Hydrotreating and Sulphur Plants. Hydrotreating is one way of removing many of the contaminants from many of the intermediate or final products. In the hydrotreating process, the entering feedstock is mixed with hydrogen and heated to 300 - 380oC. The oil combined with the hydrogen then enters a reactor loaded with a catalyst which promotes several reactions: hydrogen combines with sulphur to form hydrogen sulphide (H2S), nitrogen compounds are converted to ammonia, any metals contained in the oil are deposited on the catalyst, some of the olefins, aromatics or naphthenes become saturated with hydrogen to become paraffins and some cracking takes place, causing the creation of some methane, ethane, propane and butanes. Sulphur Recovery Plants. The hydrogen sulphide created from hydrotreating is a toxic gas that needs further treatment. The usual process involves two steps: the removal of the hydrogen sulphide gas from the hydrocarbon stream the conversion of hydrogen sulphide to elemental sulphur, a non-toxic and useful chemical. Solvent extraction, using a solution of diethanolamine (DEA) dissolved in water, is applied to separate the hydrogen sulphide gas from the process stream. The hydrocarbon gas stream containing the hydrogen sulphide is bubbled through a solution of diethanolamine solution (DEA) under high pressure, such that the hydrogen sulphide gas dissolves in the DEA. The DEA and hydrogen mixture is the heated at a low pressure and the dissolved hydrogen sulphide is released as a concentrated gas stream which is sent to another plant for conversion into sulphur. Conversion of the concentrated hydrogen sulphide gas into sulphur occurs in two stages. Combustion of part of the H2S stream in a furnace, producing sulphur dioxide (SO2) water (H2O) and sulphur (S). Reaction of the remainder of the H2S with the combustion products in the presence of a catalyst. The H2S reacts with the SO2 to form sulphur. As the reaction products are cooled the sulphur drops out of the reaction vessel in a molten state. Sulphur can be stored and shipped in either a molten or solid state.
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9.2
Natural Gas Technology Natural gas is colorless and odorless in its pure form, and a promising energy
alternative due to its availability and its similar property to petroleum. Natural gas, in which methane is the primary component, is the simplest fossil molecule of highest hydrogen to carbon ratio (4:1). Natural gas has a high calorific value of around 55.8 MJ/kg. Because of its high hydrogen-to-carbon fraction the CO2 emission becomes very low compared to coal and oil at the same calorific value. The typical emission of carbon dioxide is 56 g per MJ. While the predominant usage of natural gas is as fuel, natural gas is also an important feedstock to the petrochemical industry for a wide range of chemicals, including methanol, fertilizer and hydrogen. Gas technology plays a key role in transforming natural gas industry into more competitive market. Today’s technological challenges are focusing towards greater flexibility in development of natural gas fields. The main technology development objective is finding transportation modes that enable to transport natural gas from remote area to markets costeffectively under difference sizes of fields. Figure 9.2 showed the options to transport natural gas from supply side to the markets. Firstly, to transport the gas in gases form to market such as pipelines and Compressed Natural Gas (CNG), in liquid form - Liquefied Natural Gas (LNG), and in solid form – Gas to hydrate (GTH). Secondly, to convert the gas chemically into stable liquids, mainly, Gas to Liquids (GTL) and Gas to Chemicals (GTC). Finally, the gas is converted into electricity/power via thermodynamic and electro-catalytic conversions, called Gas to Wire (GTW).
Pipeline gas Compressed Natural Gas (CNG)
GAS SUPPLY
Liquefied Natural Gas (LNG) Gas to Hydrate (GTH)
GAS MARKETS
Gas to Liquids (GTL) Gas to Chemicals (GTC) Gas to Wire (GTW)
Figure 9.2 Strategies of natural gas utilization
Pipeline, CNG, LNG, and GTH are the physical mode of transporting natural gas in a gaseous phase in which volume is reduced. Pipeline gas usually has diameter of 6-46 inches and operates up to 340 bars. LNG is obtained by lowering the temperature below -162oC (cryogenic conditions). The density of LNG is 415 kg/m3 compared to 0.7168 kg/m3 in gaseous with volume ratio of 1/600. CNG is natural gas pressurized and stored in bottle-like tanks at
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pressures up to 3,000 psig with volume ratio ~ 1/300. GTH is a transportation mode of natural gas in the form of solid of natural gas hydrates (NGH). The hydrates are crystalline substance, of which cluster made of water molecules holds in it methane molecules and carbon dioxide molecules as guests. NGH is an artificially manufactured hydrate using such components as guests. NGH can hold gas about 170 times its volume at -20oC under atmospheric pressure. New innovations being considered are to reduce investment cost of pipeline by creating new materials for manufacturing cheaper gas pipeline than conventional pipeline, to reduce cost of LNG processing by expanding the size of LNG production units, and to develop over pressurecontainment vessel by increasing the gas-to-container weight ratio through new materials or optimizing pressure/temperature relationship. GTL and GTC, are the chemical conversion of natural gas into more easily transportable and useful chemicals or fuels. These technologies may be broadly divided into two major processes, which are described as direct and indirect routes. Direct conversion of methane into methanol, ethylene or C2+ is an interesting alternative without synthesis gas production reactions. Oxidative coupling of methane to produce ethylene and direct conversion of methane to methanol/formaldehyde are that most researched reactions. Most direct processes require oxygen to provide a thermodynamic driving force. However, direct oxidation reactions are controlled by kinetic aspect and the formation of the undesired product of CO2 which severely limits the yield that may be achieved. There are some direct processes which do not require oxygen as an oxidant such as direct conversion methane to aromatics and decomposition of methane to produce simultaneously hydrogen and nano-size of carbon, but, the yields obtained are generally small. Theoretically, direct routes should be having a distinct economic advantage over indirect routes, but to date, no direct processes in the commercial stages is being developed. The indirect routes depend on the formation of synthesis gas (mixture of CO and H2) as intermediate product in the first step, either by partial oxidation or reforming reactions, followed by conversion of synthesis gas into valuable products such as synthetic fuels, methanol, dimethyl ether (DME) and olefins. For mature technology of steam reforming, innovations are carried out mainly to improve catalyst performance due to coke formation in conventional nickel catalyst. For catalytic partial oxidation, the process needs practically pure oxygen, which requires air separation and involves hazards of handling of large quantities of undiluted oxygen and oxygen-methane mixture. Recent research directions are focusing on development of membrane reactor, millisecond reactor using structured catalyst and combined steam reforming and partial oxidation reaction that is called auto-thermal reforming. Production of synthetic fuels which is sulfur-free and has very low aromatic from synthesis gas are obtained by Fischer-Tropsch (FT) reaction, which is frequently also called as GTL. Type of catalyst for FT reaction highly depends on the type of main products such as gasoline, diesel, and wax, chemical. The catalyst must have active properties to hydrogenation reaction, capability to produce metal carbonyl due to this carbonyl role in production of long-
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chained hydrocarbons. Fe and Co are commonly used as catalyst for FT GTL processes. Diesel products are typically produced by low temperature FT process in which Cetane number is about 74 as compared of 40 in conventional diesel. The aromatic content is about 2% as compared of 32% in conventional diesel. The emission levels of hydrocarbons, CO, NOX and particles from FT diesel are 56, 33, 28 and 21%, respectively which is lower than ones of conventional diesel. Gasoline products are yielded by high temperature FT process. Gasoline produced has aromatic content of about 5% and very low benzene that fulfill the threshold, however alkenes is very high that it must be introduced into subsequent processes such as hydrogenation, isomerization and reforming in order to obtain high octane number. Gas based GTL is technologically proven and is entering a commercialization stage throughout the world with commercial production capacity in Bintulu Malaysia by Shell, called Shell Middle Distillate Synthesis (SMDS), in Mossel Bay South Africa by Mossgas GTL project (now Petro SA), and Oryx Qatar using Sasol technology. DME is in liquid phase under 20oC and pressure of 5 bars. Considering it attractive properties, DME would be as fuel substitutes for LPG and diesel. From safety and properties aspect, DME can be handled like LPG and it is suitable to compression ignition engines due to the Cetane number of 60. DME is conventionally produced through methanol dehydration reaction, consisted of three steps of reaction of methane, i.e., synthesis gas production, and methanol synthesis and methanol dehydration. Alternatively, direct conversion synthesis gas into DME with reaction 2CO + 4H2 → CH3OCH3 + H2O is interesting. This process is developed in pilot-scale by licensors such as Topsoe and NKK Japan. Two other potential processes are methanol-to-gasoline (MTG), which has been developed by Mobil, and methanol-to-olefin (MTO), by UOP. The MTG process will yield high octane gasoline which is also rich in aromatics. GTW is to bring the gas as electricity to market. Natural gas is converted to electricity by thermodynamic cycle such as simple cycle of steam turbine or gas turbine, combine cycle, micro turbine, and by electro-catalytic processes such as fuel cells. New technology innovations focusing on developing natural gas gasification combined cycle for CO2 sequestration are proposed. Micro turbines have advantages of reducing the number of moving parts, its compactness and lightness, and low emissions rates. Fuel cells have the ability to generate electricity using electrochemical reactions that are an extremely exciting for the clean and efficient generation of electricity. Basically, a fuel cell works by passing fuel (usually hydrogen) and oxidants over electrodes that are separated by an electrolyte membrane. Oxygen flows into the cathode and hydrogen into the anode. In the anode, hydrogen dissociated in the present of noble metal catalyst, forming proton (hydrogen ions) and yielding electrons to the anode. Anode reaction: H2 Æ 2H+ + 2e-. Hydrogen ions are transported through an electrolyte, as liberated electrons flow through electrical load to the cathode to participate in the catalytic oxidation reaction, forming water. Cathode reaction: 2H+ + 2e- + ½ O2 Æ H2O. This produces a chemical reaction that generates electricity without requiring the combustion of fuel, or the addition of heat as is common in the traditional generation of electricity. Micro turbines and fuel cells are
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suitable for distributed power generation due to tension variation control and supply reliability are better, and transmission and distribution costs are smaller by reason of the proximity to the load centers. Gas Combustion. Natural gas is burned to produce lower NOX emission than another fossil fuel, free of SOX. NOX is emitted in percentage of about 40% by coal and about 57% by petroleum. CO2 is emitted in percentage of about 60% by coal and of about 75% by petroleum. Therefore, natural gas is the most environmentally friendly fossil fuel. Efficiency of natural gas fueled furnace, particularly conventional furnace, is about 60% to about 90% for pulse combination furnace and boiler. The strengthen environmental regulation causes the role of catalyst in natural gas combustion becomes more important due to combustion products are extremely low levels of NOX and simultaneously low levels of carbon monoxide (CO) and unburned hydrocarbons (UHC). Another type of residential and industrial application is radiant premixed catalytic combustion. In this system catalyst is in form of honeycomb, tube or fibers. Mixture of gas and air are introduced into the catalyst which is burnt by both catalytic and gasphase oxidation, radiating energy from catalyst surface. In power density of about 120 kW/m2 and near reaction stoichiometry this system gives emission of NOX less than 5 ppm and CO of about 150 ppm Natural Gas Storage. Natural gas can be stored in a variety of ways. Usually, it is held in underground formations, i.e. in depleted oil or gas reservoirs, in natural aquifers, in cavities created in large underground salt deposits and in reconditioned hard rock mine. Gas is injected and withdrawn from these formations using much of the same type of well drilling and production equipment found in a working natural gas field. Methane Hydrate is a cage-like lattice of ice containing trapped molecules of methane. Actually, the name for its parent class of compounds is clathrates. Methane hydrates form in generally two types of geologic settings: on land in permafrost regions where cold temperatures persist in shallow sediments and beneath the ocean floor at water depths greater than about 500 meters where high pressures dominate. The hydrate deposits themselves may be several hundred meters thick. These crystals, although unmistakably a combination of both water and natural gas, would often form at temperatures well above the freezing point of ordinary ice. Worldwide, estimates of the natural gas potential of methane hydrates approach 400 million trillion cubic feet - a staggering figure compared to the 5,000 trillion cubic feet that make up the world's currently known gas reserves. This huge potential, alone, warrants a new look at advanced technologies that might one day reliably and cost-effectively detect and produce natural gas from methane hydrates. Coal Bed Methane. Methane, or natural gas, is usually associated with petroleum. However, this gas can also be found in coal beds. Methane is produced by microbial processes or from a thermal process due to the depth and heat of the coal bed. Methane reserves are most often found in coal seams close to the Earth's surface. Water gets trapped in these seams and creates pressure, which holds the gas inside the seam. Coal is usually has a large surface
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area enabling coal beds to storing a large amount of methane gas. Coal beds provide a relatively cheap source of natural gas, because the beds are often close to the surface which makes access and well drilling easier.
9.3
Coal Technology Coal plays an important role in the world’s energy system and hence global economic
and social development. However, further development in coal industries should recognize their ability to meet the challenge of environmental sustainability. Programs and technologies aiming to significantly reduce the potential greenhouse impact of coal and other carbon-intense would determine the sustainable role of coal in the global energy mix. The technologies employed and being developed to meet coal’s environmental challenges-collectively referred as clean coal technology (CCT). Clean coal technology represents a continuously developing range of option to suit different conditions and challenges in the life-cycle of coal. In general the life-cycle of coal can be classified into several activities: (i) coal extraction through surface and underground mining, (ii) coal beneficiation / preparation, (iii) coal storage and transportation, and (iv) coal utilization. The environmental issues regarding the activities through out the life-cycle coal can be summaries as follows: •
reducing the impact of coal mining activities on the existing forests and coal mine rehabilitation,
•
reducing SO2 emission and improve thermal efficiency by coal cleaning,
•
reducing potential loss in energy content due to spontaneous combustion during coal storage and transportation.
•
reducing greenhouse gas emission, particulate and trace elements from coal utilization activities. In general, Figure 9.3 represents the life-cycle of coal and the area of clean coal
technology developments. Coal Mining involves two widely applied techniques, i.e. surface and underground mining. Surface mining only economic when the coal seam is near the surface. The equipment used includes: draglines; power shovels; large trucks, which transport overburden and coal; bucket wheel excavators; and high capacity conveyors. This method is widely used in the USA, Australia and Indonesia. Currently, almost two-thirds of hard coal production worldwide comes from underground mines. Good coal mining practices including coal mine rehabilitation would secure safety and sustainability of the mining area and its surrounding. Coal Beneficiation. Depend upon the site geological structure, as-mined coal has variable quality and contains substances such as clay, sand and carbonates. Coal preparation
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or coal washing/cleaning – also known as coal beneficiation is required to clean and to remove mineral matter from mined coal. The coal is also sized and blended to meet customer specifications. Cleaner coal usually has better quality representing by higher value and lower sulfur and mineral constituents. The coal beneficiation process involves characterization, liberation, separation and disposition. The composition of the different raw coal particles is identified during the characterization process. Liberation involves crushing the mined coal and reducing it to very fine particles. Separation is the partitioning of the individual particles into their appropriate size groupings and separating the mineral matter particles from the coal. Finally the disposition stage involves the dewatering and storage of the cleaned coal and the disposal of the mineral matter. Coal Storage and Transportation. During long-term storage in open air stockpiles or long-distance transportation most coals are susceptible to weathering and oxidation. This oxidation is undesirable because it consumes or reduces the energy available in the coal. In addition to degrading the energy potential of the coal, the exothermic reaction of coal raises the internal temperature of the stockpile, increasing the risk of spontaneous combustion. The application of stockpile management principles could reduce weathering and oxidation problems. • Activated carbon injection
• Electrostatic
precipitators
• Fabric fulters • Flue gas
desulphurization
• Hot gas filtration systems
• SCR dan SNCR • Wet particle
• Coal up-grading,
scrubbers
briquetting,
• Bio-coal, synergies
• Gasification,
with renewables
liquefaction
UTILIZATION : POWER GENERATION MINING
BENEFICIATION
• Sustainable mining •
activities Mine site rehabilitation
STORAGE and TRANSPORTATION
• Improve storage design and efficiency
PRECOMBUSTION
POSTCOMBUSTION
• Pulverized coal combustion
• Fluidized bed
• •
combustion: AFBC, CFBC, PFBC, IGCC Pressurized pulverized bed combustion Supercritical and ultra supercritical technology
Figure 9.3 The life cycle of coal and the area of clean coal technology
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Coal Utilization Pre-combustion technologies Coal gasification process is carried out in an apparatus called coal gasifier. A gasifier converts hydrocarbon feedstock into gaseous components. In a gasifier, coal is fed at the top of the gasifier through a lockhopper. The coal reacts while moving down through the gasifier. The coal ash is removed from the bottom of the gasifier. From the bottom of the bed, steam and oxygen injected, and react with the coal as the gases move up through the bed. This countercurrent actions result in wide temperature difference between the top and bottom of the gasifier. A gasifier differs from a combustor in that the amount of air or oxygen available inside the gasifier is carefully controlled so that only a relatively small portion of the fuel burns completely. This "partial oxidation" process provides the heat. Rather than burning, most of the carbon-containing feedstock is chemically broken apart by the gasifier's heat and pressure, setting into motion chemical reactions that produce "syngas." Syngas is primarily hydrogen, carbon monoxide and other gaseous constituents, the proportions of which can vary depending upon the conditions in the gasifier and the type of feedstock. Coal liquefaction. Direct liquefaction processes include those that normally, proceed to liquids in a single processing sequence, using solid coal as the primary reactant. Some direct liquefaction schemes also involve chemical pretreatment steps. Indirect liquefaction processes involve gasification as the first step conversion, followed by catalytic recombination of the resulting synthesis gas mixture (CO + H2) to form hydrocarbon and oxygenates. Hydrogenation or hydro-liquefaction and pyrolysis are the two means used for direct liquefaction. In direct hydrogenation the primary reactions are a combination of homogeneous thermal cracking. Process schemes that apply pyrolysis chemistry normally involve thermolysis in an inert or reducing atmosphere and produce two principal products from coal: a tar and char. Indirect liquefaction includes 3 (three) kinds of operating condition: -
The low pressure synthesis process, which operated at relatively low pressures, in the range of 100-200kPa (1-2 atm). Catalysts were primarily cobalt based, with catalyst lives of one to two months.
-
The medium pressure synthesis process, which operated at pressures of 500-2,000 kPa (520 atm). Cobalt catalysts similar to those used for the normal pressure typically used at temperatures ranging from 170 to 200oC in tubular “heat exchanger” type reactors.
-
The high pressure synthesis process, which operated at pressures of 10 to 20 MPa (100-200 atm) and temperatures in the 400oC ranges. The plant utilizes iron catalyst in both fixed and fluidized reactor schemes.
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Efficient combustion technologies Pulverized Coal Combustion. Conventional coal-fired generation today is normally via the route of pulverized coal combustion (PCC). PCC can be used to fire a wide variety of coals, although it is not always appropriate for those with high ash content. In PCC power stations, coal is first pulverized then blown into a furnace where it is combusted at high temperature. The resulting heat is used to raise steam, which drives a steam turbine and generator. Efficiencies have been steadily rising – and hence emissions reducing – for many years and the trend continues. Fluidized Bed Combustion. In fluidized bed combustion (FBC), coal is burnt in a bed of heated particles suspended in flowing air. At sufficiently high air velocity, the bed acts as a fluid resulting in rapid mixing of the particles. This fluidizing action allows complete coal combustion at relatively low temperatures. This improves combustion, heat transfer and recovery of waste products. The higher heat exchanger efficiencies and better mixing of FBC systems allows them to operate at lower temperatures than conventional (pulverized) coalburning systems. By elevating pressures within a bed, a high pressure gas stream can be used to drive a gas turbine, generating electricity. FBC systems are popular because of the technology’s fuel flexibility; almost any combustible material can be burnt. Fluidized bed combustion (FBC), in its various forms, can reduce SOx and NOx by 90% or more. Fluidized bed combustion technologies include atmospheric pressure fluidized bed combustion in both bubbling (BFBC) and circulating (CFBC) beds, pressurized fluidized bed combustion (PFBC), while pressurized circulating fluidized bed combustion (PCFBC) is being demonstrated. Circulating Fluidized Bed Combustion (CFBC) is the version of the technology that has been most widely applied and for which there is the most extensive operating history. Circulating fluidized bed combustion (CFBC) is of particular value for low grade, high ash coals that are difficult to pulverize and which may have variable combustion characteristics, while still ensuring low emissions of NOx and SOx. CFBC uses the same thermodynamic cycle as PCC and therefore its power generation efficiency is in the same range, which is normally between 38% and 40%. Pressurized Fluidized Bed Combustion (PFBC) is based on the combustion of coal under pressure in a deep bubbling fluidized bed at 850°C. Depending on the velocity of the air through the fluidized bed, two PFBC variants exist – bubbling bed PFBC (lower velocities) and circulating bed PFBC (higher velocities). Integrated Gasification Combined Cycle. In Integrated Gasification Combined Cycle (IGCC) systems, coal is not combusted directly, but reacted with oxygen and steam to produce a ‘syngas’ composed mainly of hydrogen and carbon monoxide. The syngas is cleaned of impurities and then burned in a gas turbine to generate electricity and to produce steam for a
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steam power cycle. IGCC technology offers high efficiency levels and as much as 95-99% of NOx and SOx emissions are removed. Pressurized Pulverized Coal Combustion. Pressurized pulverized combustion of coal (PPCC) is a technology currently under development, mainly in Germany. Similar to conventional pulverized coal combustion, in that it is based on the combustion of a finely ground cloud of coal particles, the heat released from combustion generates high pressure, high temperature steam, which is used in steam turbine-generators to produce electricity. The pressurized flue gases exit the boiler and are expanded through a gas turbine to generate further electricity and to drive the gas turbine’s compressor; hence this is a form of combined cycle power generation. Supercritical & Ultra Supercritical Technology. Supercritical pulverized coal-fired power plant operate at higher steam temperatures and pressures than conventional sub critical PCC plant, and offer higher efficiencies – up to 45% – and hence lower emissions, including emissions of CO2, for a given power output. Even higher efficiencies – up to 50% – can be expected in ultra supercritical (USC) power plant, operating at very high temperatures and pressure.
Post-combustion technologies Activated Carbon Injection. Activated carbon injection involves activated carbon being injected into the flue gas stream exiting the boiler and absorbing pollutants such as mercury onto particulate matter, which is then removed in existing particulate control equipment. Electrostatic Precipitators (ESPs). Electrostatic precipitators are the most widely used particulate emissions control technology in coal-fired power generating facilities. Particulate/dust laden flue gases are passed horizontally between collecting plates, where an electrical field creates a charge on the particles. The particles are then attracted towards the collecting plates, where they accumulate. In dry electrostatic precipitators the agglomerated particles are then removed in a dry form by mechanical rapping or vibration to create a powder for disposal. In wet electrostatic precipitators the particles are sprayed and washed off as slurry. Fabric Filters. Fabric filters, also known as bag houses, collect particulates from the flue gas on a tightly woven fabric by sieving and other mechanisms. The choice between electrostatic separation and fabric filtration depends on coal type, plant size, and boiler type and configuration. Fabric filters are useful for collecting particles with resistivities either too low or too high for collection with electrostatic precipitators. Flue Gas Desulphurization. Flue gas desulphurization (FGD) technologies are used to remove sulphur emissions post-combustion. FGD technologies can be classified into six main categories: wet scrubbers; spray dry scrubbers; sorbent injection processes; dry scrubbers; regenerable processes; and combined SO2/NOx removal processes. Wet scrubbers tend to dominate the global FGD market. The technology uses alkaline sorbent slurry, which is
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predominantly lime or limestone based. A ‘scrubbing vessel’ or scrubber is located downstream of the boiler and flue gas cleaning plant, in which the sulphur dioxide in the flue gases reacts with the limestone sludge, forming gypsum. Hot Gas Filtration Systems. Hot gas filtration systems operate at higher temperatures (500-1000°C) and pressures (1 - 2 MPa) than conventional particulate removal technologies, eliminating the need for cooling of the gas. A range of technologies such as cyclones, ceramic barrier filters, high-temperature fabric filters, granular bed filters and high-temperature ESPs have been under development for many years. Some of these are in the demonstration stage but further development is needed to enable commercial exploitation. Selective Catalytic Reduction (SCR) & Selective Non-Catalytic Reduction (SNCR). In selective catalytic reduction systems, ammonia vapor is used as the reducing agent and is injected into the flue gas stream, passing over a catalyst. The optimum temperature is usually between 300°C and 400°C. The key difference between SCR and SNCR is the presence in SCR systems of a catalyst, which accelerates the chemical reactions. The catalyst is needed because SCR systems operate at much lower temperatures than SNCR; typical temperatures for SNCR are 870-1200°C. Wet Particle Scrubbers. Wet particle scrubbers for particulate control are used in a limited number of coal-fired plants, with most of these installations located in the USA, to capture fly ash in addition to sulphur dioxide (SO2). Water is injected into the flue gas stream to form droplets. The fly ash particles impact with the droplets forming a wet by-product, which then requires disposal. Wet particle scrubbers have a removal efficiency of 90-99.9%.
9.4
Renewable Energy Technology Renewable energy uses energy sources that are continually replenished by nature—the
sun, the wind, water, the earth’s heat, and plants. Renewable energy technologies turn these fuels into usable forms of energy—most often electricity, but also heat, chemicals, or mechanical power. One can classify renewable energy as follows:
Bio-energy or biomass energy
Wind energy (moving air masses driven by solar energy)
Solar energy
Hydropower
Ocean/Marine energy (such as wave energy, marine current energy, and energy from tidal barrages)
Geothermal energy
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BIOMASS ENERGY Biomass energy or bio-energy is the energy derived from biomass - a term that generally refers to any plant or animal matters. Bio-energy in the form of heat can be produced by using biomass directly as a fuel or by converting it to biogas or liquid bio-fuels. The heat produced can be converted to electricity by delivering hot fluid through a gas turbine. The main sources of biomass include industrial waste such as sugar cane waste (bagasse), wood waste from forestry operations, and wastes from crop harvest such as straw and husks. Organic wastes from animal husbandry may also be converted to biogas. Therefore, biomass energy may be classified in the forms of: 1. Biofuels. Biofuels are fuels for vehicles derived from biomass chemical or biochemical conversions such as ethanol or biodiesel; fuels for engines obtained from biomass gasification via physical or chemical conversion process to a secondary gaseous fuel; and fuels obtained from biological conversion via bacterial anaerobic digestion to methane-rich biogas as a gaseous fuel. 2. Biopower Biopower is electricity generated from biomass combustion or gasification
Biofuels Biomass can be converted directly into liquid fuels—liquid biofuels—for use in vehicles. Conversion routes for producing biofuels from biomass and the differences in maturity of biofuel options are illustrated in the following Figure 9.4.
Source: Girard and Fallot, 2006, brown box and arrow depict 1st generation biofuels, blue box and arrow indicate 2nd generation biofuels. Figure 9.4 Production pathway of biofuels
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Biofuels such as ethanol prepared by fermentation of starch/sugar-rich plant, biodiesels straight vegetable oil (SVO) and fatty acid methyl esters (FAME) from oil crops are called 1st generation because these technologies already exist. The second generation biofuels assure clear advantages over first generation biofuels, in terms of land-use efficiency, and environmental performance. Large quantities of lignocellulosic feedstock from biomass residues and wastes are already available, and can be more readily prolonged compared to food crops. Ethanol Ethanol can be mass-produced by fermentation of sugar or by hydration of ethylene from petroleum and other sources. Current interest in ethanol lies in the production derived from crops (bio-ethanol), since it is a sustainable energy resource that offers environmental and long-term economic advantages over fossil fuels, like gasoline or diesel. It is readily obtained from the starch or sugar in a wide variety of crops. Ethanol fuel production depends on availability of land area, soil, water, and sunlight Biodiesel First generation biodiesel uses oilseed-yielding plants like palm, jatropha, castor, soy, rapeseed, etc. from which straight vegetable oils (SVO) can be derived by physical and chemical treatments. SVO can then be further processed into fatty acid methyl esters (FAME), which are also known as biodiesels. Another route for biodiesels is through hydro thermal upgrading (HTU) of unprocessed bio-oils so that no transesterification is needed.
.Biopower Most electricity generated using biomass today is by direct combustion using conventional boilers. These boilers burn primarily waste wood products generated by the agriculture and wood-processing industries. When burned, the wood waste produces steam, which is used to spin a turbine. The spinning turbine activates a generator that produces electricity. The low-cost option for the use of biomass is cofiring with coal in existing boilers. Cofiring refers to the practice of introducing biomass as a supplementary energy source in highefficiency boilers. The current coal-fired power generating system substituting biomass-based renewable carbon for fossil carbon represents a direct system for carbon mitigation. Extensive demonstrations and trials have shown that effective substitutions of biomass energy can be made up to about 15 percent of the total energy input with little more than burner and feed intake system modifications to existing stations. Since the size of large-scale power boilers ranges from 100 MW to 1.3 GW, the biomass potential in a single boiler ranges from 15 MW to 150 MW. Preparation of biomass for cofiring involves well-known commercial technologies. Since biomass in general has significantly less sulfur than coal, there is a SO2 benefit, and early
217
test results suggest that there is a potential reduction of NOx of up to 30 percent with woody biomass. Investment levels are very site specific and are affected by the available space for yarding and storing biomass, installation of size reduction and drying facilities, and the nature of the boiler burner modifications. . Another potentially attractive biopower option is based on gasification. Gasification for power production involves the devolatilization and conversion of biomass in an atmosphere of steam and air to produce a medium- or low-calorific gas. This "biogas" is then used as fuel in combined cycle power generation involving a gas turbine topping cycle and a steam turbine bottoming cycle. Biomass gasification systems will also stand ready to provide fuel to fuelcell and hybrid fuel-cell/gas turbine systems, particularly in developing countries or rural areas that do not have access to cheap fossil fuels or that have an undependable transmission infrastructure. The first generation of biomass GCC systems would realize efficiencies nearly double those of the existing industry. In a cogeneration application, efficiencies could exceed 80 percent. This technology is very near to commercial availability, with one mid-size plant operating in Finland. Small modular biomass gasification systems are well suited for providing isolated communities with electricity. Producing electricity from biomass is most cost effective if biomass power or biopower plants are located near biomass feedstocks In addition, the decay of biomass in landfills produces gas (primarily methane) naturally, which can be harvested and burned in a boiler to produce steam for generating electricity.
WIND ENERGY A wind turbine converts the energy in the wind into electrical energy or mechanical energy to pump water or grind grain. Wind turbines are rated by their maximum power output in kilowatts (kW) or megawatts (1,000 kW, or MW). For commercial utility-sized projects, the most common turbines available in the market are in the range of 600 kW to 1 MW – large enough to supply electricity to 600 - 1,000 homes. The newest commercial turbines are rated at 1.5-2.5 megawatts. A typical 600 kW turbine has a blade diameter of 35 meters and is mounted on a 50 meters concrete or steel tower. Most commercial wind turbines operating today are at sites with average wind speeds greater than six meters/ second (m/s) or 22 km/h. A prime wind site will have an annual average wind speed in excess of 7.5 m/s (27 km/h). Advantages Wind energy is fueled by the wind, so it's a clean fuel source. Wind energy doesn't pollute the air like power plants that rely on combustion of fossil fuels, such as coal or natural gas. Wind turbines don't produce atmospheric emissions that cause acid rain or greenhouse gasses. Wind energy relies on the renewable power of the wind, which can't be used up. Wind is actually a form of solar energy; winds are caused by the heating of the atmosphere by the sun, the rotation of the earth, and the earth's surface irregularities. Wind energy is one of the lowest-
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priced renewable energy technologies available today, costing between 4 and 6 cents per kilowatt-hour, depending upon the wind resource and project financing of the particular project. Wind turbines can be built on farms or ranches, thus benefiting the economy in rural areas, where most of the best wind sites are found. Farmers and ranchers can continue to work the land because the wind turbines use only a fraction of the land. Wind power plant owners make rent payments to the farmer or rancher for the use of the land. Disadvantages Wind power must compete with conventional generation sources on a cost basis. Depending on how energetic a wind site is, the wind farm may or may not be cost competitive. Even though the cost of wind power has decreased dramatically in the past 10 years, the technology requires a higher initial investment than fossil-fueled generators. The major challenge to using wind as a source of power is that the wind is intermittent and it does not always blow when electricity is needed. Wind energy cannot be stored (unless batteries are used); and not all winds can be harnessed to meet the timing of electricity demands. Good wind sites are often located in remote locations, far from cities where the electricity is needed. Effective storing of electricity could enhance the value and reduce the uncertainty of wind-generated electricity through the levelling out of delivered power. There is a need for different storage techniques at different time scales. Although wind power plants have relatively little impact on the environment compared to other conventional power plants, there is some concern over the noise produced by the rotor blades, aesthetic (visual) impacts, and sometimes birds have been killed by flying into the rotors. Most of these problems have been resolved or greatly reduced through technological development or by properly siting wind plants. Stand-alone turbines will be built in vast numbers, but the installed total capacity may not be large. However, the value of electricity from these machines can be of great importance, such as in remote locations where grid connection is not feasible. System integration of wind generators with other power sources such as photovoltaic solar cells (PV) or diesel generating systems is essential in small grids where high reliability is required SOLAR ENERGY Solar energy can be used as (a) solar thermal and (b) photovoltaic solar electricity. Solar Thermal The sun’s energy can be collected directly to create both high temperature steam (greater than 100oC) and low temperature heat (less than 100oC) for use in a variety of heat and power applications. High temperature solar thermal systems use mirrors and other reflective surfaces to concentrate solar radiation. Parabolic dish systems concentrate solar radiation to a single point to produce temperatures in excess of 100oC. Line-focus parabolic concentrators focus solar radiation along a single axis to generate high temperatures. Central receiver
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systems use mirrors to focus solar radiation on a central boiler. The resulting high temperatures can be used to create steam to either drive electric turbine generators, or to power chemical processes such as the production of hydrogen. Low temperature solar thermal systems collect solar radiation to heat air and water for industrial applications including: space heating for homes, offices and greenhouses, domestic and industrial hot water, pool heating, desalination, solar cooking, and crop drying. These technologies include passive and active systems. Passive systems collect energy without the need for pumps or motors, generally through the orientation, materials, and construction of a collector. These properties allow the collector to absorb, store, and use solar radiation. Passive systems are particularly suited to the design of buildings (where the building itself acts as the collector) and thermo siphoning solar hot water systems. In colder climates, a passive solar system can reduce heating costs by up to 40 percent while in hotter climates, passive systems can reduce the absorption of solar radiation and thus reduce cooling costs. The most common active systems use pumps to circulate water or another heat absorbing fluid through a solar collector. These collectors are most commonly made of copper tubes bonded to a metal plate, painted black, and encapsulated within an insulated box covered by a glass panel.
Photovoltaic Solar Electricity A photovoltaic (PV) cell generally consists of two or more semiconductor layers. These layers have the interesting property of generating electrons when they absorb sunlight. Sunlight is composed of photons, or particles of solar energy. When photons are absorbed by the semiconductor, the energy of the photon is transferred to an electron in an atom of the material. This energised electron is able to escape from the material to become part of the direct current (DC) in an electric circuit. A number of different types of semiconductor materials can be used in PV cells. These include silicon, copper indium diselenide, cadmium telluride and gallium arsenide – each has its advantages and disadvantages and there is no one ideal material for all types of applications. Silicon is the most common type of semiconductor material used at this time and happens to be one of the most abundant materials on Earth. Most PV cells are made of one of three types of very pure silicon – monocrystalline (the cell contains one silicon crystal), polycrystalline (the cell contains many sili con crystals) or amorphous (a thin layer of non-crystalline silicon). Monocrystalline silicon cells are the most efficient but also the most costly to produce. Amorphous silicon cells are the least efficient but are flexible and so can be attached to flexible steel or plastic surfaces. These are very useful for certain applications. The semiconductor material is attached to a metallic grid that collects the electrons generated and transfers them to the external load. Another metallic grid backs the semiconductor layers to complete the electrical circuit and transfer the electrons back to the semiconductor material. A PV cell is covered with low-iron content glass or some
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other kind of transparent encapsulant to seal the cell from the external environment. This glass cover is backed with an anti-reflective coating to allow as much sunlight as possible to penetrate through to the semiconductor layers. Photovoltaic cells come in many sizes, but most are 10 cm by 10 cm and generate about half a volt of electricity. PV cells are encapsulated into modules, several of which are combined into an array to produce higher voltages and increased power. A 12-volt module, for example, depending on its power output, could have 30 to 40 PV cells. A module producing 50 watts of power measures approximately 40 cm by 100 cm. PV arrays are not highly efficient, converting only 12 to 15 per cent of the sun’s light into electricity, but laboratory prototypes are reaching 30 per cent efficiency. PV modules generate direct current (DC). Most electric devices require 220-volt alternating current (AC) as supplied by utilities. A device known as an inverter converts DC to AC current. Inverters vary in size and in the quality of electricity they supply. Less expensive inverters are suitable for simple loads, such as lights and water pumps, but models with good quality waveform output are needed to power electronic devices such as TVs, stereos, microwave ovens and computers. A PV array is usually part of a system that may also include energy storage devices (usually batteries), support frames and electronic controllers; all these systems are collectively referred to as the balance-of-system or BOS.
Efficiency of photovoltaic cells The conversion efficiency of a PV cell is the proportion of light energy falling on the cell surface that is converted to electrical energy. Much research has gone into improving the efficiency of PV cells while also reducing the cost of production. This is very important in order to make PV energy competitive with other sources of energy, such as coal or gas, and to develop systems that use as little surface area as possible per unit of energy produced. The earliest PV cells were less than 2% efficient. Today, mass produced PV modules using monocrsytalline silicon are generally 15-18% efficient (the actual efficiency depending on such factors as the strength of light and the temperature), although some of the newest modules being manufactured have been verified as over 20% efficient. Modules made of polycrystalline silicon cells are 12-15% efficient. Amorphous silicon cells are only 6-10% efficient, but this is compensated by the fact that their performance degrades less than other cells at normal working temperatures. To make an efficient silicon PV cell, the crystalline structure of the silicon must be very pure, which makes the cost of manufacturing this material quite high. Furthermore, the silicon doping processing must be done very carefully and precisely, which again adds to the manufacturing costs. However, manufacturing costs are decreasing as the manufacturing technology improves and demand increases. Because the sun's energy is abundant and free, efficiency is usually not the major factor limiting the use of PV today. This is because there is usually more than enough area on a structure for PV modules to generate the energy required, particularly if the PV material can perform another function, such as acting as a roof or a wall cladding. The cost of manufacturing the PV module is usually the limiting factor today.
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PV modules have a power and voltage rating determined under "standard conditions" of solar input of 1000W/m2 and a temperature of 25oC. Thus, a module rated at 75Wp (the "p" stands for "peak") will produce 75 watts of power under standard conditions. Typical system size varies from 50 watt (W) to 1 kilowatt (kW) for stand-alone systems with battery storage and small water pumping systems; from 500 W to 5 kW for roof-top grid connected systems and larger water pumping systems; and from 10 kW to megawatts for grid connected ground-based systems and larger building integrated systems.
HYDROPOWER The energy in falling water can be converted into electrical energy or into mechanical energy to pump water. The amount of energy that can be captured is a function of the vertical distance the water drops and the volume of the water. The definition of small-scale hydropower varies, only projects that have less than 10 megawatts (MW) of generating capacity are considered here. This definition also includes mini-hydro (<1 MW), micro-hydro (<100 kilowatts, or kW), and pico-hydro (<1 kW). Most conventional hydroelectric plants include four major components: 1. Dam. It raises the water level of the river to create falling water. It also controls the flow of water. The reservoir formed is, in effect, stored energy. 2. Turbine. The force of falling water pushing against the turbine's blades causes the turbine to spin. A water turbine is much like a windmill, except the energy is provided by falling water instead of wind. The turbine converts the kinetic energy of falling water into mechanical energy. 3. Generator. It is connected to the turbine by shafts and possibly gears so when the turbine spins it causes the generator to spin also. It converts the mechanical energy from the turbine into electric energy. Generators in hydropower plants work just like the generators in other types of power plants. 4. Transmission lines. They conduct electricity from the hydropower plant to homes and business. The main components of a small-scale hydro (SSH) system are a turbine and a generator. Other components include the physical structures to direct and control the flow of water, mechanical and/or electronic controllers, and structures to house the associated equipment. Small-scale hydro systems are modular and can generally be sized to meet individual or community needs. However, the financial viability of a project is subject to the available water resource and the distance the generated electricity must be transmitted.
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Advantages Hydropower is a fueled by water, so it's a clean fuel source. Hydropower doesn't pollute the air like power plants that burn fossil fuels, such as coal or natural gas. Hydropower relies on the water cycle, which is driven by the sun, thus it's a renewable power source. Hydropower is generally available as needed; engineers can control the flow of water through the turbines to produce electricity on demand. Hydropower plants provide benefits in addition to clean electricity. Impoundment hydropower creates reservoirs that offer a variety of recreational opportunities, notably fishing, swimming, and boating. Other benefits may include water supply and flood control. Disadvantages Most of the adverse impacts of dams are caused by habitat alterations. Reservoirs associated with large dams can cover land and river habitat with water and displace human populations. Diverting water out of the stream channel (or storing water for future electrical generation) can dry out streamside vegetation. Insufficient stream flow degrades habitat for fish and other aquatic organisms in the affected river below the dam. Water in the reservoir is stagnant compared to a free-flowing river, so water-borne sediments and nutrients can be trapped, resulting in the undesirable growth and spread of algae and aquatic weeds. In some cases, water spilled from high dams may become supersaturated with nitrogen gas and cause gas-bubble disease in aquatic organisms inhabiting the tailwaters below the hydropower plant. Hydropower projects can also affect aquatic organisms directly. The dam can block upstream movements of migratory fish. Downstream-moving fish may be drawn into the power plant intake flow and pass through the turbine. These fish are exposed to physical stresses (pressure changes, shear, turbulence, strike) that may cause disorientation, physiological stress, injury, or death. Fish populations can be impacted if fish cannot migrate upstream past impoundment dams to spawning grounds or if they cannot migrate downstream to the ocean. Upstream fish passage can be aided using fish ladders or elevators. Downstream fish passage is aided by diverting fish from turbine intakes using screens or racks or even underwater lights and sounds, and by maintaining a minimum spill flow past the turbine. In the US, biological tests are being conducted that will quantify the physical stresses that cause injury or death to fish. In addition to these tests, tools are being developed to help both the engineers and biologists to include a sensor fish, which is a "crash dummy fish." It will be able to measure the physical stresses in a turbine passage and can be used instead of live fish to gather information. Another tool is the development of a computational fluid dynamics program that models potential fish behavior in the turbine passage. The test results and tools will help turbine manufacturers design a more environmentally friendly turbine, which will reduce the physical stresses exposed to fish. New products such as greaseless bearings eliminate the possibility of petroleum products being released in the water.
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OCEAN/MARINE ENERGY Oceans cover two-thirds of the earth’s surface. These bodies of water are vast reservoirs of renewable energy. In a four-day period, the planet's oceans absorb an amount of thermal energy from the sun and kinetic energy from the wind equivalent to all the world's known oil reserves. Several technologies exist for harnessing these vast reserves of energy for useful purposes. The most promising are ocean thermal energy conversion (OTEC) and wave power plants. Both of these produce electricity from the oceans' reserves of renewable energy. As the ultimate source of energy from the oceans is the sun, ocean energy systems are renewable, have no fuel costs and are relatively nonpolluting when compared to conventional sources of energy such as coal, oil and natural gas. Ocean Thermal Energy Conversion (OTEC) power plants exploit the difference in temperature between warm surface waters heated by the sun and colder waters found at ocean depths to generate electricity. A temperature difference of 20°C or more between surface waters and water at depths of up to 1000 m is required. OTEC power plants can be located either onshore or at sea, with the generated electricity transmitted to shore by electrical cables or used on site for the manufacture of electricity intensive products or fuels. There are three potential types of OTEC power plants, open-cycle, and closed-cycle and hybrid systems. Closed-cycle systems use the ocean's warm surface water to vaporize a working fluid, which has a lowboiling point, such as ammonia. The vapor expands and turns a turbine. The turbine then activates a generator to produce electricity. Open-cycle systems actually boil the seawater by operating at low pressures. This produces steam that passes through a turbine/generator. Hybrid systems combine both closed-cycle and open-cycle systems. GEOTHERMAL ENERGY Geothermal energy is the energy contained in the heated rock and fluid that fills the fractures and pores within the earth's crust. It originates from radioactive decay deep within the Earth and can exist as hot water, steam, or hot dry rocks. Commercial forms of geothermal energy are recovered from wells drilled 100–4,500 meters below the Earth’s surface. The technology is well proven, relatively uncomplicated, and involves extracting energy via conventional wells, pumps, and/or heat exchangers. Geothermal energy can be used directly or indirectly, depending on the temperature of the geothermal resource. Geothermal resources are classified as low temperature (less than 90°C), moderate temperature (90°C - 150°C), and high temperature (greater than 150°C). The highest temperature resources are generally used only for electric power generation and found in volcanic regions. Geothermal energy can be used directly in temperatures ranging from about 35°C to 150°C to heat buildings, greenhouses, aquaculture facilities and to provide industrial process heat. Indirectly, high temperature geothermal steam can be used to drive a turbine and create electricity or in heat pumps. Using geothermal energy directly is 50 to 70 percent efficient compared to the 5 to 20 percent possible for the indirect use of generating electricity (although using the waste heat from generating electricity can also be used and thus boost the overall efficiency). Applications that
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use geothermal energy directly can also draw from both high and low temperature geothermal energy resources. Economics of Geothermal Energy Geothermal power plants can produce electricity as cheaply as some conventional power plants. It costs 4.5 to seven cents per kWh to produce electricity from hydrothermal systems. In comparison, new coal-fired plants produce electricity at about four cents per kWh. The cost of producing electricity over time is lower because the price and availability of the fuel is stable and predictable. The fuel does not have to be imported or transported to the power plant. The power plant literally sits on top of its fuel source. Initial construction costs for geothermal power plants are high because geothermal wells and power plants must be constructed at the same time. Geothermal Energy and the Environment Geothermal energy is a renewable energy source that does little damage to the environment. Geothermal steam and hot water do contain naturally occurring traces of hydrogen sulfide (a gas that smells like rotten eggs) and other gases and chemicals that can be harmful in high concentrations. Geothermal power plants emit only about one to three percent of the sulfur compounds that coal and oil-fired power plants do. Geothermal power plants use "scrubber" systems to clean the air of hydrogen sulfide and the other gases. Sometimes the gases are converted into marketable products, such as liquid fertilizer. Newer geothermal power plants can even inject these gases back into the geothermal wells.
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9.5
Electricity Technology The technological challenges in power generation are to develop more efficient (high
thermal efficiency) and more environmental friendly plants. There are promising advanced power generation such as gas turbine based technologies especially combined cycle gas turbine (CCGT), integrated gasification combined cycle (IGCC), small engines suitable for distributed applications such as microturbines, and various fuel cell technologies. These technologies are strategically important to meet electricity production with high efficiency and greatly reduced emissions to the environment and taking into account their full fuel cycles. Combined Cycle Gas Turbine (CCGT). A technology which combines gas turbines and steam turbines, connected to one or more electrical generators at the same plant. The gas turbine, usually fuelled by natural gas or oil, produces mechanical power, which drives the generator, and heat in the form of hot exhaust gases. These gases are fed to a heat recovery steam generator (HRSG), where steam is raised at pressure to drive a conventional steam turbine which is also connected to an electrical generator. The thermal efficiency of a CCGT could reach about 55 % which is higher than an open cycle turbine. Microturbines are small gas turbines used to generate electricity. They occupy a small space and typically have power outputs in the range of 25 to 300 kW. The small size of microturbines is a major advantage that allows them to be situated right at the source of electricity demand. This eliminates energy losses that usually occur when transmitting electricity from power stations. Advantages of microturbines are quiet operation with little vibration, low emission levels and, thermal efficiencies of 15-30%, low maintenance and high reliability. However, the main draw back of microturbines is the limit to the number of times that they can be started up and shutdown. Integrated Gasification Combined Cycle (IGCC). The gas turbine is driven by firing a gas fuel derived from the gasification of liquid and solid carbonaceous materials, such as coal and biomass, the cycle is known as an Integrated Gasification Combined Cycle (IGCC). IGCC's are able to convert liquid and solid fuels to electricity at high efficiencies and with low emissions. In this cycle, carbon monoxide from the synthetic gas with the help of air can be converted into CO2 , which will then be captured and sequestered into underground and ocean storages to reduce greenhouse gas. Combined Heat and Power (CHP) plant is one in which there is simultaneous generation of usable heat and power (usually electricity) in a single process. The basic elements comprise one or more prime movers usually driving electricity generators, where the steam or hot water generated in the process may be utilized via heat recovery equipment for a variety of purposes, including industrial processes, community heating, and space heating. The direct use of heat which might otherwise be wasted (or which would otherwise have to be provided from some alternative fuel use) means that CHP units can offer greater conversion efficiency than simple electricity generators.
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Power Generation from Biomass. Biomass fuels range from wood by-products, sugar cane and other agricultural residues to domestic/industrial wastes. The major driving force that led to the development of fluidized-bed combustion was the need for more efficient combustion technologies for the utilization of low-grade fuels such as biomass. Both Bubbling Fluidized-Bed (BFB) and Circulating Fluidized-Bed (CFB) technologies have both received significant attention. Biomass IGCC
power plant technology is an advanced power generation technology for large-scale gasification in the range of 30-100 MWe. Although fully demonstrated plant, which has achieved higher efficiencies and lower emissions than conventional technologies, biomass IGCC can not compete at present with natural gas combined cycles and low-cost conventional CFBs. Furthermore, a secured fuel supply for a biomass IGCC plant over its lifetime is questionable.
Fuel Cells. The fuel cell converts fuel into electricity electrochemically, without first burning it to produce heat. Fuel cells have attractive features for electricity markets characterized by increasing competition and environmental regulations: high thermodynamic efficiency (40-60%), because fuel cells convert chemical energy directly to electrical energy and not involve conversion of heat to mechanical energy., low maintenance requirements, quiet operation, near-zero air pollutant emissions without exhaust-gas controls, and high reliability. Fuel cells are likely to be economically viable even in small-scale applications. Its properties make it possible to site systems in small, unobtrusive generating facilities close to end users. Such distributed power sources make cogeneration designs economically attractive and offer the potential of reducing losses for electricity transmission and distribution equipment. Lowtemperature phosphoric acid fuel cells (PAFCs) and proton exchange membrane fuel cells (PEMCs) are well suited for combined heat and power applications in small-to medium-scale commercial and residential buildings, providing domestic hot water and space heating and cooling. PEMC has high power density, fast variable power output so that it is appropriate to automotive. The PAFC is the only commercial fuel cell. Several hundred PAFC power plants (~200 kWe natural gas fuelled units) are operating. Plug Power is focusing on smaller (less than 35-kilowatt-electric) units and plans to install in residential. In initial applications it is expected that most systems would use mainly existing natural gas infrastructure and, like PAFCs, process natural gas at the point of use in an external fuel processor into an H2-rich gas the fuel cell can use. High-temperature (600 -1000oC) molten carbonate fuel cells (MCFCs) and solid-oxide fuel cells (SOFCs) are targeted to medium- to large-scale industrial applications. They are well suited for cogeneration, including applications that use the waste heat to operate heat-driven air conditioners. They also offer the option of using directly natural gas or syngas derived through gasification from coal or other feedstocks without an external fuel processor. Comparison of fuel cell technology by type are illustrated in the following table.
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Type of Fuel Cell Characteristics
Polymer Electrolyte Membrane Fuel Cell
Phosphoric Acid Fuel Cell
Molten Carbonate Fuel Cell
(PEMC)
(PAFC)
(MCFC)
Solid Oxide Fuel Cell (SOFC)
Electrolyte Ion Exchange
Membrane
Phosphoric Acid Alkali Carbonates
Mixture
Yutria Stabilized
Fuel
H2
H2
H2, CO, HC’s
H2, CO, HC’s
Operating o Temperature, C
80
200
650
1,000
Charge Carrier
H
+
CO3
Cathode Reaction Anode Reaction
+
H +
½O2+2H +2e Æ H2O H2 Æ 2H++2e
+
½O2+2H +2e Æ H2O H2 Æ 2H++2e
2-
O2 -
O2+2CO+4e Æ 2CO32O2+2CO2+4e- Æ 2CO32-
O2+4e- Æ 2O2-
2CO+2CO32- Æ 4 CO2+4e-
2CO+2O2- Æ 2 CO2+4e-
2H2+2CO32 Æ 2H2O+2 CO2+4e-
O2+4e- Æ 2O22H2+2O2- Æ 2 H2O +4e-
Electrolyte State
Solid
Immobilized liquid
Immobilized liquid
Solid
Material of cell
Carbon or Metal Based
Graphite Based
Stainless Steel
Ceramic
Catalyst
Platinum
Platinum
Nickel
Perovskites
Heat Generation
None
Low Quality
High
High
Efficiency, %LHV
<40
40-45
50-60
50-60
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ECONOMICS OF ENERGY ALTERNATIVE
X. ECONOMICS OF ALTERNATIVE FUELS AND ELECTRICITY GENERATION
PENGKAJIAN ENERGI UNIVERSITAS INDONESIA
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The Economics of Alternative Fuels and Electricity Generation Synthetic Liquid Fuels Liquid synthetic fuels are fuels obtained by natural gas conversions called gas to liquids (GTL), by coal conversion called coal to liquids (CTL), or by biomass conversions called biomass to liquids (BTL). In principle, liquid synthetic fuels can be produced by two processes, i.e. indirect liquefaction through a stage involving synthetic gas (mixture of hydrogen and carbon monoxide) and direct liquefaction. The indirect liquefaction process starts from reforming reactions in gasification to produce synthetic gas, followed by Fischer-Tropsch (FT) which produces synthetic crude. The next stage involves upgrading of synthetic crude to synthetic fuels especially synthetic diesel fuels known as FT diesel fuels and other side products such as liquefied petroleum gas (LPG), kerosene and naphta. FT diesel fuels have some advantages compared to oil-based diesel fuels i.e. low sulfur content (< 5ppm), low aromatic content (<1%), high centane number (~70), biodegradable and non toxic. The liquid synthetic fuels can be produced without significant infrastructure modification of oil-based diesel fuels. Their combustion emissions are lower than those from fossil fuels (ultraclean fuels). Direct coal liquefaction used for the production of the liquid synthetic fuels proceeds by reacting coal and a solvent with hydrogen gas at high pressure and temperature to produce coal liquid. The following stages of the liquefaction are similar to those in the indirect liquefaction. Even though its efficiency is high, the quality of the products of the direct liquefaction is lower than that obtained by the indirect liquefaction. GTL technology is already proven and has achieved commercial stage. More than 950 million barrel synthetic fuel via FT process has been marketed through the entire world. GTL plant in commercial scale with capacity 45,000 bpd has been operated since 1991 in Mossel Bay, South Africa by PetroSA using Sasol license, and Shell in Bintulu Malaysia, Shell Middle Distillate Synthesis (SMDS) with capacity 12,500 has been operated since 1993. More than 800,000 bpd of GTL plants just under EPC or on planning stage in Qatar (Sasol, Chevron, ExxonMobil, Shell, and ConocoPhilips) involving about US $ 25 billion investment. GTL refinery Oryx I in Qatar has capacity 34,000 bpd and operate on June 2006, meanwhile Escravos GTL Nigeria has capacity 34,000 bpd will start to operate on 2008. The economic aspect of GTL and CTL projects is affected primarily by capital cost of plant which is relatively more expensive than that of oil refinery and feedstock price. As an illustration, GTL project Oryx I in Qatar needs investment cost about US $ 0.95 billion for refinery capacity of 34,000 bpd or about US $ 28,000/bpd. CTL refinery with capacity 80,000 bpd in China needs investment for US $ 3 billion or US $ 37,500/bpd. However, petroleum refinery (PR) needs about US $ 12,000 to 16,000/bpd. BTL refinery is also still expensive requiring about US $ 90,000/bpd. The most expensive components in GTL and CTL refinery capital cost are synthesis gas production unit and FT reactor, so further effort should be directed on cost reduction of these units.
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By using simple calculation (Figure 10.1) with assumption that US $ 1 equals to Rp 9,000,-, synthetic fuel distribution cost may be just 15% of petroleum fuels production cost. With tax of about 15%, then it can be estimated that for gas price of US $ 2-3.5/mmbtu (equal to US $ 20-35/barrel), the GTL fuel cost will be approximately Rp 2,700-3,700 per liter. By utilizing lignite worth about US $ 10-20/ton (equals to US $ 4-8/barrel) for producing synthetic fuels, the price of CTL synthetic fuels is about Rp 2,600-2,900 per liter. As the crude oil cost around US $ 30-50/barrel, petroleum fuel price is estimated to be around Rp 2,900-4,200 per liter.
80 70
US$/lb
60 50 40 30 20 10 0 PR30
PR50
Feedstocks
GTL20 Capex
GTL35 Opex
CTL4 Dist. Cost
CTL8 Taxes
Note: PR stands for petroleum refinery Source: Sasol, IFP, Foster Wheeler (data further processed)
Figure 10.1 Production cost of synthetic fuels
Liquid Biofuels Biofuels currently used in industrialized countries is 1st generation biodiesel produced from rapeseed and sunflower, and bioethanol from starches. They have a typical feature that their costs comprise mainly biomass feedstock costs, which cannot be flexibly reduced and may even increase if demands from other uses rise or in the event of adverse weather conditions. Feedstocks for current (1st generation) biofuels in developing countries are palm oil, castor, soy for biodiesels, and cassava, sorghum, molasses etc. for ethanol. They are in competition with food production, so that their economy is also affected by the development of agricultural commodities on the world market.
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Ethanol For conventional ethanol, production costs depend on feedstocks, plant investment, and operation, and also on the revenue from byproducts. The following figure shows indicative production costs of bioethanols from various feedstocks. The table shows that the lowest cost of production of ethanol is found in the production based on sugar cane and straw feedstocks.
Molasses Bioethanol surgar cane low Bioethanol surgar cane high Bioethanol surgar beet low Bioethanol surgar beet high Bioethanol corn low Bioethanol corn high Bioethanol Wheat low Bioethanol Wheat high Bioethanol straw 2010 Bioethanol straw Gasoline low Gasoline high
0
0.1
0.2
0.3
0.4
0.5
0.6
0.7
(US$/liter) Biomass cost
O & M cost
Other cost
Adopted from Girard and Fallot, 2006, except Bioethanol from molasses. The larger part of other cost is capital cost.
Figure 10.2 Comparison of bioethanol production costs
Biodiesel As for bioethanol, the largest biodiesel cost component (about 50-80%) comes from the feedstocks. Remaining are plant and operating costs. The plant size also affects the production cost. Feedstock production costs vary depending on where the crop is grown, quality of soils, climate, fertilizers and pesticides used for crop plantation.
233
Biodiesel soybean low
Biodiesel soybean high
Biodiesel jatropha
Biodiesel rapeseed low
Biodiesel rapeseed high
Biodiesel rapeseed longterm
Diesel low
Diesel high 0
0.1
0.2
0.3
0.4
0.5
0.6
0.7
0.8
0.9
US$/liter Biomass cost
O & M cost
Other cost
Adopted from Girard and Fallot, 2005. The larger part of other cost is capital cost. Longterm cost of biodiesel is an estimate on the basis of better use of co-products.
Figure 10.3 Comparison of biodiesel production costs
Electricity Generation Cost breakdown estimation of electricity generations based on chiefly renewable technology can be summarized in the following table. It consists of specific investment cost, fixed operational and maintenance cost, variable operational and maintenance cost, efficiency, and capacity factor.
234
Table 10.1 Typical cost breakdown of electricity generation Investment cost ($/kWe)
Fixed O&M ($/kWe)
Variable O&M ($/kWh)
Wind onshore large
810
25
n.a.
0.24
Wind onshore small Wind offshore PV off-grid PV grid-connected Solar thermal power
900 1620 10000 4860 2160
22 42.75 45 18 27
n.a. n.a. n.a. n.a. n.a.
0.24 0.375 0.2 0.15 0.25
Fission: light water reactor Mini hydro Large hydro Tidal power Geothermal
2070 1260 1850 2000 1200
45 28 30 37.5 30
n.a.
0.33
0.85 0.466 0.392 0.23 0.7
3000
14.5
0.0055
0.5
0.9
1180 800
35
0.005
0.63 0.3
0.75 0.9
510
10
0.002
0.55
0.8
1315
28
0.008
0.43
0.8
7000
67
0.01
0.25
0.75
1600 1900
43
0.002 0.015
0.38 0.35
0.75 0.75
Proton exchange membrane fuel cells Natural gas solid oxide fuel cells Micro gas turbine Gas combined cycle (CC) Integrated gasification combined cycle (IGCC) Solid waste incineration Biomass fired conventional Biomass IGCC
Efficiency
Capacity factor
Source: Smekens et al, 2003.
The table demonstrates that a gas combined cycle requires the lowest investment cost/kWe as well as lowest operating cost. The cycle may be prepared by burning natural gas, fossil fuels and coals. However, a combined cycle which is integrated with gasification (IGCC) will increase both investment and operating costs. The costs will even higher if gasification utilizes biomass as feedstocks. Renewable energy in general requires relatively high investment cost and moderate operating cost. Among various renewable energy types, wind energy onshore is estimated to have lowest investment cost. Photovoltaic, fuel cell and light water fission are still considered to be expensive due to high investment cost associated with these types of electricity generation.
235
236
ENERGY REGULATION XI. ENERGY REGULATIONS
PENGKAJIAN ENERGI UNIVERSITAS INDONESIA
237
238
ENERGY REGULATIONS Figure 11.1
Oil and Gas Regulation Hierarchical Tree Structure
239
Figure 11.1
Oil and Gas Regulation Hierarchical Tree Structure (Continued)
Translated from that of Indonesian version available in www.esdm.go.id
240
Figure 11.2 Electricity Regulation Hierarchical Tree Structure
Translated from that of Indonesian version available in www.esdm.go.id
Note : This Electricity Law was overturned by the Indonesian Constitutional Court in 2004, and currently under reviewed by the Government of Indonesia.
241
Figure 11.3 Geothermal Energy Regulation Hierarchical Tree Structure
Translated from that of Indonesian version available in www.esdm.go.id
242
ENERGY CONSERVATION
XII. ENERGY CONSERVATION
PENGKAJIAN ENERGI UNIVERSITAS INDONESIA
243
244
Energy Conservation With the tendency of continuing increase in energy prices and stringent environmental regulations, many governments have encouraged the implementation of energy conservation measures, which also known as measures concerning the rational use of energy. The first oil crisis in 1973 has triggered Japan and European countries to launch energy conservation initiatives. On the supply side, the diversification of energy sources has been pushed forward by switching to alternative energies such as natural gas, nuclear power or renewable energy. On the demand side, on the other hand, the industrial sector is playing a central role in terms of energy conservation. In the meantime, concern on global warming has encouraged developed nations at the rd
3 Session of the Conference of the Parties in Kyoto 1997 to cut their Green House Gas (GHG) emissions. This agreement also known as Kyoto protocol boosted further effort of energy conservation. This is not surprising since more than 90% of GHG consists of carbon dioxide and approximately 90% of carbon dioxide is emitted from combustion of fossil fuels. That means nearly 80 percent of GHG emissions originates from energy use.
On the basis of this
reasoning, improvement in energy efficiency by energy conservation program can solve energy and environmental problems simultaneously. As part of the Kyoto protocol, Japan for example, pledged a 6% reduction in greenhouse gas emission from the 1990 level, to be achieved in terms of the average annual value for the 2008-2012. As a result, the Long-term Energy Supply-Demand Outlook was reviewed and revised aiming to attain the GHG emission reduction target committed to Kyoto protocol as illustrated in Figure 11.1.
In the case of Business as Usual (BAU), energy
consumption and the emission of greenhouse gas in 2010 will increase respectively to 456million kL of crude oil equivalent and to 347 million carbon tons as CO2. To attain Japan’s target of the Kyoto protocol commitment, it would need not only to maintain the energy consumption in 2010 at 400 million kL, which means reducing it by 56 million kL through energy conservation, but also to introduce more active energy supply measures with lower CO2 emissions, including new and non-fossil fuel energy technologies.
245
Source: Japan Energy Conservation Handbook 2003/2004, ECCJ, 2003. Figure 11.1 GHG emission reduction target committed to Kyoto protocol.
As mentioned above, since the first oil crisis in 1973, many industrialized nations have launched energy conservation initiatives. In Japan, the Law concerning the Rational Use of Energy (Energy Conservation Law) was adopted in 1979, thus energy consumption efficiency standards for vehicles, air conditioners, and electric refrigerators were set for the first time. Some Asian countries also adopted energy conservation law, for example South Korea and Thailand. The increase of oil price recently and in years to come (Figure 11.2) is expected to affect many countries to once again consider wide range policy to promote energy conservation activities. Compare to industrialized countries, many ASEAN countries including Indonesia consume less energy per capita, but have higher energy intensity (Figure 11.3).
246
Figure 11.2 Oil price between 1973 to 2005
600
indeks (Japan = 100)
500 400 300 200 100 0 Japan Energy Insensity
OECD
Thailand Indonesia Malaysia
Energy per Capita
North America
German
Source : National Energy Blueprint 2005-2025 (Blue Print PEN 2005-2025) Figure 11.3 Energy intensity and energy consumption in ASEAN and some developed countries
247
In general, energy conservation potential of industry, transportation, household and commercial sectors in Indonesia is quite high. Table 11.1 shows that energy efficiency improvement of 15 to 30 % is achievable for typical for various sectors in Indonesia.
Table 11.1 Energy Conservation Potential in Indonesia
Sector
Total Consumption
Energy Conservation Potential
(Thousand BOE)
(Thousand BOE)
(%)
Industry
194.35
29.15 -58.31
15 - 30
Transportation
169.73
42.43
25
Household and Commercial
134.63
13.46 – 40.39
10 – 30
Source : DGEEU, 2006
In Indonesia the first regulation regarding the energy conservation program was introduced in 1982, as a response to high oil price at that time. The related regulations for energy conservation can be summarized as follows. •
Presidential Instruction No. 9/1982 concerning the Reporting System of Energy Use in Government-office Buildings,
•
Presidential Decree No. 43/1991 concerning the Energy Conservation,
•
Minister of Mines and Energy Decree acting as BAKOREN Chief No. 100.K/148/M.PE/ 1995 concerning National Master Plan of Energy Conservation,
•
Minister of Energy and Mineral Resources Decree No. 2/2004 concerning the Policy on Renewable Energy Development and Energy Conservation (Green Energy),
•
Minister of Energy and Mineral Resources Decree No. 0983.K/16/MEM /2004 concerning National Energy Policy.
•
Presidential Instruction No. 10 / 2005 concerning Efficient Use of Energy.
•
Ministerial Regulation No. 0031/2005 on Energy Ministerial Regulation No. 0031/2005 on Energy Conservation Procedure
•
Presidential Decree No.5/2006 on National Energy Presidential Decree No.5/2006 on National Energy Policy.
248
To encourage the implementation of energy conservation efforts in buildings, several National Standards (SNI) have been introduced, for example: -
SNI 03-6389-2000 : Energy Conservation on Building Envelope
-
SNI 03-6390-2000 : Energy Conservation on Air Conditioning System for Building
-
SNI 03-6196-2000 : Energy Audit Procedure for Building
-
SNI 03-6197-2000 : Energy Conservation on Lighting System for Building.
Effects of energy conservation in Indonesia’s primary energy demand, is estimated in National Energy Blueprint 2005-2025. As shown in Fig. 11.4, without energy conservation effort Indonesia’s primary energy demand in 2025 is expected to reach fivefold of the 2005 level. A nation wide policy and strong commitment to implement energy conservation in all sectors is pre-requisite in reducing primary energy demand to threefold as encouraged under energy conservation scenario. As stated earlier, energy conservation measures have to objectives, (i)
Energy demand (Million BOE )
to reduces energy demand and (ii) to meet greenhouse gas emission target.
Year
------
Year
Business as as Usual Usual Business
Withenergy energy conservation With conservationscenario scenario
Source : National Energy Blueprint 2005-2025 (Blue Print PEN 2005-2025) Figure 11.4 Prediction of energy conservation measures on Indonesia’s primary energy demand.
249
250
APPENDICES
PENGKAJIAN ENERGI UNIVERSITAS INDONESIA
251
252
APPENDICES A1. Gross Energy Content
Gas - Natural Gas
37.23
MJ/m3 (*)
- Ethane (liquid)
18.36
GJ/ m3
- 70 % ethane – 30 % propane
3.308
Million Btu/Barrel
- Propane (liquid)
25.53
GJ/ m3
- 60 % butane – 40 % propane
4.130
Million Btu/Barrel
- Butanes (liquid)
28.62
GJ/ m3
- Isobutane
3.974
Million Btu/Barrel
- Pentanes Plus
35.17
GJ/ m3
- LPG
4.0
Million Btu/Barrel
3.7
Million Btu/Barrel
Crude Oil - Light
38.51
GJ/ m3
- Heavy
40.90
GJ/ m3
- Anthracite
29.30
GJ/metric ton
- Imported Coal
25.10
GJ/metric ton
- Kalimantan Coal
25.10
GJ/metric ton
- Ombilin Coal
28.40
GJ/metric ton
Coal
- Tanjung Enim Coal
22.20
GJ/metric ton
- Lignite
18.10
GJ/metric ton
- Aviation Gasoline
32.60
GJ/ m3
- Gasoline Super
34.20
GJ/ m3
- Gasoline Premium
34.20
GJ/ m3
- Aviation Turbo Fuel
34.60
GJ/ m3
- Kerosene
34.80
GJ/ m3
- ADO
38.10
GJ/ m
- IDO
38.80
GJ/ m3
- Light Fuel Oil
38.68
GJ/ m3
- Heavy Fuel Oil
41.73
GJ/ m3
- Petroleum Coke
42.38
GJ/ m3
Petroleum Products
3
- Gasohol (10% ethanol, 90% gasoline)
120,900
Btu/gallon
- Middle Distillate or Diesel Fuel Oil
138,690
Btu/gallon
- Residual Fuel Oil
149,690
Btu/gallon
253
Ethanol
84,400
Btu/gallon
Methanol
62,800
Btu/gallon
Biofuel Wood (wet, freshly cut)
10.9
MJ/kg
Wood (air dry, humid zone)
15.5
MJ/kg
Wood (air dry, dry zone)
16.6
MJ/kg
Wood (oven dry)
20.0
MJ/kg
Charcoal
29.0
MJ/kg
8.2
MJ/kg
Bagasse (air dry)
16.2
MJ/kg
Coffee husks
16.0
MJ/kg
Rice hulls (air dry)
14.4
MJ/kg
Wheat straw
15.2
MJ/kg
Corn (stalk)
14.7
MJ/kg
Corn (cobs)
15.4
MJ/kg
Cotton stalk
16.4
MJ/kg
9.8
MJ/kg
Bagasse (wet)
Coconut husks Coconut shells
17.9
MJ/kg
Chaff (Seed Casing)
14.6
MJ/kg
Pyrolysis oil
17.5
MJ/kg
28.4
MJ/kg
37.665
MJ/kg
37.8
MJ/kg
39.49
MJ/kg
39.5
MJ/kg
39.25-39.25
MJ/kg
10
MJ/kg
Ecalene
MT
Fat Biodiesel Sunflower oil Castor Oil Olive Oil Animal Manure/Waste
Electricity
3,413
Btu/kilowatt-hour
Note : The (*) energy content of 37.23 MJ/m3 approximately the equivalent of 1,000 BTU/ft3 in the imperial system. The actual energy content will vary depending on the amount of natural gas liquids (mostly ethane) contained in the gas.
254
A.2 Conversion Factor
Type of Energy
From
To Barrel Oil Equivalent/ BOE
Refinery Fuels Refenery Feedstock Refinery Fuel Gas (RFG) Refinery Fuel Oil (RFO)
Barrel Barrel Barrel
1.0423 1.6728 1.1236
Petroleum Products ADO Aviation Gasoil (avgas) Aviation Turbin Gas (avtur) Fuel Oil (FO) Industrial Diesel Oil (IDO) Kerosene Premium Premix Super Tt
Kilo Liter Kilo Liter Kilo Liter Kilo Liter Kilo Liter Kilo Liter Kilo Liter Kilo Liter Kilo Liter
6.4871 5.5530 5.8907 6.9612 6.6078 5.9274 5.8275 5.8275 5.8275
Coal Antrasit Import Coal Ombilin Coal Tanjung Enim Coal Briqutte Riau Peat Lignit
Ton Ton Ton Ton Ton Ton Ton
4.9893 4.2766 4.8452 3.7778 3.5638 2.5452 3.0649
Biomass Charcoal Woods
Ton Ton
4.9713 2.2979
Crude Oil, Condensate, and Products Condensate Crude Oil Products
Barrel Barrel Barrel
0.9545 1.0000 1.0200
Geothermal
MWh
1.5937
Natural Gas and Products Natural Gas CNG City Gas LNG LNG LPG
Thousand SCF Thousand KCal Thousand KCal MMBTU Ton Ton
0.1796 0.0007 0.0007 0.1796 8.0532 8.5246
Hydropower
MWh
1.5937
Electricity
MWh
0.6130
255
Crude Oil From
ton (metric)
To
kilolitres
barrels
US Gallon
ton/year
Multiply by
ton (metric)
1
1.165
7.33
307.86
--
kilolitres
0.8581
1
6.2898
264.17
--
barrels
0.1364
0.159
1
42
--
0.00325
0.0038
0.0238
1
--
--
--
--
--
49.8
US Gallon Barrels/day
Natural Gas and LNG From
To
Billion cubic meters NG
Billion cubic feet NG
Million ton oil equivalent
Million ton LNG
Trillion British thermal units
Million barrels oil equivalent
Multiply by 1 billion cubic meters NG
1
35.3
0.90
0.73
36
6.29
1 billion cubic feet NG
0.028
1
0.026
0.021
1.03
0.18
1 million ton oil equivalent
1.111
39.2
1
0.805
40.4
7.33
1.38
48.7
1.23
1
52.0
8.68
0.028
0.98
0.025
0.02
1
0.17
0.16
5.61
0.14
0.12
5.8
1
1 million ton LNG 1 trillion British thermal units 1 million barrels oil equivalent
Products barrels to ton
ton to barrels
LPG
0.086
11.6
0.542
1.844
Gasoline
0.118
8.5
0.740
1.351
Kerosene
0.128
7.8
0.806
1.240
Gas Oil/ Diesel
0.133
7.5
0.839
1.192
Fuel Oil
0.149
6.7
0.939
1.065
To Convert
From
3
Kilo :
Million
6
: 10
Mega :
M
Billion
: 109
Giga :
G
Trillion
: 10
12
Tera :
T
Quadrillion
: 1015
Peta :
P
Quintillion
: 1018
Exa :
E
: 10
ton to kilolitres
Multiply by
PREFIX Thousand
kilolitres to ton
K
UNIT 1 metric tons = 2204.62 lb = 1.1023 short tons 1 kilolitre = 6.2898 barrels = 1 cubic meters 1 kilocalorie (kcal) = 4.187 kJ = 3.968 BTU 1 kilo joule (kJ) = 0.239 kcal = 0.948 BTU 1 British Thermal Unit (BTU) = 0.252 kcal = 1.055 kJ 1 kWh = 860 kcal = 3,600 kJ = 3,412 BTU
256
A3. Glossary ADO: Automation Diesel Oil. Anthracite: The highest rank of coal; used primarily for residential and commercial space heating. It is a hard, brittle, and black lustrous coal, often referred to as hard coal, containing a high percentage of fixed carbon and a low percentage of volatile matter. The moisture content of fresh-mined anthracite generally is less than 15 percent. The heat content of anthracite ranges from 22 to 28 million Btu per ton on a moist, mineral-matter-free basis. This fuel typically has a heat content of 15 million Btu per ton or less. API Gravity: An arbitrary scale expressing the gravity or density of liquid petroleum products. The measuring scale is calibrated in terms of degrees API. A lighter, less dense product has a higher API gravity. API: The American Petroleum Institute. APPI: Asia Pacific Petroleum Index Ash: The non-combustible residue of a combusted substance composed primarily of alkali and metal oxides. Asphalt: A dark brown-to-black cement-like material obtained by petroleum processing and containing bitumens as the predominant component; used primarily for road construction. It includes crude asphalt as well as the following finished products: cements, fluxes, the asphalt content of emulsions (exclusive of water), and petroleum distillates blended with asphalt to make cutback asphalts. Note: The conversion factor for asphalt is 5.5 barrels per short ton Aviation Gasoline (Avgas) : A complex mixture of relatively volatile hydrocarbons with or without small quantities of additives, blended to form a fuel suitable for use in aviation reciprocating engines. Fuel specifications are provided in ASTM Specification D910 and Military Specification MIL-G-5572. Aviation Turbine Fuel (Avtur): Aviation Turbine fuel used by turboprops and jet aircraft. BAPPEDA: Badan Perencanaan Pembangunan Daerah (Bureau of Local Development Planning) BAPPENAS: Badan Perencanaan Pembangunan Nasional (Bureau of National Development Planning) Barrel: A unit of volume equal to 42 U.S. gallons. Biodiesel: Any liquid biofuel suitable as a diesel fuel substitute or diesel fuel additive or extender. Biodiesel fuels are typically made from oils such as soybeans, rapeseed, or sunflowers, or from animal tallow. Biodiesel can also be made from hydrocarbons derived from agricultural products such as rice hulls. Biofuels: Liquid fuels and blending components produced from biomass (plant) feedstocks, used primarily for transportation. Biomass: Organic nonfossil material of biological origin constituting a renewable energy source. Bituminous coal: A dense coal, usually black, sometimes dark brown, often with well-defined bands of bright and dull material, used primarily as fuel in steam-electric power generation, with substantial quantities also used for heat and power applications in manufacturing and to make coke. Its moisture content usually is less than 20 percent. The heat content of bituminous coal ranges from 21 to 30 million Btu per short ton of a moist, mineral-matter-free basis. BMG: Badan Meteorologi dan Geofisika (Agency for Meteorology and Geophysics.
257
BOE: barrels of oil equivalent. BPPT: Badan Pengkajian dan Penerapan Teknologi (Agency for Assessment and Applications of Technology) BPS: Biro Pusat Statistik (Bureau of Statistics) British thermal unit (BTU): The quantity of heat required to raise the temperature of 1 pound of liquid water by 1 degree Fahrenheit at the temperature at which water has its greatest density (approximately 39 degrees Fahrenheit). Capacity Factor:
∑ kWh of annual gross electric production x 100% ∑ kW of installed capacity x 8,760 hour
kWh of gross electric production is kWh (energy) generated before subtracted by own-use energy. Charcoal: A material formed from the incomplete combustion or destructive distillation (carbonization) of organic material in a kiln or retort, and having a high energy density, being nearly pure carbon. (If produced from coal, it is coke.) Used for cooking, the manufacture of gunpowder and steel (notably in Brazil), as an absorbent and decolorizing agent, and in sugar refining and solvent recovery. CIF (cost, insurance, freight): A type of sale in which the buyer of the product agrees to pay a unit price that includes the f.o.b. value of the product at the point of origin, plus all costs of insurance and transportation. This type of transaction differs from a “delivered” purchase in that the buyer accepts the quantity as determined at the loading port rather than pay on the basis of the quantity and quality ascertained at the unloading port. It is similar to the terms of an F.O.B. sale, except that the seller, as a service for which he is compensated, arranges for transportation and insurance. Coal briquets: Anthracite, bituminous, and lignite briquets comprise the secondary solid fuels manufactured from coal by a process in which the coal is partly dried, warmed to expel excess moisture, and then compressed into briquets, usually without the use of a binding substance. In the reduction of briquets to coal equivalent, different conversion factors are applied according to their origin from hard coal, peat, brown coal, or lignite. Coal: A readily combustible black or brownish-black rock whose composition, including inherent moisture, consists of more than 50 percent by weight and more than 70 percent by volume of carbonaceous material. It is formed from plant remains that have been compacted, hardened, chemically altered, and metamorphosed by heat and pressure over geologic time. Coke (coal): A solid carbonaceous residue derived from low-ash, low-sulfur bituminous coal from which the volatile constituents are driven off by baking in an oven at temperatures as high as 2,000 degrees Fahrenheit so that the fixed carbon and residual ash are fused together. Coke is used as a fuel and as a reducing agent in smelting iron ore in a blast furnace. Coke from coal is grey, hard, and porous and has a heating value of 24.8 million Btu per ton. Coke (petroleum): A residue high in carbon content and low in hydrogen that is the final product of thermal decomposition in the condensation process in cracking. This product is reported as marketable coke or catalyst coke. The conversion is 5 barrels (of 42 U.S. gallons each) per short ton. Coke from petroleum has a heating value of 6.024 million Btu per barrel. Combined cycle: An electric generating technology in which electricity is produced from otherwise lost waste heat exiting from one or more gas (combustion) turbines. The exiting heat is routed to a conventional boiler or to a heat recovery steam generator for utilization by a steam turbine in the production of electricity. This process increases the efficiency of the electric generating unit. Commercial Sector: Business establishments that are not engaged in transportation or in manufacturing or other types of industrial activity (agriculture, mining, or construction). Commercial establishments include hotels, motels, restaurants, wholesale businesses, retail
258
stores, laundries, and other service enterprises; religious and nonprofit organizations; health, social, and educational institutions; Compressed natural gas (CNG): Natural gas which is comprised primarily of methane, compressed to a pressure at or above 2,400 pounds per square inch and stored in special highpressure containers. It is used as a fuel for natural gas powered vehicles. Condensate: A mixture consisting primarily of pentanes and heavier hydrocarbons which is recovered as a liquid from natural gas in lease or field separation facilities. Note: This category excludes natural gas liquids, such as butane and propane, which are recovered at natural gas processing plants or facilities. Consumer Price Index (CPI): These prices are collected in 85 urban areas selected to represent all urban consumers about 80 percent of the total U.S. population. The service stations are selected initially and on a replacement basis, in such a way that they represent the purchasing habits of the CPI population. Service stations in the current sample include those providing all types of service (i.e., full, mini, and self service). Cord of wood: A cord of wood measures 4 feet by 4 feet by 8 feet, or 128 cubic feet. Crop residue: Organic residue remaining after the harvesting and processing of a crop. Crude Oil: A mixture of hydrocarbons that exists in liquid phase in natural underground reservoirs and remains liquid at atmospheric pressure after passing through surface separating facilities. Crude oil may also include: 1. Small amounts of hydrocarbons that exist in the gaseous phase in natural underground reservoirs but are liquid at atmospheric pressure after being recovered from oil well (casing head) gas in lease separators and that subsequently are commingled with the crude stream without being separately measured. 2. Small amounts of non hydrocarbons produced with the oil, such as sulfur and other compounds. Some products and other materials are either mixed with the crude oil and cannot be separately measured or they are logically associated with crude oil for accounting purposes. Cubic foot (cf), natural gas: The amount of natural gas contained at standard temperature and pressure (60 degrees Fahrenheit and 14.73 pounds standard per square inch) in a cube whose edges are one foot long. Cull wood: Wood logs, chips, or wood products that are burned. DCO: Diluted Crude Oil Demand Factor:
∑ kW at peakload x 100 % ∑ kVA of connected power x cosϕ cos ϕ = 0.8
DESDM: Departemen Energi dan Sumber Daya Mineral (Ministry of Energy and Mineral Resources) DFO: Diesel Fuel Oil Diesel fuel: A fuel composed of distillates obtained in petroleum refining operation or blends of such distillates with residual oil used in motor vehicles. The boiling point and specific gravity are higher for diesel fuels than for gasoline. DPK: Dual Purpose Kerosene DPPU: Depo Pengisian Bahan Bakar Pesawat Udara (Airplane Fuel Filling Depo) Dry natural gas: Natural gas which remains after: 1) the liquefiable hydrocarbon portion has been removed from the gas stream (i.e., gas after lease, field, and/or plant separation); and 2) any volumes of nonhydrocarbon gases have been removed where they occur in sufficient quantity to render the gas unmarketable. Dry natural gas is also known as consumer-grade natural gas. The parameters for measurement are cubic feet at 60 degrees Fahrenheit and
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14.73 pounds per square inch absolute. Electricity Grid: A common term referring to an electricity transmission and distribution system. Electricity: A form of energy characterized by the presence and motion of elementary charged particles generated by friction, induction, or chemical change. Energy consumption: The use of energy as a source of heat or power or as a raw material input to a manufacturing process. Energy End-Use Sectors: Major energy consuming sectors of the economy. The Commercial Sector includes commercial buildings and private companies. The Industrial Sector includes manufacturers and processors. The Residential Sector includes private homes. The Transportation Sector includes automobiles, trucks, rail, ships, and aircraft. Energy Intensity: Energy consumption per GDP Energy: The capacity for doing work as measured by the capability of doing work (potential energy) or the conversion of this capability to motion (kinetic energy). Energy has several forms, some of which are easily convertible and can be changed to another form useful for work. Most of the world's convertible energy comes from fossil fuels that are burned to produce heat that is then used as a transfer medium to mechanical or other means in order to accomplish tasks. Electrical energy is usually measured in kilowatthours, while heat energy is usually measured in British thermal units. Ethanol (CH3-CH2OH): A clear, colorless, flammable oxygenated hydrocarbon. Ethanol is typically produced chemically from ethylene, or biologically from fermentation of various sugars from carbohydrates found in agricultural crops and cellulosic residues from crops or wood. It is used in the United States as a gasoline octane enhancer and oxygenate (blended up to 10 percent concentration). Ethanol can also be used in high concentrations (E85) in vehicles designed for its use. Expenditure: The incurrence of a liability to obtain an asset or service. Flare: Gas disposed of by burning in flares usually at the production sites or at gas processing plants. Fossil fuel: An energy source formed in the earths crust from decayed organic material. The common fossil fuels are petroleum, coal, and natural gas. Free on board (f.o.b.): A sales transaction in which the seller makes the product available for pick up at a specified port or terminal at a specified price and the buyer pays for the subsequent transportation and insurance. Fuel oil: A liquid petroleum product less volatile than gasoline, used as an energy source. Fuel oil includes distillate fuel oil (No. 1, No. 2, and No. 4), and residual fuel oil (No. 5 and No. 6). Gallon: A volumetric measure equal to 4 quarts (231 cubic inches) used to measure fuel oil. One barrel equals 42 gallons. Gas oil: European and Asian designation for No. 2 heating oil and No. 2 diesel fuel. Gas turbine plant: A plant in which the prime mover is a gas turbine. A gas turbine consists typically of an axial-flow air compressor and one or more combustion chambers where liquid or gaseous fuel is burned and the hot gases are passed to the turbine and where the hot gases expand drive the generator and are then used to run the compressor. Gas: A non-solid, non-liquid combustible energy source that includes natural gas, coke-oven gas, blast-furnace gas, and refinery gas. Gasohol: A registered trademark of an agency of the state of Nebraska, for an automotive fuel containing a blend of 10 percent ethanol and 90 percent gasoline. Gasoline: A refined petroleum product suitable for use as a fuel in internal combustion engines.
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Gas-Steam Power Geothermal energy: Hot water or steam extracted from geothermal reservoirs in the earth's crust. Water or steam extracted from geothermal reservoirs can be used for geothermal heat pumps, water heating, or electricity generation. Geothermal plant: A plant in which the prime mover is a steam turbine. The turbine is driven either by steam produced from hot water or by natural steam that derives its energy from heat found in rock. Gigawatt (GW): One billion watts or one thousand megawatts. Gigawatt-electric (GWe): One billion watts of electric capacity. Gigawatthour (GWh): One billion watthours. Gross Domestic Product (GDP): The total value of goods and services produced by labor and property located in Indonesia. As long as the labor and property are located in Indonesia, the supplier (that is, the workers and, for property, the owners) may be either Indonesian residents or residents of foreign countries. Heavy gas oil: Petroleum distillates with an approximate boiling range from 651degrees Fahrenheit to 1000 degrees Fahrenheit. HOMC: High Octane Motor Component Household: A family, an individual, or a group of up to nine unrelated persons occupying the same housing unit. "Occupy" means that the housing unit is the person's usual or permanent place of residence. HSD: High Speed Diesel Oil HSFO: High sulfur fuel oil Hydrocarbon: An organic chemical compound of hydrogen and carbon in the gaseous, liquid, or solid phase. The molecular structure of hydrocarbon compounds varies from the simplest (methane, a constituent of natural gas) to the very heavy and very complex. : The production of electricity from the kinetic energy of falling water. Hydroelectric power: The use of flowing water to produce electrical energy. ICP: Indonesian Crude Price IDO: Intermediate Diesel Oil IFO: industrial fuel oil Indicated Resources, Coal: Coal for which estimates of the rank, quality, and quantity are based partly on sample analyses and measurements and partly on reasonable geologic projections. Indicated resources are computed partly from specified measurements and partly from projection of visible data for a reasonable distance on the basis of geologic evidence. Industrial Sector: Manufacturing industries, which make up the largest part of the sector, along with mining, construction, agriculture, fisheries, and forestry. Establishments in this sector range from steel mills, to small farms, to companies assembling electronic components. Installed Capacity: The total capacity of electrical generation devices in a power station or system. JOB: Joint Operation Body; A form of cooperation between PERTAMINA with private companies for oil and gas exploration and exportation Joule (J): The meter-kilogram-second unit of work or energy, equal to the work done by a force of one newton when its point of application moves through a distance of one meter in the
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direction of the force; equivalent to 107 ergs and one watt-second. Kerosene: A type of heating fuel derived by refining crude oil that has a boiling range at atmospheric pressure from 400 degrees to 550 degrees F. Kilovolt-Ampere (kVa): A unit of apparent power, equal to 1,000 volt-amperes; the mathematical product of the volts and amperes in an electrical circuit. Kilowatt (kW): One thousand watts. Kilowatt-electric (kWe): One thousand watts of electric capacity. Kilowatthour (kWh): A measure of electricity defined as a unit of work or energy, measured as 1 kilowatt (1,000 watts) of power expended for 1 hour. One kWh is equivalent to 3,412 Btu. LAPAN: Lembaga Penerbangan dan Antariksa Nasional (National Space and Aeronautics Administration). Light gas oils: Liquid petroleum distillates heavier than naphtha, with an approximate boiling range from 401 degrees to 650 degrees Fahrenheit. Light oil: Lighter fuel oils distilled off during the refining process. Virtually all petroleum used in internal combustion and gas-turbine engines is light oil. Includes fuel oil numbers 1 and 2, kerosene, and jet fuel. Lignite: The lowest rank of coal, often referred to as brown coal, used almost exclusively as fuel for steam-electric power generation. It is brownish-black and has a high inherent moisture content, sometimes as high as 45 percent The heat content of lignite ranges from 9 to 17 million Btu per ton on a moist, mineral-matter-free basis. LIPI: Lembaga Ilmu Pengetahuan Indonesia (Institution of Sciences Indonesia). Liquefied natural gas (LNG): Natural gas (primarily methane) that has been liquefied by reducing its temperature to -260 degrees Fahrenheit at atmospheric pressure. Liquefied Natural Gas (LNG): Natural gas (primarily methane) that has been liquefied by reducing its temperature to -260° F at atmospheric pressure. Load (electric): The amount of electric power delivered or required at any specific point or points on a system. The requirement originates at the energy-consuming equipment of the consumers.
∑ kWh of annual total electric production Load Factor:
∑ kW at peakload x 8,70 hour
x 100%
kWh of total electric production is the sum of kWh produced by PLN and kWh purchased from outside party. Peak load is the highest load achieved within the calendar year. Load factor: The ratio of the average load to peak load during a specified time interval. LPG: Liquefied petroleum gases such as propane and butane produced at refineries or natural gas processing plants, including plants that fractionate raw natural gas plant liquids. LSDE: Lembaga Sumber Daya Energi (Center for Research on Energy Resources) LSWR: Low sulfur waxy residual fuel oil Macroeconomics: a sub-field of economics that examines the behavior of the economy as a whole, once all of the individual economic decisions of companies and industries have been summed. Economy-wide phenomena considered by macroeconomics include Gross Domestic Product (GDP) and how it is affected by changes in unemployment, national income, rate of
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growth, and price levels. Measured Resources, Coal: Coal resources for which estimates of the rank, quality, and quantity have been computed, within a margin of error of less than 20 percent, from sample analyses and measurements from closely spaced and geologically well known sample sites. Measured resources are computed from dimensions revealed in outcrops, trenches, mine workings, and drill holes. The points of observation and measurement are so closely spaced and the thickness and extent of coals are so well defined that the tonnage is judged to be accurate within 20 percent. Megavoltamperes (MVA): Millions of voltamperes, which are a measure of apparent power. Megawatt (MW): One million watts of electricity. Megawatt electric (MWe): One million watts of electric capacity. Methane: A colorless, flammable, odorless hydrocarbon gas (CH4) which is the major component of natural gas. It is also an important source of hydrogen in various industrial processes. Methane is a greenhouse gas. Methanol (CH3OH; Methyl alcohol or wood alcohol): A clear, colorless, very mobile liquid that is flammable and poisonous; used as a fuel and fuel additive, and to produce chemicals. MFA: Mega Volt Ampere MFO: Marine Fuel Oil Middle Distillate Naphtha: A generic term applied to a petroleum fraction with an approximate boiling range between 122 degrees Fahrenheit and 400 degrees Fahrenheit. Natural Gas Liquids (NGL): Those hydrocarbons in natural gas that are separated as liquids from the gas. Natural gas liquids include natural gas plant liquids (primarily ethane, propane, butane, and isobutane) and lease condensate (primarily pentanes produced from natural gas at lease separators and field facilities). Natural Gas: A hydrocarbon gas obtained from underground sources, often in association with petroleum and coal deposits. It generally contains a high percentage of methane, varying amounts of ethane, and inert gases; used as a heating fuel. Net (Lower) Heating Value (NHV): The potential energy available in a fuel as received, taking into account the energy loss in evaporating and superheating the water in the fuel. Equal to the higher heating value minus 1050W where W is the weight of the water formed from the hydrogen in the fuel, and 1050 is the latent heat of vaporization of water, in Btu, at 77 degrees Fahrenheit. Nuclear electric power (nuclear power): Electricity generated by the use of the thermal energy released from the fission of nuclear fuel in a reactor. Ocean energy systems: Energy conversion technologies that harness the energy in tides, waves, and thermal gradients in the oceans. Ocean thermal energy conversion (OTEC): The process or technologies for producing energy by harnessing the temperature differences (thermal gradients) between ocean surface waters and that of ocean depths. Warm surface water is pumped through an evaporator containing a working fluid in a closed Rankine-cycle system. The vaporized fluid drives a turbine/generator. OECD (Organization for Economic Cooperation and Development): Current members are Australia, Austria, Belgium, Canada, Czech Republic, Denmark and its territories (Faroe Islands and Greenland), Finland, France, Germany, Greece, Greenland, Hungary, Iceland, Ireland, Italy, Japan, Luxembourg, Mexico, the Netherlands, New Zealand, Norway, Poland, Portugal, South Korea, Spain, Sweden, Switzerland, Turkey, United Kingdom, and United States and its territories (Guam, Puerto Rico, and Virgin Islands).
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Oil reservoir: An underground pool of liquid consisting of hydrocarbons, sulfur, oxygen, and nitrogen trapped within a geological formation and protected from evaporation by the overlying mineral strata. Oil: A mixture of hydrocarbons usually existing in the liquid state in natural underground pools or reservoirs. Gas is often found in association with oil. OPEC (Organization of Petroleum Exporting Countries): Countries that have organized for the purpose of negotiating with oil companies on matters of oil production, prices, and future concession rights. Current members are Algeria, Indonesia, Iran, Iraq, Kuwait, Libya, Nigeria, Qatar, Saudi Arabia, United Arab Emirates, and Venezuela. P3B: Penyaluran dan Pusat Pengatur Beban Jawa Bali (Electricity Load Distribution Center Java-Bali) Panel (Solar): A term generally applied to individual solar collectors, and typically to solar photovoltaic collectors or modules. Paraffin (wax): The wax removed from paraffin distillates by chilling and pressing. When separating from solutions, it is a colorless, more or less translucent, crystalline mass, without odor and taste, slightly greasy to touch, and consisting of a mixture of solid hydrocarbons in which the paraffin series predominates Peak load: The maximum load during a specified period of time. Peat: Peat consists of partially decomposed plant debris. It is considered an early stage in the development of coal. Peat is distinguished from lignite by the presence of free cellulose and a high moisture content (exceeding 70 percent). The heat content of air-dried peat (about 50 percent moisture) is about 9 million Btu per ton. Perpres: Peraturan Presiden (Presidential Regulation). Pertamax: High octane gasoline brand produced by Pertamina. PERTAMINA: Perusahaan Pertambangan Minyak dan Gas Nasional (Oil and Gas State-Owned Company) Petroleum refinery: An installation that manufactures finished petroleum products from crude oil, unfinished oils, natural gas liquids, other hydrocarbons, and alcohol. Petroleum: A broadly defined class of liquid hydrocarbon mixtures. Included are crude oil, lease condensate, unfinished oils, refined products obtained from the processing of crude oil, and natural gas plant liquids. Note: Volumes of finished petroleum products include nonhydrocarbon compounds, such as additives and detergents, after they have been blended into the products. PGN: Perusahaan Umum Gas Negara (State Owned Gas Transmission and Distribution Company) Photovoltaic and solar thermal energy (as used at electric utilities): Energy radiated by the sun as electromagnetic waves (electromagnetic radiation) that is converted at electric utilities into electricity by means of solar (photovoltaic) cells or concentrating (focusing) collectors. Photovoltaic cell (PVC): An electronic device consisting of layers of semiconductor materials fabricated to form a junction (adjacent layers of materials with different electronic characteristics) and electrical contacts and being capable of converting incident light directly into electricity (direct current). Pipeline (natural gas): A continuous pipe conduit, complete with such equipment as valves, compressor stations, communications systems, and meters for transporting natural and/or supplemental gas from one point to another, usually from a point in or beyond the producing field or processing plant to another pipeline or to points of utilization. Also refers to a company operating such facilities. Pipeline, distribution: A pipeline that conveys gas from a transmission pipeline to its ultimate
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consumer. Pipeline, transmission: A pipeline that conveys gas from a region where it is produced to a region where it is to be distributed. PJB: Pembangkitan Jawa-Bali (electricity producer that supplies electricity needs of the people in East Java and Bali) PLTMG: Pembangkit Listrik Tenaga Micro Gas (Gas Micro scale Power Plant) PLN: Perusahaan Listrik Negara (State-Owned Electricity Company) Power (electrical): An electric measurement unit of power called a voltampere is equal to the product of 1 volt and 1 ampere. This is equivalent to 1 watt for a direct current system, and a unit of apparent power is separated into real and reactive power. Real power is the workproducing part of apparent power that measures the rate of supply of energy and is denoted as kilowatts (kW). Reactive power is the portion of apparent power that does no work and is referred to as kilovars; this type of power must be supplied to most types of magnetic equipment, such as motors, and is supplied by generator or by electrostatic equipment. Energy is denoted by the product of real power and the length of time utilized; this product is expressed as kilowathours. Power loss: The difference between electricity input and output as a result of an energy transfer between two points. Premium gasoline: Gasoline having an antiknock index (R+M/2) greater than 90. Includes both leaded premium gasoline as well as unleaded premium gasoline. Primary energy consumption: Primary energy consumption is the amount of site consumption, plus losses that occur in the generation, transmission, and distribution of energy. Primary energy: All energy consumed by end users, excluding electricity but including the energy consumed at electric utilities to generate electricity. (In estimating energy expenditures, there are no fuel-associated expenditures for hydroelectric power, geothermal energy, solar energy, or wind energy, and the quantifiable expenditures for process fuel and intermediate products are excluded.) Probable (indicated) reserves, coal: Reserves or resources for which tonnage and grade are computed partly from specific measurements, samples, or production data and partly from projection for a reasonable distance on the basis of geological evidence. The sites available are too widely or otherwise inappropriately spaced to permit the mineral bodies to be outlined completely or the grade established throughout. Probable energy reserves: Estimated quantities of energy sources that, on the basis of geologic evidence that supports projections from proved reserves, can reasonably be expected to exist and be recoverable under existing economic and operating conditions. Site information is insufficient to establish with confidence the location, quality, and grades of the energy source. Production Sharing Contract: A form of cooperation between Pertamina and private companies in accordance with Law No 44 Prp of 1960 jo Law No 8 of 1971. Propane (C3H8): A normally gaseous straight-chain hydrocarbon. It is a colorless paraffinic gas that boils at a temperature of -43.67 degrees Fahrenheit. It is extracted from natural gas or refinery gas streams. It includes all products designated in ASTM Specification D1835 and Gas Processors Association Specifications for commercial propane and HD-5 propane. Proved (measured) reserves, coal: Reserves or resources for which tonnage is computed from dimensions revealed in outcrops, trenches, workings, and drill holes and for which the grade is computed from the results of detailed sampling. The sites for inspection, sampling, and measurement are spaced so closely and the geologic character is so well defined that size, shape, and mineral content are well established. The computed tonnage and grade are judged to be accurate within limits that are stated, and no such limit is judged to be different from the computed tonnage or grade by more than 20 percent.
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Proved energy reserves: Estimated quantities of energy sources that analysis of geologic and engineering data demonstrates with reasonable certainty are recoverable under existing economic and operating conditions. The location, quantity, and grade of the energy source are usually considered to be well established in such reserves. Quad: One quadrillion Btu. (1,000,000,000,000,000 Btu) Refinery fuel: Crude oil and petroleum products consumed at the refinery for all purposes. Refinery gas: Noncondensate gas collected in petroleum refineries. Refinery: An installation that manufactures finished petroleum products from crude oil, unfinished oils, natural gas liquids, other hydrocarbons, and oxygenates. Renewable energy resources: Energy resources that are naturally replenishing but flowlimited. They are virtually inexhaustible in duration but limited in the amount of energy that is available per unit of time. Renewable energy resources include: biomass, hydro, geothermal, solar, wind, ocean thermal, wave action, and tidal action. Reserve: That portion of the demonstrated reserve base that is estimated to be recoverable at the time of determination. The reserve is derived by applying a recovery factor to that component of the identified coal resource designated as the demonstrated reserve base. Reservoir: A porous and permeable underground formation containing an individual and separate natural accumulation of producible hydrocarbons (crude oil and/or natural gas) which is confined by impermeable rock or water barriers and is characterized by a single natural pressure system. Residual fuel oil: A general classification for the heavier oils, known as No. 5 and No. 6 fuel oils, that remain after the distillate fuel oils and lighter hydrocarbons are distilled away in refinery operations. It conforms to ASTM Specifications D 396 and D 975 and Federal Specification VVF-815C. No. 5, a residual fuel oil of medium viscosity, is also known as Navy Special and is defined in Military Specification MIL-F-859E, including Amendment 2 (NATO Symbol F-770). It is used in steam-powered vessels in government service and inshore powerplants. No. 6 fuel oil includes Bunker C fuel oil and is used for the production of electric power, space heating, vessel bunkering, and various industrial purposes. Resources (Coal) : Naturally occurring concentrations or deposits of coal in the Earth's crust, in such forms and amounts that economic extraction is currently or potentially feasible. SLC: Sumatran Light Crude Solar energy: The radiant energy of the sun, which can be converted into other forms of energy, such as heat or electricity. Speculative resources (coal): Undiscovered coal in beds that may occur either in known types of deposits in a favorable geologic setting where no discoveries have been made, or in deposits that remain to be recognized. Exploration that confirms their existence and better defines their quantity and quality would permit their reclassification as identified resources. Steam: Water in vapor form; used as the working fluid in steam turbines and heating systems. Subsidy: Financial assistance granted by the Government to firms and individuals. TAC: Technical Assistance Contract; A from of cooperation between PERTAMINA and private companies for oil and gas exploration and exploitation. Therm: One hundred thousand (100,000) Btu. UPPDN: Unit Perbekalan dan Pemasaran Dalam Negeri Volt (V): The volt is the International System of Units (SI) measure of electric potential or electromotive force. A potential of one volt appears across a resistance of one ohm when a
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current of one ampere flows through that resistance. Reduced to SI base units, 1 V = 1 kg times m2 times s-3 times A-1 (kilogram meter squared per second cubed per ampere). Voltage: The difference in electrical potential between any two conductors or between a conductor and ground. It is a measure of the electric energy per electron that electrons can acquire and/or give up as they move between the two conductors. Wax: A solid or semi-solid material consisting of a mixture of hydrocarbons obtained or derived from petroleum fractions, or through a Fischer-Tropsch type process, in which the straightchained paraffin series predominates. This includes all marketable wax, whether crude or refined, with a congealing point (ASTM D 938) between 100 and 200 degrees Fahrenheit and a maximum oil content (ASTM D 3235) of 50 weight percent. Wind energy: Kinetic energy present in wind motion that can be converted to mechanical energy for driving pumps, mills, and electric power generators Wind Power Plant: A group of wind turbines interconnected to a common power provider system through a system of transformers, distribution lines, and (usually) one substation. Operation, control, and maintenance functions are often centralized through a network of computerized monitoring systems, supplemented by visual inspection. This is a term commonly used in the United States. In Europe, it is called a generating station. Wood energy: Wood and wood products used as fuel, including round wood (cord wood), limb wood, wood chips, bark, sawdust, forest residues, charcoal, pulp waste, and spent pulping liquor. WTI: West Texas Intermediate
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Profile of Editors th
Widodo Wahyu Purwanto, born in Sidoarjo, November 11 1960, received his doctorate degree in chemical engineering (1992) from Ecole Nationale Supérieure d’Ingénieurs de Génie Chimique (ENSIGC), l’Institut Nationale Polytechnique de Toulouse (INPT), France. He is an active member of the American Institute of Chemical Engineers (AIChe), the current director of Center for Energy Studies University of Indonesia and head of Sustainable Energy Research Group at the Department of Chemical Engineering University of Indonesia. Clean Energy Technology and Chemical Reaction Engineering are his preferred research domains. He regularly gives lectures to undergraduate as well as graduate students of Chemical Engineering University of Indonesia and to professionals in the oil and gas business on certain occasions. Yulianto Sulistyo Nugroho, was born in Jakarta, July 28 1968. He got his Ph.D degree from Department of Fuel and Energy, The University of Leeds, UK. Combustion engineering and Energy Study are his expertise. His research work in Coal Combustion especially spontaneous combustion of coal have been published by FUEL International Journal, International Conference on Coal Science, Proceeding of Combustion Institute, and Coal Tech. He is a Lecturer in Mechanical Engineering Department FTUI; active Instructor in professional trainings for Industrial Safety and Fire Protection Systems; and also member of Indonesian Coal Society (ICS) and Combustion Institute. He is an acting Vice Director of Center for Energy Studies in University of Indonesia. Rinaldy Dalimi, was born in Pekanbaru on April 24 1956, with the latest education in Virginia Polytechnic Institute and State University, Virginia Tech (USA), Electrical Engineering Department (with Doctoral Certificate, Ph.D). His expertise is Power System Engineering, and he is a lecturer of Undergraduate and Postgraduate Program of Electrical Engineering, Faculty of Engineering Universitas Indonesia (FTUI). He is The Dean of Faculty of Engineering University of Indonesia, and an expert staff of Center for Energy Studies University of Indonesia
A Harsono Soepardjo, was born in Solo on July 7, 1951, latest education in University of Montpellier II France with Doctoral Degree. Beside lecturer of Undergraduate and Postgraduate Program of Material Science Program and Physics of Mathematic and Natural Science (FMIPA-UI), he is an expert staff in Center for Energy Studies of University of Indonesia, Chief of Center for Marine Studies and Chief of Post Graduate for Marine Sciences Faculty of Mathematics and Natural Science University of Indonesia. Since 2001 till now, he is a Director of International Ocean Institute Affiliation Indonesia
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Abdul Wahid was born in Tegal, July 1 1967, latest education in Postgraduate Department of Chemical Engineering University of Indonesia. Research conducted in Process System Engineering such as Evaluation on the Impact of Department of Mining and Energy toward the National Economy, Optimization of LNG Refinery Capacity: a System Dynamic Approach. Now, he is a lecture of Undergraduate Program in Department of Chemical Engineering Faculty of Engineering UI and Head of Chemical Process System Laboratory.
Dijan Supramono was born in Malang, December 8, 1958.. He was awarded MSc degree in Process Integration in 1991 from Department of Chemical Engineering, University of Manchester Institute of Science and Technology (UMIST), England. His research interest is fluid mechanics and coal combustion. He is a lecturer at Department of Chemical Engineering, University of Indonesia.
Dinna Herminna, was born in Jakarta, January 26 1983, latest education in Undergraduate Program from Chemical Engineering Study Program Department of Gas and Petrochemical Engineering Faculty of Engineering University of Indonesia. She responsible for Sponsorship, Compiling and Managing Data for this book.
Teguh Ahmad Adilina, was born in Jakarta, Desember 8 1983, latest education in Undergraduate Program from Chemical Engineering Study Program Department of Gas and Petrochemical Engineering Faculty of Engineering University of Indonesia. He responsible for Managing the Energy Model (INOSYD).
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SPONSORS
PT. Pacific Oil & Gas Indonesia Jl. M.H. Thamrin No. 31 Jakarta 10230, Indonesia Telp. (62 21) 3149189 Fax. (62 21) 3149188 Email :
[email protected] Homepage : www.po-and-g.com
Premier Oil Indonesia Jakarta Stock Exchange Building, Tower 1, 10 Floor Jl. Jend. Sudirman Kav. 52-53 Jakarta 12190 Homepage : www.premier-oil.com
Star Energy Wisma Mulia 50th Floor Jl. Jend. Gatot Subroto No. 42 Jakarta 12710 - Indonesia Telp. (62-21) 52906060 Fax. (62-21) 52906050
PT. Bakrie & Brothers, Tbk Wisma Bakrie II Jl. H.R. Rasuna Said Kav B-2, 16th - 17th floor Jakarta 12920 - Indonesia P.O.Box 660 JKTM Telp. (62 21) 936 33 333, 99 999 Fax. (62-21) 520 0361 Homepage : www.bakrie-brothers.com
PT. Pendawa Consultama Sejati Gedung Graha Seti Jl. KH. Abdullah Syafei, Kav. A, No. 19 Gudang Peluru, Tebet, Jakarta Selatan 12830 PO BOX 1789, Jakarta 12017-Indonesia Telp. (62-21) 837 00235 Fax. (62-21) 837 00786 Homepage : www.pendawa.co.id
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Wisma Mulia 50th Floor Jl. Jend. Gatot Subroto No. 42 Jakarta 12710 - Indonesia Phone : 62-21-52906060 Fax : 62-21-52906050
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