Asia s First FSRU And its Role in Pushing LNG Development in Indonesia Tammy Meidharma PT Nusantara Regas 4 th LNG Supply, Transportation & Storage Indonesia, 20 May 2014, Stone Hotel, Legian, Bali
Overview Background Closing Remarks Operational Experiences & Challenges Roles of NRS in Supporting Sustainable Gas Supply For West Java
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2007, 2020 BCFD Domestic Gas Supply-Demand Kalimantan 2007 3.9 0.4 3.6 2020 4.3 2 0.7 3.6 Sumatera 2007 2020 2.1 0.4 1.7 1.7 1.1 3 0.6 Produc tion Local demand Surplus Produc tion Local demand Surplus Produc tion Local demand Surplus Production Local demand Surplus Java shortage expected to worsen by 2020, unless new infrastructure is built to transport gas from other regions Expected deficit in North Sumatera South Sumatera to remain a gas surplus region Java 2007 1.0 Produ ction 1.2-0.2 Local Deficit demand 2 2020 1 1.3 Production 3.4 Local demand -2.2 Deficit 1 Potential reserves / Current production 2 Demand shortfall as per BPHMIGAS includes unmet latent demand 3 Sumatra demand shown indicates sales to Duri for steam flooding and excludes local fertilizer sales that are assumed to be price out by Duri and SSWJ imports SOURCE: Woodmac, Energyfiles, Pertamina; FACTS; BPPT; PLN; PGN; team analysis
Regional Gas Demand Mapping FSRU Nusantara Regas Satu (NRS) has been integrated to pipeline surrounding West Java area to fulfill gas demand for industry In MMSCFD FSRU NRS & IJP Demand 2014 2018 2025 PLN M. Karang 160 160 290 PLN Tg. Priok 60 60 300 PLN M. Tawar 50 50 50 Industry 53 376 650 Total 323 646 1290 Source: Wood Mackenzie FSRU Jateng & IJP Demand 2014 2018 2025 RU IV Cilacap 75 75 75 RU VI Balongan 40 75 75 Industry 84 100 120 Total 199 250 270 Existing pipeline Existing FSRU Planned pipeline Planned FSRU & Regas LNG KTI development
West Java FSRU Project was categorized as a Fast Track Project based on President Instruction Number 1 / 2010 concerning the Master Plan for the Acceleration and Expansion of Indonesia Economic Development (MP3EI). HoA LNG SPA 18 MONTHS HoA GSA WEST JAVA FSRU PROJECT AMDAL PERMIT BIDDING PROCESS Award FSRU Award EPCIC FSRU CONVERSION EPCIC SUBSEA PIPELINE EXECUTION ORF Mech. Completion 18 Apr 2012 First STS Operation 4 May 2012 First Gas in to PLN 24 May 2012 Final Acceptance Test and Normal Operation 13 July 12 October 2010 December 2010 April 2012 May 2012 July 2012
FSRU Key Installation LNGC Khannur Mooring System Loading Arm BOG Comp. Export Gas System Pig Launcher Platform Regasification Unit FSRU Nusantara Regas Satu FSRU CAPACITY & DESIGN LNG storage tank : 125.000 m 3 Regas unit : 3 MTPA ~ 400 MMSCFD Sea water open loop system (Water > Propane > LNG) LNG Offloading System : STS Mooring System : Mooring Dolphin
Re-gasification System 1. The Re-gasification Plant has a 3 x 50% configuration. 2. Two Re-gasification Trains are normally running, where one is selected to be the LEAD Re-gasification Train and the other selected to be the LAG Re-gasification Train. The third Re-gasification Train is standby. 3. Each Re-gasification Train consists of three main sub-systems: LNG/NG System Propane System Seawater System 8
Subsea Pipeline & ORF Subsea Pipeline Design Specification : DNV OSF101 2007 Suitable for Intelegent Pig Pipeline Length : approx. 15 km Material Grade : DNV Grade 450 Coating : 3LPE & Concrete Weight Cathodic Protection : Galvanic Anode as per DNV F103 Tie in to FSRU platform Onshore Receiving Facilities Pig Receiver Gas Filter 2x500 MMscfd Gas Heater Gas Metering and Letdown System Tie-in to Customers 9
Overall Plant Availability Factor in 2013 was 97.5% which was higher than the target, 97%. On the other hand, FSRU Utilization Factor in 2013 was less than 50% of installed capacity. Hence, there is a room to optimize the excess capacity. 500 400 300 200 FSRU Utilization Factor in 2013 available capacity for future business 100 Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov To optimize the idle capacity, there is a room for PLN and subsidiary companies to utilize the FSRU and supporting facilities. PT Nusantara Regas could offer the business scheme either merchant or re-gasification fee basis. Send out gas (MMSCFD) Installed capacity (MMSCFD) 100 Plant Availability Factor in 2013 80 60 40 20 0 Scheduled Turn Around 8 days 21.57 hrs jan feb mar apr may jun jul aug sep oct nov dec Actual Target Plan
There is a 150 200 MMSCFD predicted idle capacity can be used for new electricity generations and industries starting from 2015. 600 In MMSCFD 500 Installed Capacity 400 300 200 N/A Idle Capacity Utilized Capacity 100 0 2012* 2013 2014** 2015 2016 2017 2018 1. FSRU Nusantara Regas Satu (NRS) was put in COD in August 2012* 2. Utilized capacity was calculated up to end of April 2014**
Fuel substitution for PLN Muara Karang has been carrying out since July 2012. 88.1% in average of allocated LNG in 2012-2013 had been used for fuel substitution. A little amount of allocated LNG was introduced and used for industrial in 2012-2013. Projected fuel substitution will be around 98% of allocated LNG in 2014-2018. 80,000 98% In Billion BTU (BBTU) 70,000 97.3% 60,000 50,000 40,000 30,000 78.9% Allocated LNG PLN / Power Industrial 20,000 10,000 0 0.04% 0.03% 2012 2013 2014 2015 2016 2017 2018
Actual saving in term of reduction of fuel subsidy was achieved approximately in amount of USD 259 million in 2012 and USD 546 million in 2013. The potential saving will be around USD 598 million average per year in 2014-2018. 700 In million USD 600 500 400 300 Potential Saving Actual Saving N/A 200 100 0 2012 2013 2014* 2015 2016 2017 2018 (*) Approximately actual saving as of 30 April 2014
14 A flexibility gas delivery to fulfill a sustainable gas supply could be achieved by Swapping Operation Mode. FSRU PGN Via SSWJ 2 Gas Pipe PLN MuaraTawar ORF MuaraKarang INDUSTRY West Java Re-gasified LNG
The successful operation of the First Indonesia FSRU is one of the key milestones for gas infrastructure development as well as the LNG Development for transportation. FSRU NRS is the First Hub Station for accelerating Fuel Substitution Program and maintaining Flexibility Operational of Electricity Generation Power Plant.
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There are some drivers for Gas Infrastructure Development In Indonesia which consists of Geographical, Political, Market and Technical issues. GEOGRAPHICAL POLITICAL MARKET TECHNICAL Widely dispersed archipelago No extensive gas pipeline network Government to increase the portion of gas for domestic use Government awareness on the need for using LNG to transport gas Government commits to reduce local pollution and CO2 emissions High price oil bases fuel compared with LNG Indonesian fuel subsidies are increasing & costly as electricity demand grows Need for distributed power generation Proven technical feasibility study Important infrastructure and facilities such as West Java FSRU.
18 LNG as one of the Primary Energy for National Electricity will substitute significantly the role of High Speed Diesel (HSD) and Marine Fuel Oil (MFO) beyond 2014. Role Of LNG as A Primary Energy For National Electricity
Back Up Calculation Allocated cargoes in 2014-2018 : 27 standard(*) BRs = 22x125,000m3x23.5MMBTU/m3 = 64,625,000 MMBTU TGs = 5x125,000m3x22.61MMBTU/m3 = 14,131,250 MMBTU Total = 78,756,250 MMBTU Projected Demand = 77,863,000 MMBTU In percentage = 98% (*) Based on re ADP in January 2014 Allocated cargoes in 2013 : 24 standard BRs = 22x125,000m3x23.5MMBTU/m3 = 64,625,000 MMBTU TGs = 2x125,000m3x22.61MMBTU/m3 = 5,652,500 MMBTU Total = 70,277,500 MMBTU Actual send out = 68,337,000 MMBTU In percentage = 97.25% Allocated cargoes in 2012 : 14 standard BRs = 14x125,000m3x23.5MMBTU/m3 = 41,125,000 MMBTU Actual send out = 32,438,000 MMBTU In percentage = 78.88%
Back Up Calculation Potential Saving in 2012 = 41,125,000 MMBTU x (24.10-16.11) USD/MMBTU = USD 328,588,750 Potential Saving in 2013 = 70,277,500 MMBTU x (24.10-16.11) USD/MMBTU = USD 561,517,225 Actual Saving in 2012 = 32,438,000 MMBTU x (24.10-16.11) USD/MMBTU = USD 259,179,620 Actual Saving in 2013 = 68,337,000 MMBTU x (24.10-16.11) USD/MMBTU = USD 546,012,630 Potential Saving in 2014-2018(*) = 0.95x78,756,000 MMBTU x (24.10-16.11) USD/MMBTU = USD 597,797,418 (*) Based on re ADP in January 2014 Notes: 1. Operation cost based on HSD fuel is 24.10 USD/MMBTU and re-gasified LNG is 16.11 USD/MMBTU. 2. LNG price is calculated based on crude price at 100 USD/Barrel (ICP version).
jan feb mar apr may jun jul aug sep oct nov dec 21 Operational Experiences and Technical Challenges 3.1. LNG - Send Out Gas 2012 7000 6000 5000 4000 3000 2000 1000 0 in BBTU Total Received LNG: 38,337 BBTU Average Send Out Gas: 154.1 BBTUD LNG Send Out N/A
jan feb mar apr may jun jul aug sep oct nov dec 22 Operational Experiences and Technical Challenges 3.2. LNG - Send Out Gas 2013 10,000 9,000 8,000 7,000 6,000 5,000 4,000 3,000 2,000 1,000 0 in BBTU Total Received LNG: 70,240.7 BBTU Average Send Out Gas: 198.6 BBTUD LNG Send Out None