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Sarulla Geothermal Power Project 3 x 110 MW
1GEOTHERMAL - RENEWABLE ENERGY
6th International Geothermal Workshop
Bandung Institute of TechnologyMarch 22, 2017
Table of Contents
The Project Overview
Brief History of the Project
Project Financing Scheme
Upstream development program
Reservoir Chemistry and Model
Drilling History
Drilling Challenges
The Power Plant System and Technology
Project challenges
Questions
2
3
Project Overview
4
Project Name Sarulla Geothermal Power Project
Location Pahae Jae and Pahae Julu Sub District, North Tapanuli Regency, North SumatraProvince, Indonesia
Capacity 3 X 110 MW
Sponsors PT Medco Power Indonesia (In June 2015, INPEX acquired 49% of Medco’s interest)
Itochu CorporationKyushu Electric Power Co., Inc. Ormat International, Inc.
Project Co. Sarulla Operations Ltd (“SOL”)
Financial Close 23 May 2014
Total Project Cost USD 1.6 Billion (original budget)
Commercial Operation Date
SIL : November 2016 (original schedule)NIL-1 : November 2017NIL-2 : May 2018
Contract Period 30 years after NIL-2 COD
5
MedcoSubsidiary
(99% X 37.25%)
SOL(1%)
PLN
ADB
Energy SalesContract (ESC)
HDECMultifab
Halliburton
ConstructionContract
DrillingContract
JBIC
CommercialBanks
Loan Agreement
ITOCHUSubsidiary
(99% X 25%)
Kyushu ElectricSubsidiary
(99% X 25%)
ORMATSubsidiary
(99% X 12.75%)
PertaminaGeothermal Energy (PGE)
Gov. of Indonesia
Business Viability Guarantee Letter
(BVGL)
Joint OperationContract (JOC)
Joint Operation Agreement (JOA)
Supply Contract
HDEC
Stakeholders’ Structure
HDEC: Hyundai Engineering & Construction Ltd.
Medco(51%)
INPEX(49%)
Project Location and General SitingProject Location and General Siting
6
Pahae Jae and Pahae Julu Sub District, North Tapanuli Regency, North Sumatra Province, Indonesia
Pahae Julu SubdistrictNamora-I-Langit (NIL)
2 x 110MW
Pahae Jae SubdistrictSilangkitang (SIL) -110MW
7
Brief Project History
8
Period Events
Feb 27, 1993 Unocal North Sumatra Geothermal (“UNSG”) signed JOC (with Pertamina) and ESC (with PLN)
1993 - 1997 UNOCAL conducted drilling exploration in Silangkitang, Namora I Langit (5 wells at SIL, 4 wells at NIL) and Sibual Buali, acquired partial land
1998 Economic crisis occurred in Asia, project was halted
Jan 23, 2004 Project assigned to PLN (effective February 24, 2004) by UNSG through Deed of Assignment
Dec 1, 2004 Bid Submission for taking over of Project
Jul 25, 2006 Letter of Award to SOL Consortium
Dec 14, 2007 ESC Amendment (among PLN, Pertamina Geothermal Energy (“PGE”) and Consortium) and JOC Amendment (between PGE and Consortium) were signedTariff
Mar 10, 2011 New Tariff (staged tariff) Approval by Ministry of Energy and Mineral ResourcesTariff – 3-stage tariff;
Apr 4, 2013 Second ESC/JOC Amendments were signed
Mar 28, 2014 Loan agreements were signed
May 23, 2014 Financial Close achieved / Notice to Proceed issued
9
Financing schemeUS$1.17 billion 20-year tenor project financing
Japan Bank for International Cooperation – US$492 million
Asian Development Bank – US$250 million
ADB-administered concessional lending – US$100 million
Clean Technology Fund (US$80 million)
Canadian Climate Fund for Private Sector in Asia (US$20 million)
Commercial banks (backed by JBIC extended political risk guarantee) - US$328 million
Setting the precedent
First greenfield non-recourse project financing in Indonesian geothermal sector since 1997.
Integrated project financing (non-recourse)
Three generation plants financed as one entity rather than unit-by-unit.
Steam fields development (drilling costs etc) also covered.
Tight covenants under the financing docs. Close coordination with the lenders required.
10
11
Project Status – DrillingWells Drilled to date - 32 drilled at present
P – production well; R- reinjection well
4 drill rigs were working at Site until early 2016
Reduced to 3 drill rigs until early 2017
Reducing to 1 drill rig at NIL March 2018 at WJP-1n, drilling the 3rd production well
Plant Design Requirements SIL: 110 MW
Achieved: 166 MW
Plant Design Requirements NIL: 220 MW
Achieved: 252 MW
12
Location Production Injection Drilled / abandoned
From Previous developer
SIL 3 7 0 1 P
NIL 10 9 3 1 R
Total 13 16 3 2 (P&R)
main geological structures and well location :
13
Project Status – Reservoir Model (SIL)
Heat Source
Outflow
Outflow
Project Status – Reservoir Model (SIL)
14
Depth
(m)
Pressure
(bara)
Temperature
(oC)
Enthalpy
(kJ/kg)
Permeability-thickness products
(kh)(darcy-m)
1900 - 2200 150 - 170 264 - 329 1250 - 1420 11 - 95
Physical properties
Chemical properties
Brine pH(@25oC)
Cl in reservoir(ppm)
SO4 in reservoir(ppm)
SiO2 in reservoir(ppm)
NCG in steam*(wt%)
6.4 - 8.0 880 - 980 32 - 41 650 - 760 3.1 - 4.2
* Non-condensable gas content in steam separated at 22 barA
Current status of well for SIL :
PAD Well TypeDrilling Estimated Well Capacity
Spud in Finish Production Injection
SIL1N
SIL1-2(Existing)
P 4/12/1995 6/19/1995 21.1 MW -
SIL1N-6 R 3/10/2015 5/5/2015 - 312 t/h
SIL1N-5 R 5/12/2015 7/25/2015 - 75 t/h
SIL1N-4 P 8/6/2015 10/15/2015 35.2 MW -
SIL1N-1 P 11/10/2015 12/19/2015 54.7 MW -
SIL1N-2 P 12/24/2015 1/31/2016 55.1 MW -
SIL2N
SIL2-1(Existing)
R 2/11/1995 4/3/1995 - 200 t/h
SIL2N-1 R 8/21/2015 8/21/2015 - 603 t/h
SIL2N-2 R 10/8/2015 11/1/2015 - 638 t/h
SIL2N-3 R 11/8/2015 11/27/2015 - 456 t/h
SIL3N
SIL3N-3 R 2/15/2016 4/1/2016 - 567 t/h
SIL3N-2 R 4/9/2016 5/22/2016 - 834 t/h
SIL3-1 (Existing)
R 6/28/1995 8/9/1995 - Reservoir Monitoring well
TOTAL 166.1 MW 3,685 t/h
• P = Production well:; R = Reinjection well:• The estimated well capacity at designed steam turbine inlet pressure from individual production test
15
Project Status – Well Drilling (SIL)
Current status of well for SIL :
PAD Well TypeDrilling Estimated Well Capacity
Spud in Finish Production Injection
SIL1N
SIL1-2(Existing)
P 4/12/1995 6/19/1995 21.1 MW -
SIL1N-6 R 3/10/2015 5/5/2015 - 312 t/h
SIL1N-5 R 5/12/2015 7/25/2015 - 75 t/h
SIL1N-4 P 8/6/2015 10/15/2015 35.2 MW -
SIL1N-1 P 11/10/2015 12/19/2015 54.7 MW -
SIL1N-2 P 12/24/2015 1/31/2016 55.1 MW -
SIL2N
SIL2-1(Existing)
R 2/11/1995 4/3/1995 - 200 t/h
SIL2N-1 R 8/21/2015 8/21/2015 - 603 t/h
SIL2N-2 R 10/8/2015 11/1/2015 - 638 t/h
SIL2N-3 R 11/8/2015 11/27/2015 - 456 t/h
SIL3N
SIL3N-3 R 2/15/2016 4/1/2016 - 567 t/h
SIL3N-2 R 4/9/2016 5/22/2016 - 834 t/h
SIL3-1 (Existing)
R 6/28/1995 8/9/1995 - Reservoir Monitoring well
TOTAL 166.1 MW 3,685 t/h
• P = Production well:; R = Reinjection well:• The estimated well capacity at designed steam turbine inlet pressure from individual production test
16
Project Status – Well Drilling (SIL)
Project Status – Reservoir Model (NIL)
17
Depth
(m)
Pressure
(bara)
Temperature
(oC)
Enthalpy
(kJ/kg)
Permeability-thickness products
(kh)(darcy-m)
1060 - 1800 85 - 150 261 - 273 1183 - 1220 5 - 127
Physical properties
Chemical properties
Brine pH(@25oC)
Cl in reservoir(ppm)
SO4 in reservoir(ppm)
SiO2 in reservoir(ppm)
NCG in steam*(wt%)
2.5 - 8.2 740 - 1050 290 - 780 530 - 620 6.0 – 9.0
* Non-condensable gas content in steam separated at 11.5 barA
PAD Well TypeDrilling Estimated Well Capacity
Spud in Finish Production Injection
NIL1NNIL1N-7 P 12/24/2014 4/11/2015 30.01 MW -
NIL1N-3 P 4/22/2015 6/25/2015 Abandoned -
NIL2N
NIL2N-1 P 9/23/2014 1/16/2015 27.6 MW -
NIL2N-4 P 1/26/2015 3/20/2015 42.1 MW -
NIL2N-7 P 3/30/2015 5/26/2015 39.3 MW -
NIL2N-3 P 6/11/2015 8/26/2015 14.8 MW -
NIL2N-6 P 9/5/2015 11/3/2015 17.6 MW -
NIL2N-2 P 9/23/2015 12/26/2015 44.4 MW -
WJP1N
WJP1-1 P 2/17/2016 5/26/2016 No productive -WJP1-3 P 6/2/2016 9/12/2016 23.2 MW (acidic)
WJP1-5 P 6/2/2016 1/28/2017 13.4 MW (acidic) (Estimated from short term test)
WJR2
WJR2-1 R 2/21/2015 4/30/2015 - Abandoned
WJR2-3 R 5/12/2015 7/30/2015 367 t/h
WJR2-2 R 6/26/2016 8/9/2016 537 t/h
WJR2-4 R 8/20/2016 10/8/2016 953 t/h
WJR2-5 R 11/11/2016 1/1/2017 872 t/h
WJR2-6 R 1/18/2017 Drilling in progress - -
WJR1 WJR1-1 R 7/28/2015 10/19/2015 - Abandoned
NIL3(Existing)
NIL3-1 R 1/21/1996 2/11/1998 - 292 t/h
NIL3N
NIL3N-1 R 1/11/2016 5/11/2016 - 920 t/h
NIL3N-2 R 5/19/2016 8/12/2016 1361 t/h
NIL3N-3 R 8/21/2016 10/3/2016 1883 t/h
NIL3N-4 R 10/26/2016 12/25/2016 544 t/h
NIL3N-5 R 1/10/2017 2/11/2017 1442 t/h
TOTAL 252.4 MW 9,171 t/h
18• Well capacity from flow test results estimated at separation pressure (11 bars); WJP1N-5 is estimated based on the short term test (injection test); long terms test (production test) yet to be executed.
• Reinjection capacity targeted (based on design enthalpy; to be revised)– 9,862 TPH:
Current status of well for NIL : P=Production well; R=Reinjection wellProject Status – Well Drilling (NIL)
General
Challenging logistics for 4 rig simultaneous operation.
Drilling Water Supply/Pumping Stations
Material Delivery/fuel/warehousing
Large Base camps, over 400 personnel
Drilling and flow testing on a pad at the same time
Drilling and Constructing Power plants at the same time.
Drilling Challenges for the Sarulla project
SIL
Production pad near Sumatra Highway/local residence-social
challenge
Discrepancy between the fault distributions shown in the old
UNOCAL geological model and the drilling results. Very low
permeability in originally planned injection area. Need to change
injection targets.
Stuck Pipe when near to the GSF due to clays in the fracture
formations
EPC Schedule, Constructing separator stations while drilling
Higher pressure/enthalpy than estimated, mis-match with EPC
design
Drilling Challenges for the Sarulla project
NIL
NIL formation much more fractured as compared to SIL.
Difficulties drilling wells through a high pressure shallow gas (CO2) zone at
pads NIL1N, WJR1 and WJR2.
Two abandoned injection wells due to shallow high CO2 gas
pressure.
One abandoned production well due to shallow high steam
pressure.
Multiple Stuck Pipe/Lost in Hole/Sidetracks due to paleosol (clay)
formations.
Cold water encountered in first production well on WJP-1 pad.
Acid fluids encountered in second and third wells drilled on pad WJP1.
Drilling Challenges for the Sarulla project
Field Variability Summary
Average Drilling Days for Productions wells:
SIL 47 NIL: 78
Standard casing program: 13 3/8 inch casing to 3,000 ft, 10 ¾ inch slotted liner to 6,000 ft
Cost per Production well at NIL was 70% higher as compared to SIL
Average Drilling Days for Injection Wells:
SIL 44 NIL: 65
Standard casing program: 9 5/8 inch casing to 3,000 ft, 7 inch slotted liner to 6,000 ft
Shortest Drilling Duration: SIL-2-3 (20 days) (completed shallow)
Longest Drilling Duration: NIL-3-1 (122 days) (sidetracked well)
Cost per Injection well at NIL was 35% higher as compared to SIL
Drilling Challenges for the Sarulla project
23
The SIL Power Plant
24
The SIL Power PlantSteam Field and Steam aboveground Surface (SAGS) Equipment
2 sets separator systems
5 km of gathering/injection pipeline (sizes of 36” for steam, 24” for brine, 30”for brine/condensate)
Power Plant
Integrated Geothermal Combined Cycle (IGCCU) Technology:
1 back-pressure steam turbine (62 MW gross)
4 Organic Rankine Cycle (ORC, binary cycle) condensing steam units
(7 MW gross each)
2 Organic Rankine Cycle (ORC, binary cycle) geothermal brine units (16 MWgross each)
Integrated Control System (ICS - DCS/PLC)
A 150KV double bus Substation connected to PLN substation via 2 lines of 2.25km- 150KV Transmission Line
25
SIL Site Plan
26
The SIL Power Plant
27
Wellpad Area
SIL Production wellpad & Separator System
28
The NIL Power Plant
29
The NIL Power Plant Steam Field and Steam aboveground Surface (SAGS) Equipment combined forboth NIL 1 and NIL 2 phases - drilling is still ongoing and the following may stillchange based on further drilling results
8 sets separator system and 13km of steam, brine and brine/condensatepipelines
Integrated Geothermal Combined Cycle (IGCCU) Technology. Each plant (NIL-1and NIL-2 consists of;
1 back-pressure steam turbine (57.5 MW gross)
4 Organic Rankine Cycle (ORC, binary cycle) condensing steam units
(7.5 MW gross each)
2 Organic Rankine Cycle (ORC, binary cycle) geothermal brine units (16 MWgross each)
Integrated Control System (ICS - DCS/PLC)
A 150KV double bus Substation connected to PLN substation via 2 lines of 10kms150KV Transmission Line
30
NIL Site Plan
31
NIL Production Wellpad & Separator System
32
Wellpad Area
Power Plant Technology – IGCCU(Integrated Geothermal Combined Cycle Units)
33Combined Cycle (Binary) Condensing System
Sarulla - Combined Cycle:• Uses both geothermal steam &
brine;• Reinjects 100% of the geothermal
fluid• Uses air-cooling instead of water• Multiple modular units
SIL Process Flow Diagram (PFD)
34
IGCCU Technology Features
35
Feature Advantages Disadvantages Remarks
Resource enthalpy change
More flexible to changes – loss in steam, gain in brine or vice versa
Lower steam efficiency as compared to simple steam condensing
SIL fluid enthalpy is higher than design
Modularity Expects to have higher availability factor
Lower profile; lighter equipment and smaller components
More equipment to install and maintain
Air cooling Increase resource sustainability though 100% reinjection
Eliminate mists and chemicals in water cooling
100% injection means more injection wells at the initial phase
Bigger plant footprintCost/Efficiency
Expectation is that this will benefit the project in the long run
Original Plan Current estimation
Enthalpy 1,290 kJ/kg 1,365 kJ/kg
Separator Pressure 20.4 bara 22.0 bara
Geothermal fluid
Steam 579 t/h 638t/h
Brine 2,320.88 t/h 1,972 t/h
Total Flow 2,899.99 t/h 2,610 t/h
Gross output
STG 62.85 MW 67.45 MW
Bottoming OEC 26.97 MW 29.40 MW
Brine OEC 27.78 MW 23.17 MW
Total (MWg) 117.60 MW 120.02 MW
Plant Technology Features
36
Flexibility to manage changing/variation on geothermal fluid enthalpy
Plant Technology Features
37
Combined Cycle (Binary) Condensing System
Air cooling enhances 100% reinjection and eliminates mists from water cooling towers
Project ChallengesTechnical
Fixing plant process design and proceeding with an EPC, withsimultaneous field development.
Risk that production well enthalpy will not match equipmentdesign.
Risk of designing separators stations and pipelines to wellpads, before flow capacity is actually tested and known.
pH mod system design (required due to high silica in reservoir).Corrosion, control, logistics problems.
Soil type at SIL that was hard to work under frequent raining;required more extensive earthwork and foundation.
Public road conditions not conducive to transportation of heavyequipment.
38
Project ChallengesSocial
SIL wellpad close to community – puts restraint even on certainstandard practices in more remote geothermal areas.
Private Roads become public roads. Traffic, house construction,interference with pipelines.
Demands for local contracting, Employment and businessopportunities for local community.
Communities complaints expressed through demonstrations,causing work disruptions
39
Summary and Conclusions
40
Summary and Conclusions
41