innovative tools for deep geothermal
TRANSCRIPT
Innovative tools for deep geothermal
Jean-Philippe Gibaud Business Development Manager – Schlumberger / GeothermEx [email protected] Member of the board of ETP-RHC - Vice President of Geothermal Panel
Schlumberger at a Glance 2010 Financial Highlights
Revenue : $27.45 Billion Total R&D: $ 913 Million - 25 centers More than 108 000 employees in 80 countries Leading Oil and Gas services company
• Surface Electromagnetic and Seismic
• Modeling and simulation • Directional drilling • Microseismic event monitoring • Well logging and imaging • Drilling bits
• HT Downhole pumps • Drilling fluids • Mud logging • Well stimulation (fracturation) • Cementing and perforation • Integrated project Management (IPM)
Key services in Geothermal
• Resource identification / exploration – Reinterpretation of existing data, and new data acquisition – Reservoir identification for deep and very deep geothermal – New Geological & geophysical methods – Resource assessment at different scales – Innovative geophysical tools
• Drilling – Increased ROP in hard rock formation with large diameters – HT completions and cements – HT monitoring and logging tools
• EGS:
– Exploration, finding access to potential reservoir at depth – Reservoir engineering, stimulating the fluid flow underground – Exploitation, Improving the efficiency – Monitoring, reservoir management – Corrosion & scaling – HT / HF pumps
Geothermal Strategic R&D priorities
Strategic R&D priorities
• Resource identification / exploration – Reinterpretation of existing data, and new data acquisition – Reservoir identification for deep and very deep geothermal – New Geological & geophysical methods – Resource assessment at different scales – Innovative geophysical tools
• Drilling – Increased ROP in hard rock formation with large diameters – HT completions and cements – HT monitoring and logging tools – Reservoir engineering, stimulating the fluid flow underground
• Operations:
– Exploitation, Improving the efficiency – Monitoring, reservoir management – Corrosion & scaling – HT / HF pumps
MeProRisk Cooperation: Integrated Reservoir Assessment
RWE Dea Data
RWTH Mathematics Shape optimization Design optimization
RWTH Geophysics Reservoir simulation Inverse methods Uncertainty analysis
RWTH Sci. Comp. Parallelization Autom. Differentiation Visualization
FU Berlin University Migration, Imaging Micro seismicity and Permeability
Kiel University Seismic models Structure and Geometry assessment
Geophysica GmbH Rock properties Logging, Up-scaling Reservoir model design
Site investigation
Geophysics ( surface , drill hole)
Petrophysics (logs, lab)
Hydrogeology (logs, tracer tests ,
chemistry )
General Information Geology , Hydrology
Model of Geological Structure
Model of Reservoir Update of parameters
Calibration
Operating stage Observation
Long term tests
Planning Risik assessment
Production scenarios
Prognosis Temperature
Production ( flow ) Sensitivity
Site investigation
Geophysics ( surface , drill hole)
Petrophysics (logs, lab)
Hydrogeology (logs, tracer tests ,
chemistry )
Site investigation
Geophysics ( surface , drill hole)
Petrophysics (logs, lab)
Hydrogeology (logs, tracer tests ,
chemistry )
General Information Geology , Hydrology
General Information Geology , Hydrology
Model of Geological Structure
Model of Geological Structure
Model of Reservoir Update of parameters
Calibration
Model of Reservoir Update of parameters
Calibration
Operating stage Observation
Long term tests
Operating stage Observation
Long term tests
Planning Risik assessment
Production scenarios
Planning Risk assessment
Production scenarios
Prognosis Temperature
Production ( flow ) Sensitivity
Prediction Temperature
Production ( flow ) Sensitivity
MeProRisk Cooperation: Integrated Reservoir Assessment
Logs
Lab measurement
Seismic interpretation
6 km
6 km 5 km
Stratigraphy (Petrel) model
Site model
Target layer
Numerical reservoir model
Integration of geological, structural and rock property data in a 3D model of the site
3D mapping of seismic reflection horizons using PETREL(2)
Generation of a structural 3D reservoir modell
using PETREL(2)
Integrated Reservoir Assessment
Origin of Reservoir Parameters for Simulation using ECLIPSE
• Geophysical logging (density-, sonic-, NPHI-, resistivity- logs) • Core testing • 3D seismic data
• Laboratory testing • Geothermal gradient from corrected temperature logging (HC exploration wells)
Porosity Permeability
• Core testing • Well testing (DST/Pumptests) • Stat. distribution with correlation to porosity
Heat Parameter
Integrated Reservoir Assessment
Integrated Reservoir Assessment
GT 3 GT 4
GT 1 GT 2
Multi-disciplinary approach – Geology – Seismic 2D and 3D – Borehole logging data
Integrated in a common model Best use of existing data to minimize exploration cost and risks
IF Technology
Strategic R&D priorities
• Resource identification / exploration – Reinterpretation of existing data, and new data acquisition – Reservoir identification for deep and very deep geothermal – New Geological & geophysical methods – Resource assessment at different scales – Innovative geophysical tools
• Drilling – Increased ROP in hard rock formation with large diameters – HT completions and cements – HT monitoring and logging tools – Reservoir engineering, stimulating the fluid flow underground
• Operations:
– Exploitation, Improving the efficiency – Monitoring, reservoir management – Corrosion & scaling – HT / HF pumps
BRGM - Department of Geothermal Energy (GTH)
New Na/Li geothermometer
Krafla field(dilute fluids)y = 1.967x - 1.267
R2 = 0.958
y = 0.920x + 1.105R2 = 0.994
1.00
2.00
3.00
4.00
5.00
1.0 1.5 2.0 2.5 3.0 3.5 4.0103/T (°K)
log
(Na/
Li) (
mol
ar r
atio
)
250 200 150 25100 50300350
Basalt - seawater interactions (Iceland, Djibouti, seawater, MAR, EPR)
400 0°C
Reykjanes, Svartsengi and Seltjarnarnes fields
Krafla field
Namafjall field
Hveragerdi field
Nesjavellir field
Krafla + Nesjavellir + Namafjall + Hveragerdi
(dilute fluids)y = 2.002x - 1.322
R2 = 0,967
Saline fluids (Fouillac and Michard, 1981) Cl ≥ 0.3 M
y = 1.195x + 0.13
Dilute fluids (Fouillac and Michard, 1981) Cl < 0.3 M
y = 1.000x - 0.38
Sedimentary basins (Kharaka and Mariner, 1989)y = 1.590x - 1.299
MAR, EPR
Very altered MAR, EPR
BRGM - Department of Geothermal Energy (GTH)
Schlumberger Moscow Research Centre:
ADVANCED TECHNIQUE FOR RESERVOIR THERMAL PROPERTIES DETERMINATION AND PORE-SPACE CHARACTERIZATION
Determination of: • Thermal Conductivity • Thermal Diffusivity • Volumetric Heat Capacity • Coefficient of liner thermal expansion Measurements conducted at normal and
elevated temperature (up to 250 degC) and pressure (up to 250 MPa) conditions.
Measurements can be done on full size core, core plugs and core cuttings
Possibility to measure anisotropy of thermal properties
• Resource identification / exploration – Reinterpretation of existing data, and new data acquisition – Reservoir identification for deep and very deep geothermal – New Geological & geophysical methods – Resource assessment at different scales – Innovative geophysical tools
• Drilling – Increased ROP in hard rock formation with large diameters – HT completions and cements – HT monitoring and logging tools – Reservoir engineering, stimulating the fluid flow underground
• Operations:
– Exploitation, Improving the efficiency – Monitoring, reservoir management – Corrosion & scaling – HT / HF pumps
Strategic R&D priorities
BRGM HiTI: HPHT Probe
200 °C 300 °C 400 °C
500 bars
750 bars
1 000 bars
Mechanical simulation for confirms design validity: December 2008
Pieces reception: October 2010 First test on desk: January 2010
BRGM - RNSC/RSC
BRGM - RNSC/RSC
BRGM HiTI Probe - First well logging in Krafla, Borehole KS1: June 2010
Ragnar Ásmundsson Sveinbjörn Sveinbjörnsson
ISOR High temperature well logging truck
Optimize drilling and minimize environmental impact in high-temperature applications The ENVIROTHERM NT system is a single drilling-fluid system that is chrome-free for environmental reasons, that can resist bottomhole temperatures in excess of 450°F (232°C) and that uses water-base chemistry. Their requirements stem chiefly from traditional land-based operations, but now high-temperature shale drilling has the same requirements for certain areas.
High Temperature drilling fluid with minimal environmental impact
Official release March 3, 2011, Amsterdam
Quartz gauges for HPHT well testing operations
Official release March 21, 2011
The gauges have been field tested in India, Saudi Arabia, Norway and the United Kingdom under a variety of reservoir conditions. In a HPHT offshore well, the 410 degF (210°C) temperature rating of the Signature gauges allowed the operator to position them at a depth of 5,108 meters, which was 1,750 meters closer to the reservoir than conventional gauges. The well test lasted 15 days and met the operator’s test objective of confirming the reservoirs commercial viability.
• Resource identification / exploration – Reinterpretation of existing data, and new data acquisition – Reservoir identification for deep and very deep geothermal – New Geological & geophysical methods – Resource assessment at different scales – Innovative geophysical tools
• Drilling – Increased ROP in hard rock formation with large diameters – HT completions and cements – HT monitoring and logging tools – Reservoir engineering, stimulating the fluid flow underground
• Operations:
– Exploitation, Improving the efficiency – Monitoring, reservoir management – Corrosion & scaling – HT / HF pumps
Strategic R&D priorities
Tracer tests • Tracer selection
Poly-aromatic naphthalene sulfonates answer to the criteria of validity of tracers in a high temperature field: their stability was tested until 300-350°C but they were never used in a vapor-dominated system such as Krafla
• Bottom hole temperatures range from 250 to 350°C => opportunity to validate behavior far beyond their experimentally tested field of stability
• What are the perspectives of future works? • Modeling the tracer restitution could give a new dimension to the
information (connectivity, storativity) ; • the vapor/liquid ratio has a determining impact on the result as the
tracer is concentrated in the liquid phase
BRGM - Department of Geothermal Energy (GTH)
OPTICall
A pulse of light through a strand of optical fiber running inside a wellbore reflects back the well’s temperature. Production monitoring and diagnostics
Permanent fiber-optic DTS system that tracks fluid movements in real time along the wellbore to improve field productivity
Official release 2009 IPT Conf. Doha
Down-hole seismic sondes Seismic sondes by DJB Instruments:
1. Deployment in deviated wells, 2. Does not require clamping mechanism as it rests at the bottom, 3. No moving parts and therefore increase reliability
4. Large accelerometers and low noise amplifiers; – Gives very high output – Able to detect small signals
– No deterioration of signal quality over time
5. Able to remove from a borehole very easily for deploying elsewhere. 6. Small diameter enabling freedom in borehole. 7. The selected accelerometer has large bandwidth compared to others
8. Down-hole amplifiers to improve signal to noise ratio
9. Can be operated using car batteries and therefore used in remote places 10. Low power consumption and therefore the batteries can last for a long time
References: Landau (D), The Geysers (USA)
Conclusion
A wide variety of topics A wide variety of companies From various places
One focus:
Innovative technologies for deep geothermal
Contacts Schlumberger – Jean-Philipp Gibaud – [email protected] – www.slb.com
RWTH Aachen – Prof. Christoph Clauser - [email protected]
GEO Energie Bayern: Lars Matthes – [email protected]
IF Technology: Guus Willemsen – [email protected]
HiTI Project: BRGM (F): Bernard Sanjuan – [email protected]
ISOR (IS): Ragnar Asmundson – [email protected] Also: Calidus Engineering (UK), Oxford Applied Technology Ltd (UK),
CRES (GR), GFZ-Potsdam (D), Advanced Logic Technology (LU), Geosciences Montpellier (F)
Schlumberger Research Centre Moscow: Yuri Popov – [email protected]
DJB Instruments: Paul Hunter – [email protected]