first co injection experiment at heletz (israel): determination of … · 2017-07-13 · 2...

The research leading to these results has received funding from the European Community's Seventh Framework Programme [FP72012– ENERGY.5.2 - CO2 STORAGE - Topic: ENERGY.2012.5.2.1 under grant agreement n° 309607]

TRUSTFirst CO2 injection experiment at Heletz (Israel):

determination of dissolution trapping and capillary trapping via a single well push pull experiment

Jacob Bensabat1, Auli Niemi2, Fritjof Fagerlund2, Rona Ronen1, Yoni Goren1, Lily Perez1, Igal Tsarfis1, Saba Joodaki2, Zhibing Yang2, Tian Liang2, Martin

Sauter3, Jawad Hassan4, Philippe Gouze5, and Kristina Rasmusson2

2EWRE Ltd., Israel, 2Uppsala University, Sweden, 3University of Göttingen, Germany, 4 Al-Quds University, Palestine, 5 CNRS, France

TCCS-9, Trondheim - Norway.June 13-14, 2017.

CO2GeoNet 2017, May 8-10, 2017

CO2GeoNet 2017, May 8-10, 2017

San


T TRUST1. Objectives of TRUST• Contribute to process understanding via a series of small scale highly

controlled CO2 injection experiments, including:• Trapping mechanisms (dissolution and residual trapping);• impurities (geochemical and physical);• Impact of heterogeneity;

• Test CO2 injection strategies:• “Hot” injection versus “cold” injection;• Injection of “trapped” (dissolved) CO2;• Alternating CO2 and formation brine to enhance trapping.

• CO2 Leakage detection.• Use and extensive portfolio of MMV (Measurement, Monitoring

and Validation) technologies:• Downhole P/T monitoring at different vertical levels (as of now 2);• P/T monitoring above the ground (from the CO2 tank to the

wellhead);• Distributed temperature sensing via optic fiber;• Downhole fluid sampling and onsite characterization;• Seismic monitoring.


T TRUSTHeletz

wells for CO2injection experiments

Heletz North

• Scientifically motivated CO2injection experiment site;

• Deep – allows storage of scCO2• Static pressure of 143 bar and

temperature of 64 C.• Low concentration brine (35,000

ppm Cl/l)

2. Heletz deep CO2injection experiment site


T TRUSTHeletz wells: Deep injection and monitoring and shallow seismic.


T TRUST

• Data from oil exploration wells was collected and re-analyzed;• Geological structure and regional values of hydraulic parameters

(porosity/permeability) are relatively well known;• Surface and borehole geophysics;• Geological characterization;• Hydraulic testing on cores and in-situ;• Mineralogy;• Two-phase flow CO2-Brine properties;• Rock-mechanical properties;• Thermal properties.

3. Extensive site characterization

Special Edition of International Journal of Greenhouse Gas Control Niemi,Gouze, Bensabat (eds.); Volume 48, Part 1, Pages 1-186, May, 2016 Characterization offormation properties for geological storage of CO2 – Experiences from the Heletz CO2injection site and other example sites from the EU FP7 project MUSTANG

Niemi, A. Bensabat, J, Shtivelman, V, Edlmann, K, Gouze, P., Luquot, L., Hingerl,F, Benson,S.M., Pezard, P.A, Rasmusson, K., Liang,T., Fagerlund, F., Gendler, M., Goldberg,I,Tatomir,A., Lange, T., Sauter, M., and Freifeld, B. (2016) Heletz experimental siteoverview, characterization and data analysis for CO2 injection and geological storageInt. J. of Greenhouse Gas Control.Vol 48; Pp 3-23. May 2016.


T TRUSTPermeability and porosity


T TRUSTData from old oil wells for the entire region gave a good basis, locally refined based on data from the new wells

Niemi, A. et al (2016) Heletz experimental site overview, characterization and data analysis FOr CO2 injection and geological storage. int. J. of Greenhouse Gas Control. Vol 48; Pp: 3-23.


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Edlmann. et al (2016) Int. J. of Greenhouse Gas Control. Vol 48, PP. 94-104. May 2016

Hingerl. et al (2016) Int. J. of Greenhouse Gas Control. Vol 48, PP. 69-83. May 2016.

Two-phase CO2-Brine properties


T TRUST3. Wells Completion and site preparation for CO2 injection


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Coriolis Flow Meter

CO2 Tank CO2 pump skid (booster + 2 pumps)

CO2 system


T TRUSTCO2 system

CO2 heater CO2 tank, heater and wellhead


T TRUSTOnsite laboratory

Density


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Evolution of the role of varioustrapping mechanisms with time

Residual trapped zone left behindthe mobile CO2 rich phase

(IPCC, 2005)Erlström et al, 2011, Swedish Geological Survey Report 131.

Residual trapping: key CO2 trapping mechanism


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Otway, Australia experiment demonstrated that pressure signal was an effective measure for differentiating residual saturation of gas (Sgr)

injection-withdrawal of scCO2 and brine

zone of residual trapped scCO2

Hydraulic tests Thermal tests Tracer tests

Estimate of residual trappingwhen performed with and withoutresidual CO2

Paterson et al, 2011. CO2CRC report RPT11-3158

How to measure residual trapping in the field ?

First we need to create a zone with residual saturation in the field


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injection-withdrawal of scCO2 and brine

zone of residual trapped scCO2

1 Rasmusson et al (2014) Analysis of alternative designs for push –pull …Int. J. of Greenhouse Gas Control. Vol 27, pp 155-168

Option 1: Inject CO2, then inject water to push the CO2 further and leave the residual zone behind

Option 2: Inject CO2, then pump it back and leave the residual zone behind

Option 2 was implemented, the achievement of residual zone was followed by evolution (i) tracers1 and (ii) pressure difference in the injection/withdrawal test.

Creating the residually trapped zone


T TRUSTHow to measure field scale dissolved CO2 ?

Inj In Inj OutBall valve

N₂ Drive (In)

Sample (Out)

Gravitational check valve(Ball that stops the flow)

BoreholeP= 145 bar (2103 psi)

Z=0 ground

Z=1640 m

Wellhead

(1)&(3) P= 220 bar (3200 psi)(2) P= 1 atm

P=1 atm

WaterZ=200 m water level

U-tube


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(d)

(e)

(b)(a)

Low pressure High pressurepH (a) Conductivity (d)Temperature (a) pH (e)Conductivity (a) Scaling vessel (density) (f)Alkalinity (b) Temperature (g)Gas composition (QMS) (c) Gas partial pressure (GPM) (h)

(h),(g)

(c)

(f)


T TRUSTCO2 Leakage detection

Injection wellZ(z=0 wellhead)= 8, 303, 357, 371 m


T TRUST4. The first experiment • Determine field-scale values of two key trapping mechanisms: dissolution and

residual – capillary trapping.• The experimental sequence comprised the following phases:

• Heating of the formation;• Two hydraulic tests;• Injection of formation water (previously produced and stored) with

tracers. • CO2 injection;• Pressure relief;• Production until free CO2 is removed.• Hydraulic test.• P/T was continuously monitored and recorded. • CO2 mass flowrate, temperature, pressure and density was recorded

during the production phase;• DTS was recorded during the entire sequence;• Downhole fluid sampling and measurement of high pressure pH and low

pressure alkalinity and gas composition, as well as measurement of partial pressure of CO2 were measured during the production phase.


T TRUSTHeletz site – push-pull residual saturation test


T TRUSTDuring the experiment

Auli released pressure

CO2 release, pipes’ froze


T TRUSTDuring the experiment


T TRUSTMeasured pressure sequence at two different vertical levels


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09-09 09-11 09-13 09-15 09-17 09-19 09-21 09-23 09-25 09-27 09-29

date

0.5

1

1.5

2

2.5

3

3.5

Pres

sure

diff

eren

ce 7

6-78

[Pa]

10 5

Pressure difference


T TRUSTFirst estimate of the pressure response

simple analytical solution

0 5 10 15

Time [hr]

1.4

1.41

1.42

1.43

1.44

1.45

Pres

sure

[Pa]

10 7 k = 500 mD, cp

= 1.e-9 Pa-1

Sept 9, 2016

Sept 29, 2016

4.9 m 3 /hr

7.3 m 3 /hr

0 5 10 15

Time [hr]

1.4

1.41

1.42

1.43

1.44

1.45

Pres

sure

[Pa]

10 7 k = 735 mD, cp

= 1.e-9 Pa-1

Sept 9, 2016

Sept 29, 2016

4.9 m 3 /hr

7.3 m 3 /hr

Analytical solution with Theis, fit the hydraulic test data before and after creating the residual zone

The result indicates that there is very little effect of CO2, the difference in pressure decrease can be explained by the difference in pumping rate


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0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1

Sl

0

0.1

0.2

0.3

0.4

0.5

0.6

0.7

0.8

0.9

1

Kr g

Relative permeability curves

B-C krg Sg r 0.01 (Benson k rg )

B-C krg Sg r

0.2

B-C krg Sg r

0.1

Benson kr l

data-Drainage

data-Imbibition

Multiphase flow model – sensitivity to relative permeability function

Water saturationHingerl. et al (2016) Int. J. of Greenhouse Gas Control. Vol 48, PP. 69-83. May 2016.


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0 5 10 15 20 25

Time (days)

1.25

1.3

1.35

1.4

1.45

1.5

1.55

1.6

1.65

1.7

Pre

ssur

e [k

Pa]

10 4

Pressure at the bottom of the injection well

Comparing data and simulation with different residual gas saturation

data

Sg r

0.1

Sg r

0.2

Sg r

0.01

Comparison of model and measured data – effect of residual saturation


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5 10 15 20 25

-12

-10

-8

-6

-4

-2

Gas saturation before opening the well

Simulated CO2 saturation Sgr =0.01


T TRUSTSimulated CO2 saturation Sgr =0. 1

5 10 15 20 25

-12

-10

-8

-6

-4

-2

Gas saturation before opening the well


T TRUSTSimulated CO2 saturation Sgr =0.2

5 10 15 20 25

-12

-10

-8

-6

-4

-2

Gas saturation at the end of simulation


T TRUSTConclusions and next steps

Preliminary results analysis of a single-well push-pullexperiment to quantify residual saturation of CO2 has beenpresented. The results so far indicate low residual trappingNext steps• Inclusion of hysteresis in krl function (observed in core data)• Incorporating the detailed analysis of tracer data, pressure

information in the test interval and well hydraulics.• Effect of heterogeneity.• Effect of anisotropy.• A comparative push-pull test with different approach for

creating the residual zone and with additional referencetests is planned later on this year.


T TRUSTEspecially acknowledged co-

workers contributing to earlierphases of this work

Vladimir Shtivelman, GIILinda Luguot, CSIC

Philippe Pezard, CNRSKatriona Edlmann, UEDIN

Sally Benson, Stanford UniversityFerdinand Hingerl, Stanford University

Barry Freifeld, Class VI SolutionsJesus Carrera, CSIC

and all MUSTANG and TRUST partners

3rd Advanced Course on CO2 Sequestration in Deep Geological Formations

13-14 September 2017Barcelona, Spain

www.trustco2course.wordpress.comANALYTICAL – EXPERIMENTAL – NUMERICAL

Carbon Capture and Storage (CCS) is an expanding technique, with globally addressedscientific and technical challenges, aimed at reducing carbon dioxide in the atmosphere andthereby combatting the climate change.

This course will provide the participants with the current state of the art knowledgeconcerning some key scientific and technical issues related to CO2 sequestration in deep, brine-containing geological formations. The focus will be on the processes related to CO2 injection andstorage, spreading and trapping in the target formation, their mathematical andnumerical modelling as well as experimental characterization and monitoring. Expertswill lecture on site characterization and investigations of critical processes by laboratory studiesand field techniques, as well as on planning of experimental projects and monitoring techniquesaimed at verifying the conceptual models. Emphasis will be on understanding the flow andtransport mechanisms that provide the foundation for planning of full scale projects. Risk issuesand societal aspects will also be presented and discussed.

The course is organized by the European Commission FP7 TRUST project. The recently released text book “Geological Storage of CO2 in Deep Saline Formations” (Editors: Auli Niemi, Jacob Bear and Jacob Bensabat). Springer, 2017. will be used as background reading.


T TRUST

Thank [email protected]

first co injection experiment at heletz (israel): determination of … · 2017-07-13 · 2...

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