Home

EASiTool - User Manual - V2.0

1. ee ee ee ee ee eee EN ee ee ee ee ee a P d P d Well 1 3 7 9 F Well 2 4 6 8 t Well 5 U 5 10 15 20 T me Year anr Adan m LIM n kn fl IV J1 V d o9 CI Vici I c1 YE iJ WOU IVICAITIUCI V c j 22000 1 000 0 1 000 2 000 3 000 4 000 5 000 6 000 7 000 8 000 9 000 10 000 11 000 A amp 20000 Ev L Fe L 18000 S 20 074 V Ww a 20 060 D 5 20 047 16000 20 034 e X r8 20 020 c 14000 B 20 007 2 Well 1 4 13 16 amp 19 994 S 12000 A Well 2 3 5 8 9 12 13 16 l S 8 Well 6 7 10 11 c 19 967 F eni o 10 10000 Z 19 954 1 000 0 1 000 2 000 3 000 4 000 5 000 6 000 7 000 8 000 9 000 10 000 11 000 U 5 10 15 20 Time Year d 16 wells Figure 1 Pressure distributions and bottom hole pressures for the closed boundary condition after 20 years of constant injection at depth of 1000 m Figure 2 shows the pressure distributions and bottom hole pressures after 20 years of injection using the open boundary condition It is assumed that a 100 km reservoir is located at the center of a 10 000 km basin There is a slight difference between the final pressure from simulations and the final pressure of 20 MPa in EASiTool This difference decreases when more injectors are used Also the simulation results show that the effect of pressure reaches the boundaries of the basin at the end of injection process It means that the open boundary co
2. 9 000 18 726 I 000 0L 18 613 1 000 0 1 000 2 000 3 000 4 000 5 000 6 000 7 000 8 000 9 000 10 000 11 000 l f N l l l L L a 1 well l l I I 1 000 0 1 000 2 000 3 000 4 000 5 000 6 000 7 000 8 000 9 000 10 000 11 000 1 000 Q l I 000 7 20 024 3 000 l 19 993 19 963 19 932 000 t 5 000 19 902 19 871 T T 000 9 7 000 l l 19 840 19 810 DDD 9 19 779 9 000 19 749 19 718 I 000 QL 14 000 0 1 000 2 000 3 000 4 000 5 000 6 000 7 000 8 000 9 000 10 000 11 000 f f i 1 l 1 L L b 4 wells I I I I 1 000 0 1 000 2 000 3 000 4 000 5 000 6 000 7 000 8 000 9 000 10 000 11 000 1 000 Q l l 000 7 20 116 3 000 I 20 100 20 083 000 t 20 067 5 000 20 051 20 035 T T 000 9 20 019 7 000 l l 20 003 DDD 9 19 987 9 000 19 971 I 000 0L 19 954 1 000 0 1 000 2 000 3 000 4 000 5 000 6 000 7 000 8 000 9 000 10 000 11 000 f f N l I l L c 9 wells Bottomhole Pressure kPa Bottomhole Pressure kPa Bottomhole Pressure kPa 22000 20000 18000 16000 14000 12000 10000 22000 20000 18000 16000 14000 12000 10000 22000 20000 18000 16000 14000 12000 10000 Well 1 U 5 10 15 20 Time Year Well 1 2 3 4 U 5 10 15 20 Time Year a ee a 1 a
3. Capacity Mtones of CO2 0 100 200 300 Number of Injection Wells CO2 Plume Extension so nl er nenn ee 9999992990999 rrr t t t tt e t t t t 60 400 0 100 200 300 Number of Injection Wells 400 Wells Injection Rate tone day Y km Then click on the Well Injection Rate contour to see the value and coordinates of each well Main Interface S NZ an m v GULF COAST CARBON CENTER 1 RESERVOIR PARAMETERS Pressure MPa 10 Tempreture C 40 Thickness m 100 Salinity Kg mol 0 Porosity 0 2 2 RELATIVE PERMEABILITY Brooks Corey Residual Water Saturation 05 Residual Gas Saturation 04 m 3 w m 3 SIMULATION PARAMETERS Simulation Time years 20 Injection Well Radius m 04 Max Injection Pressure MPa 20 Estimate Max Injection Pressure Internally Density of Porous Media Kg m3 Total Stress Ratio V H Biot Coefficient Poisson s ratio Coefficient of Thermal Expansion 1 K Bottom Hole Temperature Drop K Young s Modulus GPa Depth m Estimated Max Injection Pressure MPa _ Sensitivity Analysis Slow Simulation Time sec 92 5 EASiToolGUl B a 1 WC 1 OONO Ic JACKSON DOLOGY EU ne 4 NPV Drilling Cost aR sp Tax Credit Stone 10 5 RESULT CONTROLS Number of Injection Wells 400 v Export Image Files Slow CASiToo C02 Geological Capacity Esti
4. 1 000 0 1 000 2 000 3 000 4 000 5 000 6 000 7 000 8 000 9 000 10 000 11 000 1 000 0 4 000 2 000 3 000 4 000 5 000 6 000 7 000 8 000 9 000 10 000 11 000 Lo o ro o e e S S S 3 40 097 S Eo ose S e e n 40 074 b S S gt 40 062 is L S L S 140 050 z e e S 40 039 3 ce Le L S 40 027 S n rn 40 015 b S S e e gt 140 003 a 40 026 S S gt iso 992 Eoo 15 B 39 980 S 40 010 1 000 0 KUR 2 000 3 000 A00 5 000 SR 7 000 8 000 990 19 009 11 000 1 000 0 dris 2 000 3 000 A0 5 000 6 000 7 000 8 000 SN 19 009 11 000 c 9 wells d 16 wells Figure 5 Pressure distribution for closed boundary condition after 20 years of constant injection at depth of 3000 m Va C L Nian es E l Q CI Van IA i l I 10 000 0 10 000 20 000 30 000 40 000 50 000 60 000 70 000 80 000 90 000100 000 10 000 0 10 000 20 000 30 000 40 000 50 000 60 000 70 000 80 000 90 000 100 000 LO o Ke D o e e L S L S S g amp 5 re J a 38 646 re ma 39 548 eo e a g 37 835 amp 38 693 3 3 L 37 025 5 37 837 e e e e 5 2 36 214 E 36 982 L S L S i 2 35 404 3 36 127 c a o LO d 2 34 593 2 35 272 e zi e a Z 33 782 L S 34 417 E B amp 32 972 amp 33 562 e e 8 8 g 32 161 g 32 706 31 351 31 851 B 30 540 rg 7 M30 996 10 000 0 19 009 20 000 30 000 A000 50 000 SD 70 000 90 000 90 000100 000 e 10 000 0 30 099 20 000 30 000 490 000 50 000 89 000 70 000 80 000 LO 100 000 1 L L L
5. WARNING This program is protected by copyright law and international treaties Copyright 1984 2014 The MathWorks Inc Protected by U S and other patents See MathWorks com patents lt Back Next gt Cancel MathWorks 2 1 99 EASiTool User Manual V2 0 Select Yes to accept the terms of license agreement Then click Next a License Agreement as The MathWorks Inc A MATLAB COMPILER RUNTIME MCR LIBRARIES LICENSE IMPORTANT NOTICE BY CLICKING THE YES BUTTON BELOW YOU ACCEPT THE TERMS OF THIS LICENSE IF YOU ARE NOT WILLING TO DO SO SELECT THE NO BUTTON AND THE INSTALLATION WILL BE ABORTED 1 LICENSE GRANT Subject to the restrictions below The MathWorks Inc MathWorks hereby grants to you whether you are an individual or an entity a license to install and use the MATLAB Compiler Runtime Libraries MCR solely and expressly for the purpose of running software created with the MATLAB Compiler the Application Software and for no other purpose This license is personal nonexclusive and nontransferable 2 LICENSE RESTRICTIONS You shall not modify or adapt the MCR for any reason You shall not disassemble decompile or reverse engineer the MCR You shall not alter or remove any proprietary or other legal notices on or in copies of the MCR Unless used to run Application Software you shall not rent lease or loan the MCR time share the MCR provide service bureau use or use the MCR for supporting an
6. Kim S and Hosseini S A 2014 Above zone pressure monitoring and geomechanical analyses for a field scale CO injection project in Cranfield MS Greenhouse Gases Science and Technology 4 1 81 98 King C W Gulen G Cohen S M and Nunez Lopez V 2013 The system wide economics of a carbon dioxide capture utilization and storage network Texas Gulf Coast with pure CO2 EOR flood Environmental Research Letters 8 034030 Mathias S A Gluyas J G Gonzalez Martinez de Miguel G J Bryant S L and Wilson D 2013 On relative permeability data uncertainty and CO injectivity estimation for brine aquifers International Journal of Greenhouse Gas Control 12 200 212 Mathias S A Gluyas J G Gonzalez Martinez de Miguel G J and Hosseini S A 2011 Role of partial miscibility on pressure buildup due to constant rate injection of CO into closed and open brine aquifers Water Resources Research 47 W12525 opycher N Pruess K and Ennis King J 2003 CO2 H20 mixtures in the geological sequestration of CO l Assessment and calculation of mutual solubilities from 12 to 100C and up to 600 bar Geochimica et Cosmochimica Acta 67 16 3015 3031 Tseng P H and Lee T C 1998 Numerical evaluation of exponential integral Theis well fuction approximation Journal of Hydrology 205 38 51 U S Geological Survey 2013 National Assessment of Geologic Carbon Dioxide Storage Resources Data h
7. kv 1 0 0 3 Gas end point relative permeability Krg Table 3 shows the simulation parameters It is assumed that the maximum allowable pressure in the reservoir should not be above 20 MPa after 20 years of injection with constant rates Table 3 Simulation Parameters Simulation time year 20 Injection well radius m 0 1 Maximum injection pressure MPa 20 The basin models were prepared for numerical simulation using CMG GEM for both boundary conditions The injection rates calculated by EASiTool were used in numerical simulation to compare the analytical and numerical results Figure 1 shows the pressure distributions throughout the reservoir and bottom hole pressures of all wells after 20 years of injection using 1 4 9 and 16 injectors The injection rates were calculated using the closed boundary condition of EASiTool The color legend shows the range of pressure throughout the reservoir at the time of 20 years It is observed that the maximum pressure in the reservoir is very close to the target pressure of 20 MPa The pressure distribution is more uniform by using more injectors The bottom hole pressure of all wells is very similar throughout the injection period I I I 1 000 0 1 000 2 000 3 000 4 000 5 000 6 000 7 000 8 000 9 000 10 000 11 000 1 000 0 l I 000 7 19 742 19 629 3 000 I 19 516 000 t 19 404 5 000 19 291 19 178 T 000 9 7 000 l l 19 065 18 952 DDD 9 18 839
8. 13 A 50 o o O O 12 0 0 20 40 60 80 100 0 20 40 60 80 100 Number of Injectors Number of Injectors Figure 3 CO capacity for 20 years of injection Figure 4 CO2 capacity for 20 years of injection versus number of injectors using closed boundary versus number of injectors using open boundary condition at depth of 1000 m condition at depth of 1000 m The same comparative study was performed for a reservoir at a depth of 3000 m The initial temperature and pressure in this study were 90 C and 30 MPa respectively It was assumed that the maximum pressure in the reservoir would be 40 MPa after 20 years of injection Figures 5 and 6 show the final pressure distribution obtained by simulation Again the results of the closed boundary case are closer to the results of EASiTool than are the results of the open boundary case l l I I I 1 000 0 1 000 2 000 3 000 4 000 5 000 6 000 7 000 8 000 9 000 10 000 11 000 1 000 0 1 000 2 000 3 000 4 000 5 000 6 000 7 000 8 000 9 000 10 000 11 000 Lo o ro o e ce S L S N D 8 40 019 2 40 165 S o 926 S Wo 141 e o L 39 832 n S 8 439 739 s 39 646 z E E s 39 552 3 ce o gt L S 039459 L B 74 n b 39 366 b e e 3 3 gt 39 272 gt S S an 179 z amp 15 S 39 086 B 39 925 1 000 0 300 2 000 3 000 4209 5 000 SER 7 000 8 000 000 19009 11 000 1 000 0 1 000 2 000 3 000 Rial 5 000 BER 7 000 8 000 san is 10 009 11 000 1 1 L L L 1 1 L L a 1 well b 4 wells
9. L 1 L L L a 1 well b 4 wells 10 000 0 40 000 20 000 30 000 40 000 50 000 60 000 70 000 80 000 90 000100 000 10 000 0 40 000 20 000 30 000 40 000 50 000 60 000 70 000 80 000 90 000 100 000 o D o o e e L S L S S g 3 re J a 40 163 re gm 40 231 o e a 3 39 275 S 3 F b 38 386 5 e e e e E e 37 497 a L S L al 2 36 609 2 8 2 35 720 re 7 e e e a e e 34 832 L S R F 5 33 943 amp 3 S eo B 33 054 g 32 166 l 32 304 E 3 J S 31 277 31 424 10 000 0 19 009 20 000 30 000 A000 50 000 DR 70 000 sini 90 000100 000 e 10 000 0 19 090 20 000 30 000 0 000 50 000 0 000 70 000 80 000 90 000190 000 1 L 1 1 L i L L L c 9 wells d 16 wells Figure 6 Pressure distribution for open boundary condition after 20 years of constant injection at depth of 3000 m Figures 7 and 8 show the maximum capacity for closed and open boundary problems versus the number of injectors It is observed that the open boundary reservoirs have a much larger storage capacity 18 300 o uo 5 o 17 K 250 c c 9 2 3 16 200 G 15 S 150 e a o O O en 14 amp 100 E g g 43 50 o o O O 12 0 0 20 40 60 80 100 0 20 40 60 80 100 Number of Injectors Number of Injectors Figure 7 CO2 capacity for 20 years of injection Figure 8 CO2 capacity for 20 years of injection versus number of injectors using closed boundary versus number of injectors using open boundary condition at depth of 3000 m condition at dept
10. MtCO NPV M CO2 Plume Extension Graphical map view and Well Injection Rate tonne day In the orange Results Controls box check the Export Image Files Slow to save the graphical results at the location where the installation folder was installed 20 35 EASiTool User Manual V2 0 To look at the values press the Data Cursor icon in the upper tab F Main Interfpeen m mm Na Es A ru GULF COAST CARBON CENTER 1 RESERVOIR PARAMETERS Pressure MPa 10 Tempreture C 40 Thickness m 100 Salinity frenet 0 Porosity 0 2 Permeability mD 100 Rock Compressib ty 1 P3 5e 10 Reservoir Area km2 100 2 RELATIVE PERMEABILITY Brooks Corey Residual Water Saturaton 0 5 Residual Gas Saturation 01 m 3 3 SIMULATION PARAMETERS Simulaton Time years 20 Injection Well Radius m 01 Max Injection Pressure MPa Estimate Max Injection Pressure Internally Density of Porous Media Kg m3 Total Stress Ratio V H Biot Coefficient Poisson s ratio Coefficient of Thermal Expansion 1 K Bottom Hole Temperature Drop K Young s Modulus GPa Depth m Estimated Max Injection Pressure MPa _ Sensitivity Analysis Stow Run Simulation Time sec 92 5 gt BUREAU OF FEONOMIC DOLOGY EASIToolGUI JACKSON 5 RESULT CONTROLS Number of Injection Wells 400 v _ Export Image Files Slow C ASiTool CO2 Geological Capacity Estimation
11. m Sar Sensitivity Analysis Slow Vitour webste Saliniy Permeability n Krad L Temperature ressure cx 13 14 15 CO2 Geological Capacity Estimation 16 17 18 19 Capacity Simulation Time sec 25 6 The tornado chart on the lower right hand side shows the impact of each parameter on the total capacity On this chart the parameters are listed downward from the highest direct impact to the highest inverse impact 23 35 Examples and Verifications Table 1 summarizes the input for the EASiTool template The aquifer is located at a depth of 1000 m In this study the problem was solved for closed and open boundary conditions The basin area is the same as the reservoir area for the case of the closed boundary condition The basin area is 10 000 km for the case of the open boundary condition Table 1 Template Input Initial pressure MPa 10 Initial temperature C 40 Thickness m 100 Salinity kg mol 0 Porosity 0 2 Permeability mD 100 Rock compressibility 1 Pa 5 0E 10 Reservoir area km 100 Basin area km 100 or 10000 Boundary Condition Closed or Open Table 2 summarizes the relative permeability parameters used in the Brooks Corey model for a two phase flow of gas and aqueous phases Table 2 Relative Permeability Parameters for Brooks Corey Model Residual water saturation wr 0 5 Residual gas saturation Sgr 0 1 Water exponent 3 0 Gas exponent l 3 0 Water end point relative permeability
12. 0 0 and lt 0 9999 Residual gas saturation Sgr 2 0 0 and s 0 9999 Water relative permeability Corey exponent m lt 1 0 Gas relative permeability Corey exponent n lt 1 0 Water end point relative permeability KraO 2 0 0 and s 1 0 Gas end point relative permeability KrgO 2 0 0 and s 1 0 13 35 EASiTool User Manual V2 0 Typical range of relative permeability parameters based on data published in literature is listed in the table below Residual water saturation Sar 0 2 0 6 Residual gas saturation Sgr 0 1 0 35 Water relative permeability Corey exponent m 1 5 4 0 Gas relative permeability Corey exponent n 1 5 4 0 Water end point relative permeability KraO 1 0 Gas end point relative permeability KrgO 0 1 0 6 3 Simulation Parameters Section 3 has three input parameters for simulation simulation time years injection well radius m and maximum injection pressure MPa r EASiToolGUI n Main Interface rn w L M A A Pu ue GULF COAST CARBON CENTER Economic JACKSON oe Fe eye LO eons CASiToo CO2 Geological Capacity Estimation The maximum acceptable injection well radius is 1 0 m The maximum injection pressure should also be larger than the initial pressure and smaller than three times the initial pressure 14 35 Geomechanics Package The new version of EASiTool can calculate the maximum allowable injection pressure internally from the reservoir properties To include t
13. 829 Mad oe a 17500 a L 17 899 Pn S Pa gt 2 16 969 2 4 p Rans g 15000 y Well 1 3 7 9 o gt o y j E S 15 109 9 Well 2 4 6 8 2 2 B o 12500 Wellit 5 ca amp 13 248 8 man 10000 s U 5 10 15 20 8 Time Year 8 10 458 s 710 000 0 19 009 20 000 30 000 RR 50 000 BR 70 000 90 000 90 000100 000 i c 9 wells Lp r 34 25000 10 000 0 10 000 20 000 30 000 40 000 50 000 60 000 70 000 80 000 90 000 100 000 L S amp 22500 G x E J gm 19 877 R 2 5 20000 S 118 937 a 7 un a 17 998 w e S a e a 17 058 1 500 L S vo R 16 119 o E i E 15 180 c 15000 d a j L a DIETS 9 Well 1 4 13 16 m amp o gt S 13 001 cea 12500 Well 2 3 5 8 9 12 13 16 8 2 12 361 Well 6 7 10 11 in 11 422 LS J 10000 2 10 483 2 10 000 10 000 20 000 30 000 40 000 50 000 60 000 70 000 80 000 90 000100 000 U 5 10 15 20 Time Year d 16 wells Figure 2 Pressure distributions and bottom hole pressures for open boundary condition after 20 years of constant injection at depth of 1000 m Figures 3 and 4 show the maximum capacity for closed and open boundary problems versus the number of injectors It is observed that the open boundary reservoirs have a much larger storage capacity The storage capacity of reservoirs becomes constant after a specific number of injectors 18 300 un o c c 17 Z 250 c c 9 9 3 16 200 E G 15 S 150 a a o o O O en 14 amp 100 2 2 A
14. EASITOO V2 0 User Manual Table of Contents MO do s Tesis earnan nea ERBE BEHFEBEEEFEFEREREPOREEFCEELUOSEERPEEEHELHELTEEPEENESEEEEUFETTEERFPURBERLERCUESEERDER 3 YVES v WE 3 EIZ sll STATE T d System Requirements sss sss ss sss sss sss sss sss ssa un un un un un En nanna nanna naaa aana n d PE SEAS ING ern i 4 Input Pal amiel el S a a nn een 8 1 Reservoir Parameters anne 8 2 Relative Permeability Parameters sese ee eee ee eee ee e eee eee 13 3 Simulation Paramet EiS ae a era een 14 e VIE eU 18 Running the Simulation sss eee ee ee eee ee eee 19 TUES scat E L 20 1 Optimal Constant Injecti n Rate aan 20 2 oensltiviE ne SI Sa ee Ta en 23 Examples and Verifications u2zs2u2s2n0nnnnnnnnn nn nn nn nn nn nn nn nn nun nn nn nun nn nn nn nn nn nun nnne ann nenne 24 AL Le 34 Bo gc ERINNERN RI BIENEN OE 35 Introduction Welcome to the second released version of EASiTool Enhanced Analytical Simulation Tool developed for CO storage capacity estimation and uncertainty quantification This User Manual will help you install and use EASITool EASiTool is intended to help users achieve a fast reliable science based estimate of storage capacity for any geological formation containing brine EASiTool which provides strategies for optimizing a project s net present value NPV offers three major features e An advanced closed f
15. H a Ww e Ww e Lu e Ln S un e Lun e Ww e Ta e Lun LE N C eo eo lt wy Ww LD LD m m CO CO Mean Permeability of Porouse Interval K mD 12 35 L e e 9 100 EASiTool User Manual V2 0 2 Relative Permeability Parameters Section 2 allows input of parameters for relative permeability including residual saturation of brine Sar critical gas saturation Sgc end point relative permeability for aqueous phase krao end point relative permeability for gas phase krgo and power law exponents for the aqueous and gas phases mand n This section includes equations for relative permeability calculations from the Brooks Corey model 5a Sar m l Sa Sir gt 1 S ar EN 5 zi F iL oC ar D s I F n Kai 3839 _ 5 s Mnt gt u a De A P EASiToolGUI 5 l x ka 2 BUREAU Ol GULF COAST CARBON CENTER Economic JACKSON DOLOGY PETITUM 3 SIMULATION PARAM Sendiaton Time years 20 injection Wet Radius m 01 Max Injection Pressure MPa 20 __ Estimate Max Injection Pressure Internally Density of Porous Media Kg m3 Total Stress Ratio V H Biot Coefficient Poisson s ratio Coefficient of Thermal Expansion 1 K Bottom Hole Temperature Drop K Young s Modulus GPs Depth m CASiToo C02 Geological Capacity Estimation The following table shows the range of relative permeability parameters that are accepted by EASiTool Residual water saturation Sar 2
16. User Manual V2 0 FREQUENCY 14 12 10 6 Ee 4 as 2 es 0 Formation Pressure P MPa B DOE nn oo e OH oa vr 00 a S da a st ww e o Ss aS d eS na m m nm m mn Mm FREQUENCY 20 18 16 14 12 10 6 as 4 as 2 as 0 mono M G wn S BY EB RES N NN MO rm S NAN W WB Pe Pe DOO o in m Mean Formation Temperature T C 10 35 in La ei eo N m Ww N La m DOE 130 135 140 145 150 FREQUENCY FREQUENCY 25 20 15 10 5 0 16 14 12 10 6 4 2 as 0 EASiTool User Manual V2 0 m DOE C LD CO e C LD CO e N LD CO e LD CO e oO e e e e 4 e ed vd j j N j N en en en en Salinity mol kg m DOE m USGS TIN lu 388 2822338 38382883 SH ERS EEE BES EN SSR SS B S Mean Thickness h m 11 35 FREQUENCY FREQUENCY 0 20 0 18 0 16 0 14 0 12 0 10 0 08 0 06 0 0 I 50 45 40 35 30 25 20 15 10 5 0 EASiTool User Manual V2 0 m DOE m USGS NMOrFmMmUwUonrWOHoOoaANmMA uu D Fr 00 01 QO e cx e t 4 r 000 QO e cC MN TWH oOo o OO O O ci ei cei cei ei ei e e 4 C41 C4 C C CV C C C C cO e en en en en Go ooo d ood cood dooodod d odod dcod d d od o d o od o c sG Porosity d B DOE E USGS u d nu m
17. ent value NPV analysis along with the simulation Here you can input parameters such as Drilling Cost million well Operation Cost kilo well year Monitoring Cost kilo year km and Tax Credit tonne r EASiToolGUI 7 E Main Interface ff A MAAS GULF COAST CARBON CENTER A om JACKSON CASiTool The following table shows the range of NPV parameters that are accepted by EASiTool Drilling Cost 2 0 0001 million well Operation Cost gt 0 0001 kilo well year Monitoring Cost 2 0 0001 kilo year km Tax Credit 2 0 0 tonne 18 35 EASiTool User Manual V2 0 Running the Simulation To run the simulation click Run in the EASiTool interface A progress bar pops up showing the percentage of the progress in calculations LZ Main Interface am d v dc 38 GULF COAST CARBON CENTER EASiToolGUI 1 RESERVOIR PARAMETERS 3 SIMULATION PARAMETERS Simulation Time years 20 Pressure MPa 10 Injection Well Radius m 01 Tempreture C 40 Max Injection Pressure MPs E 20 Thickness m 100 _ Estimate Max Injection Pressure Internally Salinity Kg mol 0 Density of Porous Media Kg m3 Total Stress Ratio V H Permeab ty mD 100 Biot Coefficient Rock Compressibility 1 Pa 5e 10 Poisson s ratio Reservoir Area km 2 100 Basin Area km 2 100 Coefficient of Thermal Expansion 1 K Bottom Hole Temperature Drop K Young s Modulus GPa Depth m Estimated Max I
18. eservoir heterogeneity on the EASiTool estimations was studied The same anticline in Figure 9 was used for reservoir simulation with the average properties and simulation parameters of Tables 4 and 5 Two realizations for permeability distribution were prepared with Petrel Figures 10 and 11 show the histograms of the two realizations The second model is more heterogeneous ZEBNBTCTEUDPEISESESIUISEISETUTESIST 0001 0 01 0 1 1 10 100 1000 10000 3 Permeability X EASiTool Figure 10 Histogram of permeability for first realization EEE EBIBZID ES E23 EZ E BEI 92 E24 UIT 0 001 0 01 0 1 1 10 100 1000 10000 EJPemesbilty X EASiTool2 Figure 11 Histogram of permeability for second realization 31 35 EASiTool User Manual V2 0 Figures 12 and 13 show the permeability distributions of the respective models The estimated injection rates by EASiTool were used as input for reservoir simulation for both models 10 000 00 2 734 71 147 90 204 53 99 94 15 30 4 18 1 14 0 31 0 09 Figure 12 Permeability distribution for first realization 0 02 10 000 000 1 584 894 291 199 39 811 6 310 1 000 0 158 0 025 0 004 0 001 0 000 Figure 13 Permeability distribution for second realization 32 35 EASiTool User Manual V2 0 Figures 14 and 15 show the pressure distribution in the reservoir after 20 years of injection with 16 injectors The simulation predicts the maximum pressure o
19. ess 1 Kn Kn is coefficient of lateral stress or lateral stress ratio on ov Biot Coefficient a The effective stress principle is of fundamental significance in soil and rock mechanics and is defined as Oeff Oc Op where Oc and op are the total confining stress and fluid pore pressure respectively However in fluid saturated rocks Terzaghi s effective stress principle may not be always valid The Biot coefficient a other than unity was suggested to modify the effective stress principle Biot 1941 which is given by oett Oc a Op Ihe Biot coefficient a is a property of a solid constituent only The existence of the Biot coefficient suggests that pore pressure modifies not only effective normal stresses but also effective shear stresses Note p lt a lt 1 where o is porosity a will be near its upper limit for soil like materials Poisson s Ratio v An elastic constant that is a measure of the compressibility of material perpendicular to applied stress i e the ratio of latitudinal to longitudinal strain 0 v 0 5 Poisson s ratio can be expressed in terms of properties that can be measured in the field including velocities of P waves and S waves Approximate Poisson s ratio for carbonate rocks Is 0 3 for sandstones 0 2 and for shale above 0 3 Coefficient of Thermal Expansion 1 K The coefficient of thermal expansion describes how the size of an object changes with a change in temperature Specifically it meas
20. f 25 07 and 25 51 MPa respectively which are very close to the target pressure of 25 MPa 25 074 24 988 24 902 24 816 24 731 24 645 24 559 24 473 24 387 24 301 24 215 Figure 14 Pressure distribution for first realization 25 514 25 406 25 297 25 188 25 079 24 970 24 862 24 753 24 644 24 535 24 427 Figure 15 Pressure distribution for second realization 33 35 References Azizi E and Cinar Y 2013 A new mathematical model for predicting CO injectivity Energy Procedia 37 3250 3258 Azizi E and Cinar Y 2013 Approximate analytical solutions for CO injectivity into saline formations SPE Reservoir Evaluation amp Engineering 16 2 123 133 Bachu S and Bennion B 2008 Effects of in situ conditions on relative permeability characteristics of CO2 brine systems Environmental Geology 54 8 1707 1722 Duan Z and Sun R 2003 An improved model calculating CO solubility in pure water and aqueous NaCl solutions from 273 to 533 K and from 0 to 2000 bar Chemical Geology 193 257 271 Hosseini S A Mathias S A and Javadpour F 2012 Analytical model for CO injection into brine aquifers containing residual CH4 Transport in Porous Media 94 795 815 Kim S and Hosseini S A 2014 Geological CO storage Incorporation of pore pressure stress coupling and thermal effects to determine maximum sustainable pressure limit Energy Procedia 63 3339 3346
21. h of 3000 m EASiTool User Manual V2 0 EASITool assumes that the reservoir is square flat and horizontal The effect of reservoir shape and structure on the EASiTool estimations was studied An anticline model was used for reservoir simulation with the average properties of the reservoir used as input for EASiTool Estimated injection rates by EASiTool were also used as input for reservoir simulation Tables 4 and 5 show the average properties of the anticline reservoir and the simulation parameters Figure 9 shows the pressure distribution in the reservoir after 10 years of injection with 16 injectors The simulation predicts the maximum pressure of 24 07 MPa which is very close to the target pressure of 25 MPa Table 4 Properties of Anticline Reservoir Reference pressure MPa 16 55 Reference depth m 1750 Initial temperature C 40 Average thickness m 24 39 Salinity kg mol 0 Porosity 0 2 Permeability mD 100 Rock compressibility 1 Pa 5 0E 10 Reservoir area km 42 87 Basin area km 42 87 Boundary Condition Closed Table 5 Simulation Parameters Simulation time year 20 Injection well radius m 0 1 Maximum injection pressure MPa 25 24 072 23 993 23 914 23 836 23 757 23 678 23 599 23 520 23 441 23 363 23 284 Figure 9 Pressure distribution after 20 years of injection with 16 injectors CLO 2 C1 EASiTool User Manual V2 0 EASiTool assumes that the reservoir is homogeneous The effect of r
22. he geomechanics check Estimate Max Injection Pressure Internally Then in the new boxes provide the following properties to estimate the maximum injection pressure P EASiToolGUI E Main Interface ey a P 3 n BUREAU OF r GULF COAST CARBON CENTER ECONOMIC JACKSON DOLOGY BE OF SEGEDE 1 RESERVOIR PARAMETERS 3 SIMULATION PARAMETERS 4 NPV Simulation Time years 20 Driling Cost Pressure MP3 10 v 1 injection We Radius Tempreture C 40 0 1 Operation Cost KS well year 00 Max Injection Pressure MP3 Thickness m 00 Ahaus Monitoring Cost KS year kem 2 V Estimate Max injection Pressure internally Tax Credit Stone 10 Density of Porous Media Kg m3 2200 Total Stress Ratio V H 0 65 Biot Coefficient 0 95 Poisson s ratio 0 25 C Export Image Files Siow Bottom Hole Temperature Drop K Young s Modulus GPa 10 2 RELATIVE PERMEABILITY Brooks Corey Depth m 1200 L L L L L L L L L L L L L I Coefficient of Thermal Expansion 1K 0 00001 L L L L L i I I i Estimated Max Injection Pressure MPa I c LE CASiToo Simulation Time sec C02 Geological Capacity Estimation Density of Porous Media p kg m Density of porous media can be calculated as p pa 1 9 pr where is porosity pris fluid density and pais dried density of the matrix Total Stress Ratio V H The ratio of vertical to horizontal str
23. in the 5 Result Controls Number of Injection Wells section click on the location of all four wells on the Well Injection Rate plot The pop up boxes provide the injection rate tonne day corresponding to these four wells that is 509 8 tonne day for the 1 well 509 8 tonne day for the 2 well 509 8 tonne day for the 3 well and 509 8 tonne day for the 4 well The rate of all four wells is similar as a result of symmetry Optimal constant injection rate This procedure guarantees that nonidentical constant injection rates are calculated optimally at each well to meet the maximum pressure limit at the end of simulation time For example if the pressure limit is selected to be 20 MPa for a 20 year simulation then the program will calculate injection rates for all wells so that the bottom hole pressure of the wells will increase by 20 MPa at the end of 20 years 221 05 EASiTool User Manual V2 0 2 Sensitivity Analysis After completing a simulation with sensitivity analysis you can see the results on the right hand side of the window P EASiToolGUI 5 Main Interface QS E B A N GULF COAST CARBON CENTER WP saz JACKSON 8 DOLOGY Kr rat YT KET ECE v S gt 8 a co o 0 10 20 30 0 10 20 30 Number of Injection Wells Number of Injection Wells CO2 Plume Extension Wells Injection Rate tone day 10 km Porosity Thickness Rock Comp Krg0 Estimated Max Injection Pressure MPa
24. jection Wells CO2 Plume Extension e99996999690996559999 5 eoctcocc009000000090259 9l eeocttiiciiiitiiiivnosdn gieeeeeeecececcccecoos BRE SULT CONTROLS meeoreeeeoeoevr eee H H H es eeoreereereoeoeeeeeeeoe oo 1 wor rer re Number of Injection Wells 400 iw Ger eres seeoverere e Pee worte wor Herren 2 worte re ka Export Image Files Stow gt Alecsceotoosccetiooson et 9 99 9929259 9 99 9 pie PT See CRT T See eT see eee ee ee ees nn rer Meeccccccccccccceccns ASiTool C02 Geological Capacity Estimation 19 35 km 0 100 200 300 400 Number of Injection Wells Wells Injection Rate tone day 0 EASiTool User Manual V2 0 Outputs This section provides information on how to evaluate the outputs of EASiTool 1 Optimal Constant Injection Rate After completing a simulation you can see the results on the right hand side of the window P EASiToolGUI BEN Main Interface T MAAGS DLOLOGY j BUREAU OF KAU GULF COAST CARBON CENTER Economic JACKSON Capacity Mtones of CO2 60 0 100 200 300 400 0 100 200 300 400 Number of Injection Wells Number of Injection Wells CO2 Plume Extension Wells Injection Rate tone day 10 km T Coefficient of Thermal Expansion 1 K Bottom Hole Temperature Drop K Young s Modulus GPa Depth m CASiToo The results include the Storage Capacity
25. mation 21 35 Capacity Mtones of CO2 km 0 100 200 300 Number of Injection Wells CO2 Plume Extension 2 0 9 9 8 80H HH TT LR B HH H H eee Nm 0 100 200 300 Number of Injection Wells 400 Wells Injection Rate tone day EASiTool User Manual V2 0 The number of injection wells can be changed by clicking on the drop down menu for Number of Injection Wells P EASIToolGUI o x Main Interface vios gt Md a BUREAU OF GULF COAST CARBON CENTER saz JACKSON DOLOGY Capacity Mtones of CO2 1 4 0 100 200 300 400 0 100 200 300 400 Number of Injection Wells Number of Injection Wells CO2 Plume Extension Wells Injection Rate tone day 10 km Rock Compressibility 1 Pa Se 10 Reservoir Area km 2 100 Basin Area km 2 100 Coefficient of Thermal Expansion 1 K Bottom Hole Temperature Drop K Young s Modulus GPa Depth m Estimated Max Injection Pressure MPs Sensitivity Analysis Slow GASIT CO2 Geological Capacity Estimation Simulation Time sec 90 9 The total CO storage capacity and NPV of the simulated scenario based on number of injection wells can be viewed by clicking on the circles of the Capacity and NPV plots The Zoom In and Zoom Out options can be used to focus on the output figures To interpret the results from figures For example for the scenario of a total of four wells refer to the drop down menu
26. ndition is not accurate for a 20 year process 25000 10 000 0 10 000 20 000 30 000 40 000 50 000 60 000 70 000 80 000 80 000100 000 o o CL S 22500 i S vo b X 3 20000 ee a a E 20000 om e u NEN uu E n an S B 402 ad a a n iex s 17500 8 2 15 826 E5039 15000 o gt 8 14 251 9 2 12500 Well 1 S 13 464 L amp i 12 676 S 10000 2 11 888 F S zn U 5 10 l 15 20 3 Time Yeat E 10 313 s 710 000 0 19 009 20 000 30 000 A000 50 000 BR 70 000 90 000 90 000100 000 i a 1 well 25000 10 000 0 10 000 20 000 30 000 40 000 50 000 60 000 70 000 80 000 90 000 100 000 ro O a x 22500 g KH G i I J000 Lan pnn eon pn pe oi m n G n a iis cj gn b a ee ee LS 1 135 7 20000 gin po 5 Li a 18 262 g a iu 17500 I e 16 516 L S 15000 2 d Wang Well 1 2 3 4 r8 sus E 42500 a 2 o S aeos L 8 13 025 8 10000 2 12 152 S gni U 5 10 15 20 g Time Year B 10 406 10 000 0 10 000 20 000 30 000 40 000 50 000 60 000 70 000 80 000 90 000190 000 1 1 1 L l h 1 L b 4 wells enr Nissan e V CA VIAT gt VA intl M lel 1 Ci V out IVIGIIUCI N 25000 10 000 0 10 000 20 000 30 000 40 000 50 000 60 000 70 000 80 000 80 000100 000 La o a x 22500 L S T x i S J3 J0000 nnm e m n mn d mn n mn a a LS 19760 E 20000 o 5 v ae S 18
27. ness m porosity permeability mD rock compressibility 1 Pa reservoir area km 2 basin area km 2 and boundary condition as shown in Section 1 at the top left hand side of the input screen Note Currently we only accept one set of fixed units if units are different from what is shown on the interface they have to be converted first EASiToolGUI GULF COAST CARBON CENTER Bureau ce JACKSON ECOLOGY 3 SIMULATION PARAMETERS Simulation Time years 20 Injection Wel Radus m Max Injection Pressure MPa Estimate Max Injection Pressure Internally Density of Porous Media Kgim2 Total Stress Ratio V H Biot Coefficient Poisson s ratio Coefficient of Thermal Expansion 1 K Bottom Hole Temperature Drop K Young s Modulus GPa 2 RELATIVE PERMEABILITY Brooks Corey Depth m Residual Water Saturation 05 Estimated Max Injection Pressure MPa Residual Gas Saturation 01 Sensitivity Analysis Slow Simulation Time sec CASiToo C02 Geological Capacity Estimation Reservoir Area km 2 A reservoir is a part of the basin in which injectors are distributed In the current version we assume that reservoirs do not include detailed structures or dip angles We also assume that reservoirs are square and placed at the center of the basins Basin Area km 2 A basin is the whole areal extent of the storage formation in which the reservoir of our interest is loca
28. njection Pressure MPa _ Sensitivity Analysis Slow Run L Simulation Time sec Burs Besse JACKSON DOLOGY nm m 4 NPV Drilling Cost R Operation Cost KS wellyear 500 Monitoring Cost KS year km 2 m Tax Credit S tone 10 5 RESULT CONTROLS Number of Injection Wale El calculation in prog 25 complete Please wait EN gt _ Export Image Fi ASiTool CO2 Geological Capacity Estimation The simulation results will appear on the right side of the controller window to inform you that the simulation is complete E lt Main Interface im vl v do GULF COAST CARBON CENTER 1 RESERVOIR PARAMETERS 3 SIMULATION PARAMETERS Simulation Time years 20 Pressure MPa 10 Injection Well Radius m 04 Max Injection Pressure MPa 20 Estimate Max Injection Pressure Internally Density of Porous Media Kg m3 Total Stress Ratio V H Biot Coefficient Poisson s ratio Coefficient of Thermal Expansion 1 K Bottom Hole Temperature Drop K Young s Modulus GPa 2 RELATIVE PERMEABILITY Brooks Corey Depth m Residual Water Saturation 05 Estimated Max Injection Pressure MPa Residual Gas Saturation 01 3 7 Sensitivity Analysis Slow n 3 Krad 1 Run Simulation Time sec 99 3 EASITooIGUI BUREAU OF KSON Economic JACKS IN 5 OGEOLOGY mr r GEOES Oo 5 v o c gt o 9 a e 600 0 100 200 300 400 Number of In
29. ny agency thereof Further Information This software has been developed using MATLAB R2015a What s New Important changes in EASiTool V2 0 e The program platform has been transferred from GoldSim to MATLAB e Asimple geomechanical model has been coupled with the base model to evaluate the maximum injection pressure internally User still has the option to enter the maximum injection pressure manually e Graphical outputs have been added to the results Outputs include capacity vs number of injection wells NPV vs number of injection wells extend of CO plume in injection area optimal injection rate of wells and tornado chart for sensitivity analysis EASiTool User Manual V2 0 Getting Started This section has information on system requirements and installment for EASiTool System Requirements EASiTool is a Windows application Windows Vista Windows 7 either 32 bit or 64 bit versions or Windows 8 are the recommended operating systems Windows XP SP3 is also supported You must have administrative privileges on the system You need a minimum of 600 MB disk space during the installation process 16 bit color depth is required 32 bit recommended Installment Once you download the install file from EASiTool website double click it to start the installment Click Next once you see the window below C EASIToolGUI Installer o Connection Settings EASiToolGUI 2 0 Enhanced Analytical Simulation Tool EASiTo
30. ol An analytical based Enhanced Analytical Simulation Tool EASiTool developed to produce a fast reliable estimate of storage capacity for any geological formation EASiTool includes closed form analytical solutions that can be used as a first step for screening of geological formations to determine which formation can best accommodate storage needs over given period of time Seyyed Abolfazl Hosseini seyyed hosseini beg utexas edu Cancel 4 35 EASiTool User Manual V2 0 Determine the destination folder If you don t want to change the location where the installation folder will be saved click Next a Installation Options Enter the full path to the installation folder C Program Files EASiTool2 0 64bit Browse Restore Default Folder Add a shortcut to the desktop Cancel MATLAB Compiler Runtime is required Determine the destination folder If you don t want to change the location where the installation folder will be saved click Next F Required Software d MATLAB Compiler Runtime is required Install MATLAB Compiler Runtime in C Program Files MATLAB MATLAB Compiler Runtime Browse Download Size 0 MB Restore Default Folder MATLAB and Simulink are registered trademarks of The MathWorks Inc Please see www mathworks com trademarks for a list of additional trademarks Other product or brand names may be trademarks or registered trademarks of their respective holders
31. orm analytical solution for pressure buildup calculations used to estimate both injectivity and reservoir scale pressure elevation in both closed and open boundary aquifers version 1 1 e Asimple geomechanical model coupled with a base model to evaluate and avoid the possibility of fracturing reservoir rocks by injecting cold supercritical CO into hot formations which can cause rock deformation version 2 0 e An active reservoir management system throughout the brine extraction process version 3 0 to be released in 2016 Disclaimer This project is funded by the U S Department of Energy DE FE0009301 This report was prepared as an account of work sponsored by an agency of the United otates Government Neither the United States Government nor any agency thereof nor any of their employees makes any warranty express or implied or assumes any legal liability or responsibility for the accuracy completeness or usefulness of any information apparatus product or process disclosed or represents that its use would not infringe privately owned rights Reference herein to any specific commercial product process or service by trade name trademark manufacturer or otherwise does not necessarily constitute or imply its endorsement recommendation or favoring by the United States Government or any agency thereof The views and opinions of authors expressed herein do not necessarily state or reflect those of the United States Government or a
32. stress and angle with reference to minor principal stress respectively EASiTool User Manual V2 0 Sensitivity Analysis EASiTool currently can do sensitivity analysis on any combination of initial reservoir pressure temperature salinity thickness porosity permeability rock compressibility and relative permeability parameters To include the sensitivity analysis of any of these parameters check Sensitivity Analysis Slow Then in the new boxes provide the percentage of the variation of the parameters for sampling The one parameter at a time method is used for sampling in this version of EASiTool In this method information about the effect of a parameter is gained by varying only one parameter at a time Because this procedure is repeated in turn for all parameters to be studied running sensitivity analysis simulations may take a few minutes to complete r EASiToolGUI n Main Interface h f KJ x 42 ud GULF COAST CARBON CENTER Econom JACKSON DOLOG Or RC 7 Coefficient of Thermal Expansion 1K Bottom Hole Temperature Drop K Young s Modulus GPa Depth m Estimated Max Injection Pressure MPa Im a AC CASiToo Simulation Time sec CO2 Geological Capacity Estimation Sensitivity variation value should be less than 100 and greater than 0 17 35 EASiTool User Manual V2 0 4 NPV Analysis Section 4 provides the option to conduct a very simple net pres
33. ted In the current version we assume that basins do not include detailed structures or dip angles We also assume that basins are square Basin area should be bigger or equal to reservoir area Boundary Condition Using the drop down menu select either an open or a closed boundary condition In the current version of EASiTool the selected boundary condition will be enforced on all four sides of the basin A reservoir can be considered open as long as the pressure change has not reached the boundaries In an industrial scale injection operation it is expected that the pressure effect reaches the boundaries of the basin at late times Note EASiTool is designed to do the calculations for multiple scenarios where the number of wells increases from 1 to 400 in square numbers 1x1 2x2 3x3 4x4 20x20 In each scenario wells are equally spaced over the reservoir area For example well distribution for a 2x2 pattern is as shown below Basin Reservoir The following table shows the range of parameters that are accepted by EASiTool Initial Pressure lt 60 0 MPa Initial Temperature lt 300 0 C Thickness 20 1m Salinity gt 0 0 mol kg and s 6 0 mol kg Porosity 2 0 0 and lt 0 9999 Permeability 2 0 0 mD Rock Compressibility lt 1 0E 08 1 Pa Reservoir Area lt Basin Area The following six figures show the range and frequency of some reservoir parameters based on two data sets prepared by DOE and USGS EASiTool
34. ttp oubs usgs gov ds 774 Zeidouni M Pooladi Darvish M and Keith D 2009 Analytical solution to evaluate salt precipitation during CO injection in saline aquifers International Journal of Greenhouse Gas Control 3 600 611 Contacts Principle Investigator Seyyed A Hosseini 10100 Burnet Rd Bldg 130 Austin TX 78758 Phone 1 512 471 2360 Email seyyed hosseini beg utexas edu
35. ures the fractional change in size per degree change in temperature at a constant pressure Bottom Hole Temperature Drop 1 K The temperature difference between the formation and the injected fluid CO at the bottom of the well bore The fluid temperature is lower than the bottom hole static temperature The corresponding temperature difference causes thermal stresses in the formation and affects the Max Injection Pressure Young s Modulus E Pa Young s modulus also known as the tensile modulus modulus of elasticity or elastic modulus is defined as the ratio of the stress force per unit area along an axis to the strain ratio of deformation over initial length along that axis in the range of linear behavior of the material Depth m Depth of the fluid injection depth of perforation zone Estimated Max Injection Pressure MPa Pressure above which injection of fluids will cause the rock formation to fracture hydraulically Reactivation of preexisting fracture planes via shear slip is likely to occur prior to other types of geomechanical failures in most cases The Mohr Coulomb shear failures criterion for the maximum pressure limit Fmax ig expressed as t C T Om UP ux Ju where is shear stress is normal stress acting on a preexisting fracture plane is cohesion and is the coefficient of friction Then the max is 11 1 1 sin2 J where 1 73 and are major principal stress minor principal
36. y other party s use of the MCR You shall not sublicense sell or otherwise transfer the MCR to any third party You shall not republish any documentation which may be provided in connection with the MCR All rights not granted including without limitation rights to reproduce sublicense rent sell distribute create derivative works serve other software by means of decompile reverse engineer and disassemble the MCR are expressly anm mmm mnl L BA_ L1A _ Do you accept the terms of the license agreement Yes No Click Install to begin the installation a Confirmation EASiToolGUI will be installed in C Program Files EASiTool2 0 64bit EASIToolGUI requires MATLAB Compiler Runtime R2014a MATLAB Compiler Runtime R2014a will be installed in C Program Files MATLAB MATLAB Compiler Runtime v83 Cancel 6 35 EASiTool User Manual V2 0 Once the installation is completed this may take a few minutes you will see the window below Click Finish F Installation Complete KS Installation completed successfully Now you are ready to use EASiTool software by simply double clicking on the EASiTool icon 1 198 Input Parameters Section 1 has information on the input data required to run the program 1 Reservoir Parameters Necessary input for reservoir parameters includes in situ pressure MPa temperature C salinity of the formation brine mol kg thick

EASiTool - User Manual - V2.0

Contents

Download Pdf Manuals

Related Search

Related Contents