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EMADIBALADEHI-DISSERTATION-2014

1. h 1 jP LLL LII EEEEEEEEEEEERERR R r KRN F p d Figure 5 30 Stress vs Strain at 160 F 184 Texas Tech University Seyedhossein Emadibaladehi August 2014 Poisson s Ratio vs Stress at T2160 F AA Poisson s Ratio in LVDT s 02 04 Direction DD EU bo gt Average Poisson s Ratio 0 4 LL _ Poisson s Ratio in LVDT s 01 03 Direction 1 9 9 AMA du hb 0 35 D T t Poisson s Ratio e K K L l _ M 8 amp NER 02 T 1771 DL T NI 4al LI j 1 j urn i m i n T 1 1 1 1 Laure 4 _ 2 al 0 15 34 1 4 l 4 my lan Jl _ U 0 1 Rm w ine i ra B P T EN 0 05 ADEM NIMMT ae D 7 rt Stress psi Figure 5 31 Poisson s Ratio vs Stress at 160 F 185 Texas Tech University Seyedhossein Emadibaladehi August 2014 Stress vs Strain ttt Figure 5 32 Stress vs St
2. inte iets RA 3 llo Osmosis n Shale Eormatons uy sine 3 Te MITISE 1516 sa 5 FUN heat cet T 5 1 2 Rl ch RA 6 L5 Reach Methodolosy od oto ceca sg baec uta 6 ZU LITERATURE REVIEW o yt uu 8 Jew Mme Pro pc EDIG uuu l Uu OG runi muni 9 2 2 B Heels OF Temperi e aaa er lote doses qvi oben 9 3 EXPERIMENTAL SETUP EQUIPMENTS AND PROCEDURES 10 2 Test ApDparalb s a toc Elster Eier ea 10 3 1 1 Pre Wired Strain 10 813 ORA MICA 11 3 1 3 M Prep Conditioner and 12 Jl 12 Joe cmm 13 SA EEK LK FIR GYR 14 3 1 7 V Shay Data Acquisition 5 15 3 1 8 Mechanical Testing and Sensing Solutions MTS Machine 15 3 1 9 Linearly Variable Displacement Transducer _ 16 Test Proc QUEE uuu G tU Dem 17 3 3 High Pressure High Temperature HPHT Test Apparatus 19 3 oI Design or tie EGUMEN oto u al dc 19 3 3 2 HPHT Setup Components and Sp
3. Figure 5 26 Stress vs Strain at 140 F 180 Texas Tech University Seyedhossein Emadibaladehi August 2014 Poisson s Ratio vs Stress Poo 7 5000 011 h TTT TT E EM E EN HB 4000 Stress psi 2000 3000 Figure 5 27 Poisson s Ratio vs Stress at 140 F n s RatioinLVDT s 01 03 Direction 1000 Average Poisson s Ratio Oley s uossioq 181 Texas Tech University Seyedhossein Emadibaladehi August 2014 Stress vs Strain UTE EE ETE WI LTTE EEE e T Figure 5 28 Stress vs Strain at 150 F 182 Texas Tech University Seyedhossein Emadibaladehi August 2014 Poisson s Ratio vs Stress at 150 F 0 5 LE Poisson s Ratio in LVDT s 02 04 Direction 0 45 Average Poisson s Ratio 0 4 Poisson s Ratio in LVDT s 01 03 Direction 0 35 Poisson s Ratio 5 Pea LA Figure 5 29 Poisson s Ratio vs Stress at 150 F 183 Texas Tech University Seyedhossein Emadibaladehi August 2014 Stress vs Strain b11111111111111111111111111171111111 LL Li _ _
4. Node 05 Swelling Rate 0 0000350 0 0000300 0 0000250 0 0000200 0 0000150 Axial Radial Diagonal 0 0000100 0 0000050 Swelling Rate in hr 0 0000000 0 0000050 0 000100 40 0000150 Time hr Figure 4 46 Node 05 Swelling Rate 7 Perpendicular 87 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 06 Displacement 0 0003000 0 0002500 0 0002000 3 Axial Radial Diagonal 0 0001000 Displacement in 0 0000500 0 0000000 0 0000500 0 0001000 Time hr Figure 4 47 Node 06 Displacement 7 KCI Perpendicular 88 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 06 Swelling Rate 0 0000300 0 0000200 e E 0 0000100 Axial Radial E 0 0000000 Diagonal 0 0000100 D 0000200 D 0000300 Time hr Figure 4 48 Node 06 Swelling Rate 7 KCI Perpendicular 99 Texas Tech University Seyedhossein Emadibaladehi August 2014 Swelling Ratio 7 KCl Perpendicular 5 4 3 2 1 01 t 1 L Node 02 0 Node 03 p Node E 1 Node 05 Node 06 Time hr Figure 4 49 Swelling Ratio 7 KCl Perpendicular 90 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 01 Displacement 0 00002 0 00002 Axial Radial Diagonal D place ment in
5. Parallel 94 Figure 4 54 Node 03 Displacement 7 Parallel 95 Figure 4 55 Node 03 Swelling rate 7 KCI Parallel 96 Figure 4 56 Node 04 Displacement 7 KCI Parallel 97 Figure 4 57 Node 04 Swelling rate 7 KCI Parallel 98 Figure 4 58 Node 05 Displacement 7 KCI Parallel 99 Figure 4 59 Node 05 Swelling rate 7 KCI Parallel 100 Figure 4 60 Node 06 Displacement 7 KCI Parallel 101 Figure 4 61 Node 06 Swelling rate 7 KCI Parallel 102 1X Texas Tech University Seyedhossein Emadibaladehi August 2014 Figure 4 62 Node 01 Displacement 7 KCI Diaeonal 103 Figure 4 63 Node 01 Swelling rate 7 KCI Diaeonal 104 Figure 4 64 Node 02 Displacement 7 KCI Diaeonal 105 Figure 4 65 Node 02 Swelling rate 7 KCI Diaeonal 106 Figure 4 66 Node 03 Displacement 7 KCI Diaeonal 107 Figure 4 67 Node 03 Swelling rate 7 KCI Diag
6. 0 000004 0 000005 0 000006 Node 05 Swelling Rate Time hr Figure 4 84 Node 05 Swelling Rate OBM Perpendicular 125 Texas Tech University Seyedhossein Emadibaladehi August 2014 Displacement in 0 00025 0 0002 0 00015 3 0 00005 0 0001 0 00015 Node 06 Displacement 140 160 180 Time hr Axial Radial Diagonal Figure 4 85 Node 06 Displacement OBM Perpendicular 126 Texas Tech University Seyedhossein Emadibaladehi August 2014 Swelling Rate in hr 0 000002 U Node 06 Swelling Rate Time hr Figure 4 86 Node 06 Swelling Rate OBM Perpendicular 127 Texas Tech University Seyedhossein Emadibaladehi August 2014 Displacement 0 00012 0 0001 0 00008 0 00002 0 00002 0 00004 0 00006 Node 01 Displacement Time hr Figure 4 87 Node 01 Displacement OBM Parallel 128 Texas Tech University Seyedhossein Emadibaladehi August 2014 Swelling Rate in hr 0 000006 0 000004 0 000002 0 000004 Node 01 Swelling Rate Time hr Figure 4 88 Node 01 Swelling Rate OBM Parallel 129 Texas Tech University Seyedhossein Emadibaladehi August 2014 Displacement 0 0012 0 0002 e Node 02 Displacement Time hr Figure 4 89 Node 02 Displacement OBM Parallel 130 Texas Te
7. 46 Figure 4 7 Node 01 Swelling Rate Distilled 47 Figure 4 8 Node 02 Displacement Distilled Water 48 Figure 4 9 Node 02 Swelling Rate Distilled Water 49 Figure 4 10 Node 03 Displacement Distilled Water 50 Figure 4 11 Node 03 Swelling Rate Distilled Water 51 Figure 4 12 Node 04 Displacement Distilled Water 22 Figure 4 13 Node 04 Swelling Rate Distilled Water 53 Figure 4 14 Node 05 Displacement Distilled Water 54 Figure 4 15 Node 05 Swelling Rate Distilled Water 55 Figure 4 16 Node 06 Displacement Distilled Water 56 Figure 4 17 Node 06 Swelling Rate Distilled Water 57 Figure 4 18 Strain Ratios for all Four Submerged Nodes Distilled WW C P 58 Figure 4 19 Node 01 Displacement 776 KC iiie aa 59 Figure 4 20 Node 01 Swelling Rate 790 KCl cu ata eate ea 60 Figure 4 21 Node 02 Displacement 7 61 Fieure 4 22 Node 02 Swelling Rate 7 Fo KOL
8. DUDODD 0 DO t T Axial E H Radial a Diagonal B 7 R 1 0000 DI Time sec Figure 4 6 Node 01 Displacement Distilled Water 46 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 01 Outside 3E 09 ZE 09 1E 04 EM Axial kon D L2DODD 140000 p w 2 Diagonal iE D8 T gt PS dy Swalling Rate in sec Time sec Figure 4 7 Node 01 Swelling Rate Distilled Water 47 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 02 Outside GO EDD 100000 120000 140000 E Axial D 00006 2 Lo Radial Az m Diagonal a 0 00008 D 0001 gr ih WB Time sec Figure 4 8 Node 02 Displacement Distilled Water 48 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 02 Outside 1 09 A 9 pao A RFA IN Axial m 1E 09 Radial en E 1 5E 09 2E 09 4 2 5E 08 Time sec Figure 4 9 Node 02 Swelling Rate Distilled Water 49 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 03 Inside 0 0012 0 001 0 0008 ee E 0 0006 LI E T Radial I CL 0 0004 D Time sec Figure 4 10 Node 03 Displacement Distilled Water 50 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 03 Inside
9. Each task or operation that the user wants the DAQ to carry out must be programmed into a VI Individually executable VIs can be called into another program as a sub VI by using their specific icon and connector pane this usage 1s similar to subroutines in conventional programming languages LabVIEW is a dataflow programming language this means that data flows from a data source to one or more sinks and then propagates through the system It can operate multiple programs simultaneously in parallel without any interference or intrusion AII LabVIEW VIs have two main parts or windows the front panel and the block diagram The front panel is the virtual instruments display It 1s the interface through which the end user communicates with the program and all other devices depending on the operation or the purpose of the VI The front panel has two main graphical objects a control and an indicator control 1s a front panel object that the user manipulates to interact with the VI such as buttons slides dials and textboxes An indicator 1s a front panel object that displays data to the user example of such include graphs plots nu meric display gauge thermometers 33 Texas Tech University Seyedhossein Emadibaladehi August 2014 The block diagram 15 usually in the background this is where the codes that operate the VI are written It is the programming powerhouse of LabVIEW It is a com bination of several functions wires
10. Figure 4 41 Node 03 Displacement 7 KCI Perpendicular 82 Texas Tech University Seyedhossein Emadibaladehi August 2014 Swelling Rate in hr 0 0000500 0 0000400 0 0000300 0 0000200 0 0000100 0 0000000 0 0000100 Node 03 Swelling Rate Time hr Figure 4 42 Node 03 Swelling Rate 7 KCI Perpendicular 93 Texas Tech University Seyedhossein Emadibaladehi August 2014 Displacement 0 0003000 0 0002500 0 0002000 0 0001500 0 0001000 0 0000500 0 0000000 0 0000500 0 0001000 Node 04 Displacement Time hr Axial Radial Diagonal Figure 4 43 Node 04 Displacement 7 KCI Perpendicular 84 Texas Tech University Seyedhossein Emadibaladehi August 2014 Swelling Rate in hr 0 0000350 0 0000300 0 0000250 0 0000200 0 0000150 0 0000100 0 0000050 0 0000000 0 0000050 Node 04 Swelling Rate Time hr Figure 4 44 Node 04 Swelling Rate 7 Perpendicular 85 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 05 Displacement 0 0003500 0 0003000 0 0002500 0 0002000 0 0001500 i Axial s Radial 0 0001000 Diagonal Displacement in 0 0000500 0 0000000 Q 0 0000500 0 0001000 Time hr Figure 4 45 Node 05 Displacement 7 KCI Perpendicular 86 Texas Tech University Seyedhossein Emadibaladehi August 2014
11. e Ease Lo tse cur En 193 6 2 Recominendati9 nsS bands 194 NOMENCEATURE citta astare Sos eases iis sees 196 BIBLIOGRAPHY cani 198 N PRU 201 1 Texas Tech University Seyedhossein Emadibaladehi August 2014 ABSTRACT The industry 1s still at the beginning of the learning curve for shale oil drilling operations however many shale oil wells have been drilled in recent years Drilling through shale oil formations may very problematic and imposes significant costs to the operators owing to wellbore stability problems These problems include but are not limited to tight holes stuck pipe fishing sidetracking and well abandonment To more efficiently and effectively drill through these formations we should better understand their properties Few experiments have been performed on shale oil samples to better understand their properties Most experiments conducted thus far were performed on common shale core samples which are significantly different from shale oil samples In this study we first determined the mineralogy of shale oil core samples from the Eagle Ford field and then investigated the swelling properties and Cation Exchange Capacity CEC of the core samples in the laboratory Experiments have been conducted with the samples par tially submerged in distilled water potassium c
12. the UCS decreases from 8 000 psi to 6 600 psi in other words by increasing 40 F UCS decreases by 18 The results demonstrate that during drilling if formation temperature increases the likelihood of wellbore stability problems goes up and similarly by cooling the formation we will have a more stable wellbore The results also illustrate that tem perature does not have a considerable effect on the Young s modulus of Eagle Ford shale oil rock Three Poisson s ratios were calculated for each sample one for each pair of ra dial LVDTs two pairs and one for the average of all four radial LVDTs As we can Observe in Figure 5 27 Figure 5 29 Figure 5 31 Figure 5 33 and Figure 5 35 Pois son s ratios which were calculated from the two perpendicular pair of LVDTs are quite different Total Poisson s ratios in all three samples are between 15 and 25 These uneven values are due to natural fractures This 15 also proved by the way in which the 190 Texas Tech University Seyedhossein Emadibaladehi August 2014 specimens failed After the UCS tests it was observed that all specimens failed through a vertical plane clearly marked from the top of the sample continuing all the way to the bottom and also the smooth surface of the sample after UCS thus clarifying the existence of the natural fractures Figure 5 37 Figure 5 38 and Figure 5 39 Figure 5 37 On the left 140 F sample after running UCS test
13. 0 0001 0 00012 Time hr Figure 4 50 Node 01 Displacement 7 KCI Parallel 91 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 01 Swelling Rate 0 00001 0 000005 0 000005 Axial Radial 0 00001 Diagonal Swelling Rate in hr 0 000015 0 00002 0 000025 Time hr Figure 4 51 Node 01 Swelling rate 7 KCI Parallel 92 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 02 Displacement 0 0005 0 0004 0 0003 0 0002 0 0001 Radial Diagonal Displacement in 0 0001 0 0002 0 0003 Time hr Figure 4 52 Node 02 Displacement 7 KCI Parallel 93 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 02 Swelling Rate 0 00004 0 00002 0 z 0 00002 5 Radial Diagonal F 0 00004 un 0 00006 0 00008 0 0001 Time hr Figure 4 53 Node 02 Swelling rate 7 KCI Parallel 94 Texas Tech University Seyedhossein Emadibaladehi August 2014 Dis place ment in 0 0006 0 0005 0 0004 0 0003 0 0002 0 0001 Node 03 Displacement Time hr Figure 4 54 Node 03 Displacement 7 KCI Parallel 95 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 03 Swelling Rate 0 00005 0 00004 0 00003 0 00002 Axial Radial Diagonal Swelling Rate
14. 1 1E D8 n i E 09 09 Axial Radial HNN ND SEM M T EN A Per Y e zz im 100000 si Ex soe 700000 1E 09 a 1 09 Swelling Rate in sec Time sec Figure 4 11 Node 03 Swelling Rate Distilled Water 51 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 04 Inside Diagonal Displacement OZ ZZ Time sec Figure 4 12 Node 04 Displacement Distilled Water 52 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 04 Inside 1E DE Diagonal TT SES VA Swelling Rate in sec Figure 4 13 Node 04 Swelling Rate Distilled Water 53 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 05 Inside 0 0012 0 001 D DDR 4 E 0 0006 MW x 2 Radial 5 S 0 0004 Diagonal lt DOOR FHH A SDM Figure 4 14 Node 05 Displacement Distilled Water 54 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 05 Inside 1 2 08 1E DE 09 09 yT 46 05 u Axial m 2 09 _ 1 ve Radil en iin Diagonal 0 E E 100000 200000 300000 400000 500000 500000 700000 I Time sec Figure 4 15 Node 05 Swelling Rate Distilled Water 23 Texas Tech University Seyedhossein Emadib
15. Displacement Time hr Figure 4 79 Node 03 Displacement OBM Perpendicular 120 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 03 Swelling Rate 0 000006 0 000004 0 000002 0 000002 Swelling Rate in hr 0 000004 0 000006 0 000008 Time hr Figure 4 80 Node 03 Swelling Rate OBM Perpendicular 121 Texas Tech University Seyedhossein Emadibaladehi August 2014 Displacement in Node 04 Displacement 0 00002 e 0 00002 Radial Diagonal 0 00012 Time hr Figure 4 81 Node 04 Displacement OBM Perpendicular 172 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 04 Swelling Rate 0 000003 0 000002 0 000001 0 000001 ng Rate in hr 0 000002 Swell 0 000003 0 000004 0 000005 0 000006 Time hr Figure 4 82 Node 04 Swelling Rate OBM Perpendicular 123 Texas Tech University Seyedhossein Emadibaladehi August 2014 Displacement in 0 0002 0 00015 0 0001 0 00005 0 00005 0 0001 Node 05 Displacement 140 160 180 Time hr 2040 Axial Radial Diagonal Figure 4 83 Node 05 Displacement OBM Perpendicular 124 Texas Tech University Seyedhossein Emadibaladehi August 2014 Swelling Rate in hr 0 000004 0 000003 0 000002 0 000001 i 0 000003
16. Table 1 3 Mineralogy of a core sample from Shale Gas Eagle Ford said EM MM m T 6 Table 3 1 C2A 06 250WW 350 Strain Gauge Properties 10 Table 4 1 Mineralogy for a core sample from Shale Oil Eagle Ford IC SRL mem 4 Table Sample SDECITICOLIOTIS r d rien 4 Table Sample Ser CAO ae hd ul A ae 154 Table 5 2 HPH TF Tesine Parameter aaa k 155 Table 2 5 Measured Parameters au u GM OFN 192 vi Texas Tech University Seyedhossein Emadibaladehi August 2014 LIST OF FIGURES Figure 3 1 Stacked rosette strain 11 Fiure 5 2 M Bond Type IO uu RO as 11 Figure 3 3 M Bond Adhesive Resin Type AE 11 5 4 M Prep NeutraliZer Skill betreut eee Ni 12 Eioure 325 JVI Prep Conditioner se oet ou ee 12 Fiore S OAO r A o baut etaed 13 Pisure 3 7 M Bond 200 Adhesive s 14 5 599 HC OTI aaa f FFYN 14 Figure 3 9 V Shay Data Acquisition System 15 Fisure 5210 MTS Mao due cete A a 16 Jio aC m 16 Ligure 5 12 Pelco Laboratory a ae I 21 Figure 3 13 Phoenix Precision Instruments Core Holder 22 Eioure gt 14 Hydraulic ee ae uus 23 Figure 3 15 Ametek Chandler Positive Disp
17. on the right 150 F sample after running UCS test Figure 5 38 On the left 160 F sample after running UCS test on the right 170 F sample after running UCS test 191 Texas Tech University Seyedhossein Emadibaladehi August 2014 Figure 5 39 180 F sample after running UCS test Table 5 3 summarizes the values of UCS Young s modulus E and Poisson s ratio v for all five samples As it can be seen temperature has a detrimental effect on rock uniaxial compressive strength makes the rock weaker and accordingly increases the probability of wellbore stability problems As is observed temperature has some effect on Poisson s ratio v More tests should be run to investigate that effect How ever it can also be seen that temperature does not have a significant effect on Young s modulus E of the Eagle Ford shale oil rock samples Table 5 3 Measured Parameters 140 F 8 000 1 25 x 106 150 F 7 600 1 40 x 10 160 F 7 300 1 30 x 106 170 F 7 000 1 40 x 106 180 F 6 600 1 30 x 10 192 Texas Tech University Seyedhossein Emadibaladehi August 2014 CHAPTER 6 CONCLUSIONS AND RECOMMENDATIONS The conclusions which were drawn from both swelling and HPHT experiments are presented in this chapter 6 1 Conclusions The following conclusions were made from the data gathering data analysis and test investigations 1 Temperature has a negative effect on the Eagl
18. 3 2 Swelling Test Procedure Experimental procedures which were used to run swelling and UCS tests are described in detail below l 2 10 11 Cut 1 5 widthx3 length core sample Add 15 ml of M Bond Type 10 to M Bond Adhesive Resin Type AE and stir it for five minutes to prepare the epoxy Put the epoxy on the regions of the core sample which strain gauges will be mounted The epoxy has to be spread on the rock sample which pro vides a smooth surface that allows to have a good bondage between strain gauge and the sample and consequently precise data from strain gauges Leave the epoxy on the rock sample for 24 hours to cure completely Clean the strain gauges spots with M Prep Conditioner Neutralizer and alcohol for two minutes Leave them until they all get dry Connect the strain gauges using super glue M Bond 200 Adhesive Press the strain gages to the rock sample for one minute in order to re move all the air and accordingly better bondage and more precise data reading Put enough silicon on all strain gages and leave it for at least 24 hours to get dry Connect strain gages to the V Shay Data Acquisition System Put the rock sample with the strain gauges inside the vessel that fluid will be poured afterwards Pour the fluid inside the vessel up to desired level Cover the top of the vessel with aluminum foil which prevents fluid from vaporizing hence the fluid level as well as concent
19. 4020 1 6719 1 6038 1 5438 1 6052 3 5700 For the swelling tests samples were half submerged in the fluids for seven days while strain gauges were recording swelling at six different points four strain gauges were submerged and two were above fluid level as shown in Figure 4 1 4 Texas Tech University Seyedhossein Emadibaladehi August 2014 a SECHS EEE Ben EEE CEE Pee EDD ND TATE porc A Bu Ed tiu 222222 pm D I p TI DN AWN AD NR NA o Pris Petri K ie N K 2 LEA IAU 227 Bl 222222 2242222 2222222 S cp T E 0 de o 2 Four Strain Gages located under thefluid line Submerged Figure 4 Strain gauge locations setups were arranged in an environmental chamber Figure 4 3 so the tests could be performed under a constant temperature of 24 C Swelling tests were com pleted by submerging the specimens in the fluids specified Table 4 2 an bn e D co os a o 5 2 d Oc MQ 99 NS F E lt Figure 4 2 Sample prepared for swelling test 42 Texas Tech University Seyedhossein Emadibaladehi August 2014 nt Figure 4 3 Environmental chamber In order to obtain compressive strength for the shale oil core samples used in this study and to observe th
20. 7 KCI Diagonal 111 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 05 Swelling Rate 0 00006 0 00004 0 00002 elling Rate in hr Sw 0 00002 Time hr Figure 4 71 Node 05 Swelling rate 7 KCl Diagonal 112 Texas Tech University Seyedhossein Emadibaladehi August 2014 Displacement in 0 0006 0 0005 0 0004 3 3 0 0001 Node 06 Displacement Time hr Figure 4 72 Node 06 Displacement 7 KCI Diagonal 113 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 06 Swelling Rate 0 00005 0 00004 0 00003 i Axial Radial 0 00001 Diagon al Swelling Rate in hr 0 00001 0 00002 Time hr Figure 4 73 Node 06 Swelling rate 7 KCI Diagonal In the first three tests 7 KCl swelling in all directions stabilize after 36 hours approximately Swelling rates in all directions are high during first 20 hours but then they drop and become nearly constant after almost two days Maximum swelling hap pened in the core sample which was parallel to the bedding while minimum swelling which is almost half of the maximum swelling occurred in the core sample which was perpendicular to the bedding Maximum and minimum swellings after almost two days were 0 04340 and 0 021 respectively 114 Texas Tech University Seyedhossein Emadibaladehi August 2014 Swelling Ratio 7 KCl
21. E 2 en B A E Figure 4 35 Strain gage locations setups were arranged in the environmental chamber Figure 4 3 so the tests could be performed under a constant temperature of 24 C Swelling tests were com pleted by submerging the specimens in the 776 KCl and OBM fluids The CEC of the sample is 45 5me 100gr which is categorized in the reactive shale group 76 Texas Tech University Seyedhossein Emadibaladehi August 2014 The swelling tests were performed on six samples submerged in two different fluids 7 KCl and OBM The data was recorded on six stacked rosette strain gauges which were mounted on the two ends of each sample four of them were inside the fluid and the rest were outside It is significant to mention that each stacked rosette strain gauge consists of three strain gages which are able to measure swelling in various di rections including axially radially and diagonally Also to refer easier to the swelling location on the specimen the location of strain gauges has been identified as nodes shown in Figure 4 36 NODE 04 NODE 01 Figure 4 36 Locations of nodes for the specimens 71 Texas Tech University Seyedhossein Emadibaladehi August 2014 4 2 2 Swelling Test Results 7 KCl In this section the swelling results of the three commercial Eagle Ford shale oil sample perpendicular parallel diagonal 45 to the bedding submerged in 796 wi
22. Engineering staff 15 highly appreciated you foster the bond of cooperation and atmosphere that accelerates progress and productiv ity A special thanks to the present and past chairs of the department who provided the leadership and stability required for research throughout my work on this research A special appreciation to my dear family Words cannot express how grateful I am to my mother Safoura and father Reza for all the sacrifices you have done for me to be where I am now and all your prayer which sustained me thus far Special thanks to my siblings Zahra Fatemeh Mohammad and Hamed for all your support I would also like to thank all of my friends who helped me to strive towards my goal Finally and most reverently I thank God the giver of life wisdom his blessings grace mercies and inspiration which are numerous without him and his help this work would not be done 11 Texas Tech University Seyedhossein Emadibaladehi August 2014 TABLE OF CONTENTS ACKNOWLEDGMENT S ee YID FEE CENE ii ADBSURACT EE Y r A UM V t vi LIST OV FIG UR E5 u cita tiae ana Ui a vii 1 INTRODUCTION en ring 1 1 1 Differences between Common Shale and Shale Oil Samples Properties 2 T loe Cation Exchange Capaci CEC ee 2 11 2 OWNING PROD CICS Au unun m
23. Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 03 Displacement 0 0008 0 0007 0 0006 0 0005 Axial Radial Diagonal 0 0003 0 0002 Displacement in 0 0001 D 0001 0 0002 Time hr Figure 4 66 Node 03 Displacement 7 KCI Diagonal 107 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 03 Swelling Rate 0 00005 0 00004 0 00003 0 00002 0 00001 Swelling Rate in hr 0 00001 0 00002 0 00003 0 00004 Time hr Figure 4 67 Node 03 Swelling rate 7 Diagonal 108 Texas Tech University Seyedhossein Emadibaladehi August 2014 Displacement in 0 0006 0 0005 0 0001 0 0001 Node 04 Displacement Time hr Figure 4 68 Node 04 Displacement 7 KCI Diagonal 109 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 04 Swelling Rate 0 00005 0 00004 0 00003 0 00002 Axial Radial Diagonal Swelling Rate in hr 0 00001 0 00002 Time hr Figure 4 69 Node 04 Swelling rate 7 KCI Diagonal 110 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 05 Displacement 0 0008 0 0007 0 0006 0 0005 Axial Radial Diagonal 0 0003 0 0002 Displacement 0 0001 0 0001 0 0002 Time hr Figure 4 70 Node 05 Displacement
24. University Seyedhossein Emadibaladehi August 2014 Displacement 0 0004 0 00035 0 0003 0 00025 0 0002 0 00015 0 0001 0 00005 Node 02 Displacement 120 140 160 180 Time hr Figure 4 101 Node 02 Displacement OBM Diagonal 142 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 02 Swelling Rate 0 000008 0 000006 0 000004 Axial 0 000002 Radial Diagonal Swelling Rate in hr 0 000002 0 000004 0 000006 Time hr Figure 4 102 Node 02 Swelling Rate OBM Diagonal 143 Texas Tech University Seyedhossein Emadibaladehi August 2014 Displacement in Node 03 Displacement 100 120 140 160 180 Time hr Figure 4 103 Node 03 Displacement OBM Diagonal 144 Texas Tech University Seyedhossein Emadibaladehi August 2014 Swelling Rate in hr 0 00005 0 00003 0 00001 0 00001 0 00003 Node 03 Swelling Rate Time hr Figure 4 104 Node 03 Swelling Rate OBM Diagonal 145 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 04 Displacement 0 0003 0 00025 0 0002 0 00015 Axial Radial Diagonal 0 0001 Displacement in 0 00005 140 160 180 0 00005 0 0001 Time hr Figure 4 105 Node 04 Displacement OBM Diagonal 146 Texas Tech University Seyedhossein Emadibaladehi August 2014 S
25. a review of pioneering research and experiments which were done on effect of swelling and temperature on the sedimentary rocks will be discussed 2 1 Swelling Properties Shale fluid interaction has been intensively investigated in laboratories Mody and Hale 1993 used an experimental setup which allows them to apply confining stress on the shale rock core sample They used different fluids as formation and drilling fluid at the two ends of the samples to investigate effects of different fluid on pore pressure and wellbore stability during drilling operations Wellbore stability in shale is very much influenced by the type of drilling fluid Muniz et al 2005 Many experiments and studies have been conducted on the swelling properties of conventional shale rock samples to better understand those properties the problems associated with them and to come up with effective and efficient solutions to eliminate those problems Guo et al 2012 However no experiment has been done to investigate effects of different fluids including both water based and oil based fluids on swelling properties of shale oil core samples 2 2 Effects of Temperature The behavior of source rocks with high total organic carbon TOC is strongly temperature dependent and predominantly plastic at elevated temperatures Microfrac ture systems are generated which resemble natural assemblages The fractures are ten sile and related to internal pressure built up in th
26. aes 62 Figure 4 23 Node 03 Displacement 7 63 Figure 4 24 Node 03 Swelling Rate 7 64 Figure 4 25 Node 04 Displacement 7 KC nnn 65 Figure 4 26 Node 04 Swelling Rate 7 66 Figure 4 27 Node 05 Displacement 7 KE 67 Figure 4 28 Node 05 Swelling Rate 7 eere eene 68 Figure 4 29 Node 06 Displacement 7 69 Figure 4 30 Node 06 Swelling Rate 7 KCI 70 Figure 4 31 Strain Ratios for all Four Submerged Nodes 7 KCl 71 Figure 4 32 Stress vs Strain for all Three Samples 73 viii Texas Tech University Seyedhossein Emadibaladehi August 2014 Figure 4 33 On the left intact sample after UCS test in the middle distilled water sample after UCS test on the right 7 KCIsample atter ade 74 Figure 4 34 Sample prepared for swelling test Diagonal to bedding 76 Ligure 4 5 2age lOCATIONS OU ke 76 Figure 4 36 Locations of nodes for the specimens 71 Figure 4 37 Node 01 Displacement 7 KCI Perpendicular 78 Figure 4 38 Node 01 Swelling Rate 7 KCI Perpendicul
27. formation was selected The mate rial can be described among sedimentary rocks as a Shale Oil with 26 of clay water content w of 0 6596 absorption 146 and a unit weight of 158 pcf More mineralogy information about the sample is presented Table 4 1 40 Texas Tech University Seyedhossein Emadibaladehi August 2014 Table 4 1 Mineralogy for a core sample from Shale Oil Eagle Ford reservoir Company Data Mineral Calcite Mixed Layer 1 5 Kaolinite Quartz Pyrite Feldspar Apatite TOC To have one sample for each experiment three samples were cored and prepared from the main sample All samples were tested for unconfined compressive strength experiments The first sample was tested intact and the other two were tested after swell ing tests under distilled water and 7 KCl fluid All samples were prepared according to specifications of American Society for Testing and Materials ASTM D 2938 and identified as Intact Distilled Water and 7 KCI Table 4 2 Table 4 2 Sample Specifications Large Diameter in Middle Diameter in small Diameter in Large Cross Sectional Area in Medium Cross Sectional Area in Small Cross Sectional Area in Average Cross Sectional Area in Length in Intact Sample 1 1690 1 1630 1 1685 1 0733 1 0623 1 0724 1 0658 2 4390 Distilled Water Sample 1 4330 1 4220 1 4020 1 6128 1 5881 1 5438 1 5849 2 9550 7 KCl Sample 1 4590 1 4290 1
28. from each other so different magnitudes of radial and axial stresses can be applied using the same hydraulic pump A picture of the hydraulic pump is illustrated in Figure 3 14 22 Texas Tech University Seyedhossein Emadibaladehi August 2014 Figure 3 14 Hydraulic Pump 3 3 2 4 Positive Displacement Pumps Two Quizix pumps which were manufactured by Ametek Chandler Engineering used in HPHT setup in order to apply drilling fluid as well as pore fluid pressures The pump is series and its model number is QX6000HC It is a completely integrated self contained pump and contains a pump controller which directs the action of two completely independent positive displacement piston pumps These two pistons pumps can each be used individually for single stroke volumes or as a pair to provide pulseless continuous fluid flow for a single fluid Each piston pump contains its own motor drive mechanics pump cylinder piston pressure transducer valve and fluid plumbing The pump 19 rated at 6 000 psi Stroke volume and maximum flow rate 12 3 ml and 50 ml per minute 3 liters per hour respectively The cylinders are made of Hastelloy which provides superior corrosion resistance The valves used Quizix Pumps are air actuated Air 15 taken into the system through the air inlet and distributed to the pilot solenoid manifold The pilot solenoids then distribute and control the air flow to the valves Nitrogen was used to run
29. had worked for National Iranian Oil Company NIOC as assistant drilling supervisor for one and half years He got his Master of Science MSc in Drilling Engineering from Petroleum University of Technology PUT Tehran Iran Prior of getting his MSc degree he had received his BSc in Petroleum Engineering from the same university PUT Ahwaz Iran His motivation for coming to Texas Tech University was to learn and expand his knowledge in petroleum engineering in general and drilling engineering specifically for future career prospect in the petroleum industry While doing his PhD in Texas Tech University he has worked with several of his professors as a teaching assistant He performed as the teaching assistant for various courses including Petroleum Production Methods PETR 4303 Petroleum Develop ment Design PETR 3401 Drilling Engineering PETR 4307 and Horizontal Well Technology PETR 5315 at both graduate and undergraduate levels 201
30. in hr 0 00001 0 00002 0 00003 Time hr Figure 4 55 Node 03 Swelling rate 7 KCI Parallel 96 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 04 Displacement 0 0005 0 0004 0 0003 0 0002 Axial Radial E 0 0001 Diagonal 0 0001 0 0002 Time hr Figure 4 56 Node 04 Displacement 7 KCI Parallel 977 Texas Tech University Seyedhossein Emadibaladehi August 2014 Swelling Rate in hr 0 00004 0 00003 0 00002 0 00001 0 00002 Node 04 Swelling Rate Time hr Figure 4 57 Node 04 Swelling rate 7 KC Parallel 98 Texas Tech University Seyedhossein Emadibaladehi August 2014 D place ment in 0 0006 0 0005 0 0004 POP B 0 0001 0 0002 Node 05 Displacement Axial Radial Diagonal Time hr Figure 4 58 Node 05 Displacement 7 KCI Parallel 99 Texas Tech University Seyedhossein Emadibaladehi August 2014 Swelling Rate in hr 0 00006 0 00004 0 00002 0 00004 0 00006 Node 05 Swelling Rate Time hr Figure 4 59 Node 05 Swelling rate 7 KCI Parallel 100 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 06 Displacement 0 0009 0 0008 0 0007 0 0006 0 0005 0 0004 Axial Radial 0 0003 Di place ment in Diagonal 0 0002
31. 0 0001 0 0001 0 0002 Time hr Figure 4 60 Node 06 Displacement 7 KCI Parallel 101 Texas Tech University Seyedhossein Emadibaladehi August 2014 Swelling Rate in hr 0 00008 0 00006 0 00002 0 00002 Node 06 Swelling Rate Time hr Figure 4 61 Node 06 Swelling rate 7 KC Parallel 102 Axial Radial Diagonal Texas Tech University Seyedhossein Emadibaladehi August 2014 Displacement in 0 0008 0 0007 0 0006 0 0005 0 0003 0 0002 0 0001 Node 01 Displacement Time hr Figure 4 62 Node 01 Displacement 7 KCI Diagonal 103 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 01 Swelling Rate 0 00003 0 00002 0 00001 0 00001 Swelling Rate in hr 0 00002 0 00003 0 00004 Time hr Figure 4 63 Node 01 Swelling rate 7 KCI Diagonal 104 Texas Tech University Seyedhossein Emadibaladehi August 2014 Displacement in 0 0006 0 0004 0 0002 0 000 Node 02 Displacement Time hr Figure 4 64 Node 02 Displacement 7 KCI Diagonal 105 Texas Tech University Seyedhossein Emadibaladehi August 2014 Swelling Rate in hr 0 000005 0 000001 7 0 000001 Node 02 Swelling Rate NL A Time hr Figure 4 65 Node 02 Swelling rate 7 KCI Diagonal 106
32. 0 001 0 0008 0 0006 Axial Diagonal Radial 0 0004 Figure 4 23 Node 03 Displacement 7 KCl 63 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node03 In 1 2E 08 BL NE N N j Radial 0 Diognal an 200000 300000 400000 500000 BDDDDD 700000 2 09 Swelling Rate in sec BE 03 Time sec Figure 4 24 Node 03 Swelling Rate 7 KCl 64 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 04 Out 0 0002 0 00015 0 0001 q Axial z D 00005 Diagonal 2 Radial i Time sec Figure 4 25 Node 04 Displacement 7 KCI 65 Texas Tech University Seyedhossein Emadibaladehi August 2014 Swrelling Rate in sec Node04 Out Axial Radial Diagonal Time sec Figure 4 26 Node 04 Swelling Rate 7 KCl 66 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 05 In Diagonal Radial f Displacement in 0 0002 Time sec Figure 4 27 Node 05 Displacement 7 67 Texas Tech University Seyedhossein Emadibaladehi August 2014 Swelling Rate in sec Node05 In 1 5E DR A LAN a N el N N en 1E 09 200000 00000 400000 SDDDDD BDDDDD TDDDDD Figure 4 28 Node 05 Swelling Rate 7 68 Texas Tech Universit
33. D E CON ADHESIVE WN ued ROL NO 1167 2 EXP DATE c uen 413 12 Jul 15 Phone 1 919 36 Figure 3 6 Alcohol 3 1 5 Super Glue super glue M Bond 200 Adhesive was used to mount strain gages on the rock samples as shown in Figure 3 7 Super glue provides an excellent bondage between strain gauges and rock sample and also prevents strain gauges from moving during run ning the experiments Strain gauge has to be pressed against the rock sample to make sure there 19 no air between it and the rock sample till the super glue gets dry 13 Texas Tech University Seyedhossein Emadibaladehi August 2014 Figure 3 7 M Bond 200 Adhesive 3 1 6 Silicone Silicon was used to electrically insulate the strain gauges which were submerged in the fluid Silicone was chosen because not only it gives very good insulation but also does not restrict strain gauge s movement and can be easily removed from sample after running the experiment Silicone is shown in Figure 3 8 Figure 3 8 Silicon 14 Texas Tech University Seyedhossein Emadibaladehi August 2014 3 1 7 V Shay Data Acquisition System V Shay data acquisition system was used to collect data from strain gauges This system records data from all six strain gauges every second This device has 20 channels which enables us to collect data from 20 different strain gauges However only 18 chan nels were used during running the swelling experiments The V Sha
34. Diagonal C Node 02 Ed Node 03 Node E Node 05 1 Node 06 3 5 Time hr Figure 4 74 Swelling Ratio 7 KCI Diagonal 115 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 01 Displacement 0 00002 0 00001 U Axial Radial Displacement in 0 00003 0 00004 0 00005 Time hr Figure 4 75 Node 01 Displacement OBM Perpendicular 116 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 01 Swelling Rate 0 000003 0 000002 0 000001 U 0 000002 Swelling Rate in hr 0 000003 0 000004 0 000005 Time hr Figure 4 76 Node 01 Swelling Rate OBM Perpendicular 117 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 02 Displacement 0 00025 0 0002 0 00015 0 0001 Axial Radial 0 00005 Diagonal Displacement 140 160 180 D 00005 0 0001 Time hr Figure 4 77 Node 02 Displacement OBM Perpendicular 118 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 02 Swelling Rate 0 000002 e Swelling Rate in hr d 0 00001 Time hr Figure 4 78 Node 02 Swelling Rate OBM Perpendicular 119 Texas Tech University Seyedhossein Emadibaladehi August 2014 Displacement 0 00025 0 0002 0 00015 0 0001 0 00005 0 00005 Node 03
35. I E U 15pt Application Font Im or ES EM Search A 1 MudPressure 0 RadialStress 0 Axial Stress 0 Figure 3 23 LabView Front Panel 35 Texas Tech University Seyedhossein Emadibaladehi August 2014 Test vi Block Diagra File Edit View Project Operate Tools Window Help e 9 5 2 FieldPoint IO Point FieldPoint CoreLab cFP TC 120 2 Channel 0 r Mm gt 27 716 FieldPoint IO Point FieldPoint CoreLab cFP Al 112 1 Channel 0 v 1002 2 gt Pore Pressure zur 16 871 FieldPoint IO Point I FieldPoint CoreLab cFP Al 112 1 Channel 7 v 995 94 Iz Radial Stress FieldPoint IO Point T6 FieldPoint CoreLab cFP AI 112 1 Channel 11 gt Axial Stress 10 782 FieldPoint IO Point FieldPoint CoreLab cFP Al 112 1 Channel 14 v 992 85 992 85 gt LV E KB gt DE Figure 3 24 LabView Block Diagram 36 Texas Tech University Seyedhossein Emadibaladehi August 2014 Pressure Transducer V Valve Axial Stress Gauge Pressure Gauge Pore Fluid 30 000 ppm Brine Mud Pressure Gauge 7 M Injection Pump FPA inn in Core Holder Pore Fluid Tr Hydraulic Oil v7 FPA Oven LEE Pressure Gauge Hydraulic Oil Hand Pump Injection Pump Radial Stress Gauge Figure 3 25 HPHT Setup Schem
36. Investigation of Effects of Temperature and Swelling on Wellbore Stability in Unconventional Reservoirs by Seyedhossein Emadibaladehi B Sc MSc A Dissertation In Petroleum Engineering Submitted to the Graduate Faculty of Texas Tech University in Partial Fulfillment of the Requirements for the Degree of DOCTOR OF PHILOSOPHY Approved Dr Mohamed Y Soliman Chair of Committee Dr Robello Samuel Dr Lloyd R Heinze Dr James Sheng Mark A Sheridan Dean of the Graduate School August 2014 Copyright 2014 Seyedhossein Emadibaladehi Texas Tech University Seyedhossein Emadibaladehi August 2014 ACKNOWLEDGMENTS I would like to express the deepest appreciation to my committee chair Profes sor Mohamed Y Soliman who has been a tremendous mentor for me I would like to thank you for encouraging me to perform my research and for giving me the opportunity to develop a grasp understanding of research Your advice on research as well as on my professional career has been invaluable I would like to thank my committee members Dr Robello Samuel Dr Lloyd R Heinze and Dr James Sheng for their support and for serving as my committee members even at hardship I also want to appreciate all your brilliant comments and guidance received an extraordinary help form Mr Shannon Hutchison and Mr Joseph McInerney with laboratory tests and experimental aspects of this research The help and support of the department of Petroleum
37. PHT experiments 53 Texas Tech University Seyedhossein Emadibaladehi August 2014 Table 5 1 Sample Specifications Sample Sample Sample Sample Sample Large Cross 1 6604 17087 1 6106 1 6128 1 6309 Area in Medium Cross R 1 6513 1 7018 1 6083 1 5971 1 6286 Area in Average Cross Sectional 1 6087 1 6012 1 5987 1 629 Area 1n dm 3 007 2 917 2 849 2 801 2 757 Small Cross 1 6173 1 6764 1 5637 1 5859 1 6286 Area in 5 2 HPHT Experimental Condition Since it was intended to mimic wellbore condition during actual drilling opera tion Eagle Ford reservoir horizontal and overburden stresses and pore pressure were used to run HPHT experiments Initially all the five core samples were vacuumed and saturated with 30 000 ppm brine and placed in a High Pressure High Temperature HPHT core holder which was located inside a laboratory oven for 12 hours simulating wellbore conditions afterwards Minimum horizontal stress was computed by means of pore pressure and fracture propagation pressure which had been acquired from the field data A homogeneous horizontal stress regime SH Sn around the wellbore was pre sumed during running all HPHT experiments Reservoir depth and overburden stress gradient for these experiments were assumed 6 000 ft and lpsi ft correspondingly Fracture pressure and pore pressure gradients were assumed 0 95 psi ft and 0 58psi ft respectively In order to calculate reservoir tempe
38. VA ab 180 P 188 Figure 5 55 Poisson s Ratio vs Stress at 180 F 189 Figure 5 36 Stress vs Strain for Five Samples 190 Figure 5 37 On the left 140 F sample after running UCS test on the right 150 F sample after running UCS test 191 Figure 5 38 On the left 160 F sample after running UCS test on the right 170 F sample after running UCS test 191 Figure 5 39 180 F sample after running UCS test 192 xli Texas Tech University Seyedhossein Emadibaladehi August 2014 CHAPTER 1 INTRODUCTION The industry 1s still at the beginning of the learning curve for shale oil drilling operations however many shale oil wells have been drilled in recent years Drilling through shale oil formations 19 very problematic and imposes significant costs to the operators owing to wellbore stability problems These problems include but are not limited to tight holes stuck pipe fishing sidetracking and well abandonment Over 90 percent of wellbore instability problems occur in shale formations Instability in shale formations is a continuing problem that results in substantial annual expenditure by the petroleum industry 700 million according to conser
39. adibaladehi August 2014 Overburden Stress vs Time Figure 5 13 Overburden Stress vs Time at 160 F 167 Texas Tech University Seyedhossein Emadibaladehi August 2014 Horizontal Stress vs Time Time hr Figure 5 14 Horizontal Stress vs Time at 160 F 168 Texas Tech University Seyedhossein Emadibaladehi August 2014 Temperature vs Time Figure 5 15 Temperature vs Time 169 Texas Tech University Seyedhossein Emadibaladehi August 2014 Mud Pressure vs Time Figure 5 16 Drilling Fluid Pressure vs Time at 170 F 170 Texas Tech University Seyedhossein Emadibaladehi August 2014 Pore Pressure vs Time P psi Time hr Figure 5 17 Formation Pore Pressure vs Time at 170 F 171 Texas Tech University Seyedhossein Emadibaladehi August 2014 Overburden Stress vs Time Figure 5 18 Overburden Stress vs Time at 170 F 172 Texas Tech University Seyedhossein Emadibaladehi August 2014 Horizontal Stress vs Time HB P mn i s 5400 Figure 5 19 Horizontal Stress vs Time at 170 F 173 Texas Tech University Seyedhossein Emadibaladehi August 2014 Temperature vs Time Figure 5 20 Temperature vs Time 174 Texas Tech University Seyedhossein Emadibaladehi August 2014 Mud Pressure vs Time Figure 5 21 Drilling Fluid Pressure vs Time at 180 F 175 Texa
40. aladehi August 2014 Displacement in D 0007 D 0005 0 0001 D 0001 Node 06 Inside Time sec Radial Diagonal Figure 4 16 Node 06 Displacement Distilled Water 56 Texas Tech University Seyedhossein Emadibaladehi August 2014 Mode 06 Inside BR i HH n E a N W N W 4449949944444 rrr N a a gt 4 ee eee ee ee Ab 7 J4 4 q asa 484840 4444 444444 4444444499999999 3E 09 3E 09 1E 09 1E 09 09 5 09 385 ui guion s Time sec Distilled Water 17 Node 06 Swelling Rate Figure 4 57 Texas Tech University Seyedhossein Emadibaladehi August 2014 Strain Ratio Distilled Water 0 3 Strain Ratio Time sec Figure 4 18 Strain Ratios for all Four Submerged Nodes Distilled Water In the first test distilled water swelling rates 1n the axial and diagonal direc tions dropped at an early stage and then stabilized after almost 1 6 days The swelling rates remained approximately constant for almost 2 8 days then they gradually dropped and get stabilized afterwards The swelling rate in the radial direction was negative at the beginning increased as time passed and became almost constant after 1 6 days After that it behaved like axial swelling with a different rate Also a difference between rates at nodes was observed Based on the results s
41. aladehi August 2014 Figure 3 19 Autoclave Engineering Incorporation valve 3 3 4 Data Acquisition System DAQ The data acquisition system including hardware and software will be discussed in the following sections The main basis for the acquisition system is the National In strument NI system which 15 used to record all the parameters including temperature radial stress axial stress pore pressure and drilling fluid pressure 3 3 3 Desktop Computer A desktop computer was used as the host computer to record radial and axial stresses pore and drilling fluid pressures and temperature during running the HPHT experiments The computer was connected to a National Instruments NI Compact FieldPoint cFP with a crossover Ethernet cable Online data from pressure and tem perature sensors was sent to the Compact FieldPoint and from there to the host com puter A LabView program was employed to convert the input data in voltage to the pressures and temperature The same program was also adopted to record and save the online data on the computer 28 Texas Tech University Seyedhossein Emadibaladehi August 2014 3 3 3 2 Compact FieldPoint cFP A NI Compact FieldPoint cFP was used to receive the online data from the pressure transducers and temperature sensor and send them to the computer through a crossover Ethernet cable It has an internal Central Processing Unit CPU which con trols all the activities in the cFP This
42. ar 79 Figure 4 39 Node 02 Displacement 7 KCI Perpendicular 90 Figure 4 40 Node 02 Swelling Rate 7 Perpendicular 81 Figure 4 41 Node 03 Displacement 7 KCI 82 Figure 4 42 Node 03 Swelling Rate 7 KCI Perpendicular 93 Figure 4 43 Node 04 Displacement 7 KCI Perpendicular 94 Figure 4 44 Node 04 Swelling Rate 7 Perpendicular 95 Figure 4 45 Node 05 Displacement 7 86 Figure 4 46 Node 05 Swelling Rate 7 Perpendicular 97 Figure 4 47 Node 06 Displacement 7 KCI Perpendicular 88 Figure 4 48 Node 06 Swelling Rate 7 Perpendicular 99 Figure 4 49 Swelling Ratio 7 KCI Perpendicular 90 Figure 4 50 Node 01 Displacement 7 KCI Parallel 91 Figure 4 51 Node 01 Swelling rate 7 KCI Parallel 02 Figure 4 52 Node 02 Displacement 7 Parallel 93 Figure 4 53 Node 02 Swelling rate 7
43. at the early stage and go up as time passes Like axial and diagonal swelling rates they stabi lize after 2 days and almost remain constant until the end of the test It should also be cited that radial swelling rates are greater than axial and diagonal swelling rates in nodes three and five whilst in nodes two and six axial swelling rates are at the maximum Furthermore swelling rates in nodes three and five are almost twice that of swelling 71 Texas Tech University Seyedhossein Emadibaladehi August 2014 rates in nodes four and six Figure 4 22 Figure 4 24 Figure 4 28 and Figure 4 30 This illustrates that swelling in the various directions is different so finding the direc tion in which the least swelling happens is unquestionably crucial to minimize swelling and consequently wellbore stability problems The strain ratios for all four nodes sub merged in the 7 KCI solution are almost the same as strain ratios in distilled water Figure 4 31 Swelling rates all directions for the distilled water test are greater than the ones for the 7 solution In some cases the swelling rate of the specimen in the 7 KCI fluid 15 as low as half of that for the one in distilled water The total volume change of the specimen submerged in distilled water and the one submerged in 7 KCl fluid are 0 69 and 0 15 correspondingly The volume change was measured from the original volume As the results clearly show the swelling in di
44. atic 37 Texas Tech University Seyedhossein Emadibaladehi August 2014 3 4 HPHT Test Procedure Experimental procedure which was used to run HPHT and UCS tests are de scribe detail below l 2 10 1 m 12 13 14 15 16 17 Cut core sample from the main core sample Measure and record the core sample dimensions and dry weight Vacuum the core sample for 12 hours using two Welch vacuum pumps which provide 14 7 psi vacuum pressure Saturate the core sample with 30 000 brine for 12 hours Put the core sample inside the core holder Close valve numbers 6 and 7 Open valve number 5 Open axial and radial stresses valves valve numbers 3 and 4 Put the core holder inside the oven Turn on the oven at desirable temperature and run it for 12 hours Open valve number 7 Apply axial and radial stresses up to 4 600 psi simultaneously using En erpac P 392 Hand Pump Close axial stress valve valve number 3 Resume applying radial stress to 6 000 psi Close radial stress valve valve number 4 Open the nitrogen cylinder regulator Pressure has to be in the range of 65 115 psi Start Quizix pumps to apply pore pressure 3 500 psi and drilling mud pressure 3 800 psi 38 18 19 20 2 22 29 24 Texas Tech University Seyedhossein Emadibaladehi August 2014 Start the LabView to record the pressures and temperature data Run the test for 12 hour
45. cFP was designed and manufactured by National Instruments The model number of cFP is cFP 2200 It has al28 Mega Bites MB Dy namic Random Access Memory DRAM and 1 128 MB storage and one Ethernet slot The model and specifications of the two modules which were used to receive pressure and temperature data will be discussed in the following sections 3 3 3 2 1 cFp AI 112 cFP AI 112 is a 16 channel 16 bit analog input AI module This is FieldPoint analog input module with the following features and specifications cFP Al 112 manual e 16 analog voltage input channels e Fight voltage input ranges 0 1 V 0 5 V 0 10 V 10 V 5 V 10 V 60 mV and 300 mV e 16 bit resolution e 50 and 60 Hertz Hz filter settings 250 Vrms CAT II continuous channel to ground insolation verified by 2 300 Vrms one minute dielectric withstand test 40 to 70 C operation Host swappable Gain error drift 20 ppm C Offset error drift 6 wV C Power from network module 350 mW Humidity 10 90 RH noncondensing This module has 16 channels and can handle inputs from up to 16 channels however for HPHT tests only four channels were used to receive data from four Heise pressure transducers 3 3 3 2 2 cFP CT 120 The cFP TC 120 is a 16 bit FieldPoint thermocouple input module with the fol lowing features CFP CT 120 manual e Eight thermocouple or millivolt inputs 20 Texas Tech University Seyedhossein Emadibaladeh
46. ch University Seyedhossein Emadibaladehi August 2014 Node 02 Swelling Rate 0 000012 0 00001 Swelling Rate in hr Time hr Figure 4 90 Node 02 Swelling Rate OBM Parallel 131 Texas Tech University Seyedhossein Emadibaladehi August 2014 Displacement in 0 0003 0 00025 0 0002 0 00015 0 0001 0 00005 0 00005 Node 03 Displacement Time hr Figure 4 91 Node 03 Displacement OBM Parallel 132 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 03 Swelling Rate 0 000005 0 000004 0 000003 0 000002 ing Rate in hr 0 000001 0 000002 0 000003 0 000004 Time hr Figure 4 92 Node 03 Swelling Rate OBM Parallel 133 Texas Tech University Seyedhossein Emadibaladehi August 2014 Displacement in 0 00025 0 0002 0 00015 0 0001 0 00005 0 00005 Node 04 Displacement Time hr Figure 4 93 Node 04 Displacement OBM Parallel 134 Texas Tech University Seyedhossein Emadibaladehi August 2014 Swelling Rate in hr 0 00001 3 0 000002 Node 04 Swelling Rate Time hr Figure 4 94 Node 04 Swelling Rate OBM Parallel 135 s Axial Radial Diagonal Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 05 Displacement 0 0003 0 00025 0 0002 0 00015 Axial Radial Diagonal 0 0001 Displacem
47. ch University Seyedhossein Emadibaladehi August 2014 Temperature vs Time T T RA III I TA Figure 5 5 Temperature vs Time 159 Texas Tech University Seyedhossein Emadibaladehi August 2014 Mud Pressure vs Time Figure 5 6 Drilling Fluid Pressure vs Time at 150 F 160 Texas Tech University Seyedhossein Emadibaladehi August 2014 Pore Pressure vs Time P psi Time hr Figure 5 7 Formation Pore Pressure vs Time at 150 F 161 Texas Tech University Seyedhossein Emadibaladehi August 2014 Overburden Stress vs Time Figure 5 8 Overburden Stress vs Time at 150 F 162 Texas Tech University Seyedhossein Emadibaladehi August 2014 Horizontal Stress vs Time stress psi Time hr Figure 5 9 Horizontal Stress vs Time at 150 F 163 Texas Tech University Seyedhossein Emadibaladehi August 2014 Temperature vs Time i III x x Figure 5 10 Temperature vs Time 164 Texas Tech University Seyedhossein Emadibaladehi August 2014 Mud Pressure vs Time P psi Time hr Figure 5 11 Drilling Fluid Pressure vs Time at 160 F 165 Texas Tech University Seyedhossein Emadibaladehi August 2014 Pore Pressure vs Time P psi Time hr Figure 5 12 Formation Pore Pressure vs Time at 160 F 166 Texas Tech University Seyedhossein Em
48. ction will discuss the experimental equipment the second section will discuss the data acquisition hardware and software while the third section will give details of the experimental procedures used 3 1 Swelling Test Apparatus Experimental apparatus and their specifications which were used in running swelling tests are discussed in this section 3 1 1 Pre Wired Strain Gauge Pre wired stacked rosette strain gauges were used to measure swelling of the sample inside as well as outside the water based and oil based fluids as shown in Figure 3 allows us to measure swelling in three different directions axial lateral and diago nal 0797 457 907 The strain gauges were supplied by Vishay Precision Group The strain gauge model was C2A 06 250WW 350 The strain gauge properties are shown in Table 3 Table 3 1 C2A 06 250WW 350 Strain Gauge Properties Gage Resistance Ohm 350 20 690 Gage Length in 0 250 Overall Pattern Length in 0 362 Grid Width in 0 100 Overall Pattern Width in 0 375 Matrix Length in 0 420 Matrix Width in 0 480 10 Texas Tech University Seyedhossein Emadibaladehi August 2014 Figure 3 1 Stacked rosette strain gauge 3 1 2 Epoxy Epoxy was used to prepare a proper base for strain gages which will be mounted on rock samples Epoxy yields a better bondage between strain gages and rock sample and as a results more accurate data will be collected Epoxy is put on rock sample 24 hours before in
49. der to equalize solute con centration on the both sides There are two types of semi permeable membrane which are called ideal semi permeable membrane and non ideal semi permeable membrane Texas Tech University Seyedhossein Emadibaladehi August 2014 An ideal semi permeable membrane only allows water molecules to pass through while a non ideal semi permeable membrane allows water molecules and ions to move to the region of lower concentration Shale is a non ideal semi permeable membrane and the degree of non ideality depends on shale parameters e g CEC pore throat size and surface area and fluid parameters e g size of hydrated solute The ideality of the membrane system 15 the ratio of the measured osmotic pressure to the theoretical os motic pressure The membrane efficiency 15 calculated using the equation AP where AP is the actual osmotic pressure and Az is the theoretical osmotic pressure Van Oort et al 1996 concluded that the extent of osmotic flow in shale in contact with water based drilling fluids 1s determined by the efficiency of the non ideal shale fluid membrane system Typically shale predominantly consists of very small less than 0 0004 cm sized particles of silt and clay Rabideau et al 1998 As a result shale have extremely low permeability For instance the permeability of Wellington shale is 3x 10 7 mD under the 8 000 psi effective stress Chenevert and Sharma 1993 It has been shown that the hydra
50. does Since maximum and minimum swelling take place in the directions of parallel and perpendicular to the bedding drilling in the direction of per pendicular to the bedding provides a more stable wellbore in matter of swelling OBM results in less swelling in comparison with 7 KCl and accord ingly using OBM as drilling fluid during drilling operations causes less wellbore stability problems in terms of swelling Shrinkage was observed at the beginning of the swelling tests which were run in OBM This phenomenon 15 most likely because of the wet tability properties of the core samples which causes oil absorption that pushes initial water content away 6 2 Recommendations The followings are the recommendations for further work and future research l It is recommended obtaining more core samples in various directions in cluding perpendicular parallel and diagonal to the bedding and then running the swelling and UCS tests to come up with a better determina tion of the best possible path for drilling wells with the least wellbore stability problems It is also recommended that experiments be run with different drilling fluids including Oil Based Mud OBM to investigate the effect of the various drilling fluids on rock UCS Additionally It is recommended to run more experiments using Water Based Muds WBM with various additives like glycol and compare the results with OBM and 7 KCl in order to come up with the best
51. e Drilling Fluid Interaction for Studies of Wellbore Stability Paper 05 816 presented at the 40th U S Symposium on Rock Mechanics USRMS Anchorage Alaska June 25 29 Quint Power Supply Manual QX Series Pump User s Manual Rabideau A Khandewal A 1998 Boundary conditions for modeling transport in vertical barriers J Environ Eng ASCE 124 11 1135 1139 Stephens M Gomez Nava S Churan M 2009 Laboratory Methods to Assess Shale Reactivity with Drilling Fluids Paper AADE 2009 NTCE 11 04 presented at the AADE Nation Technical Conference and Exhibition New Orleans Tare U Mody F K and Mese A L 2000 Understanding Chemical Potential Related Transient Pore Pressure Response to Improve Real Time Borehole In Stability Predictions Paper SPE PS CIM 65514 Calgary Thelco Oven Installation Service Manual 199 Texas Tech University Seyedhossein Emadibaladehi August 2014 Walls J D amp Sinclair S W 2011 Eagle Ford Shale Reservoir Properties from Digital Rock Physics EAGE First Break Volume 29 200 Texas Tech University Seyedhossein Emadibaladehi August 2014 VITA Seyedhossein Emadibaladehi known as Hossein at Texas Tech came to Lub bock Texas in June 2011 to pursue a PhD degree in petroleum engineering Before joining Texas Tech he worked for Petropars Ltd PPL as drilling and wellsite drilling engineer for three and half years approximately Prior to working for Petropars Ltd he
52. e Ford rock uniaxial com pressive strength UCS By increasing temperature from 140 to 180 F UCS decreases down to 72 of original value 2 Temperature does not have substantial effects on the Young s modulus E of the Eagle Ford rock samples 3 Temperature has a minor effect on the Poisson s ratio v of the Eagle Ford rock samples 4 The Eagle Ford core samples fail through a vertical plane clearly marked from the top of the sample continuing all the way to the bottom which is quite different how sandstone samples fail This behavior could be ex plained by the existence of natural fractures 5 The results of the experiments demonstrate that swelling is not very im portant in the Actual Eagle Ford oil shale core samples Maximum vol ume change due to swelling was 0 69 using distilled water When using 7 KCI swelling of sample dropped to 0 15 6 Swelling rates in 7 KCl are almost half of the swelling rate distilled water In addition volume change due to swelling in 7 KCl is almost one third of the volume change due to swelling in distilled water Hence by using 7 KCl a more stable wellbore during drilling operations will be anticipated 193 4 10 Texas Tech University Seyedhossein Emadibaladehi August 2014 Both 7 KCI and distilled water have unfavorable effects on rock com pressive strength but the 7 KCI solution reduces rock compressive strength less than the distilled water
53. e data during running HPHT tests LabVIEW is a graphical programming language that uses icons instead of lines of text to create applications In contrast to text based programming languages where instructions determine program execution Lab VIEW uses dataflow programming where the flow of data determines execution Lab View manual In LabVIEW a user interface with a set of tools and objects is built The user interface is known as the front panel Then a code using graphical representations of functions to control the front panel objects is added The block diagram contains this code In some ways the block diagram resembles a flowchart 32 Texas Tech University Seyedhossein Emadibaladehi August 2014 LabVIEW as a data acquisition software makes the following tasks possible real time and simultaneously e acquisition of data at specified sampling rate e data acquisition processing and analysis e programmable hardware control and automation e data storage to disk e single user interface to communicate with various data acquisition modules and boards LabVIEW is programmed with a set of icons that represents controls functions and other tools that are used in writing an executable program It has several program ming tools like debugging data acquisition functions mathematical libraries data anal ysis and data storage Abiodun Mathew Amao 2011 An executable LabVIEW program or code is called a virtual instrument VI
54. e effect of each fluid on the rock mechanical properties including unconfined compressive strength UCS Young s modulus E and Poisson s v ratio one intact sample was tested and the result was compared to the results obtained from the samples after being submerged and tested for swelling UCS tests were performed according to ASTM D 29538 To perform the UCS an MTS machine and five Linearly Variable Displacement Transducers LVDT s were employed To obtain Poisson s ratio the five LVDT s were used to measure radial and axial displacements For radial displacements four transducers were located around the specimen and measurements were recorded MTS machine and LVDTs configuration is shown in Figure 4 4 43 Texas Tech University Seyedhossein Emadibaladehi August 2014 Figure 4 4 MTS machine and LVDT s set up As previously shown in Table 4 1 in matter of mineralogy the Eagle Ford shale oil rock samples are extensively different from conventional shale formations As shown in Table 4 1 the amount of clay is significantly lower than conventional shale rocks which typically have 6096 clay minerals This results in these shale oil samples be less sensitive to water compared to common shale samples The of the sample 15 17 3me 100gr which is categorized in the moderately reactive shale group Moderately reactive shale has a CEC value from 10 to 20me 100gr while reactive shale has a CEC value greater than 20me 100gr Stephe
55. e pore fluid Lempp et al 1994 The effect of temperature on tensile and compressive strengths and Young s modulus of oil shale was investigated at elevated temperature P J Closmann and W B Bradley 1979 They found that both tensile and compressive strengths of oil shale show a marked decrease in strength as temperature increased They also found that Young s modulus in both tension and compression decreases with temperature with the decrease for tension being the greater Texas Tech University Seyedhossein Emadibaladehi August 2014 The effect of the temperature on mechanical behavior of shale core samples was investigated Masri et al 2009 The range of temperature in that study was from 68 F to 482 F and the range of confining stress was from O to 2 900 psi They found that strength of the shale core sample Tournemire Shale is strongly dependent of tempera ture Effect of temperature on yielding behavior of carbonate rocks was also investi gated Lisabeth et al 2012 No experiments were carried out to assess effect of temperature on the mechan ical properties of shale oil rock core samples Texas Tech University Seyedhossein Emadibaladehi August 2014 CHAPTER 3 EXPERIMENTAL SETUP EQUIPMENTS AND PROCEDURES This chapter gives the description of the equipment and procedures used in car rying out the measurement of swelling rock mechanical properties and HPHT setup used for this study The first se
56. ecifications 20 3 9 9 VACUUM a 24 3 3 4 Data Acquisition System 28 SAPI Roc cede dtu tm i atas 38 4 S WELLING EXPERIMENTS RESULTS AND DISCUSSION OF RESULTS R P 40 4 1 Experimental Results Actual Eagle Ford Core Samples 40 4 1 1 Core GharacterzallOD ci oic e 40 4 1 2 Swelling Test Results Distilled 46 4 1 3 Swelling Test Results 7 59 4134 JOSI lu u u ee 73 4 2 Experimental Results Commercial Eagle Ford Core Samples 75 111 Texas Tech University Seyedhossein Emadibaladehi August 2014 4 2 1 Core Characterization ee OLL GE SLE 75 4 2 2 Swelling Test Results 7 4 8 78 5 HPHT EXPERIMENTS RESULTS AND DISCUSSION OF RESULTS 153 Jl Core C DaraeterizadtiOts ore etr ess inea vie Sean Sects ce doe eret sr k i 153 HPHT Experimental Conditio see 154 HPHT Experimental Result aaa 180 6 CONCLUSIONS AND RECOMMENDATION S 193 Ole OMG IUSIOLDSi un sata tut ince
57. ella R Wu 2012 Shale Gas Drilling Experience and Lessons Learned from Eagle Ford Paper SPE 155542 presented at the American Unconventional Resources Conference Pittsburgh LabView manual Lempp Ch Natau O Bayer U Welte D H 1994 The effect of temperature on rock mechanical properties and fracture mechanisms in source rocks Experimental 198 Texas Tech University Seyedhossein Emadibaladehi August 2014 results Paper SPE 28039 presented at Rock Mechanics in Petroleum Engineering Delft Netherlands 29 31 August http dx do1 org 10 2118 28039 MS Lisabeth H P Watter K E Zhu W 2012 Effect of Temperature on Yielding Behavior of Carbonate Rocks Paper ARMA 12 427 presented at 46 US Rock Mechanics Geomechanics Symposium Chicago IL USA 24 27 June 2012 Masri M Siabi M Shao J 2009 Experimental Study of the Temperature on the Mechanical Behavior of Anisotropic Rock Paper SINOROCK 2009 040 ISRM Conference Paper Methylene Blue Test for Drill Solids and Commercial Bentonites Section 12 Recommended Practices 13I Laboratory Testing of Drilling Fluids 7th ed And ISO 10416 2002 American Petroleum Institute February 2004 34 38 Mody F K amp Hale A H 1993 Borehole stability Model to Couple the Mechanics and Chemistry of Drilling Fluid Shale Interactions Paper JPT 1093 1101 Muniz E S Fontoura S A B Duarte R G Lomba R T F 2005 Evaluation of the Shal
58. elling Rate OBM Perpendicular 123 Figure 4 83 Node 05 Displacement OBM 124 Figure 4 84 Node 05 Swelling Rate OBM Perpendicular 125 Figure 4 85 Node 06 Displacement OBM 126 Figure 4 86 Node 06 Swelling Rate OBM Perpendicular 127 Figure 4 87 Node 01 Displacement OBM 128 Figure 4 88 Node 01 Swelling Rate OBM Parallel 129 Figure 4 89 Node 02 Displacement OBM 130 Figure 4 90 Node 02 Swelling Rate OBM Parallel 131 Figure 4 91 Node 03 Displacement OBM 132 Figure 4 92 Node 03 Swelling Rate OBM Parallel 133 X Texas Tech University Seyedhossein Emadibaladehi August 2014 Figure 4 93 Node 04 Displacement OBM 134 Figure 4 94 Node 04 Swelling Rate OBM Parallel 135 Figure 4 95 Node 05 Displacement OBM 136 F
59. ent 0 00005 0 00005 0 0001 Time hr Figure 4 95 Node 05 Displacement OBM Parallel 136 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 05 Swelling Rate 0 000015 0 00001 Swelling Rate in hr 0 000005 0 00001 0 000015 Time hr Figure 4 96 Node 05 Swelling Rate OBM Parallel 137 Texas Tech University Seyedhossein Emadibaladehi August 2014 Displacement 0 001 0 0002 Node 06 Displacement Time hr Figure 4 97 Node 06 Displacement OBM Parallel 138 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 06 Swelling Rate 0 000015 0 00001 0 000005 Swelling Rate in hr 0 000005 Time hr Figure 4 98 Node 06 Swelling Rate OBM Parallel 139 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 01 Displacement 0 00004 0 00003 0 00002 0 00001 0 00001 Displacement 0 00002 0 00003 0 00004 0 00005 Time hr Figure 4 99 Node 01 Displacement OBM Diagonal 140 Texas Tech University Seyedhossein Emadibaladehi August 2014 Swelling Rate in hr 0 000004 0 000003 0 000002 0 000001 U 0 000002 0 000003 0 000004 Node 01 Swelling Rate 80 100 120 140 150 180 Time hr Figure 4 100 Node 01 Swelling Rate OBM Diagonal 141 Texas Tech
60. erational functions LabVIEW works with an accompanying software called MAX Measurement and Automation Explorer MAX is the software through which the user interfaces di rectly with the devices on the data acquisition DAQ system MAX can be used to configure a DAQ device troubleshoot and install software etc Compatible MAX soft ware versions must be installed on the host computer and the device drivers 34 Texas Tech University Seyedhossein Emadibaladehi August 2014 When data are about to be acquired using an executable VI it must be physically ensured that all the field devices are powered and working normally LabVIEW is then launched and the VI 16 started by clicking the run button This leads to a sequence of events The VI is downloaded via the Ethernet to the compact field point module cFP 2200 The cFP 2200 then initializes and commands all the other data acquisition mod ules on the chassis to start acquiring data from the transducers based on the specific instructions given by the program user The cFP 2200 then acquires the data from the modules and transmits them to LabVIEW on the host computer via the crossover Ether net Figure 3 23 and Figure 3 24 are depicting the front panel and block diagram of the VI designed for the HPHT setup experiments The HPHT setup schematic is shown in Figure 3 25 Testvi Front Panel E _ ae File Edit View Project Operate Tools Window dms
61. esent swell and cause the shale to break apart A higher CEC shale sometimes is referred to as gumbo shale Stephens et al 2009 in common shale rock samples are higher than shale oil samples Common shale samples are usually highly reactive while shale oil samples are usually low or moderately reactive As a case in the point two CEC s for shale gas and shale oil core samples from Eagle Ford formation are 5 and 17 3 meg 100g respectively Guo et al 2012 and Emadi et al 2013 Table 1 1 CEC of Major Clay Minerals and sand Stephens et al 2009 Clay Mineral CEC Meq 100g Smectite 80 120 Chlorites 10 40 Illites 10 40 Kaolinites 3 15 Sand 0 5 meq 100g Texas Tech University Seyedhossein Emadibaladehi August 2014 1 1 2 Swelling Properties While drilling through shale formation due to formation low permeability there is a constant movement of water based drilling fluid into the formation which causes an increase in pore pressure in the shale formation which ultimately results in swelling In the case of swelling the shale formation extends into the wellbore and is eroded by the circulating drilling mud Over time the erosion causes a larger borehole diameter than originally drilled hole Borehole washout is the technical term which is used to describe this problem This might result in pipe stuck during drilling operation excessive torque and drag pipe stuck during casing running operation a
62. f a core sample from Shale Gas Eagle Ford reservoir Guo et al 2012 Mineral Smectite Calcite Quartz Dolomite Feldspars Kaolinite Pyrite 1 2 Research Objectives The objectives of this research are e Investigate effects of different water based fluids on swelling properties and rock mechanical properties of Eagle Ford Shale Oil samples e Investigate effects of water based fluid and oil based fluid on swelling properties of Eagle Ford Shale Oil samples e Finding optimum well path in Eagle Ford shale oil formation e Investigate effect of temperature on rock mechanical properties of Eagle Ford Shale Oil samples 1 3 Research Methodology These objectives will be achieved by following the framework presented below e Representative core samples are obtained from productive Eagle Ford reservoir e Mineralogy and of the core samples are determined e Swelling of the core samples are measured in various directions while the sample is submerged in different water based and oil based fluids Texas Tech University Seyedhossein Emadibaladehi August 2014 A High Pressure High Temperature HPHT setup is built which allows to simulate wellbore condition during drilling operation Uniaxial Compressive Strength USC test is performed on the core sam ples after putting the HPHT setup Texas Tech University Seyedhossein Emadibaladehi August 2014 CHAPTER 2 LITERATURE REVIEW In this chapter
63. hloride KCI brine and Oil Based Mud OBM Several experiments have been performed using strain gages to measure lateral axial and diagonal swelling in both submerged and non submerged areas To simulate actual well conditions a High Pressure High Temperature HPHT core holder was used to apply different axial and radial confining stresses equivalent formation pore pressure and drilling fluid wellbore pressure The experiments were conducted under elevated temperatures to better mimic real drilling operations Satu rated shale oil core samples from the Eagle Ford field were tested under various tem peratures including reservoir temperature I also performed Unconfined Compressive Strength UCS tests were performed to investigate the effect of temperature on the compressive strength of the core samples The experimental setup was modified to ac commodate five Linearly Variable Displacement Transducers LVDTSs to measure Young s Modulus and Poisson s ratio v Various experiments were run to quantify the effect of temperature on the rock compressive strength E and v Experiments have shown a distinct change in the mechanical properties of the rock V Texas Tech University Seyedhossein Emadibaladehi August 2014 LIST OF TABLES Table 1 1 CEC of Major Clay Minerals and sand Stephens et al 2009 2 Table 1 2 Mineralogy for a core sample from Shale Oil Eagle Ford IC CO E CA O 5
64. hown in Figure 4 18 strain ratios the ratio of radial strain to axial strain for all four nodes submerged into the water are nearly the same 58 4 1 Texas Tech University Seyedhossein Emadibaladehi August 2014 3 Swelling Test Results 7 KCl In this section the swelling results of the actual Eagle Ford shale oil sample submerged in 7 KCl are presented Displacement in Node 01 Out D 00035 D 0003 Radial Axial Diagonal u I 7 D 0D01 Time sec Figure 4 19 Node 01 Displacement 7 KCl 59 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node01 Out 5E 10 v a uh g m 0 Axial 2 Radial 8 Diagonal 1E 09 Time sec Figure 4 20 Node 01 Swelling Rate 7 KCl 60 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 02 In ao j L Radial SPASA Figure 4 21 Node 02 Displacement 7 KCl 61 Texas Tech University Seyedhossein Emadibaladehi August 2014 Swelling Rate in sec Node02 In Radial 2 09 Axial Diagonal w ae T musim Ca Calm lt ar 100000 200000 300000 ADDDDD SDDDDD 700000 1E 09 Time Sec Figure 4 22 Node 02 Swelling Rate 7 KCl 62 Texas Tech University Seyedhossein Emadibaladehi August 2014 Displacement Node 03 In
65. i August 2014 e Built in linearization and cold junction compensation for eight thermocouple types J K R S T N E and B Four voltage ranges 25 50 100 and 20 to 80 mV Open thermocouple detection and indicator LEDs 16 bit resolution Differential inputs Filtering against 50 and 60 Hz noise 2 300 Vrms transient overvoltage protection between the inter module commu nication bus and the I O channels 250 Vrms isolation voltage rating 40 to 70 operation Hot plug and play This module has 8 channels and can handle inputs from up to 8 channels how ever for HPHT tests only two channels were used to record oven and room tempera tures its modules and power supply are depicted Figure 3 20 Figure 3 20 cFP 2200 its modules and power supply 30 Texas Tech University Seyedhossein Emadibaladehi August 2014 3 3 3 3 Pressure Transducers Four pressure transducers were employed to convert pore pressure drilling mud pressure radial and axial stresses to voltage and send it to the cFP of them were designed and manufactured by HEISE The model number of the pressure transducers is 621 with serial numbers 56 5447 56 7996 S6 13645 56 13638 They are rated at 10 000 psi The input and output voltage for them are 20 40 Volt Direct Current VDC and 0 10 VDC respectively 20 VCD was used through the all HPHT experi ments pictorial view of the Heise pressure transducer 15 show
66. igure 4 96 Node 05 Swelling Rate OBM Parallel 137 Figure 4 97 Node 06 Displacement OBM Parallel 138 Figure 4 98 Node 06 Swelling Rate OBM Parallel 139 Figure 4 99 Node 01 Displacement OBM Diaeonal 140 Figure 4 100 Node 01 Swelling Rate OBM Diaseonal 141 Figure 4 101 Node 02 Displacement OBM Diaeonal 142 Figure 4 102 Node 02 Swelling Rate OBM Diaeonal 143 Figure 4 103 Node 03 Displacement OBM Diaeonal 144 Figure 4 104 Node 03 Swelling Rate OBM Diaseonal 145 Figure 4 105 Node 04 Displacement OBM Diaeonal 146 Figure 4 106 Node 04 Swelling Rate OBM Diaseonal 147 Figure 4 107 Node 05 Displacement OBM Diaeonal 148 Figure 4 108 Node 05 Swelling Rate OBM Diaseonal 149 Figure 4 109 Node 06 Displacement OBM Dtiagonal 150 Figure 4 110 Node 06 Swelling Rate OBM Diaseonal 151 Figure 5 1 D
67. illing operations six experiments clearly demonstrate that more wellbore stability problems associated with swelling happen if wellbore 1s drilled in the parallel direction to the bedding 152 Texas Tech University Seyedhossein Emadibaladehi August 2014 CHAPTER 5 HPHT EXPERIMENTS RESULTS AND DISCUSSION OF RE SULTS In this chapter the results of HPHT experiments carried out on actual Eagle Ford core samples are presented In the first part the experimental conditions including stresses pressures and temperatures will be discussed in details In the second part the results of UCS tests including unconfined compressive strength Young s modulus E and Poisson s ratio v which were performed after running HPHT tests will be pre sented 5 1 Core Characterization For this study a sample from the Eagle Ford shale oil formation was selected The material can be described among sedimentary rocks as a shale oil with 26 clay 0 65 water content w 196 absorption and a unit weight of 158 lbm ft pcf Five samples were cored and prepared from the main sample so we had one sample per experiment All samples were prepared according to specifications from American So ciety for Testing and Materials ASTM D 2938 and labeled as 140 F 150 F 160 F 170 F and 180 F indicating the temperature under which the samples were tested Table 5 1 summarizes specifications of the all five core samples which were used for H
68. iversity Seyedhossein Emadibaladehi August 2014 1 1 Differences between Common Shale and Shale Oil Samples Proper ties Shale formations have some properties which distinguish them from other com mon formations such as sandstone limestone and dolomite Shale formations are also different from shale oil and shale gas formations The properties which distinguish shale formations from shale oil formations will be discussed below 1 1 1 Cation Exchange Capacity CEC Cation Exchange capacity CEC 1s a measure of the exchangeable cations pre sent on the clays in a shale sample These exchangeable cations are the positively charged ions that neutralize the negatively charged dry particles Typical exchange ions are sodium calcium magnesium iron and potassium The CEC measurements are ex pressed as milli equivalent per 100 grams of dry clay meq 100g Stephens et al 2009 Typically the oil and gas industry measures the CEC with an API recommended methylene blue capacity test API Recommended Practices 131 The CEC of common clay minerals have been measured and presented in Table 1 1 The higher the CEC 1s the more reactive the shale Sandstone and limestone typically are nonreactive and have CEC values of less than 1 meq 100g Moderately reactive shale has CEC value from 10 to 20 meg 100g while reactive shale has a value greater than 20 meq 100g A low can still be problematic if the small amount of clays pr
69. lacement Quizix Pumps 24 Figure 3216 Welch vacuum DO ooo eot OO cone ala a yo 23 Figure 3 17 Floating Piston Accumulators used in HPHT Setup 26 Figure 3 18 Nitrogen Cylinder used in HPHT Setup 27 Figure 3 19 Autoclave Engineering Incorporation valve 28 Figure 3 20 cFP 2200 its modules and power supply 30 Fisure 5 21 HEISE Pressure Transdueer au ee cedo deeem un oed ded eui a n 3 Figure 3 22 EXTECH Instruments power supply 32 Fioure 5 25 Lab iw Front Pane ae E 35 Figure 5 24 Labview Block Dia er ain nen ea ves AND Gyw sr rea CURODD 36 Fiure gt 25 DREI Setun Schemata zarten anal 37 Fiseure 41 Strain cause oca OBS anna 42 Figure 4 2 Sample prepared for swelling 42 Lieure 4 5 Environmental Chamber au san po a 43 Picure 4A MIS machine and LADY Ss ae i to 44 vli Texas Tech University Seyedhossein Emadibaladehi August 2014 Figure 4 5 On the left is the placement of nodes for the specimen submerged in 7 KCI fluid on the right is the location of nodes for the sample submerged in distilled water 45 Figure 4 6 Node 01 Displacement Distilled
70. ll be presented Displacement in 0 00018 0 00016 0 00014 0 00012 0 0001 0 00008 0 00006 0 00002 0 00002 0 00004 Node 01 Displacement Axial Radial Diagonal Time hr Figure 4 37 Node 01 Displacement 7 KCI Perpendicular 78 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 01 Swelling Rate 0 000005 0 000004 0 000003 0 000002 D 000001 Swelling Rate in hr I 0 000002 0 000003 0 000004 Time hr Figure 4 38 Node 01 Swelling Rate 7 KCI Perpendicular 79 Texas Tech University Seyedhossein Emadibaladehi August 2014 Displacement in 0 0002000 0 0001500 0 0001000 3 Node 02 Displacement 0 0000000 Time hr Figure 4 39 Node 02 Displacement 7 KCI Perpendicular 90 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 02 Swelling Rate 0 0000500 0 0000400 0 0000300 Axial m 0 0000200 Radial E Diagonal 0 0000100 0 0000000 D 0000100 Time hr Figure 4 40 Node 02 Swelling Rate 7 KCI Perpendicular 81 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 03 Displacement 0 0002500 0 0002000 0 0001500 0 0001000 Axial Radial Diagonal Displacement in 0 000000 0 0000500 0 0001000 Time hr
71. mulator was located outside the oven which contained drilling fluid 7 KCl The hydraulic oil FPA which was designed and manufactured by Ruska has a volume of 300 ml and is rated at 12 000 psi The drilling fluid FPA was also designed and manufactured by Ruska and has a volume of 1 000 ml and 15 rated at 12 000 psi The pore fluid FPA has a volume and working pressure of 500 ml and 3 000 psi respec tively Figure 3 17 displays all three FPA s 25 Texas Tech University Seyedhossein Emadibaladehi August 2014 7 KCI FPA 1 000 ml Brine FPA 500 ml Hydraulic Oil FPA 300 ml Figure 3 17 Floating Piston Accumulators used in HPHT Setup 3 3 2 7 Nitrogen Cylinder Bottle Nitrogen Cylinder was used to provide pressure and gas for the Quizix pumps As mentioned earlier the Quizix pumps need 65 115 psi 4 to 8 bar to operate properly A pictorial view of nitrogen cylinder is depicted in Figure 3 18 26 Texas Tech University Seyedhossein Emadibaladehi August 2014 Figure 3 18 Nitrogen Cylinder used in HPHT Setup 3 3 2 8 Valves Since all the experiments were conducted at high pressure Autoclave Engineer ing Incoprporation valves which are rated at 11 000 psi were used Therefore except for the brine FPA and Quizix pumps the HPHT setup can be used to run experiments at 10 000 psi Figure 3 19 shows Autoclave valve 27 Texas Tech University Seyedhossein Emadib
72. n in Figure 3 21 86 544 JOC Ds _ 10000 3 PUT 0 10 vor failure resutting in sure beyond top of sc pressure contalnin BAC or consult Dress ERE Figure 3 21 HEISE Pressure Transducer 3 3 3 4 Power Supplies Two power supply units were hired in the HPHT setup to provide the power for pressure transducers as well as a cFP Power Supply This 19 a Quint power supply and provides power for cFP during running HPHT tests It provides 24 Voltage V and 5 Am pere output The input can vary from 100 to 240 V at 50 60 Hz pictorial view of this power supply is shown in Figure 3 20 Quint Power Supply Manual 31 Texas Tech University Seyedhossein Emadibaladehi August 2014 b Pressure Transducers Power Supply This is an EXTECH Instruments power supply which provides power for four pressure transducers while running HPHT experiments It has dimensions of 7 9x3 5x8 5 WxHxD inches The input varies from 100 to 120 Volts Alternating Current V AC at 50 60 Hz It provides an output voltage up to 30 VDC and a current up to 20 A Figure 3 22 shows a picture of the EXTECH Instru ments power supply EXTECH Instruments Power Supply Manual DC REGULATED gt POWER SUPPLY VOLTAGE Figure 3 22 Instruments power supply 3 3 3 4 Data Acquisition Software National Instruments LabView National Instruments LabView 2012 software was used to record temperature and pressur
73. nd poor cementing operation Swelling properties depends on clay content and types of clay present in sample Since clay content in common shale formations 15 above 50 swelling in common shale sam ples is substantial and consequently causes costly problems during drilling operations Unlike common shale samples clay content in productive shale oil formation 15 less than 30 and the amount of smectite which 1s the most reactive clay type 15 very low For instance tests performed on two Eagle Ford shale oil and gas samples demonstrate very low clay content in both samples One which was taken from the oil producing region had 13 clay and the other one from gas producing zone had only 8 clay It should be mentioned that gas producing sample had only 6 smectite while the other one had no smectite Guo et al 2012 and Emadi et al 2013 Accordingly swelling in productive shale oil formations is much less than common shale formations Lab re sults also show that the failure mechanism and shale fluid interaction of Eagle Ford shale are different than dispersion or swelling which are typical of traditional shale for mations The main mechanism of shale fluid interaction 1s fracturing and de lamination along the bedding and enlargement of pre existing fractures Guo et al 2012 1 1 3 Osmosis in Shale Formations Osmosis is the net movement of solvent molecules through a semi permeable membrane into a region of higher solute concentration in or
74. neralogy for two different core samples which were taken from Eagle Ford reservoir are shown in Table 1 3 and Table 1 2 As illustrated Table 1 3 and Table 1 2 clay content shale gas and shale oil core samples from Eagle Ford reservoir are 8 and 13 respectively Moreover clay content in another core sample which was taken from Eagle Ford Shale Oil field en compasses 27 7 clay Walls and Sonclair 2011 Table 1 2 Mineralogy for a core sample from Shale Oil Eagle Ford reservoir Company Data Mineral Calcite Illite Mixed Layer 1 5 Kaolinite Quartz Pyrite Feldspar Apatite TOC 1 1 5 Pore Fluid Since common shale formations are not considered as hydrocarbon producing formations the most common fluid which is found in those formations is brine It should be mentioned that type of brine pore spaces differs from one formation to another Dissimilar common shale formations in addition to brine hydrocarbon is also present in pore spaces of shale oil and shale gas reservoirs As a result the presence of hydro carbon in the pore spaces and its interaction with drilling fluids must be taken into ac count while designing optimum drilling fluid to drill through shale oil and shale gas Texas Tech University Seyedhossein Emadibaladehi August 2014 formation in order to decrease the likelihood of wellbore stability problems as well as drill oil and gas wells more cost effectively Table 1 3 Mineralogy o
75. ns M Gomez Nava S Churan M 2009 As a result these core samples are not as reactive as conventional shale specimens and accordingly results in less wellbore stability problems due to swelling during drilling operations The swelling tests were performed on two samples submerged in two different fluids distilled water and 7 KCl The data was recorded on six stacked rosette strain gauges which were mounted on the two ends of each sample four of them were inside the fluid and the rest were outside It is important to mention that each stacked rosette 44 Texas Tech University Seyedhossein Emadibaladehi August 2014 strain gauge consists of three strain gages which are able to measure swelling in various directions including axially radially and diagonally 0 45 90 Also to refer easier to the swelling location on the specimen the location of strain gauges has been identified as nodes shown in Figure 4 5 NODE 01 NODE 02 Figure 4 5 On the left is the placement of nodes for the specimen submerged in 7 KCI fluid on the right 15 the location of nodes for the sample submerged in distilled water 45 Texas Tech University Seyedhossein Emadibaladehi August 2014 4 1 2 Swelling Test Results Distilled Water In this section the swelling results of the actual Eagle Ford shale oil sample submerged in distilled water will be resented Node 01 Outside ZHHF 150 3700 573 F7 117500
76. objects and other DAQ tools The VI receives in structions from the block diagram it 15 a pictorial solution to a programming problem and the source code of the VI LabVIEW has three palettes used in designing and programming They are con trol function and tools palettes The control palette is only available in the front panel window it contains controls and indicators used to create the front panel The controls and indicators are located on sub palettes grouped based on types and functions The functions palette is only available in the block diagram It contains the in built VIs and functions used to build program the block diagram The in built VIs are located on sub palette based on types and functions Tools palette are available in both the front panel and the block diagram A tool is a special operating mode of the mouse cursor Tools are used to modify and operate front panel and block diagram objects Terminals represent data types of the control or indicator They are also entry and exit ports that exchange information between the front panel and block diagram Nodes are objects in the block diagram that have input and or outputs and per forms operation when a VI is executed They are analogous to statements operators functions and subroutines in a text based programming language Wires are used to transfer data among block diagram objects Wires connect controls and indicators terminals to the nodes or op
77. onal 108 Figure 4 68 Node 04 Displacement 7 KCI Diaeonal 109 Figure 4 69 Node 04 Swelling rate 7 KCI Diagonal 110 Figure 4 70 Node 05 Displacement 7 KCI Diagonal 111 Figure 4 71 Node 05 Swelling rate 7 Diagonal 112 Figure 4 72 Node 06 Displacement 7 KCI Diaeonal 113 Figure 4 73 Node 06 Swelling rate 7 KCl Diaeonal 114 Figure 4 74 Swelling Ratio 7 KC Diagonal 115 Figure 4 75 Node 01 Displacement OBM 116 Figure 4 76 Node 01 Swelling Rate OBM Perpendicular 117 Figure 4 77 Node 02 Displacement OBM 118 Figure 4 78 Node 02 Swelling Rate OBM Perpendicular 119 Figure 4 79 Node 03 Displacement OBM 120 Figure 4 80 Node 03 Swelling Rate OBM Perpendicular 121 Figure 4 81 Node 04 Displacement OBM 122 Figure 4 82 Node 04 Sw
78. possible 194 Texas Tech University Seyedhossein Emadibaladehi August 2014 drilling fluid which minimizes the likelihood of wellbore stability prob lems associated with swelling Moreover it is recommended running triaxial tests to assess the effect of temperature on rock triaxial compressive strength Lastly it 1s recommend investigating effects of temperature fluctuation which continuously happens during drilling on the rock mechanical properties 195 AI ASTM CEC cFP CPU DAQ DRAM FPA HPHT Kip LVDT MAX MB meq MTS nD NI OBM pcf UCS VAC VDC VI WBM Texas Tech University Seyedhossein Emadibaladehi August 2014 NOMENCLATURE Analog Input American Society for Testing and Materials Cation Exchange Capacity Compact FieldPoint Central Processing Unit Data Acquisition System Dynamic Random Access Memory Young s Modulus Floating Piston Accumulator High Pressure High Temperature Hertz kilo pounds Linearly Variable Displacement Transducer Measurement and Automation Explorer Mega Bites Millidarcy Milliequivalent Mechanical Testing and Sensing Solutions Nanodarcy National Instruments Oil Based Mud lbm ft Uniaxial Compressive Strength Volts Alternating Current Volts Direct Current Virtual Instrument Water Based Mud 196 AP AT Texas Tech University Seyedhossein Emadibaladehi August 2014 Poisson s Ratio actual osmotic pressure theoretical osmotic pre
79. rain at 170 F 186 Texas Tech University Seyedhossein Emadibaladehi August 2014 Poisson s Ratio 0 5 0 45 0 4 0 35 0 3 0 25 0 2 0 15 0 1 0 05 Poisson s Ratio vs Stress at T 170 F Average Poisson s Ratio Poisson s Ratio in LVDT s 01 03 Direction Poisson s Ratio in LVDT s 02 04 Direction Figure 5 33 Poisson s Ratio vs Stress at 170 F 187 Texas Tech University Seyedhossein Emadibaladehi August 2014 Stress vs 5train Figure 5 34 Stress vs Strain at 180 F 188 Texas Tech University Seyedhossein Emadibaladehi August 2014 Poisson s Ratio vs Stress at T 180 F 0 5 Poisson s Ratio in LVDT s 02 04 Direction 0 45 Average Poisson s Ratio 0 4 Poisson s Ratio in LVDT s 01 03 Direction 0 35 am Tr B ee 0 25 F cL E CNET un 4 a Poisson s Ratio 0 15 PAPEN pi ims eS DN P 01 mmm bee ut k At 0 05 Stress psi Figure 5 35 Poisson s Ratio vs Stress at 180 F 189 Texas Tech University Seyedhossein Emadibaladehi August 2014 Stress vs Strain Ta 5000 55 2 140 2 T2150 F Es T 170F vi 2 180 F T 180 F 2000 1000 D 0 001 D DD2 0 003 D 0D4 0 005 D DD5 D DD7 DDE 0 004 Strain Figure 5 36 Stress vs Strain for Five Samples As is observed in Figure 5 36 by increasing temperature from 140 F to 180 F
80. ration remain con stant 17 12 13 14 15 16 17 18 Texas Tech University Seyedhossein Emadibaladehi August 2014 Calibrate the strain gauges Start recording data using V Shay Data Acquisition System Run each test for seven days while checking fluid level Stop V Shay Data Acquisition System save and collect the recorded data Disconnect strain gauges from V Shay Data Acquisition System Remove silicone strain gauges and epoxy from the rock sample surface Run UCS test using MTS machine in order to measure rock sample me chanical properties UCS Young s modulus E and Poisson s Ratio v Load rate while running UCS test was 0 005 in min 18 Texas Tech University Seyedhossein Emadibaladehi August 2014 3 3 High Pressure High Temperature HPHT Test Apparatus In pursuit of the proposed research objectives a HPHT experimental set up was designed This setup enabled us to mimic wellbore situation during drilling operations at reservoir conditions including pressure and temperature Before designing and build ing this set up the department did not have HPHT setup capable of running such exper iments For that reason one HPHT setup was designed and built for the HPHT phase of this research In order to build such a setup a former coreflooding experimental setup which existed in the PVT lab was de assembled and modified The details of the HPHT equipment the accompanying data acquisition sys
81. rature normal geothermal gradient 19F 70ft and surface temperature equals to 68 F were presumed Experi mental conditions counting overburden stress horizontal stress pore pressure and drill ing fluid pressure are summarized in the table 5 2 Since the intention of these experi ments was examining effects of temperature on rock sample mechanical properties as 154 Texas Tech University Seyedhossein Emadibaladehi August 2014 well as wellbore stability during drilling operations all the stresses and pressures were remained constant during running all five tests Temperature varied from 140 F to 180 F by 10 F incrementally Table 5 2 HPHT Testing Parameters Overburden Stress psi 6 000 Horizontal Stress psi 4 600 Mud Pressure psi 3 800 Mud Pressure vs Time 3950 3900 3850 3750 3700 3650 Time hr Figure 5 1 Drilling Fluid Pressure vs Time at 140 155 Texas Tech University Seyedhossein Emadibaladehi August 2014 Pore Pressure vs Time P psi Time hr Figure 5 2 Formation Pore Pressure vs Time at 140 F 156 Texas Tech University Seyedhossein Emadibaladehi August 2014 Overburden Stress vs Time T T Figure 5 3 Overburden Stress vs Time at 140 F 157 Texas Tech University Seyedhossein Emadibaladehi August 2014 Horizontal Stress vs Time Figure 5 4 Horizontal Stress vs Time at 140 F 158 Texas Te
82. re vs Time at 1709 2 20 00000 170 Figure 5 17 Formation Pore Pressure vs Time at 170 F 171 Figure 5 18 Overburden Stress vs Time at 170 F 172 Figure 5 19 Horizontal Stress vs Time at 1709F a 173 Fioure 5 20 Temperature TINE aaa a ae 174 Figure 5 21 Drilling Fluid Pressure vs Time at 180 F 175 Figure 5 22 Formation Pore Pressure vs Time at 180 F 176 Figure 5 23 Overburden Stress vs Time at 1809 2 2 00 00002 177 Fieure 5 24 Horizontal Stress vs Time at 150 ana edes 178 Figure 3 23 Temperalure Vs rr Robe R 179 Proure 5 20 Stress Vs tram at ana 180 Figure 5 27 Poisson s Ratio vs Stress at 140 F 181 Figure 5 25 Stress ys VAND AV 1507 Rasse 182 Figure 5 29 Poisson s Ratio vs Stress at 150 F 183 Fieure 50 Stress vs tram at 160 Pale a dB alva odo etsi 184 Figure 5 31 Poisson s Ratio vs Stress at 160 E uid ree erede eng aene een Dda 185 Figure 3 52 5 ress VS Man Pa uan eco suat gu een 186 Figure 5 33 Poisson s Ratio vs Stress at 170 F 187 Piseure 5 94 516518
83. rilling Fluid Pressure vs Time at 140 F 155 Figure 5 2 Formation Pore Pressure vs Time at 140 F 156 Figure 5 3 Overburden Stress vs Time at 140 F 157 Figure 5 4 Horizontal Stress vs Time at 140 F 158 Fioure gt 5 Temperature ys DIE unio opa e a dedu op toux eedem peut 159 Figure 5 6 Drilling Fluid Pressure vs Time at 150 F 160 Figure 5 7 Formation Pore Pressure vs Time at 150 F 161 Figure 5 8 Overburden Stress vs Time at 150 F 162 Frieure 5 9 Horizontal stress vs Lime at 190 Eu u ideo te oe eae dedico 163 Friseure IO Temperature vs area 164 Figure 5 11 Drilling Fluid Pressure vs Time at 160 F 165 Figure 5 12 Formation Pore Pressure vs Time at 160 F 166 Figure 5 13 Overburden Stress vs Time at 160 167 1 Texas Tech University Seyedhossein Emadibaladehi August 2014 Figure 5 14 Horizontal Stress vs Time at 160 F 168 Ligure 5 15 Temperature vs KT a oe e eee RE BR 169 Figure 5 16 Drilling Fluid Pressu
84. rly stages Reading negative numbers for the nodes inside and outside the fluid might last up to 140 and 190 hours respectively The early shrinkages which were observed in the all three samples might come from the wettability properties of the rock sample The rock samples are most likely oil wet which results in absorbing oil and losing initial water content which consequently causes shrinkage and negative swelling at the begin ning of the all three experiments After the early shrinkage and due to more oil absorp tion all the strain gauges including the ones which were outside the fluid begin to read positive values Similar to the first three experiments which were run in 7 KCl max imum and minimum swelling happened in the directions of parallel and perpendicular to the bedding correspondingly Maximum and minimum swellings after almost seven days were 0 062 and 0 012 respectively 151 Texas Tech University Seyedhossein Emadibaladehi August 2014 By comparing the results of the two different fluids 7 KCl and OBM it was Observed that with regard to swelling using OBM as drilling fluid provides a more sta ble wellbore during drilling operations Additionally since the results of both fluids illustrate that minimum swelling occur in the direction of perpendicular to the bedding it was concluded that in terms of swelling drilling in the perpendicular direction to the bedding generates less wellbore stability problems during dr
85. s Stop LabView save and collect the data Stop Quizix pumps and release both pore and drilling fluid pressures Release both axial and radial stresses by opening both axial and radial valves valve numbers 3 and 4 Remove the core sample from the core holder Run UCS test by using MTS machine and LVDT s in order to measure compressive strength Young s modulus E and Poisson s ratio v 39 Texas Tech University Seyedhossein Emadibaladehi August 2014 CHAPTER 4 SWELLING EXPERIMENTS RESULTS AND DISCUSSION OF RESULTS In this chapter the results of swelling test experiments carried out on both actual and commercial Eagle Ford core samples are presented The chapter is divided into two parts the first part presents the results of swelling and UCS tests which were carried out on actual core samples and the second part presents the results of swelling tests which were performed on commercial core samples 4 1 Experimental Results Actual Eagle Ford Core Samples The results of swelling tests run on the actual Eagle Ford core samples are pre sented in this part Two different fluids were used to run the swelling test distilled water and 7 KCI First the results of the test which distilled water was used as the drilling fluid will be presented The results of the test which 7 KCl was used as the drilling fluid will be presented afterwards 4 1 1 Core Characterization For this study a sample from the Eagle Ford
86. s Tech University Seyedhossein Emadibaladehi August 2014 Pore Pressure vs Time P psi Time hr Figure 5 22 Formation Pore Pressure vs Time at 180 F 176 Texas Tech University Seyedhossein Emadibaladehi August 2014 Overburden Stress vs Time Figure 5 23 Overburden Stress vs Time at 180 F 177 Texas Tech University Seyedhossein Emadibaladehi August 2014 Horizontal Stress vs Time Figure 5 24 Horizontal Stress vs Time at 180 F 178 Texas Tech University Seyedhossein Emadibaladehi August 2014 Temperature vs Time F snl EL o gwr unidas N O Oeh i x ma n BES S Inm Figure 5 25 Temperature vs Time 179 Texas Tech University Seyedhossein Emadibaladehi August 2014 5 3 HPHT Experimental Results In this section the results of UCS tests which were conducted on the core sam ples after running HPHT tests are presented Effects of temperature on core sample me chanical properties including Uniaxial Compressive Strength UCS Young s modulus E Poisson s ratio v are discussed in detail Stress vs 5train NR H H H H r am m Stress psi L H H H H H H H H _ H H H H H L H H H H H H H r RLRNLENE La tt te tT TT TTT EET TE TT TT TT
87. ssure membrane efficiency 197 Texas Tech University Seyedhossein Emadibaladehi August 2014 BIBLIOGRAPHY Amao A M PhD Dissertation 2011 Improved Characterization Matrix for Carbon Dioxide Enhanced Oil Recovery Process cFP AI 112 manual cFP CT 120 manual Chenevert M E and Sharma A K 1993 Permeability and effective pore pressure of Shales Paper SPE 21918 Drilling and Completion EXTECH Instruments Power Supply Manual Emadi H Soliman M Samuel R Ziaja Moghaddam R B Hutchison 5 Experimental Study of the Swelling Properties of Unconventional Shale Oil and the Effects of Invasion on Compressive Strength Paper SPE 166250 MS presented at the 2013 SPE Annual Technical Conference and Exhibition New Orleans Louisiana USA Emadi H Soliman M Samuel R Harville D Gamadi T Moghaddam R B Effect of Temperature on the Compressive Strength of Eagle Ford Oil Shale Rock An Experimental Study Paper SPE 167928 MS presented at the 2014 IADC SPE Drilling Conference and Exhibition Fort Worth Texas USA Emadi H Soliman M Samuel R Heinze L R Moghaddam R B Hutchison S Experimental Study of the Swelling Properties of Unconventional Shale Oil Rock Samples Using both Water Based and Oil Based Muds Paper SPE 170686 MS will be presented at the 2014 SPE Annual Technical Conference and Exhibition Amsterdam Netherlands Guo Q L Ji V Rajabov J Friedheim C Port
88. stalling strain gauges M Bond Adhesive Resin Type AE and M Bond 10 which are V Shay micro measurement products were used to prepare the epoxy Figure 3 3 and Figure 3 2 are the pictorial presentations of M Bond Adhesive Resin Type AE and M Bond Type 10 MFG DATE EX SKIN 4 Dec 12 255 IST ERE UNMIXED AT ORE Phone 1 9197 WN U Y Figure 3 3 M Bond Type 10 Figure 3 2 M Bond Adhesive Resin Type AE 11 Texas Tech University Seyedhossein Emadibaladehi August 2014 3 1 3 M Prep Conditioner and Neutralizer M Prep Conditioner is a weak phosphoric acid used to remove oil and other re sidual materials that prevent good bondage between strain gauge and epoxy M Prep Neutralizer 15 a basic fluid which 19 used to neutralize the surface of the epoxy on the rock sample as shown in below Figure 3 4 M Prep Neutralizer Figure 3 5 M Prep Conditioner 3 1 4 Alcohol Alcohol was used to clean the surface of the epoxy after M Prep Neutralizer dries up It is used after M Prep Conditioner and M Prep Neutralizer to remove the possible residual oil from the surface of the sample This helps us to have a more reliable bondage between strain gauges and epoxy which had been spread on surface of core samples Figure 3 6 demonstrates the pictorial view of the alcohol 12 Texas Tech University Seyedhossein Emadibaladehi August 2014 200 CATAL YST C FM FOR USE WITH gy ig CERTIFIED 4 M BON
89. stilled water is almost three times greater than the swelling in the 7 KCI solution Based on this using 7 as drilling fluid will result less swelling and subsequently a lower likelihood of wellbore stability problems during drilling operations Moreover since the swelling rates in 7 KCl are approximately half of the swelling rates in distilled water using 7 KCI drilling mud gives us more stability time during drilling However the total volume change due to swelling is practically negligible less than 1 which insinuates that swelling is not the major cause of wellbore stability problems in Eagle Ford shale oil reservoirs 1 2 Texas Tech University Seyedhossein Emadibaladehi August 2014 4 1 4 UCS Results In this section the results of UCS tests which were performed on one intact core sample and two other samples after conducting swelling tests will be presented Stress vs Strain 7 KCI Distilled Water Intact Sample Stress psi Strain Figure 4 32 Stress vs Strain for all Three Samples Comparing the UCS results we observed that the specimen which was sub merged in distilled water shows lower compressive strength and Young s Modulus E than the intact sample As we noticed UCS and Young s Modulus E decreased from 9 400 psi and 1 0 x 10 psi to 6 800 psi and 0 88 x 10 psi respectively Submerging the specimen into 7 KC fluid reduces UCS from 9 400 psi to 8 000 psi bu
90. t increases Young s Modulus E from 1 0 x 10 psi to 1 40 x 10 psi Figure 4 32 73 Texas Tech University Seyedhossein Emadibaladehi August 2014 After the UCS tests it was observed that all specimens including the intact sam ple failed through a vertical plane clearly marked from the top of the sample continuing all the way to the bottom thus explaining the existence of the natural fractures Figure 4 33 Figure 4 33 On the left intact sample after UCS test in the middle distilled water sample after UCS test on the right 7 KCI sample after UCS test 74 Texas Tech University Seyedhossein Emadibaladehi August 2014 4 2 Experimental Results Commercial Eagle Ford Core Samples The results of swelling tests run on the commercial Eagle Ford core samples are presented in this part Two different fluids were used to run the swelling test 7 KCl and Oil Based Mud OBM First the results of the tests which 7 KCl was used as the drilling fluid will be presented The results of the tests which OBM was used as the drilling fluid are presented next In order to run these experiments six core samples two perpendicular two parallel and two diagonal to the bedding were taken to find the optimum well path which minimizes problems associated with swelling and conse quently minimizes wellbore stability problems during drilling operations 4 2 1 Core Characterization For this study si
91. tem and the experimental procedure used are discussed in the following sections 3 3 1 Design of the HPHT Equipment The HPHT experiments were conducted on Eagle Ford shale oil real core sam ples at reservoir conditions In order to achieve reservoir conditions in the laboratory all the tests were performed at high pressure and temperatures The high pressure for drilling fluid and pore fluid were supplied by using two Quizix pumps which allow us to maintain the pressure at desirable values In order to apply radial and axial stresses on the core rock sample inside the core holder an Enerpac P 392 Hand Pump was em ployed which enables us to apply high pressure by compressing hydraulic oil In order to run all the experiments at elevated temperature close to the reservoir temperature a Thelco laboratory oven was used This oven contains tri axial core holder and high pres sure vessels An appropriate high pressure tri axial core holder was selected to put vertically inside the oven This core holder was fixed inside the oven by using in situ vertical holder There were tri axial core holder and two floating piston accumulators FPAs These two contain hydraulic oil and 30 000 ppm brine as reservoir fluid It is vitally important that the fluids have the same temperature as rock core sample Stainless steel tubing of 1 8 inches was used to connect floating piston accumulators to the core holder and the Quizix pumps 19 Texas Tech Uni
92. the experiments The air pressure must be between 65 to 115 psi 4 to 8 bar The operation of the cylinders could be paired or single The pump can be run on six different modes including independent cylinder operation paired cylinder operation constant rate constant pressure constant delta pressure and 29 Texas Tech University Seyedhossein Emadibaladehi August 2014 fluid recirculation The experiments were conducted using the paired constant pressure mode Safety pressure working pressure pumping rate and operating mode can be cho sen by using Front Panel Main Window QX Series Pump User s Manual A picture of Quizix pumps is displayed in Figure 3 15 Figure 3 15 Ametek Chandler Positive Displacement Quizix Pumps 3 3 3 Vacuum Pump Two Welch vacuum pumps were used to vacuum and saturate the core samples These pumps can produce up to 14 7 psi pressure difference Vacuum pump 15 shown pictorially in Figure 3 16 24 Texas Tech University Seyedhossein Emadibaladehi August 2014 Figure 3 16 Welch vacuum pumps 3 3 2 6 Floating Piston Accumulators FPA s Floating piston accumulators are cylindrical pressure vessels which were used to contain fluids and separate those fluids from Quizix pumps Two floating piston ac cumulators which contain hydraulic oil and pore fluid 30 000 ppm brine were located inside the oven in order to have the same temperature as core sample There was another floating piston accu
93. ulic permeability of shale vary from 10 7 to 10 12 Darcies Hale et al 1993 The extremely low permeability of Shale results in forming no filter cake and consequently there is always drilling fluid flow into shale formations due to osmo sis Accordingly osmotic flow plays a pivotal role in wellbore stability issues during drilling operations in shale formations With regard to permeability shale oil and shale gas formation are different from common shale formations In order to have a productive shale oil formation permeabil ity should be higher than 1000 nD Not only shale oil formations have higher permea bility than common shale formations but also have natural fractures which distinguish them from shale formations In light of higher permeability existence of natural fractures the importance of the osmotic flow in shale oil formations has to be investi gated accurately Subsequently to assess the effect and importance of osmotic flow in shale oil formations experiments have to be conducted 4 Texas Tech University Seyedhossein Emadibaladehi August 2014 1 1 4 Mineralogy In terms of mineralogy common shale formations and shale oil formations are quite different Common shale formations contain 60 clay minerals on average while shale oil formations mostly consist of calcite Clay content in shale oil formations can be as high as 3096 which 1s considerably less than clay content in common shale for mations The mi
94. vative estimates Tare et al 2000 To more efficiently and effectively drill through these formations the industry should better understand their properties Many experiments and studies have been conducted in order to comprehend properties of common shale formations and the problems which are associated with those formations As of yet most of the experiments which have been conducted on shale core samples have focused on the chemical reactions between drilling fluid and clay minerals as well as pore fluid Few tests have been done to investigate the effect of temperature on the wellbore stability Investigating effect of temperature on shale oil rock properties allows us to more precisely predict wellbore stability problems and find ing effective and efficient ways in order to prevent those costly problems Few experiments have been performed on shale oil samples to better understand their properties Most experiments conducted thus far were performed on common shale core samples which are significantly different from shale oil samples Since there are significant differences between common shale rock samples and shale oil samples in cluding different clay content different pore fluid and the existence of natural fractures the results of the experiments which have been performed on shale rock samples cannot be applied to shale oil samples Therefore properties of shale oil rock samples must be investigated separately Texas Tech Un
95. versity Seyedhossein Emadibaladehi August 2014 3 3 2 HPHT Setup Components and Specifications In this section HPHT setup components functions and specifications will be described 3 3 2 Oven A Thelco laboratory oven which was designed and manufactured by Precision Scientific Incorporated used to contain the core holder and hydraulic oil and brine FPAs Three digital displays show actual temperature set point temperature and hours The Timer Button put the oven into either Continuous or Timed mode as indicated by the Hours digital display The model number of the oven 15 130 DM The dimension of the chamber are 15 75x18 5x27 DxWxH inches and a volume of 4 5 ft 129 liters Thelco Oven Installation Service Manual The overall dimensions of the oven are 21 25 24 40 DxWxH inches Heat is circulated in the oven by mechanical convec tion which is controlled by an analog solid state thermostat It operates by drawing air into the chamber the air 15 heated over heating coils and then blown through a duct network into the main chamber Temperature inside the oven is controlled by a micro processor Maximum attainable temperature using this oven is 250 C It has a sensitivity of 0 1 C 0 18 F It uses normal laboratory voltage of 115 50 60 Hz Figure 3 12 shows the pictorial view of the Thelco oven 20 Texas Tech University Seyedhossein Emadibaladehi August 2014 BERGER Figure 3 12 Thelco Laborator
96. welling Rate in hr 0 000008 0 000006 0 000004 0 000002 0 000002 0 000004 Node 04 Swelling Rate Time hr Figure 4 106 Node 04 Swelling Rate OBM Diagonal 147 Texas Tech University Seyedhossein Emadibaladehi August 2014 Displacement 0 00025 0 0002 0 00015 0 0001 0 00005 Node 05 Displacement 100 120 140 160 180 Time hr Figure 4 107 Node 05 Displacement OBM Diagonal 148 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 05 Swelling Rate 0 000008 0 000006 0 000004 0 000002 Swelling Rate in hr o 0 000002 0 000004 0 000006 0 000008 Time hr Figure 4 108 Node 05 Swelling Rate OBM Diagonal 149 Texas Tech University Seyedhossein Emadibaladehi August 2014 Displacement 0 0003 0 00025 0 0002 0 00015 0 0001 0 00005 Node 06 Displacement 100 120 140 160 180 Time hr Figure 4 109 Node 06 Displacement OBM Diagonal 150 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node 06 Swelling Rate 0 000005 0 000004 0 000003 Axial Radial Diagonal 0 000002 ng Rate in hr U 200 0 000001 0 000002 0 000003 0 000004 0 000005 Time hr Figure 4 110 Node 06 Swelling Rate OBM Diagonal In the last three tests OBM swelling all directions 1s negative at the ea
97. x core samples two perpendicular two parallel and two diag onal to the bedding from eagle ford formation were selected The material can be de scribed among sedimentary rocks with water content w of 1 absorption 5 and a unit weight of 137 pcf Dimensions of all six samples were the same 1 5 inches diam eter inches length For the swelling tests samples were half submerged in the 7 KCl and OBM two days and seven days correspondingly Figure 4 1 schematically shows the locations of the strain gauges during running swelling tests Four of them were inside the fluid while two of them were out Likewise previous phase of swelling tests which were conducted on the actual Eagle Ford core samples Pre wired stacked rosette strain gauges model C2A 06 250WW 350 were used to measure swelling inside the fluid as well as outside Figure 4 34 shows a pictorial view of one of the samples before running the swelling test 75 Texas Tech University Seyedhossein Emadibaladehi August 2014 Sample 3 Diagonal to Bedding Swelling Test May 21 2014 34 Sample prepared for swelling test Diagonal to bedding Figure 4 RER DE EEE LEN FD D L AT TTA Ro UU UN po I p ITI o o o v 4 5 So M 9 Lob a 3 E MUS Ee ki os E erro mM 5
98. y Seyedhossein Emadibaladehi August 2014 Node 06 In D 00035 D 0003 0 00025 0 0002 Axial 0 00015 Diagonal Radial D 0001 Displacement in 0 00005 400000 OOO TUUM N 0 0001 Time sec Figure 4 29 Node 06 Displacement 7 KCl 69 Texas Tech University Seyedhossein Emadibaladehi August 2014 Node06 In 4E 09 09 2 09 u aa x 1E 09 Axial Radial E Diognal un D TDDDDD 1E 09 2E 09 Time sec Figure 4 30 Node 06 Swelling Rate 7 KCl 70 Texas Tech University Seyedhossein Emadibaladehi August 2014 Strain Ratio 7 KCl 24 03 Node 02 Node 06 MA Node 03 5 Node 05 E 0 gt 27 ADOOOO0 500000 TODODO 1 ll 7 02 Time Figure 4 31 Strain Ratios for all Four Submerged Nodes 7 KCl In the second test 7 KCl displacements due to swelling in nodes three and five which are in the same alignment are almost twice as large as swellings in nodes two and six which are in the same direction Figure 4 21 Figure 4 23 Figure 4 25 and Figure 4 29 Swelling rates in the axial and diagonal directions decrease at the begin ning and after 2 days they stabilize and the readings remain fairly constant till the end of the test Swelling rates in the radial direction on the other hand are negative
99. y Data Acquisition System is shown pictorially in Figure 3 9 Figure 3 9 V Shay Data Acquisition System 3 1 8 Mechanical Testing and Sensing Solutions MTS Machine MTS machine was employed to run Unconfined Compressive Strength UCS test on the rock samples Using this machine enables us to measure and record axial load as well as vertical displacement of the rock sample This device was used to run USC test both constant load rate and constant deformation rate mode The load cell 15 Texas Tech University Seyedhossein Emadibaladehi August 2014 model and serial number are 661 23E 01 and 10378189 respectively This MTS ma chine can be used to measure force in the range of 0 5 110 kilo pounds kip Maximum amount of error is 0 52 The load cell was calibrated in compliance with ASTM E74 Figure 3 10 shows the pictorial view of the MTS machine Figure 3 10 MTS Machine 3 1 9 Linearly Variable Displacement Transducer LVDT Five LVDT s were used during running UCS tests to measure both axial and lateral displacement of the rock sample in perpendicular directions All the five LVDT s were calibrated before running the tests The data which was recorded using V Shay data acquisition system was used to calculate Young s modulus E and Poisson s ratio v LVDT s configuration is shown pictorially in Figure 3 11 Figure 3 11 LVDT 16 Texas Tech University Seyedhossein Emadibaladehi August 2014
100. y Oven 3 3 2 2 Core Holder The core holder is a tri axial core holder which enables us to apply different values of both radial and axial stresses It was made of stainless steel and manufactured by Phoenix Precision Instruments It is rated at 7 500 psi The hassler sleeve which sur rounds the core rock samples is made of Viton rubber and has dimensions of 1 5 x 6 WxL inches The hassle sleeve was rated at 10 000 psi The core holder can take cores up to 2 9 inches 7 36 cm Since an adjustable axial piston was used in the core holder core length can vary from the minimum desirable length up to 2 9 inches The length of the axial piston can be adjusted by applying pressure hydraulically Overburden stress is applied through a port on the side of the core holder using the hydraulic pump It has 21 Texas Tech University Seyedhossein Emadibaladehi August 2014 two inlet ports on the end plug of the adjustable piston side and one port on the other end plug Core holder is shown pictorially in Figure 3 13 Figure 3 13 Phoenix Precision Instruments Core Holder 3 3 2 3 Hydraulic Pump The hydraulic pump used in the HPHT setup was an Enerpac P 392 manual hy draulic pump This pump is rated at 10 000 psi The pump was used to apply axial and radial stresses on the core samples during running the HPHT tests In order to apply different axial and radial stresses two high pressure valves were employed which isolate axial and radial parts

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