MINI FRAC & AFTER CLOSURE ANALYSIS REPORT

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MINI FRAC & AFTER CLOSURE ANALYSIS REPORT Company Ld. Name Field Name Formaion February 6 18, 013 DISTRIBUTION: Clien Name/Company Ld. DEFINITIVE PROJECT COORDINATOR: PREPARED BY: Definiive Opimizaion DATE: March 7, 013 Definiive Opimizaion AER/OGC Requiremens Oil/Gas Opimizaion - Technical Services 300, 80-6 TH Ave SW, Calgary, Albera TP 3E5 Tel: 1 (855) 933-3678 Fax: 1 (03) 79-0055 Websie: www.defop.com

SUMMARY OF RESULTS (MINI-FRAC) 1. Fracure closure ime ( c) was deermined o be 853.9 min.. Fracure closure pressure (P c) was deermined o be 9033 psia a he oe sleeve (D daum = 113.0 fkb-tvd), 10 psia a surface. 3. The insananeous shu-in pressure was deermined o be 11 psia a D daum, 6518 psia a surface, and herefore, he ne fracure pressure was calculaed o be 11 psi. Closure ime was iniially difficul o assess, however, was furher confirmed uilizing oher available echniques.. Fracure gradien was deermined o be 1.009 psi/f. 5. Based on he G-funcion ime (Gc) of 106.5, he fluid efficiency for he waer injecion was deermined o be 98.%. SUMMARY OF RESULTS (AFTER-CLOSURE) 6. The derivaive plo used for afer closure flow regime idenificaion indicaes a ransiion ino a lae-ime rend of approximae -1/ slope signifying linear flow. The presence of pseudo-radial flow was no observed. 7. Alhough pseudo-radial flow was no observed, a lae-ime exrapolaion was conduced on he radial plo o obain a maximum permeabiliy and pressure esimae. In addiion, a lae-ime exrapolaion was also conduced on he linear plo o obain a minimum pressure esimae. Esimaes from he sraigh-line analyses were used as saring parameers for simulaion. The analysis was conduced using a fracure model. Since pseudo-radial flow was no observed, confidence in he resuls is low. However, he esimaed reservoir pressure from simulaion is wihin he pressure range obained. 8. The iniial reservoir pressure of 8698 psia a D daum was obained from simulaion. 9. The flow capaciy (kh) o was also obained from simulaion and was deermined o be 0.111 md-f. The effecive permeabiliy o oil (k o) was herefore esimaed o be 0.007 md, based on a ne pay of 15.0 fee. www.waservices.com (P098) Definiive Opimizaion AER/OGC Requiremens Oil/Gas Opimizaion - Technical Services 300, 80-6 TH Ave SW, Calgary, Albera TP 3E5 Tel: 1 (855) 933-3678 Fax: 1 (03) 79-0055 Websie: www.defop.com

RESULTS Injecion Pressure a D daum, P inj (psia)... 1990 Insananeous Shu In Pressure a Surface, ISIP (psia)... 6518 Insananeous Shu In Pressure a D daum, ISIP (psia)... 11 Fracure Closure Pressure a Surface, P c (psia)... 10 Fracure Closure Pressure a D daum, P c (psia)... 9033 Ne Fracure Pressure a D daum, pne (psi)... 11 Fracure Closure Time, c (min)... 853.9 G-Funcion Time, G c... 106.5 Fracure Gradien, (psi/f)... 1.009 Fluid Efficiency, (%)... 98. Esimaed Iniial Reservoir Pressure a D daum, P Ri (psia)... 8698 Toal Fluid-Loss/Leakoff Coefficien, C (f/min 1/ )... T.e- Reservoir Fluid-Loss/Leakoff Coefficien, C (f/min 1/ )... R 1.69e- Flow Capaciy, (kh) o (md.f)... 0.1110 Permeabiliy o Oil, k o (md)... 0.007 Fracure Half-Lengh, X f (f)... 80.0 Choked Fracure Skin, s c... 0.0 Skin equivalen o X f, s xf... -.9 Apparen Skin, s... -.9 Amospheric Pressure: 13.89 psi RESERVOIR PARAMETERS Ne Pay, h (f)... 15.0 Effecive Horizonal Well Lengh, L e (f)... 953.0 Porosiy, φ (%)... 6.0 Gas Sauraion, S g (%)... 0.0 Oil Sauraion, S o (%)... 7.0 Waer Sauraion, S w (%)... 6.0 Temperaure, T R ( F)... 70.0 Source : Company Energy Inc. GAS PROPERTIES Gas Relaive Densiy, G (air = 1)... Gas Composiion, N (%)... Gas Composiion, CO (%)... Gas Composiion, H S (%)... Pseudo Criical Pressure, P c (psi)... Pseudo Criical Temperaure, T c (K)... N/A N/A N/A N/A N/A N/A Source : N/A OIL PROPERTIES Oil API, ( o API)... 3.0 Oil Densiy, (lb/f 3 )... 50.6 Source : Company Energy Inc. www.waservices.com (P098) Definiive Opimizaion AER/OGC Requiremens Oil/Gas Opimizaion - Technical Services 300, 80-6 TH Ave SW, Calgary, Albera TP 3E5 Tel: 1 (855) 933-3678 Fax: 1 (03) 79-0055 Websie: www.defop.com

WATER PROPERTIES (Treaing Fluid) Waer Specific Graviy... 1.000 Fluid Composiion... Fresh Waer Surface Fluid Temperaure ( F)... N/A Source : Company Energy Inc. INJECTION Final Injecion/Pump Rae (bbl/min)... 6.07 Final Injecion/Pump Rae (bbl/d)... 8737.7 Waer Injecion Volume (bbl)... 167.0* Pump Time (min)... 7.5 Source : Company Energy Inc., * Includes bbl, 9.9 ppg brine, ** Final pump ime. min. DOWNHOLE CONFIGURATION Well Type... Horizonal Oil Well License... 0000000 KB, (f)... 00.0 GL, (f)... 00.0 KB - GL, (f)... 0.0 Frac Sring Deph, (fkb-md)... 00000.00 Frac Sring Deph, (fkb-tvd)... 00000.00 Frac Sring O.D., (in)... 0.00 Frac Sring Densiy, (lb/f)... 0.00 Inermediae Casing Deph, (fkb-md)... 00000.00 Inermediae Casing Deph, (fkb-tvd)... 00000.00 Casing O.D. (in)... 0.00 Casing Densiy, (lb/f)... 0.00 Producion Casing/Liner, (fkb-md)... 00000.00 Producion Casing/Liner, (fkb-tvd)... 00000.00 Casing/Liner O.D. (in)... 0.00 Casing/Liner Densiy, (lb/f)... 0.00 PBTD, (fkb-md)... 00000.00 PBTD, (fkb-tvd)... 00000.00 Packer Deph, (fkb-md)... 00000.00 Packer Deph, (fkb-tvd)... 00000.00 Sage Top, (fkb-md)... 00000.00 Sage Top, (fkb-tvd)... 00000.00 Sage Boom, (fkb-md)... 00000.00 Sage Boom, (fkb-tvd)... 00000.00 D daum, (fkb-md)... 00000.00 D daum, (fkb-tvd)... 00000.00 Source : Company Energy Inc. www.waservices.com (P098) Definiive Opimizaion AER/OGC Requiremens Oil/Gas Opimizaion - Technical Services 300, 80-6 TH Ave SW, Calgary, Albera TP 3E5 Tel: 1 (855) 933-3678 Fax: 1 (03) 79-0055 Websie: www.defop.com

Liquid Rae (bbl/d) 1000 Company Energy Inc. Name Field / Name Formaion February 6 18, 013 DFIT End Injecion Well Shu In For Falloff Toal Tes Measured pressures were convered from surface o 113.0 fkb-tvd (Ddaum). 0 Dae 013/0/06 13:19:3 13000 q w.90 h 0.1 h 1990.0 psi(a) -8737.7 bbl/d -1000 1000 ISIP (surface) 6518.3 psi(a) ISIP (D) 113.9 psi(a) D daum Frac grad 113.000 f 1.009 psi/f -000 Pressure (psi(a)) 11000 10000 9000 ISIP.91 h 0.00 h 113.9 psi(a) End of Tes Dae 013/0/18 08:01:03 85.60 h 8.69 h 886.8 psi(a) -3000-000 -5000 Analysis 1 8000-6000 7000-7000 6000-8000 -9000 5000 q waer 0 5 50 75 100 15 150 175 00 5 50 75 300 Time (h) WellTes3 TM Ver 7.5..11

Liquid Rae (bbl/d) 1000 Company Energy Inc. 100/00-00-000-00W0/0 (Surfac 00-00) Name Field / Name Formaion February 6 18, 013 DFIT Measured pressures were convered from surface o 113.0 fkb-tvd (Ddaum). Toal Tes (Magnified) End Injecion Well Shu In For Falloff 0 13000 1000 Dae 013/0/06 13:19:3.90 h 0.1 h q w 1990.0 psi(a) -8737.7 bbl/d ISIP (surface) 6518.3 psi(a) ISIP (D) 113.9 psi(a) D daum Frac grad 113.000 f 1.009 psi/f ISIP -1000-000 Pressure (psi(a)) 11000 10000 9000 End Injecion Dae 013/0/06 10:36:03 0.18 h 0.03 h q w 997.7 psi(a) -8737.7 bbl/d End Injecion Dae 013/0/06 11:39:33 1. h 0.0 h q w 1007.1 psi(a) -8737.7 bbl/d.91 h 0.00 h 113.9 psi(a) -3000 Analysis 1-000 -5000 Began Final Injecion 8000 7000 6000 Dae 013/0/06 10:3:03 0.15 h 0.00 h q w 670.9 psi(a) -8737.7 bbl/d End of Falloff Began Injecion Dae 013/0/06 11:38:9 q w 1. h 1.0 h 863.9 psi(a) 0.00 bbl/d Dae 013/0/06 1:5:57.50 h 1.6 h q w 8717.8 psi(a) 0.00 bbl/d -6000-7000 -8000 q waer 5000-9000 0.00 0.50 1.00 1.50.00.50 3.00 3.50 Time (h) WellTes3 TM Ver 7.5..11

Firs Derivaive dp/dg (psi(a)) p (psi(a)) Company Energy Inc. Name Field / Name Formaion February 6 18, 013 DFIT 50 G-Funcion 13000 000 00 350 Pump Time ISIP (surface) ISIP (D) D daum Frac grad. min 6518.3 psi(a) 113.9 psi(a) 113.000 f 1.009 psi/f Analysis 1 1500 1000 0000 18000 Semilog Derivaive G dp/dg (psi(a)) 300 50 Fracure Closure Dae 013/0/09 :10:37 G c 106.98 c c pc (surface) p c p ne 851.3 min 853.9 min 139.7 psi(a) 9033.1 psi(a) 98.16 % 10.7 psi 00 10500 150 Semilog Derivaive Firs Derivaive 11500 11000 10000 16000 1000 1000 10000 8000 6000 100 9500 000 50 9000 000 0 8500 0 0 10 0 30 0 50 60 70 80 90 100 110 10 130 10 150 160 170 180 190 00 10 G-funcion ime WellTes3 TM Ver 7.5..11

Firs Derivaive dp/d( 1/ ) (psi(a)/hr 1/ ) p (psi(a)) Company Energy Inc. Name Field / Name Formaion February 6 18, 013 DFIT 700 MiniFrac Sqr() 15000 1000 Semilog Derivaive ( 1/ ) dp/d( 1/ ) (psi(a)) 600 1000 1000 500 00 Pump Time ISIP (surface) ISIP (D) D daum. min 6518.3 psi(a) 113.9 psi(a) 113.000 f Frac grad 1.009 psi/f 13000 10000 Fracure Closure Dae 013/0/09 :10:37 c c pc (surface) p c p ne 851.3 min 853.9 min 139.7 psi(a) 9033.1 psi(a) 10.7 psi Semilog Derivaive Firs Derivaive 1000 8000 300 11000 6000 00 10000 000 Analysis 1 100 9000 000 0 8000 0 0 6 8 9 11 13 15 17 1/ (h) WellTes3 TM Ver 7.5..11

Firs Derivaive d p/d( ) (psi/hr) Company Energy Inc. Name Field / Name Formaion February 6 18, 013 DFIT 10 5 Derivaive 10 6 6 Derivaive daa PPD daa 3 10 5 10 p, Semilog Derivaive ( )d p/d( ) (psi(a)) 6 3 10 3 6 3 User Defined Slope 0.500 Slope -1/ 10 10 3 10 10 1 10 6 3 Fracure Closure Dae 013/0/09 :10:37 1.0 10 1 10-3 3 5 6 7 10-3 5 6 7 10-1 3 5 6 7 1.0 (h) 3 5 6 7 10 1 3 5 6 7 10 3 5 6 7 10-1 10 3 WellTes3 TM Ver 7.5..11

Company Energy Inc. Name Field / Name Formaion February 6 18, 013 DFIT 900 Minifrac Radial (Nole) 9150 9100 9050 9000 p (psi(a)) 8950 8900 Pseudo-radial flow was no observed. Permeabiliy is maximum esimae. 8850 Analysis 1 8800 kh 0.186 md.f h 15.000 f k 0.01 md p* 8771.5 psi(a) 8750 Upper range esimae of reservoir pressure 8700 1.50 1.0 1.30 1.0 1.10 1.00 0.90 0.80 0.70 0.60 0.50 0.0 0.30 0.0 0.10 0.0 F R1 WellTes3 TM Ver 7.5..11

Company Energy Inc. Name Field / Name Formaion February 6 18, 013 DFIT 900 Minifrac Linear (Nole) 9100 p (psi(a)) 9000 8900 Analysis 1 pc 9033.1 psi(a) C R 1.69e-0 f/min 1/ C T.e-0 f/min 1/ p* 8671.0 psi(a) Lower range esimae of reservoir pressure 8800 8700 8600 1.00 0.90 0.80 0.70 0.60 0.50 F L 0.0 0.30 0.0 0.10 0.0 WellTes3 TM Ver 7.5..11

p (PPD) (psi/hr) Error (%) Pressure (psi(a)) p (psi(a)) 1000 13000 1000 11000 10000 9000 8000 7000 6000 p model Ex. p model Early Time 5000 0 5 50 75 100 15 150 175 00 5 50 75 300 1000 13000 1000 11000 10000 Hisory (h) WellTes3 TM Ver 7.5..11 C:\Users\Jean\Documens\Well Tes Analysis\PeraCa Energy Services\13-000 Lawlar 1-15SH\XTO Energy-Lawlar 1-15SH-DFIT (013-0-18).fk 07-Mar-13 Impulse Derivaive ( ) d p/d( ) 15000 1000 13000 1000 11000 10000 9000 8000 7000 p model Lae Time 6000 Ex. pmodel 5000 000 3500 3000 500 000 Simulaion aemps were conduced wih a primary focus on he lae-ime and early-ime daa o obain esimaes of pressure and permeabiliy. p i (syn) 8698.0 psi(a) p wo (syn) 1800.0 psi(a) 3 1 0 10 5 10 10 3 10 Derivaive daa Derivaive model PPD daa PPD model 1 / (h -1 ) Derivaive 1500 1000 500 0 9000-1 10 1 10 8000-1.0 10 1 7000 kh 0.1110 md.f s' -.885-3 h 15.000 f s Xf -.893 6000 k 0.007 md X f 80.000 f s c 0.000 % Error 5000-5 0 8 73 97 11 15 169 193 17 66 90 Time (h) (psi hr) p (psi(a)) 10-1 1.0 p model - 10-10 -1 10-3 5 10-3 3 5 10-3 5 10-1 3 5 1.0 3 5 10 1 3 5 10 3 5 10 3 (h) 10 6 10 5 10 10 3

Gauge 1 Casing Temperaure, F Company Energy Inc. Sar Tes Dae: 01/1/13 Final Tes Dae: 013/0/18 1000 Surface Pressure and Temperaure Plo Formaion: Well Name Name 00 8000 = 1319.5067 p = 5168.99 013/0/06 11:39:33 End Injecion = 131.1706 p = 8073.66 013/0/06 13:19:3 End of Injecion Well Shu In For Falloff 300 Gauge 1 Casing Pressure, psi(a) = 1318.83 p = 5095.56 013/0/06 10:36:03 End Injecion Pressure = 1603.8650 p = 3973.59 013/0/18 08:01:03 000 00 = 130.7633 p = 388.67 013/0/06 1:5:57 End of Falloff Began Final Injecion = 1318.17 p = 1787.0 0 013/0/06 10:3:0 Began Injecion = 1319.889 p = 37.91 013/0/06 11:38:9 End of Falloff Began Injecion = 160.00 p = 5.63 013/0/18 08:3:33 100 Temperaure -000 0 0:00 1:00 0:00 1:00 0:00 1:00 0:00 1:00 0:00 1:00 0:00 013// /5 /7 /8 /10 /11 /13 /1 /16 /17 /19 Gauge 1 Time

Company Energy Inc. Sar Tes Dae: 01/1/13 Final Tes Dae: 013/0/18 9000 Surface Pressure Plo (Magnified) Formaion: Well Name Name = 131.1706 p = 8073.66 013/0/06 13:19:3 End of Injecion Well Shu In For Falloff Gauge 1 Casing Pressure, psi(a) 6000 3000 = 1318.83 p = 5095.56 013/0/06 10:36:03 End Injecion = 1319.5067 p = 5168.99 013/0/06 11:39:33 End Injecion = 1319.889 p = 37.91 013/0/06 11:38:9 End of Falloff Began Injecion = 130.7633 p = 388.67 013/0/06 1:5:57 End of Falloff Began Final Injecion = 1318.17 p = 1787.0 013/0/06 10:3:0 Began Injecion 0 10:00 013//6 10:30 11:00 11:30 1:00 1:30 13:00 13:30 1:00 Gauge 1 Time

Company Ld. Well Name Name Field Name Formaion February 6 18, 013 * TERMS: The inerpreaions and conclusions presened in his repor are he opinions based on informaion from geological, engineering and oher available daa. This repor embodies he auhor s bes, sound engineering pracices and effors and he resuls are no and should no be guaraneed. The auhor does no guaranee he accuracy of geological, engineering and oher available daa and inerpreaion provided for use in his analysis. The auhor does no accep any responsibiliy and shall no be liable in negligence or oherwise, for any loss or damage resuling from he possession or use of he repor in erms of correcness or oherwise. The use and applicaion of his repor in whole or par is exclusively a he user s own risk. The release of liabiliy shall also be binding upon he clien s permied assigns, adminisraors, heirs, execuors and successors. The auhor s liabiliy o he clien shall no exceed he amoun of fees i received for performing he services under his agreemen under no circumsances. www.waservices.com (P098)

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