All depths reported in mkb TVD per EUB requirements. All pressures reported in (a) per EUB requirements. 9.01 used as atmospheric pressure adjustment to convert from gauge to absolute pressure. XYZ COMPANY LTD. Prepared For: JOHN DOE XYZ et al Knopcik 100/01-0-00-0-W/0 P R E S S U R E T R A N S I E N T A N A L Y S I S PAS-TRG Dinosaur Park Formation.00.00 mkb Test Date: October 8, 00 Release Date: May, 008 Job No.: 08.001 Prepared by:
ANALYSIS SUMMARY Company: Test Date: October 8, 00 Contact: John Doe Report Date: May, 008 Well Name: XYZ et al Knopcick Job Number: 08.001 Location: 100/01-0-00-0-W/0 Formation: Dinosaur Park (.00.00 mkb) Objective: The test was conducted to determine the reservoir/fracture parameters and flow characteristics from the buildup then predict the well deliverability from the test results. The test was to fulfill the well s deliverability and reservoir pressure requirements for EUB file submission. Data Preparation: The reservoir pressure was obtained from the post frac surface flow & buildup test data conduced from October 8, 00. The welltest data was recorded at surfacing using an electronic data acquisition system. The surface casing (quiet side) pressures were extrapolated to the gas-water interface depth (LLD = 8. m) using Cullnder and Smith correlation and further to the mid point of the perforated interval (MPP =.0 mkb) using an assumed water gradient of 9.9 /m. The rate data used in the interpretation was from the testers Fieldnotes. A conventional Log-Log diagnostic plot was constructed to identify the flow regimes during the pressure buildup response. The pressure transient response was indicative of a fractured reservoir, as bilinear and linear (fracture) flow regimes were indentified and eventually radial flow conditions developed during the late-time buildup. The test was analyzed and model matched to a Finite Conductivity Fracture model using a ½ section drainage area. The model results were used to indicate a stabilized rate after months of production, AOF and perform a deliverability forecast. All pressures are absolute assuming 9. Reservoir Pressure (Pi(syn)) 01 a Final Casing Shut In Pressure (PSIC) 19 a Final Sandface Shut In Pressure (Psi) 8 a Flow Duration 1 Hr Final Surface Tubing Pressure (Pwft) 98 a Final Sandface Flowing Pressure (Pfws) 1818 a Reservoir Flow Capacity (kh). mdm Results: Reservoir Permeability (k). md Fracture Half Length (Xf) M Apparent Skin Factor (s ) -. Final Gas Rate (qg). 10 m /d Test Sandface AOFst 10. 10 m /d n =1 Stabilized Sandface AOFst.0 10 m /d n = 1 ( months) Test Wellhead WAOFt.1 10 m /d n = 1 Stabilized Wellhead WAOFst. 10 m /d n = 1 ( months) Redress: Should you have any questions or concerns, please email slavin-away@lonewolfsolutions.ca
WellTest Ver.08 C:\ARTEV\LONE WOLF SOLUTIONS\EXAMPLE ANALYSIS REPORT\EXAMPLE ANALYSIS REPORT.fkt -Apr-0 000 900 100/01-0-00-0w/0 Dinosaur Park ( - mkb) October - 8, 00 Calculated Pressure @ MPP=. mkb Total Test t 9.90 hr p data 8. 11.00 10.0 10.00 800 9.0 00 9.00 8.0 00 8.00 00.0.00 00.0 Pressure, 00 00.00.0.00 Gas Rate, 10 m /d 100.0 000 1900 1800 100 t 1.0000 hr p data 181. q g.0 10 m /d.00.0.00.0.00 1.0 1.00 100 0.0 p data 100 q gas 0.00 10 1 0 0 0 0 0 0 80 8 90 9 100 10 110 11 10 1 10 1 10 1 10 1 10 1 10 Time, hr
WellTest Ver.08 C:\ARTEV\LONE WOLF SOLUTIONS\EXAMPLE ANALYSIS REPORT\EXAMPLE ANALYSIS REPORT.fkt -Apr-0 9 100/01-0-00-0w/0 Dinosaur Park ( - mkb) October - 8, 00 Diagnostic Analysis 1 Typecurve t t p 11.0 hr 9.90 hr 8. Storage 1 Radial 0, 10 / Pa.s 10-1 9 Linear Fracture 1/ Bilinear 1/ 10-9 10-8 8 8 8 8 10-10 - 10-1 1.0 10 1 10 Pseudo-Time, hr data Derivative data
WellTest Ver.08 C:\ARTEV\LONE WOLF SOLUTIONS\EXAMPLE ANALYSIS REPORT\EXAMPLE ANALYSIS REPORT.fkt -Apr-0 0.8 0.80 0. 100/01-0-00-0w/0 Dinosaur Park ( - mkb) October - 8, 00 Analysis 1 k =.9 md kh = 8.808 mdm s' = -.98 p* = 010.8 Diagnostic Analysis 1 Radial t t p 11.0 hr 9.90 hr 8. 000 900 800 0.0 00 0. 00, 10 / Pa.s 0.0 0. 0.0 00 00 00 p, 0. 00 0.0 100 000 0. 1900 0.0 1800 0. 8 9 8 9 8 9 8 9 8 10 10 10 10 10 1 Superposition Radial Pseudo-Time ( t Ra ), hr data p i 1.0 100
C:\ARTEV\LONE WOLF SOLUTIONS\EXAMPLE ANALYSIS REPORT\EXAMPLE ANALYSIS REPORT.fkt -Apr-0 Ver.08 Gas Well Test - Buildup Radial Flow Analysis 100/01-0-00-0w/0 Dinosaur Park ( - mkb) October - 8, 00 Analysis Results Total Sandface Rate (q t B t) 9.889m /d Semilog Slope (m) 9.1 Apparent Skin (s') -.98 Skin - Damage -.98 Gas Permeability (k g ).9mD Skin - Inclination Oil Permeability (k o ) md Skin - Partial Penetration Water Permeability (k w ) md Pressure Drop Due to Skin ( p s ) -8.1 Flow Capacity (kh) Total Mobility (k/ t ) Total Transmissivity(kh/ t ) 8.808mD.m 9.8mD/mPa.s 8.mDm/mPa.s Damage Ratio (DR) 0.8 Flow Efficiency (FE). Reservoir Parameters Pressures Net Pay (h).00m Total Porosity ( t ) 0.00% Water Saturation (S w ).00% Oil Saturation (S o ) 0.00% Initial Pressure (p i ) Extrapolated Pressure (p*) Final Flowing Pressure (p wfo ) 8. 010.8 181. Gas Saturation (S g ).00% Wellbore Radius (r w ) 0.10m Formation Temperature (T).8 C Formation Compressibility (c f ).89e- -1 Total Compressibility (c t ).e- -1 Production and Times Corrected Flow Time (t c ) 9.98hr Cumulative Gas Production 1.10 m Final Gas Rate.010 m /d Fluid Properties Gas Gravity (G) 0. N 1.% CO.0% H S 0.00% Critical Pressure (P c ) 81. Critical Temperature (T c ) 0.08K PVT Reference Pressure (p PVT ) 8. Gas Compressibility (c g ).19e- -1 Gas Compressibility Factor (z) 0.9 Gas Viscosity ( g ) 11.1 Pa.s Gas Formation Volume Factor (B g ) 0.008m /m
Dimensionless Pressure 10 1 1.0 10-1 10-10 - 10 - Fin. Cond. Frac. Dimensionless Typecurve 10-10 -1 1.0 10 1 10 10 10 10 10 10 10 8 Dimensionless Time, 10 / Pa.s 0.80 0.0 0.0 0.0 0.0 Fin. Cond. Frac. Radial 8 8 9 8 8 10 10 10 10 10 1 Superposition Radial Pseudo-Time ( t Ra ), hr 800 00 000 1.0 p, Fin. Cond. Frac. Total Test Fin. Cond. Frac. Typecurve p i (syn) 01.9 p avg 011.8 800 Pressure, 00 1 0-1 Error, %, 10 / Pa.s 10-1 10-000 kh.08 mdm s Xf -.8 h.00 m s f 0.11 k. md X f. m k f W 9.80 mdm r e.00 m 0 0 0 80 100 10 10 10 Time, hr - 10-8 8 8 8 8 10-10 - 10-1 1.0 10 1 10 Pseudo-Time, hr WellTest Ver.08 C:\ARTEV\LONE WOLF SOLUTIONS\EXAMPLE ANALYSIS REPORT\EXAMPLE ANALYSIS REPORT.fkt -Apr-0
C:\ARTEV\LONE WOLF SOLUTIONS\EXAMPLE ANALYSIS REPORT\EXAMPLE ANALYSIS REPORT.fkt -Apr-0 Ver.08 Finite Conductivity Fracture Gas Well Model Case Name : Fin. Cond. Frac. Dinosaur Park ( - mkb) 100/01-0-00-0w/0 October - 8, 00 Model Parameters Permeability (k).md Fracture Flow Capacity (k f w) 9.80mD.m Wellbore Storage Constant Dim. (C D ) 11.09 Turbulence Factor (D) 0.00(10 m /d) -1 Fracture Face Skin (sf) 0.11 Fracture Half Length (x f ).m Exterior Radius (r e ).00m Skin Equivalent to Xf -.8 Formation Parameters Net Pay (h).00m Total Porosity ( t ) 0.00% Gas Saturation (S g ).00% Water Saturation (S w ).00% Oil Saturation (S o ) 0.00% Wellbore Radius (r w ) 0.10m Formation Temperature (T).8 C Formation Compressibility (c f ).89e- -1 Total Compressibility (c t ).e- -1 Fluid Properties Gas Gravity (G) 0. N 1.% H S 0.00% Production and Pressure Final Gas Rate.010 m /d Cumulative Gas Production 1.10 m Final Measured Pressure 8. Synthesis Results Average Error -0.1% Synthetic Initial Pressure (p i ) 01.9 Average Reservoir Pressure 011.8 Pressure Drop Due To Fracture Face Skin ( p sf ) 1. Flow Efficiency (FE) 0.8 Damage Ratio (DR) 1.11 Forecasts CO.0% Forecast Flowing Pressure (P flow ) 181. Critical Pressure (P c ) 81. Critical Temperature (T c ) 0.08K PVT Reference Pressure (p PVT ) 8. Gas Compressibility (c g ).19e- -1 Gas Compressibility Factor (z) 0.9 - Month Constant Rate Forecast @ Curr. Skin.910 m /d - Month Constant Rate Forecast @ Curr. Skin.9910 m /d Forecast Flow Duration (t flow ) 1.00month Constant Rate Forecast @ Curr. Frac. Face Skin.10 m /d Constant Rate Forecast @ Frac. Face Skin=0.8010 m /d Gas Viscosity ( g ) 11.1 Pa.s Gas Formation Volume Factor (B g ) 0.008m /m
WellTest Ver 0.000 C:\ARTEV\LONE WOLF SOLUTIONS\EXAMPLE ANALYSIS REPORT\EXAMPLE ANALYSIS REPORT.fkt -Apr-0 1 100/01-0-00-0w/0 Dinosaur Park ( - mkb) October - 8, 00 Transient Forecast 1.0 1 1 1 11 p i (syn) 01.9 GIP transi 1. 10 m k. md h.00 m kh.08 mdm X f. m k f W 9.80 mdm s Xf -.8 Rate @ 1818 s = 0.1 Rate @ 1000 s = 0.1 Cum. Production @ 1818 s = 0.1 Cum. Production @ 1000 s = 0.1 1.0 1.0 1.0 1.0 10 1.10 Rate, 10 m /d 9 8 1.00 0.90 0.80 0.0 0.0 Cum. Production, 10 m 0.0 0.0 0.0 0.0 1 0.10 0 0.00 0 1 8 9 10 11 1 Time, Months
100/01-0-00-0w/0 Dinosaur Park ( - mkb) October - 8, 00 Fin. Cond. Frac. Item Time Rate @ 1818 s = 0.1 Cum. Prod. @ 1818 s = 0.1 P R @ 1818 s = 0.1 P wf @ 1818 s = 0.1 Rate @ 1000 s = 0.1 Cum. Prod. @ 1000 s = 0.1 P R @ 1000 s = 0.1 P wf @ 1000 s = 0.1 Months 10 m /d 10 m 10 m /d 10 m 1 0.00 8.8 0.000 01.00 01.00 1.1 0.000 01.00 01.00 0.0 8.8 0.009 01. 1818.00 1.1 0.01 011.81 1000.00 0.0.80 0.01 011.0 1818.00 9. 0.0 010.09 1000.00 0.10.0 0.0 010.10 1818.00 8. 0.00 008. 1000.00 0.1.1 0.0 009.09 1818.00.8 0.08 00.1 1000.00 0.1.1 0.0 008.1 1818.00. 0.0 00.80 1000.00 0.0.090 0.08 00.1 1818.00.111 0.0 00. 1000.00 8 0..91 0.0 00. 1818.00.89 0.09 00.8 1000.00 9 0.. 0.0 00. 1818.00. 0.0 00.0 1000.00 10 0.0.9 0.0 00. 181.0.09 0.0 000.90 1000.00 11 0..9 0.0 00.80 1818.00.0 0.09 999. 1000.00 1 0.. 0.01 00.99 1818.00.9 0.08 998. 1000.00 1 0.9.9 0.0 00.0 1818.00.1 0.091 99.1 1000.00 1 0..9 0.00 001. 1818.00.09 0.09 99. 1000.00 1 0..9 0.0 000. 1818.00.9 0.10 99. 1000.00 1 0.9.1 0.08 999.89 1818.00.88 0.109 99.8 1000.00 1 0..1 0.08 999.1 181..81 0.11 99. 1000.00 18 0..118 0.08 998.9 1818.00. 0.11 99.19 1000.00 19 0.9.0 0.091 99. 1818.00.9 0.1 991.1 999.0 0 0..0 0.09 99.9 1818.00.8 0.1 990.1 1000.00 1 0..999 0.099 99.0 1818.00.8 0.18 989.1 1000.00 0.9.9 0.10 99.9 1818.00.9 0.1 988.1 1000.00 0..9 0.10 99.8 1818.00.9 0.19 98.1 1000.00 0..90 0.110 99.0 1818.00. 0.1 98.1 1000.00 0.9.8 0.11 99. 1818.00.1 0.10 98.18 1000.00 0.8.8 0.118 99.8 1818.00. 0.1 98.0 1000.00 0.8.8 0.1 991.99 1818.00.9 0.10 98. 1000.00 8 0.89.9 0.1 991.0 1818.00.0 0.1 98.8 1000.00 9 0.9. 0.10 990. 1818.00. 0.181 981. 1000.00 0 0.9. 0.1 989.9 1818.00. 0.18 980.8 1000.00 1 0.99.1 0.1 989. 1818.00.1 0.191 99. 1000.00 1.00.1 0.19 988.9 1818.00.199 0.19 99.0 1000.00.00.88 0. 90. 1818.00. 0.8 9.9 1000.00.00.189 0.9 9.8 1818.00.9 0. 98.8 1000.00.00.00 0. 9.91 1818.00. 0.0 90. 1000.00.00.9 0. 919. 1818.00.1 0.0 881.8 1000.00.00.889 0.10 90.1 1818.00.01 0.8 89. 1000.00 8.00.8 0.9 888.01 1818.00.9 0.9 8. 1000.00 9 8.00.8 0.80 8.0 1818.00.8 1.091 81.1 1000.00 0 9.00.1 0.8 8.8 1818.00.801 1.0 9.08 1000.00 1 10.00. 0.9 8.9 1818.00. 1.0. 1000.00 11.00.18 1.0 88.1 1818.00. 1..98 1000.00 1.00. 1.10 81.1 1818.00.0 1..9 1000.00 ModelDll Ver.08 -Apr-0 1
WellTest Ver.08 -Apr-0 100/01-0-00-0w/0 Dinosaur Park ( - mkb) October - 8, 00 Sandface Deliverability Simplified Analysis (Pressure Squared) Time Sandface Pressure P P Gas Rate hr 10 10 10 m /d Extended Flow Stab. Shut-in Stab. Flow 1.0000 1818.00 01.00 1818.00.1 9.08.1.8.8.0.189 Stabilized Extended Transient AOF n C.01 1.000.18e-0 10. 1.000 1.18e-0 1.000 10 m /d 10 m /d/( ) n 10 8 AOF.01 10 m /d n 1.000 C.18e-0 P R 01.00 Extended Point Stabilized Point 10 1 8 P, 10 1.0 8 10-1 8 9 8 9 1.0 10 1 8 10 Gas Rate, 10 m /d
WellTest Ver.08 -Apr-0 100/01-0-00-0w/0 Dinosaur Park ( - mkb) October - 8, 00 Sandface Deliverability Curve Simplified Analysis (Pressure Squared) Stabilized Shut In Pressure = Alternate Shut In Pressure 1 = Alternate Shut In Pressure = 01.00 00.00 000.00 Flowing Pressure Gas Rate @ 01.00 Gas Rate @ 00.00 Gas Rate @ 000.00 10 m /d 10 m /d 10 m /d 0.00 00.00 800.00 100.00 100.00 000.00 00.00 00.00 800.00 01.00.01.9.0.18.00.80 1.8 1. 0.8 0.000.9.1.09..0 1. 0.0 0.000.0.119 1.8 1.1 0.9 0.000 800 Deliverability @ 01.00 Deliverability @ 00.00 Deliverability @ 000.00 00 000 Pressure, 100 100 800 00 0 0.00 0.0 0.80 1.0 1.0.00.0.80.0.0.00.0.80.0 Gas Rate, 10 m /d
WellTest Ver.08 -Apr-0 100/01-0-00-0w/0 Dinosaur Park ( - mkb) October - 8, 00 Wellhead Deliverability Simplified Analysis (Pressure Squared) Time Wellhead Pressure P P Gas Rate hr 10 10 10 m /d Extended Flow Stab. Shut-in Stab. Flow 1.0000 98.00 89. 98.00 0.9 8. 0.9...0.189 Stabilized Extended Transient AOF n C.90 1.000.11e-0.1 1.000 8.0e-0 1.000 10 m /d 10 m /d/( ) n 10 8 AOF.90 10 m /d n 1.000 C.11e-0 P ts 89. Extended Point Stabilized Point 10 1 8 P, 10 1.0 8 10-1 8 9 8 9 1.0 10 1 8 10 Gas Rate, 10 m /d
WellTest Ver.08 -Apr-0 100/01-0-00-0w/0 Dinosaur Park ( - mkb) October - 8, 00 Wellhead Deliverability Curve Simplified Analysis (Pressure Squared) Stabilized Shut In Pressure = Alternate Shut In Pressure 1 = Alternate Shut In Pressure = 89. 81.1 190.0 Flowing Pressure Gas Rate @ 89. Gas Rate @ 81.1 Gas Rate @ 190.0 10 m /d 10 m /d 10 m /d 0.00 00.00 00.00 900.00 100.00 100.00 1800.00 190.0 100.00 81.1 00.00 00.00 89..90..1.0.9..0 1.89 1. 1.0 1.018 0.88 0.000..98.18.00 1. 1.09 1.001 0.89 0.0 0.000 1.9 1.9 1.8 1.1 0.90 0.0 0.1 0.000 800 Deliverability @ 89. Deliverability @ 81.1 Deliverability @ 190.0 00 000 Pressure, 100 100 800 00 0 0.00 0.0 0.0 0.0 0.80 1.00 1.0 1.0 1.0 1.80.00.0.0.0.80.00.0.0 Gas Rate, 10 m /d