XYZ COMPANY LTD. Prepared For: JOHN DOE. XYZ et al Knopcik 100/ W5/06 PAS-TRG. Dinosaur Park Formation
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1 All depths reported in mkb TVD per EUB requirements. All pressures reported in (a) per EUB requirements used as atmospheric pressure adjustment to convert from gauge to absolute pressure. XYZ COMPANY LTD. Prepared For: JOHN DOE XYZ et al Knopcik 100/ 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 mkb Test Date: October 8, 00 Release Date: May, 008 Job No.: Prepared by:
2 ANALYSIS SUMMARY Company: Test Date: October 8, 00 Contact: John Doe Report Date: May, 008 Well Name: XYZ et al Knopcick Job Number: Location: 100/ W/0 Formation: Dinosaur Park ( 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 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 slavin-away@lonewolfsolutions.ca
3 WellTest Ver.08 C:\ARTEV\LONE WOLF SOLUTIONS\EXAMPLE ANALYSIS REPORT\EXAMPLE ANALYSIS REPORT.fkt -Apr / w/0 Dinosaur Park ( - mkb) October - 8, 00 Calculated MPP=. mkb Total Test t 9.90 hr p data Pressure, Gas Rate, 10 m /d t hr p data 181. q g.0 10 m /d p data 100 q gas Time, hr
4 WellTest Ver.08 C:\ARTEV\LONE WOLF SOLUTIONS\EXAMPLE ANALYSIS REPORT\EXAMPLE ANALYSIS REPORT.fkt -Apr / w/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 Linear Fracture 1/ Bilinear 1/ Pseudo-Time, hr data Derivative data
5 WellTest Ver.08 C:\ARTEV\LONE WOLF SOLUTIONS\EXAMPLE ANALYSIS REPORT\EXAMPLE ANALYSIS REPORT.fkt -Apr / w/0 Dinosaur Park ( - mkb) October - 8, 00 Analysis 1 k =.9 md kh = mdm s' = -.98 p* = Diagnostic Analysis 1 Radial t t p 11.0 hr 9.90 hr , 10 / Pa.s p, Superposition Radial Pseudo-Time ( t Ra ), hr data p i
6 C:\ARTEV\LONE WOLF SOLUTIONS\EXAMPLE ANALYSIS REPORT\EXAMPLE ANALYSIS REPORT.fkt -Apr-0 Ver.08 Gas Well Test - Buildup Radial Flow Analysis 100/ w/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 ) 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
7 Dimensionless Pressure Fin. Cond. Frac. Dimensionless Typecurve Dimensionless Time, 10 / Pa.s Fin. Cond. Frac. Radial Superposition Radial Pseudo-Time ( t Ra ), hr p, Fin. Cond. Frac. Total Test Fin. Cond. Frac. Typecurve p i (syn) 01.9 p avg Pressure, Error, %, 10 / Pa.s 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 Time, hr Pseudo-Time, hr WellTest Ver.08 C:\ARTEV\LONE WOLF SOLUTIONS\EXAMPLE ANALYSIS REPORT\EXAMPLE ANALYSIS REPORT.fkt -Apr-0
8 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/ w/0 October - 8, 00 Model Parameters Permeability (k).md Fracture Flow Capacity (k f w) 9.80mD.m Wellbore Storage Constant Dim. (C D ) 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 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) Month Constant Rate Curr. Skin.910 m /d - Month Constant Rate Curr. Skin.9910 m /d Forecast Flow Duration (t flow ) 1.00month Constant Rate Curr. Frac. Face Skin.10 m /d Constant Rate Frac. Face Skin= m /d Gas Viscosity ( g ) 11.1 Pa.s Gas Formation Volume Factor (B g ) 0.008m /m
9 WellTest Ver C:\ARTEV\LONE WOLF SOLUTIONS\EXAMPLE ANALYSIS REPORT\EXAMPLE ANALYSIS REPORT.fkt -Apr / w/0 Dinosaur Park ( - mkb) October - 8, 00 Transient Forecast p i (syn) 01.9 GIP transi m k. md h.00 m kh.08 mdm X f. m k f W 9.80 mdm s Xf s = s = 0.1 Cum s = 0.1 Cum s = Rate, 10 m /d Cum. Production, 10 m Time, Months
10 100/ w/0 Dinosaur Park ( - mkb) October - 8, 00 Fin. Cond. Frac. Item Time 1818 s = 0.1 Cum s = 0.1 P 1818 s = 0.1 P 1818 s = s = 0.1 Cum s = 0.1 P 1000 s = 0.1 P 1000 s = 0.1 Months 10 m /d 10 m 10 m /d 10 m ModelDll Ver.08 -Apr-0 1
11 WellTest Ver.08 -Apr-0 100/ w/0 Dinosaur Park ( - mkb) October - 8, 00 Sandface Deliverability Simplified Analysis (Pressure Squared) Time Sandface Pressure P P Gas Rate hr m /d Extended Flow Stab. Shut-in Stab. Flow Stabilized Extended Transient AOF n C e e m /d 10 m /d/( ) n 10 8 AOF m /d n C.18e-0 P R Extended Point Stabilized Point P, Gas Rate, 10 m /d
12 WellTest Ver.08 -Apr-0 100/ w/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 = Flowing Pressure Gas Gas Gas m /d 10 m /d 10 m /d Pressure, Gas Rate, 10 m /d
13 WellTest Ver.08 -Apr-0 100/ w/0 Dinosaur Park ( - mkb) October - 8, 00 Wellhead Deliverability Simplified Analysis (Pressure Squared) Time Wellhead Pressure P P Gas Rate hr m /d Extended Flow Stab. Shut-in Stab. Flow Stabilized Extended Transient AOF n C e e m /d 10 m /d/( ) n 10 8 AOF m /d n C.11e-0 P ts 89. Extended Point Stabilized Point P, Gas Rate, 10 m /d
14 WellTest Ver.08 -Apr-0 100/ w/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 = Flowing Pressure Gas 89. Gas 81.1 Gas m /d 10 m /d 10 m /d Pressure, Gas Rate, 10 m /d
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