DOC PREVIEW
TAMU PETE 662 - 662_HW1_soln

This preview shows page 1-2-3-4-5-6 out of 17 pages.

Save
View full document
View full document
Premium Document
Do you want full access? Go Premium and unlock all 17 pages.
Access to all documents
Download any document
Ad free experience
View full document
Premium Document
Do you want full access? Go Premium and unlock all 17 pages.
Access to all documents
Download any document
Ad free experience
View full document
Premium Document
Do you want full access? Go Premium and unlock all 17 pages.
Access to all documents
Download any document
Ad free experience
View full document
Premium Document
Do you want full access? Go Premium and unlock all 17 pages.
Access to all documents
Download any document
Ad free experience
View full document
Premium Document
Do you want full access? Go Premium and unlock all 17 pages.
Access to all documents
Download any document
Ad free experience
View full document
Premium Document
Do you want full access? Go Premium and unlock all 17 pages.
Access to all documents
Download any document
Ad free experience
Premium Document
Do you want full access? Go Premium and unlock all 17 pages.
Access to all documents
Download any document
Ad free experience

Unformatted text preview:

PETE 662 Spring 2014 Homework#1: Vertical Well Performance 1/21/14-1/28/14 Problem 1PETE 662 Spring 2014 Homework#1: Vertical Well Performance 1/21/14-1/28/14PETE 662 Spring 2014 Homework#1: Vertical Well Performance 1/21/14-1/28/14PETE 662 Spring 2014 Homework#1: Vertical Well Performance 1/21/14-1/28/14PETE 662 Spring 2014 Homework#1: Vertical Well Performance 1/21/14-1/28/14 Problem 2PETE 662 Spring 2014 Homework#1: Vertical Well Performance 1/21/14-1/28/14PETE 662 Spring 2014 Homework#1: Vertical Well Performance 1/21/14-1/28/14 Problem 3 Table -- Given Data Parameter Value Oil flow rate, bbl/day 500 WOR 1.5 Gas gravity 0.71 Oil gravity, ᵒAPI 32 Reservoir Temperature, ᵒF 150 GOR 500 Seperator Temperature, ᵒF 100 Seperator Pressure, psig 100 ( ) ( ) ( ) ( ) Calculate in terms of reservoir pressure P: ( ) ( ) Calculate oil formation volume factor: ( ) ( ) ( )( ) Calculate as a function of P: ( ) ( ( ) ( ) ( )( ))PETE 662 Spring 2014 Homework#1: Vertical Well Performance 1/21/14-1/28/14 Plot as a function of P: Matlab Code: Qo=500; % bbl oil /day WOR=1.5; % water oil ratio GOR= 500; % gas oil ratio gas_gravity=0.71; % gas gravity oil_gravity=32; % oil gravity in degrees API T=150; % degrees Farenheit P=0:2:4336; A=oil_gravity/(T+460); Rs=(gas_gravity*(P.^1.187)/56.06)*(10^(10.393*A)); F=(T-60)*(oil_gravity/gas_gravity); Bo=1+4.67*10^-4*Rs+0.11*10^-4*F+0.1337*10^-8.*Rs.*F; Ql=Qo.*(WOR+Bo); plot(P,Ql) xlabel('Pressure (psia)') ylabel('Liquid Flow rate (bbl/day)') 0 500 1000 1500 2000 2500 3000 3500 4000 4500125013001350140014501500Pressure (psia)Liquid Flow rate (bbl/day)PETE 662 Spring 2014 Homework#1: Vertical Well Performance 1/21/14-1/28/14 Problem 4PETE 662 Spring 2014 Homework#1: Vertical Well Performance 1/21/14-1/28/14PETE 662 Spring 2014 Homework#1: Vertical Well Performance 1/21/14-1/28/14 Problem 5 Given Data Parameter Value re, ft 1490 Pwf, psi 3000 Gas gravity 0.65 k 0.17 Reservoir Temperature, ᵒF 180 h 78 Pi, psi 4613 We are told to assume the gas reservoir is under pseudosteady state and so we take to be  Equation (4-47) can be rearranged into Equation (4-50) :    ( ( ) )      ( ( ) )   We can use the quadratic equation to solve for the flow rate at each new reservoir pressure:     ( ( ) )   √ Remember that  is decreasing at or psi per day for three years. Also realize that the temperature is constant (isothermal process) but the pressure is changing, meaning that the viscosity and the Z factor will only change with pressure. I will present how to calculate the Z-factor and the viscosity as a function of pressure.PETE 662 Spring 2014 Homework#1: Vertical Well Performance 1/21/14-1/28/14 (a) Case 1: S=0 Cumulative production after 3 years: 0 200 400 600 800 1000 1200050010001500200025003000Time (days)Flow rate (Mscf/day)0 200 400 600 800 1000 1200024681012141618x 105Time (days)Cumulative Production (Mscf)0 200 400 600 800 1000 12001.51.61.71.81.922.12.22.3Time (days)Mscf/psiPETE 662 Spring 2014 Homework#1: Vertical Well Performance 1/21/14-1/28/14 (b) Case 2: S=10 Cumulative production after 3 years: 0 200 400 600 800 1000 12000200400600800100012001400Time (days)Flow rate (Mscf/day)0 200 400 600 800 1000 12000123456789x 105Time (days)Cumulative Production (Mscf)0 200 400 600 800 1000 12000.820.840.860.880.90.920.940.960.981Time (days)Mscf/psiPETE 662 Spring 2014 Homework#1: Vertical Well Performance 1/21/14-1/28/14 (c) At what flow rate is the non-Darcy flow effect on production reduction equal to the effect of skin factor of 10 These calculations will be made with the average reservoir pressure equal to 4613 psi Set this change in production equal to the change in production when flow rate changes (  )   [ ( ) ] (  )   [ ( ) ] Solve for q, that would make non-Darcy effect on production reduction the same decrease in production rate from an increase of skin factor from zero to ten You can also plot residual as a function of q and see at what q the residual is zero (  )   [ ( ) ] Flowrate = 0 1 2 3 4 5 6 7 8 9 10x 104-2500-2000-1500-1000-50005001000X: 1.43e+04Y: 0.03959residualFlow rate (Mscf/day)PETE 662 Spring 2014 Homework#1: Vertical Well Performance 1/21/14-1/28/14 Matlab code for Problem 5: % Problem 5 (3-4 PPS 2nd edition) re=1490; % drainage radius (ft) rw=0.328; % wellbore radius (ft) Pwf=3000; % flowing bottom hole pressure (psi) T=180; % reservoir temperature (degrees Farenheit) p=4613; % average reservoir pressure (psi) t=1:1:(365*3); % this is the time vector, well is produced 1095 days gas_gravity=0.65; % gas gravity k=0.17; % permeability (md) h=78; % reservoir height (ft) D=10^-3; % non-Darcy coefficient (Mscf/d)^-1 S=0; % skin factor pvec=[]; % vector will be used to collect average reservoir pressure q_vec=[]; % vector will be used to collect the daily flow rate Qg=0; % used for first summation in the loop Q_total_vec=[]; % vector will be used to collect the cumalative flow rate % Loop calculates daily flow rate as the average reservoir pressure % decreases. Gas properties (viscosity and Z-factor) are calculated at each % new reservoir pressure for i=1:length(t) pvec=[pvec p]; % stores average reservoir pressure [z, rho_g, mu_g, Bg]= gas_properties(gas_gravity, p, T); % calls gas_properties function to calculate z, density, viscosity a=(1424*mu_g*z*T*D)/(k*h); % used to solve quadratic c=-1*(p^2)+Pwf^2; % used to solve quadratic b=((1424*mu_g*z*T/(k*h))*(log(0.472*re/rw)+S)); % used to solve quadratic q=(-b+sqrt(b^2-4*a*c))/(2*a); % quadratic equation q_vec=[q_vec q]; % stores flow rate into vector Qg=Qg+q; % cumulative production Q_total_vec=[Q_total_vec Qg]; % stores cumulative production into vector p=p-500/365; % new average reservoir pressure (decreases by 500/365 psi/day) endPETE 662


View Full Document

TAMU PETE 662 - 662_HW1_soln

Documents in this Course
Load more
Download 662_HW1_soln
Our administrator received your request to download this document. We will send you the file to your email shortly.
Loading Unlocking...
Login

Join to view 662_HW1_soln and access 3M+ class-specific study document.

or
We will never post anything without your permission.
Don't have an account?
Sign Up

Join to view 662_HW1_soln 2 2 and access 3M+ class-specific study document.

or

By creating an account you agree to our Privacy Policy and Terms Of Use

Already a member?