You have a single straight and vertical gas completion that you would like to run 2-7/8” 6.5ppf N80 EUE8Rd tubing insdie of 7" 26 ppf L80 LTC casing set at 10,500 ft (PBTD = 10,410 ft).  There is one interval which is under a strong water drive.

Perforations            10,050 ft – 10,120ft

The well will require an fracture stimulation of the zone.

• 5,000 psi surface treating pressure
• Initial surface pressure in tubing and annulus – 0 psi  
• 15.0 ppg fracture fluid  
• Initial fluid in tubing and casing – 7.3 ppg
• Initial surface temperature – 80^oF
• Final surface temperature – 60^oF  
• Initial BHT – 150^oF 
• Final BHT - 130^oF
• Packer is a Baker Model "D" Retrieva Permanent Packer (size 86-32) set 50 feet above top perforation
• Final annular fluid – 7.3 ppg
• Initial annular pressure – 0 psi  
• Final annular pressure – 1,000 psi
• Slackoff weight - 20,000 lbf
• Modulus of Elasticity is 30.5 X 10⁶ psi

Determine the following:

1. Piston effect force
2. Piston effect movement
3. Buckling effect movement
4. Ballooning effect force
5. Ballooning effect movement
6. Temperature effect force
7. Temperature effect movement
8. Mechanically applied movement
9. Total force at the packer
10. Total movement at the packer
11. Tubing movement at neutral setdown (F_m = 0)
12. Force at the top of the tubing at final conditions

You need to work out the math on your own; however, you can use the Baker Tubmove spreadsheets to confirm your solutions.