This preview shows pages 1–2. Sign up to view the full content.
This preview has intentionally blurred sections. Sign up to view the full version.
View Full Document
Unformatted text preview: PGE 362 Homework 1 Solution Due at the start of lecture on Feb 9th. Data: Depth = 7500’ BHP = 4500 psi BHT = 190 deg F Tubing: 2 7/8”, 6.5 ppf, N80, EUE 8rnd Casing: 5 ½”, 17 ppf, N80, LTC Completion fluid (left above the packer): 8.5 ppg, 3% KCl water Packer: permanent type with a 3.00” bore. Differential pressure rating is 10,000 psi. The tubing will be landed with 8,000 lbs of weight placed in compression on the packer. The packer seals have the same internal diameter as the tubing. Other strength and dimensional data for the tubulars can be obtained from the Halliburton Red Book, which is available as a free on line down load from the Halliburton web site, or any other tubular hand book. A fracture stimulation is to be performed through the tubing and packer. The maximum surface pressure during the job is 7000 psi. The heaviest fluid used during the fracturing job is 11.3 ppg. The injected fracturing fluid will be 75 deg F. During the fracturing job 1500 psi will be held on the annulus at the surface. Please show your work to answer the following questions....
View
Full
Document
This note was uploaded on 02/13/2012 for the course PGE 362 taught by Professor Bommer during the Spring '08 term at University of Texas.
 Spring '08
 Bommer

Click to edit the document details