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Unformatted text preview: PGE 362 Production Engineering HWK 2 - Solution (1) You have inherited a well that was configured by an engineer from another university. This well is to be hydraulically fractured using water. You must decide if the well is configured correctly for the new service. Data: Packer Depth: 8,000’ Packer Type: Permanent packer with 6’ of seals. BHT: 195 deg F at 8,000’ Proposed Injected Water Temperature: 60 deg F. Annulus Fluid: 8.5 lb/gal 2% KCl water. Annulus Pressure: During the fracturing job 1,500 psi can be held on the annulus by a pump at the surface. Injected fracturing fluid: 12 ppg sand laden water with a maximum surface pressure of 5,500 psi. Dimensions and strengths: Casing: 4 ½”, 11.6 ppf, N-80, LTC Tubing: 2 3/8”, 4.7 ppf, N-80, EUE 8rnd Packer: OD when set is the same as the ID of the casing. ID = 2.5” Differential pressure rating is 10,000 psi. Seal OD = 2.5” Seal ID is the same as the tubing ID. Tubing Latch: None Tubing weight left on the packer: 10,000 lbs (1) As the worst case scenario, assume the fracturing job lasts long enough to cool the tubing to the temperature of the injected water. (a) (+1.0) Compute the pressure differential across the packer....
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This homework help was uploaded on 04/07/2008 for the course PGE 362 taught by Professor Bommer during the Spring '08 term at University of Texas at Austin.
- Spring '08