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FALL 2014

 

 

 

 

 

Design of surface and subsurface assembly

PROJECT 1

PNGE420

 

 

 

 

 

 

Dr                                                                                                     10/16/14

 

Abstract

For this project a proposed oil well in the Hitts Lake (Paluxy) field is to be completed with a packer and tubing design. After designing the tubing and packer configuration, the forces and length changes associated with the configuration will be calculated. A strength analysis is also used to test the integrity of the design. During the first portion of the project the well will be considered under natural flow. In the next case the well will be considered to be under stimulation treatment. The well is to have 9‘’5/8 casing and will be perforated between 9,973’ – 9,981’.

In order to do this tubing and packer configuration must first be chosen based on the constraints of the well casing flowing pressure and other constraints of the well. Once all of the necessary data has been collected the design calculations can commence. All of the forces that are exerted on the packer and tubing will be calculated as well the length changes that are associated with each force. Once this has been completed it will then be possible to determine the total forces and length changes. Lastly the stress associated with the forces placed on the design configuration can be calculated and compared to the design limitations of the tubing and packer.

 

 

 

 

 

Problem Statement

The objective of this project was to design a packer completion set up based upon a well situated in a field of choice. The forces and length changes of the tubing will be calculated under natural flow and stimulation treatment. The design limitations of the packer and tubing will be tested to ensure the design configuration is safe.

 

Geology & Location:

The producing formation of the well is Paluxy.

Address: 700 Rockmead, Suite 204 Kingwood, Texas 77339

County: Smith

RRC lease or Id Number: 05990

Section, block, and survey: John Lane (A-557)

Type of well: Oil.

 

Packer Selection:

For the design a mechanically set packer will be chosen, with a rating of 10,000 psi, for its ability to be retrieved as well as its tough yet economical design. It should be noted that the casing size of the well is 7’’ and the tubing is 2 7/8’’.

 

 

 

 

 

 

 

 

 

 

Wireline-Set Perma-Series® Production Packers

 

Casing Size Casing Weight Packer OD Sealbore ID Seal Unit ID*
in. mm lb/ft kg/m in. mm in. mm in. mm in. mm in. mm
 

4 1/2

 

114.30

9.5-12.6 14.14-18.75 3.79 96.27 2.55 64.90 1.68 42.60 1.81 45.97 1.920 48.77
9.5-12.6** 14.14-18.75 3.79 96.27 2.75 69.85 1.91 48.51        
9.5-13.5 14.14-20.09 3.72 94.49 2.37 60.33 1.53 38.86 1.74 44.07    
13.5-15.1 20.09-22.47 3.64 92.46 2.55 64.90 1.68 42.60 1.81 45.97 1.920 48.77
13.5-15.1** 20.09-22.47 3.64 92.46 2.75 69.85 1.91 48.51        
13.5-16.8 20.09-25.00 3.60 91.44 2.37 60.33 1.53 38.86 1.74 44.07    
 

5

 

127.00

15-21 22.32-31.25 3.96 100.58 2.55 64.90 1.68 42.60 1.81 45.97 1.920 48.77
15-21** 22.32-31.25 3.96 100.58 3.12 79.25 2.39 60.71        
23.2-24.2 34.53-36.01 3.79 96.27 2.55 64.90 1.68 42.60 1.81 45.97 1.920 48.77
23.2-24.2** 34.53-36.01 3.79 96.27 2.75 69.85 1.91 48.51        
 

5 1/2

 

139.70

13-20 19.35-29.76 4.54 115.32 2.75 69.85 1.83 46.48 1.93 48.95    
13-20 19.35-29.76 4.54 115.32 3.00 76.20 1.93 48.95 2.24 56.90 2.330 59.18
13-20** 19.35-29.76 4.54 115.32 3.50 88.90 2.51 63.75        
20-26 29.76-38.69 4.36 110.74 2.75 69.85 1.83 46.48 1.93 48.95    
20-26 29.76-38.69 4.36 110.74 3.00 76.20 1.93 48.95 2.24 56.90 2.330 59.18
20-26** 29.76-38.69 4.36 110.74 3.50 88.90 2.51 63.75        
23-28.4 34.23-42.26 4.26 108.20 3.00 76.20 1.93 48.95 2.24 56.90 2.330 59.18
23-28.4** 34.23-42.26 4.26 108.20 3.12 79.25 2.39 60.71        
 

6 5/8

 

168.28

17-32 25.30-47.62 5.47 138.89 2.75 69.85 1.83 46.48        
17-32 25.30-47.62 5.47 138.89 3.25 82.55 2.35 59.69        
17-32** 25.30-47.62 5.47 138.89 4.25 107.95 3.25 82.55 1.93 48.95    
20-24 29.76-35.72 5.69 144.45 4.00 101.60 2.97 75.44        
20-24** 29.76-35.72 5.69 144.45 4.75 120.65 3.85 97.79        
 

7

 

177.80

17-20 25.30-29.76 6.25 158.75 4.00 101.60 2.97 75.44        
17-23 25.30-34.23 6.18 156.97 3.25 82.55 2.35 59.69        
17-23** 25.30-34.23 6.18 156.97 4.25 107.95 3.25 82.55        
20-26 29.76-38.69 6.00 152.40 4.00 101.60 2.97 75.44        
23-38 34.23-56.55 5.69 144.45 2.75 69.85 1.83 46.48        
23-38 34.23-56.55 5.69 144.45 3.25 82.55 2.35 59.69        
23-38** 34.23-56.55 5.69 144.45 4.25 107.95 3.25 82.55 1.93 48.95    
23-32 34.23-47.62 5.88 149.23 4.00 101.60 2.97 75.44        
23-32** 34.23-47.62 5.88 149.23 5.00 127.00 3.93 100.03        
32-38 47.62-56.55 5.69 144.45 4.00 101.60 2.97 75.44        
32-38** 47.62-56.55 5.69 144.45 4.75 120.65 3.85 97.79        
32-45.4 47.62-67.56 5.47 138.89 2.75 69.85 1.83 46.48        
32-45.4 47.62-67.56 5.47 138.89 3.25 82.55 2.35 59.69        
32-45.4** 47.62-67.56 5.47 138.89 4.25 107.95 3.25 82.55        
 

7 5/8

 

193.68

26.4-39 39.29-58.04 6.38 161.93 2.75 69.85 1.83 46.48        
26.4-39 39.29-58.04 6.38 161.93 3.25 82.55 2.35 59.69        
26.4-39 39.29-58.04 6.38 161.93 4.00 101.60 2.97 75.44        
33.7-39 50.15-58.04 6.38 161.93 4.50 114.30 2.97 75.44        
33.7-39** 50.15-58.04 6.38 161.93 5.25 133.35 4.00 101.60 1.92 48.77    
33.7-45.3 50.15-67.41 6.18 156.97 3.25 82.55 2.35 59.69        
33.7-45.3** 50.15-67.41 6.18 156.97 4.25 107.95 3.25 82.55        
33.7-45.3 50.15-67.41 6.25 158.75 4.00 101.60 2.97 75.44        
8 5/8 219.08 36-49 53.57-72.92 7.26 184.40 4.00 101.60 2.97 75.44        
 

9 5/8

 

244.48

36-47 53.57-69.94 8.42 213.87 6.00 152.40 4.86 123.44        
36-59.4 53.57-88.40 8.12 206.25 3.25 82.55 2.35 59.69        
36-59.4 53.57-88.40 8.12 206.25 4.00 101.60 2.97 75.44        
36-59.4 53.57-88.40 8.12 206.25 5.00 127.00 3.85 97.79        
36-59.4** 53.57-88.40 8.12 206.25 6.50 165.10 5.00 127.00        
40-53.5 59.53-79.62 8.22 208.79 6.00 152.40 4.86 123.44        
40-53.5** 59.53-79.62 8.22 208.79 7.00 177.80 6.13 155.58        
47-58.4 69.94-86.90 8.16 223.11 6.00 152.40 4.86 123.44        

*Thread type and size control seal unit ID

**Upper Ratch-Latch™ head style only

Approach:

In order to develop an approach to solving the design problem the size of the tubing, packer and casing must first be considered.

2

 

Once this is completed the areas needed to solve the problem can be calculated as shown below.

 

Next consider the production data of the well in order to determine the density of the oil and water mix that will be produced.

 

Next all the necessary pressures will be calculated from the following equations.

 

 

With this complete the Piston effects can be considered from the following equations.

 

 

Next the Buckling Effect can be determined from the following equations

 

 

 

 

Note: n must be calculated in order to determine if the length needs to be corrected for the neutral point.

 

The next step is to determine the Ballooning Effect from the following equations.

 

 

 

Now the temperature effect will be considered by utilizing the fooling equations below.

 

 

 

The Mechanical Effect will be considered from the following equations. Where Fs (Slack Off Force) will be considered based upon the result of the other forces.

 

 

With all the forces and length changes calculated the sum of each can now be determined from the following equations:

 

 

Last the tubing strength analysis can be done from the following equations.

 

 

 

 

 

 

 

Results for Natural Flow:

 

Force (lbs) Length (in) Stress (psi)
F1 -870.13 ∆L1 -1.56088 Ss -32872
F2 0 ∆L2 -1.3758 σa 5239.68
F3 5062.32 ∆L3 8.59416 σb -22983
F4 25656.6 ∆L4 44.6447 Si 24412.8
Fs -30000 ∆LS -41.808 So 28027.2
Fp -197.26 ∆Ltotal 9.89764    
Fa -11983        
FTJ 66394.1        

 

 

Results for Fracture Stimulation:

Force (lbs) Length (in) Stress (psi)
F1 -16933 ∆L1 -30.108 Ss 46829.4
F2 0 ∆L2 -22.834 σa -5908.9
F3 -13898 ∆L3 -25.885 σb 8020.62
F4 -51513 ∆L4 -90.29 Si 27802.3
Fs 40000 ∆LS 88.68 So 28083.4
Fp -42228 ∆Ltotal -81.559    
Fa -28917        
FTJ 91698.6        

 

 

 

 

 

Conclusion

To sum it all, the results indicate that the tubing chosen, N80* 7.8#/ft OD 2.875 in ID 2.323 in will be sufficient for the pressures and forces associated with the well. The strength of the tubing is 80,000psi. The collapse rating: 13,890 psi. The burst rating is 13,440psi, and the tension strength is 180,300lbs. Since all of the stresses calculated are less than 80,000 the tubing should be strong enough to sustain the stress of natural flow as well as fracture stimulation. Meanwhile, it is most likely that as a student we will encounter a more complex well configuration that encloses many producing formations. So to conclude a life-long lesson would be to take away from this project that one should always design the tubing, packer, and other assembly to encounter forces not immediately observed in the initial design.

 

 

 

 

 

 

 

 

 

 

 

References

 

  • Class Notes for Production Engineering (Dr. H.I. Bilgeseu, PNGE 420 Fall 2014)
  • Halliburton Packer Catalog http://www.halliburton.com/public/cps/contents/Books_and_Catalogs/web/CPSCatalog/Sect_06_Packers.pdf
  • Railroad Commission of Texas, Oil & Gas Well Records, http://www.rrc.state.tx.us/

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Appendix A: Forces and Length Changes Due to Production under Natural Flow

 

Initial Conditions

Fluids:                          9.5 ppg inside tubing

9.5 ppg inside annulus

Temperature:              180˚ F Bottomhole

70˚ F Wellhead

Pressure:                     Casing 0 psi

Tubing 0 psi

Final Conditions

Fluids:                          7.11 ppg inside tubing

9.5 ppg inside annulus

Temperature:              180˚ F Bottomhole

180˚ F Wellhead

Pressure:                     Casing 1950 psi

Tubing 1630 psi

 

 

 

 

 

 

Piston Effects

 

 

Buckling Effect

 

 

 

 

 

 

 

 

 

 

Since  the length does not need to be corrected for the neutral point.

 

Ballooning Effect

 

 

 

 

 

 

 

 

 

 

Temperature Effect

 

 

 

 

 

 

Mechanically Applied Effect

 

 

 

 

 

Total Forces and Length Changes

 

 

 

 

Tubing Strength Analysis

The tubing chosen for the design was N80* OD 2.875 in ID 2.323 in 7.8 lbs/ft. The Yield Strength is 80,000 psi with a Burst Pressure of 13,440 psi, a Collapse Pressure of 13,890 psi, and Tensional Strength of 180,300 lbs.

 

Burst and Collapse Forces

Resultant Pressure of top of casing = 1,950 psi – 1,630 psi = 320 psi

Resultant Pressure of bottom of casing = 6,877 psi – 5,317 psi = 1,560 psi

Since the Collapse Pressure is 13,890 >> 1,560 and 320 the design is adequate.

 

Tension Force at Top Joint

 

 

 

Since 180,300 lbs > 66,394 lbs the design is adequate.

 

Stress due to Slack off Weight

 

 

Since the tubing yield strength is 80,000 the design is adequate.

 

Stress at the Inner Wall of Tubing due to Pressure and Temperature

 

 

 

Since 24,423 psi < 80,000 psi the design is adequate.

 

Stress at the Outer Wall of Tubing due to Temperature and Pressure

 

 

Since 28,027 psi < 80,000 psi the design is adequate.

 

Appendix B: Forces and Length Changes Due to Fracture Stimulation

Initial Conditions

Fluids:                          7.11 ppg inside tubing

9.5 ppg inside casing

Temperature:              180˚ F Bottomhole

180˚ F Wellhead

Pressure:                     Casing 1,950 psi

Tubing 1,630 psi

 

Final Conditions

Fluids:                          12.2 ppg inside tubing

9.5 ppg inside casing

Temperature:              70˚ F Bottomhole

70˚ F Wellhead

Pressure:                     Casing 2,400 psi

Tubing 6,500 psi

 

 

 

 

 

 

 

Piston Effects

 

 

 

 

Buckling Effect

 

 

 

 

 

 

 

 

 

Since  the length does not need to be corrected for the neutral point.

 

Ballooning Effect

 

 

 

 

 

 

 

 

 

 

Temperature Effect

 

 

 

 

 

Mechanically Applied Effect

 

 

 

Total Forces and Length Changes

 

 

 

 

Tubing Strength Analysis

 

The tubing chosen for the design was N80* OD 2.875 in ID 2.323 in 7.8 lbs/ft. The Yield Strength is 80,000 psi with a Burst Pressure of 13,440 psi, a Collapse Pressure of 13,890 psi, and Tensional Strength of 180,300 lbs.

 

Burst and Collapse Forces

 

Resultant Pressure of top of casing = 6,500 psi – 2,400 psi = 4,100 psi

Resultant Pressure of bottom of casing = 12,827 psi – 7,327 psi = 5,500 psi

 

Since the Collapse Pressure is 13,890 >> 5,500 and 4,100 the design is adequate.

 

Tension Force at Top Joint

 

 

 

 

 

Since 180,300 lbs > 91,497 lbs the design is adequate.

 

 

 

 

Stress due to Slack off Weight

 

 

Since 43,829 pai < 80,000 psi the design is adequate.

 

Stress at the Inner Wall of Tubing due to Pressure and Temperature

 

 

 

Since 29,002 psi < 80,000 psi the design is adequate.

 

Stress at the Outer Wall of Tubing due to Temperature and Pressure

 

 

 

Since 20,983 psi < 80,000 psi the design is adequate.

 

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