pte514 drilling project new

8/13/2019 PTE514 Drilling Project New

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Derrick Calculations


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Derrick Calculations

Use 3-1/2drill pipe

5 drill collars

Drill pipe (3/1/2, 9.5 lbf/ft)

(From Applied Drilling Engineering, page 19, Chapter 1)

ID = 2.992

OD = 3.5

Drill collars (5, 59 lbf/ft)

(From Fundamentals of Drilling Engineering, page 587, Table 9.1, Mitchell, R. F. and Miska, S. Z)

ID = 1-3/4

OD = 5

Drillstring weight at depth 5250

Assume 30 length for the drill collars

Type Amount Length

(ft)

Total Length

(ft)

Weight/ft Total Weight

(lbf)DC 4 30 120 59 7,080

DP 1 5130 5,130 9.5 48,735

Total drill string weight 55,815 lbf

With a safety factor (SF) of 1.5,

Or

Maximum load on derrick will be seen when running 7, 32 lbf/ft casing of 283,574.42 lbf

(determined from the casing design calculation)


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Tension in fast line can be calculated from the following equation:

Where W is the load supported by the travelling block

E is the efficiency

n is the number of lines

With W = 283,583.5 lbf,

n E En Ff

6 0.874 5.244 54,077.7

8 0.841 6.728 42,149.7

10 0.81 8.1 35,010.3

12 0.77 9.24 30,690.9

Tension in the dead line can be determined from the following equation:

n fs

6 47,263.9

8 35,447.9

10 28,358.4

12 23,632.0

The load of the derrick is determined from the following equation:


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n Ff Fs W Fd Assuming

SF=1.5

6 54,077.7 47,263.9 283,583.5 384,925.1 577,387.7

8 42,149.7 35,447.9 283,583.5 361,181.2 541,771.8

10 35,010.3 28,358.4 283,583.5 346,952.2 520,428.2

12 30,690.9 23,632.0 283,583.5 337,906.3 506,859.5

If 6 lines were to be used , the rig needs to be capable of handling an anticiapted load of 580,000

lbf.


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Cement Calculations


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Cement Calculations

Starting with the surface casing

Excess = 150%

Hole size = 15

Frac = Max Weight =

From the Red Book (Halliburton)

Looking at page 107, Section 122, under Vol. & Hgt. Between: Tbg., Csg., D.P. & Hole Tab,

For 15 (hole) 10-3/4 (casing), gives

Looking at page 25, Section 210, under Capacity Tab,

For 10-3/4 (casing), 40.5 lbf/ft, gives

Under Technical Data, Section IV: Class G Cement

Use Class G Cement w/10% Bentonite, density = 12.8 PPG

Pump at a rate of 2-3 bbls to maintain 100 psi surface pressure

Class G w/ 10% Bentonite,

Volume of cement in shoe joint

100'

950'40'

16'

10-3/4''


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40 ft shoe joint

Go to Capacity Tab, Section 210

Number of sacks =

Volume of cement in 16, 65 lbf/ft (casing) 10-3/4, 40.5 lbf/ft annulusLooking at Section 221, page 129, under Vol. & Hgt. Between; Tbgs., Tbg. & Csg., Csgs., D.P.

& Csg. Tab, gives

So, conductor casing is set until 100

Number of sacks =

Volume of cement in the open hole 15 10-3/4 casing annulus

With an excess of 150%, so

Number of sacks =

Total volume = Total number of sacks = Thus, use approximately 410 sacks.


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10-3/4, 40.5 lbf/ft, K-55, to 950

OD = 11.75

ID = 10.05

Drift = 9.894

Collapse resistance = 1580 psi

Burst resistance = 3130 psi

Capacity = 0.0981

7, 32 lbf/ft, C-75 to 5250

OD = 7.656

ID = 6.094

Drift = 5.969

Collapse resistance = 8,230 psi

Burst resistance = 8,490 psi

100'

950'40'

16''

10-3/4''

5250'

15'' hole

7''

8-5/8'' hole


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Capacity = 0.036

For the 7 (casing) 10-3/4 (casing), from Vol. & Hgt. Between; Tbgs., Tbg. & Csg., Csgs.,D.P. & Csg. Tab, it is found that the flow is 0.0505

As for the 7 (casing) 8-5/8 (hole), from Vol. &Hgt. Between: Tbg., Csg., D.P. & HoleTab, it is found that the flow is 0.0247

Displacement

10-3/4, 40.5 lbf/ft to bump plug

Bump plug at 3 bpm (or barrels per minute)

Time =

Bump plug w/

Bump plug w/ 1,000 psi

Now for the production casing

Referring to the previous diagram,

Class C, Econolite 3%, yield is

Class G, Bentonite 8%, yield is

For the 7 (casing) 8-5/8 (hole), from Vol. & Hgt. Between: Tbg., Csg., D.P. & Hole Tab,it is found that the flow is 0.0247


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Class C

Total volume Total number of sacks = Thus, use approximately 120 sacks

Class G

Total volume = Total number of sacks = Thus, use approximately 450 sacks

Pressure

Total =

Displacement

7, 32 lbf/ft to bump plug

Bump plug at 5 bpm (or barrels per minute)

Time =

Bump plug w/

Bump plug w/ 5,000 psi


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Casign Design Calculations


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Casing Design Calculations

Assume:

Trip margin= 0.5 lbm/gal

Kick margin= 0.5 lbm/gal

Fracture gradient= 0.8 psi/ft

Pore pressure gradient= 0.439 psi/ft (Applied Drilling Engineering, Table 6.1, page 247, for

California Area)

Safety Factor (SF)= 2

Pore Pressure + Trip margin= 8.44 + 0.5 = 8.94 PPG

Fracture PressureKick margin= 15.380.5 = 14.88 PPG

Surface Casing

The surface casing design follow the guidelines that are outlined in Example 7.9 (From Applied

Drilling Engineering).

Burst

For burst considerations, use an injection pressure that is equivalent to a mud density 0.3 lbm/gal

greater than the fracture gradient. Also assume that any gas kick is composed of methane, which

has a molecular weight (M) of 16. Ideal gas behavior is also assumed for simplicity.

1. Determine potential internal pressure, pi

2. Determine potential gas pressure (Still following Example 7.9, Applied DrillingEngineering)


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Formation temperature, T is

Using Equation 4.5 from

Gradient for methane is

3. Surface Casing Pressure for design loading condition is (pressure diferential that tends toburst casing at the surface)

External pressure at surface= 0 psi

External pressure at casing seat=

Pressure diferential that tends to burst casing at the casing seat

Using a safety factor of 2,

At the surface: At the casing seat:

For 10-3/4 casing, J-55/K-55 casing grades meet the burst requirements.

The planned mud density when running the 10-3/4 casing is 8.94 PPG

Collapse

The external pressure of collapse-design load

The internal pressure for the collapse-design load is controlled by the maximum loss in

fluid level that could occur if a severe lost-circulation problem is encountered. To

determine the depth to which the mud level will fall, assume a normal-pressure and so

lost-circulation zone will be encountered near the depth of the next casing seat (5250),

and also if no permeable zones are exposed above this depth, then


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Using Equation7.24b from Applied Drilling Engineer

Depth to which the mud level will fall, Dm

( )

For these conditions, the mud level would fall to within 293 of the casing seat at 950.

The pressure differential that leads to collapse of the casing is zero at the surface.

Collapse of the casing seat at 950

External pressureinternal pressure w/ mud level at 627 ft


At657 ft: At 950 ft:

10-3/4 casing of all grades, except F-25 meet these design requirements.

Axial Tension

For 10-3/4 casing, using K-55, 40.5 lbf/ft,

(From Red Book, Halliburton)

OD= 11.75 (with coupling)

ID= 10.05

Casing weight=

Cross sectional area of steel


Or


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(overpull)

10-3/4, K-55 has a joint strength of 450,000 lbfand this is greater than the calculated

lbfat axial tension.Thus, 10-3/4, K-55, 40.5 lbf/ft surface casing will be run.

Production Casing

The production casing design will also follow the guidelines that are outlined in Example 7.9

(From Applied Drilling Engineering).

TVD= 5250

Burst

Potential internal pressure, pi

Potential gas pressure

To find the pressure differential that tends to burst casing at the surface,

External pressure at the surface= 0 psi

External pressure at the casing seat=

With a safety factor of 2,

At the surafce: At the casing seat of 5250:

Hence, 7, C-75, 32 lbf/ft casing would meet the burst requirement.


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Collapse

Earlier, it has already been determined that lost circulation was encountered, the fluidlevel would drop to 657 (950-293) from the surface.

Assume collapse if all the fluid in the wellbore was lost.

Gas gradient=

To collapse casing seat of 5250,


7, C-75, 32 lbf/ft has a collapse resistance of 8,230 psi which is greater than the

estimated collapse resistance of 4,080.2 psi.

Axial Tension

For 7 casing, using C-75, 32 lbf/ft,

(From Red Book, Halliburton)

OD= 7.656 (with coupling)

ID= 6.094

Casing weight=

Cross sectional area of steel



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Or

(overpull)

7, C-75, 32 lbf/ft, LT&C has a joint strength of 633,000 lbf, which is greater than the

worst case of 283,583.5 lbf.

Conclusion

Surface casing: 10-3/4, K-55, 40.5 lbf/ft, set at 900 in a 15 hole(Based on Table 7.7,Chapter 7, page 331, Applied Drilling Engineering)

Production casing: 7, 32 lbf/ft, C-75 set at 5250 in a 8-5/8 hole (Based on Table 7.7,

Chapter 7, page 331, Applied Drilling Engineering)

Chapter 7, page 332, Table 7.8 illustrated that the largest bit through 10-3/4, 40.5 lbf/ft

is 9-7/8 bit

15bit will pass through 16 conductor pipe


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Mud Information and Annular Velocity

Calculations


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Mud Information and Annular Velocity Calculations

There is a need to determine if there is enough rate at 375 GPM to keep the hole clean.

Assume Bingham Plastic Model (Based on the sample drilling reports)

15 hole

q= 375 GPM

Drill pipe ID= 2.992

Using Equation from Table 4.6,

Drill pipe mean velocity,

=8.94 ppg

d= 2.992

= 16

Turbulence criteria

(Turbulent flow through the drill pipe)

7 9-7/8hole annulus

Turbulence criteria

Right at turbulent criteria for the annulus.


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10-3/4 15hole annulus

Turbulence criteria

Right at turbulent criteria for the annulus.


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Directional Plan


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Directional Plan


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Drilling Program Outline


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Figure 1: Schematic arrangement of solids control equioment to be used

Shale Shaker

Desander

Mud Cleaner

Centrifuge

Reserve mud pits

Return line from well

Solids to pit

Solids to pit

Solids to pit

Solids to pit

Liquified returnto mud system

Liquids

Liquids

Liquids

Liquids


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Plan not to scale

Figure 2: Illustration of well trajectory

0

200

400

600

800

0 200 400 600 800 1000 1200 1400

South

(-)

/North(+)

West(-)/East(+)

Surface Location Reference Point Bottom Hole Location

Bottom Hole

Location- 600' North,

1200' East of "AA"

Surface Location- 300'

North, 600' East of

"AA"

"AA"

pte514 drilling project new

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