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PETE 661 Drilling Engineering

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Title: PETE 661 Drilling Engineering


1
PETE 661 Drilling Engineering
  • Lesson 24
  • Circulation Kill Techniques

2
NOTE
  • No more Homework!
  • The Solution to HW 12 is on the Web
  • Our FINAL EXAM will be on Friday, May 2, 1230
    p.m. 230 p.m. Rm. 208
  • Equations will be provided, as usual
  • You may bring one 8 ½ 11 Eq. Sheet

3
Circulation Kill Techniques
  • Shut-In Pressures
  • Weighting Up the Mud
  • Drillers Method
  • Wait Weight Method
  • Concurrent Method

4
Shut-In Pressures
  • Once a kick is detected, and proper shut-in
    procedures are followed, the influx will
    continue…
  • until the fluids in the wellbore are compressed
    sufficiently to where the Shut-in Surface
    Pressure the HSP Formation pressure
    (annulus or DP?)
  • No more influx

5
Shut-In Pressures
  • Once the influx is stopped
  • The kick fluids must be removed from the
    wellbore, and
  • The low density drilling fluid that was in the
    hole when the kick occurred must be replaced
    with KWM

6
U-Tube concept
The Stabilized BHP SIDPP HSPmud_dp SICP
HSPmud_ann HSPkick Formation
Press.
KICK
7
Back Pressure Valve in the Drillstring
How do you measure the SIDPP?
Flapper
8
Measurement of SIDPP and SICP with Back Pressure
Valve
SIDPP
9
Weighting Up the Mud
  • Example 5.6
  • OWM 13.2 ppg
  • MD 10,350
  • TVD 10,075
  • SIDPP 400 psig
  • Estimate the mud weight required to kill the well

10
Example 5.6
  • KWM OWM SIDPP/(0.052 TVD)
  • KWM 13.2 400/(0.052 10,075)
  • KWM 13.2 0.76 13.96 14.0 ppg
  • This would be considered a 0.8 ppg kick
    (kick intensity)

11
Example 5.7
12
Example 5.7
13
Example 5.7
(3.35 lb/gal)
14
Example 5.10
(ok)
15
Example 5.10
16
Kill Procedures
17
KRCP - Kill Rate Circ. Press. - usually fairly
low...
  • Lower annulus friction pressure
  • Less pressure fluctuation in response to a
    change in choke setting
  • Reduced risk of pump breakdown or other
    mechanical problems
  • Circulating with larger underbalance pressures
    for the pump liner rating

18
KRCP - SPP - KRP
  • Reduced instantaneous gas rates through the
    choke manifold and mud-gas separator
  • Minimum cuttings throughput at the choke
  • Keeping within the capabilities of the
    mud-mixing system
  • Normally 1/3 to 1/2 of normal drilling
    circulation rate

19
KRP taken
  • Every tour by each driller
  • When the pumps are repaired or liners changed
  • If mud properties are changed
  • Every 500 feet of hole drilled
  • When the BHA changed
  • When bit nozzles are changed

20
Well Data
21
Well Data
22
Well Data
23
KRCP (well control)
CDPP (drilling)
Drillstring
Annulus
24
ICP KRCP SIDPP
25
Driller Method
26
Example 5.12
27
Example 5.12
( 424.28.34 1,470 )
28
Example 5.12
29
Circulating Drillpipe Pressure
Drillers Method
30
Circulating Drillpipe Pressure
Drillers Method
31
(No Transcript)
32
Circulating Casing Pressure
(MAASP) Maximum Allowable Annulus Surface
Pressure
33
Circulating Casing Pressure
34
Circulating Pressure at Casing Seat
35
Circulating Pressure at Casing Seat
36
  • Kick / Mud Mixing
  • Kick Migration
  • Velocity Profile

37
Pit gain while circulating out kick
How might this differ for the Wait and Weight
method?
38
Effect of pit gain on casing pressure
39
Effect of kick intensity on surface casing
pressure (25 bbl gain)
40
Effect of hole size on surface casing pressure
(bbl gain)
41
Effect of kick fluids on surface casing pressure
(25 bbl gain)
42
WW
43
FCP KRP (KWM/OWM)a a 0.75 for turbulent flow
in pipe a 1.0 through bit
44
Bit Pressure Drop Increase
Annular Friction
a 1.00 a 0.75
45
Circulation Kill Techniques
  • Drillers Method
  • Wait Weight Method
  • Concurrent Method
  • Annulus Pressure Profiles
  • Kicks in Oil-Based Mud

46
Example 5.13
(Final Circulating Pressure)
Make up Table of DPP vs. Strokes
47
Example 5.13
Procedure
SICP
48
Example 5.13
1,230
1,013
49
Example 5.13
WW
50
(No Transcript)
51
Safety factor added to KWM
(Balanced FCP 1,013 psig)
52
Safety factor added to KWM
53
Example 5.14
54
Example 5.14
SIDPP 1,300 psi
55
Example 5.14
SIDPP 1,300 psi KRP 1,100 psi
56
Example 5.14
SIDPP 1,300 psi KRP 1,100 psi ICP
2,400 psi
SIDPP 1,300 psi KRP 1,100 psi
57
Directional Well
58
Concurrent Method
59
(No Transcript)
60
(No Transcript)
61
(No Transcript)
62
Kicks in Oil-Based Mud
  • Solubility of gas in oil
  • reduces surface pit gain measurements
  • reduces surface measurements of flow rate
    increase
  • reduces SICP
  • stays in solution until pressure is reduced to
    bubble point
  • as compared to water based mud systems

63
Free gas present at the start of circulation
Note effect of gas expansion
64
All gas in solution initially (in the Oil Base
Mud)
No gas expansion - initially
65
All gas stays in solution throughout circulation
(in the Oil Base Mud)
So, no gas expansion
66
Example 5.17
67
Example 5.17
68
Example 5.17
69
(No Transcript)
70
Example 5.17
71
Example 5.17
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