Operation concerned Hydraulic set packer using tandem packer with mechanical set ETI-R3 for zonal isolation...in Mann Oil Field, Central basin of Myanmar.

1. ‘ETI-DLH’ Hydraulic Set Packer
Technical Meeting
 Objectives of using a Hydraulic Set Packer
 How does it work ?
 Operation summary of Hydraulic Set packer at Well M-197
 Production Allocation test using Tandem Packers
 Recommendations
12 Oct 2012 / PPE

2. Technical Meeting 12 Oct 2012 / PPE
Named: Hydraulic set single-string retrievable packer
Objectives of using a Hydraulic Set Packer
 Used in virtually any Production Application
 Able to set Multi-zone completion,
used in above permanent or retrievable packer
 Designed for differential pressure up to 7500 psi

3. Technical Meeting 12 Oct 2012 / PPE
Cross-sectional View for Packer Component

4. Technical Meeting 12 Oct 2012 / PPE
Operations Features
 Running Sequence
 Setting Sequence
 Releasing Procedures
**Pre- job Scraping is strongly recommended
prior to running.
The location of any tight spots
should be noted ……. Reduce
running speed of packer through
these tight spots…………….

5. Technical Meeting 12 Oct 2012 / PPE
Running Sequence
Make up the Packer in tubing
string and landed prior to desired
setting depth ……..
Precaution
 Avoid torque- transmission through the
packer
 Slow steady running speed
 Be careful of external forces caused by
debris or tight spots (These forces load the
mandrel through the chamber and body
lock)

6. Technical Meeting 12 Oct 2012 / PPE
 Large internal by-pass
reduces swabbing effect
while running and retrieving
 While running process,
well fluid stream through
the annulus, packer by-pass
port and around the packer
body

7. Technical Meeting 12 Oct 2012 / PPE
Running inside casing, excess speed can
result in swabbing off the packing
element….
Or
It can be subject to preset conditions by
pressure waves through the fluid……
Slow steady running speed …………
Recommended running speed should
not be more than 30 sec. per joint (~30
ft)
Avoid sudden stops and starts (while
running, setting or pulling slip)

8. Technical Meeting 12 Oct 2012 / PPE
How does it work……………..
PumpFluidinside
packer/pressurized
Internal tubing pressure
enters the setting
chamber through the
setting port….
Tubing pump pressure
is used to set the packer
 Setting force is locked
into the packer by body
lock ring
 Acts upward on the
setting sleeve…..
 Downwards on the
setting chamber / lower
cone
Setting Sequence

9. Technical Meeting 12 Oct 2012 / PPE
How does it work……………..
Setting Chamber
Setting Sleeve
Shear Pins
Lock Ring
12 Oct 2012 / PPE
Setting Sequence continued
 Applied load acting on the
pistons exceed the valve of the
setting initiation shear screws
 Shear screws will shear and
allow to the setting process to
proceed
 The setting sleeve pushes up
through the setting shear pins
 Setting sleeve closing the valve
& setting upper slip
 Setting chamber/lower cone
pushes down & setting the lower
slip
 Further pressuring shears the
setting shear pins & pack off the
packer element

10. Technical Meeting 12 Oct 2012 / PPE
Setting Sequence continued
Note:
 No mandrel movement occurs during
setting sequence
 Some residual tension will remain in
tubing, due to the tubing elongation
caused by piston effect

11. Technical Meeting 12 Oct 2012 / PPE
Releasing Procedures
Packer is released by tension on the tubing string, following sequence of events:
 The upper and lower shear screws shear as tension
 The mandrel begins to move up relative to the packer body
 By-pass valve open, upward raises the upper slip / releasing upper slip
 Continued upward movement, lift the packer body, relaxing packer elements,
bottom cone upward and releasing the lower slip
 The final stage of un-setting => lower slip body & slip reach the bottom sub=>
 Thus allowing tool to move freely up or down
 After un-setting, wait about 10 minutes to allow rubber to relax, pull out of the
hole
The shear release value can be adjusted by adding or removing shear
screws from housing => => 2 upper shear screws (5000 lb/screw) for
10000 lb
=> 4 lower shear screws (6000 lb/screw) for 24000 lb
=> Total shear 34000 lb (i.e. Tension force to release the
packer)

12. Technical Meeting 12 Oct 2012 / PPE
Operations on M-197
 To apply the Hydraulic set packer
 To test the application of the combination of
hydraulic + Mechanical set packer in single string
 To identify the production allocation test for the
candidates using tandem packer method

13. Technical Meeting 12 Oct 2012 / PPE
M-197 Wellbore
Schematic
Fluid level 1200 ft from
surface
Ground 182 ft
KB 192 ft
KB-GR 10 ft
PBTD 3574 ft
TD 3600 ft
Sand 2700/3200 ft sd
Casing 5-1/2” 23#, RTC
Clean out depth
3473 ft

14. Technical Meeting 12 Oct 2012 / PPE
‘ETI-DLH’ PKR,
2792 ft
‘ETI-R3’ PKR,
2872 ft
PSD 2862 ft
Operations Summary
 Rigged up P-70
 PJSM
 Ran in Bowen Scraper
 Bottom cleaning by Bailer
 Made up R3 PKR in tubing
string below PSD & ran in hole
(set standing valve at seating
nipple)
 Continued running tubing and
made up Hydraulic PKR in the
string, ran in desired depth with
slow speed
 Set R3 PKR and set well head
slip
 Set Hydraulic PKR with holding
pressure 3500 psi inside tubing
for 8 minutes
 Applied 1700 psi annulus
pressure to test the PKR, sound,
bled off pressure
 Retrieved standing valve 
Bailed depth
3473 ft

15. Technical Meeting 12 Oct 2012 / PPE
‘ETI-DLH’ PKR,
2792 ft
‘ETI-R3’ PKR,
2872 ft
PSD 2862 ft
Operations Summary

 Ran in hole insert pump and
sucker rod string
 Pumping test
Bailed depth
3473 ft

16. BHP/BHT Survey result of Well 197
Pressure Gradient
Pressure Temperature Profile

17. Zonal Isolation Test
Objectives:
 Identifying water bearing sand for the high water cut wells
 Identifying production allocation for no/low water cut wells
Follow up:
 Selecting candidates
 Water shut off
 Re-perforation
 Deepening or in-fill drilling possibility

18. 1978 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 2000 01 02 03 04 05 06 07 08 09 10 11 12
0
250
500
750
1000
1250
Date
170
cv .mav oil ( bbl/d )
cv .mav wtr ( bbl/d )
22AB/23
23/25
2200C
Production history of Well 170
2
3
16
23
27
68
73
89
98
99
101
103
106
111 126
127
129
141
147
155
170
172
173
174
177
181
187
197
203
205
207
211
213
216
220
223
224
228
233
236
237
240
243
246
247
252
257
258
262
275
276
278
280
283
285
286
287
289
298
303
311
321
355
356
357
403
410
421
422
441
443
447
449
451
454
455
457
464
470
471
474
475
476
483
484
497
498
510
531
537
607
624
629
642
Gas Producer
High Oil Producer
High Oil Producer1
Oil Producer
Swabbing producer
Temporary shut in
Waste Water Disposal

19. Operation time line of Well 170
FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC JAN
2005 2006
0
75
150
225
300
375
Date
170
OIL ( bbl/d )
WATER ( bbl/d )
3/30/2005Reopenandpumptest
4/14/2005Changetubingsize
9/11/2005Zoneisolation(Isolate2100'sand)
9/17/2005Zoneisolation

20. Zonal isolation plan for Well 170
 Sands are 21/22ABC/23A/23B/25, out of them, squeezed all except that 22C&25
 24 ABCD sands have not been perforated yet
 Currently a swabbing producer and slightly up dip of Well 177
 Seems that it is worth to test 22AB only by setting PKR A & PKR B.
 A good playing ground for setting exercises hydraulic set PKR as well

21. 1990 91 92 93 94 95 96 97 98 99 2000 01 02 03 04 05 06 07 08 09 10 11 12
0
15
30
45
60
75
Date
627
cv .mav oil ( bbl/d )
cv .mav wtr ( bbl/d )
38ABC
3700AB
3100
Production history of Well 627
5
13
16
18
23
37
38
41
43
47
51
68
71
73
79
85
86
87
89
91
92
93
94
95
96
97
98
103
106
110
111
114
117
121
122
125
126
127
128
129
130
134
135
136
139
146
147
150
151
152
155
158
162
167
168169
170
171
173
177
178
179
180
183
185
186
187
191
192
194
195
196
197
202
203 204
205
206
207
210
211
215
216
217
218
220
223
224
227
237
238
239
240
244
245
246
258
260
262
263
264
265
266
270
274
278
280
281282
291
294
296
298
299
301
304
305
307
308
311
312
316
317
321 327
345
353
354
355
356
394
400
401 414
447
461
470
472
476
497
498
504
521
523
5
560
570
573
582
584
586
591
592
593
595
596
599
601
604
605
607
608
609
610
611
614
615
616
617
620
622
6
624
625
627
628
629
630
633
634
637
639
640
641
643
644
645
661
Drain pit oil added
Gas Producer
High Oil Producer
High Oil Producer1
Oil Producer
Swabbing producer
Temporary shut in
Waste Water Disposal

22. Production history of Well 627
Dynamic Fluid Level cannot identify
exactly which sand is giving oil
4020
4040
4060
4080
4100
4120
4140
4160
Main Depth to Liq Level TVD (ft)
Main Depth to LiqLevelTVD (ft)
4120 ft

23. Zonal isolation plan for Well 627
 Seems that water out from 3100 ft sand
 Ignorable water rate though
 38 sand inflow was quickly less after perforate
 Decline rate of 37 ft sand is reasonable
 Dynamic fluid level cannot tell exactly whether 38 ft sand is contributing or not
 Propose to isolate between 37 and 38 ft sand by the PKR
 Consider to re-perf the 38 ft sands if there is no production from 38 sand
 Downside 1: Initial rate of 38 sand is low 30 bopd
 Downside 2: Approximate saturation and sand quality ??
 Upside 1: Why quickly end producing life ( potential left oil?? )
 Upside 2: 10 bopd additional and producing life 6 moth would be quite
commercial

24. Technical Meeting 12 Oct 2012 / PPE
4
14
15
24
28
35
36
44
46
49
56
66
67
74
76
83
84
88
105
108
118
1
140
144
149
166
176
182
188
189
212
226
235
242
249
250 267
268
271
279
295
309
310
318
328
332
333
334
335
337
349
364
376
378
384
39
399
407
409
446
452
460
468
479
480
489
496
499
500
514
518
522
535
544
594
598
646
65
664
100
High Oil Producer
Oil Producer
Swabbing producer
Temporary shut in
OKH and PA combination in Fault
FC
 Selective wells producing from both
OKH and PA sands are
Well 407, 468, 364, 166, 144, 49
&496
 Set hydraulic PKR for production
allocation
 Objective is to figure out which
sands are potential for re-perf.

25. Technical Meeting 12 Oct 2012 / PPE
Multi Zone Testing comparison between Conventional and Tandem PKR
Save the tripping time
Used Retrievable BP + Packer
Operation
 Run in retrievable BP to desired
depth
 Pull out BP setting tool to surface
 Run in completion string with
Packer => set PKR => pumping test
 Pull out pumping string with
packer
 Run in retrieving tool to top of BP
 Retrieve the BP and pull out string
Total 3 round trips
Used Tandem Packer
Operation
 Run in pumping string
with Tandem packer
(Hydraulic set PKR+ R3
compression packer) to
desired depth, set R3 PKR =>
set WH slip => set Hydraulic
PKR => Pumping test
 Retrieved Tandem packer
and pull out pumping string
Total 1 round trip
Vs.

26. Technical Meeting 12 Oct 2012 / PPE
Conclusion & Recommendation
Candidates Objectives
Well 627 - to allocate 37 and 38 ft sands
- reperf possibility ?
Well 407, 468, 364, 166, 144, 49& 496 - To identify which sands are producing ?
 Exercise for Hydraulic set packer is successful
 Can use tandem packer instead of using bridge plug to reduce round trip time
 Select the candidates
PROS:
 can be isolated as tandem packer
 less trip time
 suitable for inclined and/or dog leg wells
 not required to apply tubing rotation
 setting is more actuate than other type
CONS:
 surface pump is necessary
 need to use a drop ball/wireline plug/others
 running speed is critical
 must redress after every retrieve
 cannot reset like others (setting is certain)