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‘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
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
Technical Meeting 12 Oct 2012 / PPE
Cross-sectional View for Packer Component
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…………….
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)
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
Technical Meeting 12 Oct 2012 / PPE
Running inside casing, excess speed can result in swabbing off the packing element….OrIt 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)
Technical Meeting 12 Oct 2012 / PPE
How does it work…………….. Pump Fluid inside
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
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
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
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)
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
Technical Meeting 12 Oct 2012 / PPE
M-197 Wellbore Schematic
Fluid level 1200 ft from surface
Ground 182 ftKB 192 ftKB-GR 10 ftPBTD 3574 ftTD 3600 ftSand 2700/3200 ft sdCasing 5-1/2” 23#, RTC
Clean out depth 3473 ft
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
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
BHP/BHT Survey result of Well 197
Pressure Gradient
Pressure Temperature Profile
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
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 11 120
250
500
750
1000
1250
Date
170cv.mavoil ( bbl/d )
cv.mavwtr ( bbl/d )
22
AB
/23
23
/25
22
00
C
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
174177
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
483484
497
498
510
531
537
607
624
629
642
Gas ProducerHigh Oil ProducerHigh Oil Producer1Oil ProducerSwabbing producerTemporary shut inWaste Water Disposal
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
170OIL ( bbl/d )
WATER ( bbl/d )
3/3
0/2
00
5
Re
op
en
and
pu
mp
test
4/1
4/2
00
5
Ch
an
ge
tu
bin
g s
ize
9/1
1/2
00
5
Zo
ne
isola
tio
n (
Iso
late
21
00' sa
nd)
9/1
7/2
00
5
Zo
ne
isola
tio
n
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
1990 91 92 93 94 95 96 97 98 99 2000 01 02 03 04 05 06 07 08 09 10 11 120
15
30
45
60
75
Date
627cv.mavoil ( bbl/d )
cv.mavwtr ( bbl/d )
38A
BC
3700
AB
3100
Production history of Well 627
5
13
16
18
23
37
38
41
43
47
51
68
71
73
79
80
85
86
87
89
91
92
93
94
95
96
97
98
103
106
110
111
114
117
121
122125
126
127
128
129
130
134
135
136
139
146
147
150
151
152
155
158
162
167
168169
170
171
173177
178
179
180
183
185
186
187
191192
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
545
560
570
573
582
584
586
591
592593
595
596
599
601
604
605
607
608
609
610
611
614
615
616
617
620
622
623
624
625
627
628
629
630
633
634
637
639
640
641
643
644
645
661
Drain pit oil addedGas ProducerHigh Oil ProducerHigh Oil Producer1Oil ProducerSwabbing producerTemporary shut inWaste Water Disposal
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 Liq Level TVD (ft)
4120 ft
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
Technical Meeting 12 Oct 2012 / PPE4
14
15
24
28
35
36
44
46
49
52
56
66
67
74
76
83
84
88
104
105
108
116
118
132140
144
149
153
165
166
175176
182
188
189212
226
235
242
249
250 267
268
271279
295
309
310
318
328
332
333
334
335
337
349
364
376
378
384
388395
398
399
407
409446
452
460
468
479
480
488
489
490495
496
499
500
514
518
522
535
536
544
594
598
646
655
664
1001
High Oil ProducerOil ProducerSwabbing producerTemporary 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.
Technical Meeting 12 Oct 2012 / PPE
Multi Zone Testing comparison between Conventional and Tandem PKRSave 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.
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)