Operations ETI-DLH

‘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


Cross-sectional View for Packer Component


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…………….


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)


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


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)


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


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


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


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)


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


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


‘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


‘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

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1250

Date

170cv.mavoil ( bbl/d )

cv.mavwtr ( bbl/d )

22

AB

/23

23

/25

22

00

C

Production history of Well 170

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3

16

23

27

68

73

89

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111 126

127

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155

170

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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

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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

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5

Zo

ne

isola

tio

n (

Iso

late

21

00' sa

nd)

9/1

7/2

00

5

Zo

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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

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Date

627cv.mavoil ( bbl/d )

cv.mavwtr ( bbl/d )

38A

BC

3700

AB

3100


5

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Drain pit oil addedGas ProducerHigh Oil ProducerHigh Oil Producer1Oil ProducerSwabbing producerTemporary shut inWaste Water Disposal


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

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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.


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.


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)

Operations ETI-DLH

Engineering

Transcript of Operations ETI-DLH