tepi - vico capillary string workshop

7/23/2019 TEPI - VICO Capillary String Workshop

1/21

TEPI VICO CAPILLARY STRING WORKSHOP

Sharing the experiences key success for the future !!


2/21

Decreasing gas rate

new well,

high gas rate Well died !!

Liquid loading issue will always occurs in gas wells, just only wait in the

matter of time when it comes !!

At initial stage of production, the gas will

carry produced liquids up to surface as the gasvelocity is high enough.

The energy available to transport theproduced liquids to surface declines due to thedepletion drive of reservoirs.

When the gas produced are below gas

critical rate, the liquids start toaccumulate in the wellboreincreasing hydrostatic pressure, backpressure into formation. As a result,thegas rate will significantly drops and thewell died

Quick overview: liquids loading phenomena in gas wells

TEPIVICO Capillary String Workshop


3/21

2

1 32

IP of the well is deceasing very fast after offload due to

water production from the reservoirs

Very fast transition (a few days) from steady state (offload)to death

Frequent offloads between repressurization period

Water loading kills the well

Objective of capillary = stabilize the rate

1 32

1- 2 weeks

1- 2months

IP of the well is downgraded because of partial water

loading

The well is able to produce during a long period

Offloads are less frequent

Water loading limits the gas rate

Objective of capillary = enhance the gas rate

Offloads

TIME

GASRATE

2

Targeted wells; 2 types

Offloads

TIME

GAS

RATE

1



4/21

reps. pseudo diedcategory

need special

operating procedure

Below 50% Turner

velocity line

validated in 2011

campaign

50% above Turner

velocity line

validated in 2010

campaign

Turner Velocity

Conclusion: Foaming technology can be applied in all region BUT it will

not work if the well has reservoir pressure issue (som e black w ells)

Test the limit of foaming technology !!

Weak wells

loading mode



5/21

TN-X8was in

Regular offloadcategory

With CS

Sustainable production for 16 months

(No off-load was required)

Qg: 0.8 MM

Surfactant

60 L/D

Qw: 30 bwpd

TN-H5 was in

Regular offload category

With CS

Sustainable production for 12 months

(No off-load was required)

Some good results: Off-loaded wells, critical velocity


6/21

TN-F7was in died

category since 2010

With CS

Intermittent production = 7

MMscfD more than 4 weeks

Unique well (died, even only

shut in for 2 hours)

Very good response if the well has strong inflow (high DEQ) but severe problem in

the outflow

Qg: 5.2 MM

~1 month~1 month

The special one !! good surprise of revival

Well

revivalLong offload

+ testLong offload

+test

6TEPIVICO Capillary String Workshop


7/21

Negative response due to reservoir pressure issue (low deq)

TN-ML5was in died category

Negative response (production

can not be sustained):

Offload 4x

1x intermittent well opening

The died well: negativeresponse !!



8/21

0

10

20

30

40

50

60

70

80

90

100

0

1

2

3

4

5

17-May-11 6-Jun-11 26-Jun-11 16-Jul-11 5-Aug-11 25-Aug-11 14-Sep-11

WHFP(Bar)

Surfact

antInejctionrate(L/D)

GasRate(MMSCFD)

Production Evolution on Well TN-X8

Gas Rate Surfactant Injection Rate Water Production oil Production WHFP

LP

mode

SI for CS

installation

QG increase After surfactant injection

DP downhole linked to dewatering is > DP linked to LP mode

TN-X8: Dewatering dP downhole evaluation



9/21

DEPTH REACHED (TARGET VS ACTUAL)

Some tolerance to the setting depth



10/21

Highlights from pilot phase Gain obtained 6.84 MMscfd (5 wells put on production).

TN-F7 rePoP after offload (+4.8 MM) ; TN-F5 plugged due to drilling activity. TN-X8 still low after misunderstanding of program.

TN-R23 is SI due to need to replace a part of DH equipment.

Highlights from Industrial phase Gain obtained 8.41 MMscfd (7 wells put on production).

TN-M18 rePoP : +3.7 MM TN-I9 rePoP failed : inject de-mineral then stop injection while waiting rig move out.

TN-I1 is waiting rig move-out for an intervention (gas found in control line)

TN-P23 SI for pressure Build up

TN-Lx41 rePoP : +0.5MM

TN-H12 diedafter switch to MP. SIBU

TN-Dx20 to be rePoP this week.

Result of current FAL project (per W1 Dec 12) No. Well Site Phase Date Gas Rate Surf. Inj.Rate (L/D) WHFP (bar) WHFT(deg C)1 TN-T6 SPU

Pilot

2-Dec 0.54 MMSCFD 20 14.5 36

2 TN-X8 SPU 2-Dec 0.38 MMSCFD 60 11 33

3 TN-H5 SPU 2-Dec 0.82 MMSCFD 60 12 35

4 TN-H3 SPU 2-Dec 0.35 MMSCFD 30 12 33

5 TN-F5 SPU 2-Dec 0.00 MMSCFD 5 0 0


7 TN-R23 SPU 2-Dec 0.00 MMSCFD 0 60 0

8 TN-K11 NPU

Industria

l

2-Dec 0.40 MMSCFD 126 9 36.6

9 TN-P14 NPU 2-Dec 1.79 MMSCFD 50 12 41.7

10 TN-P23 NPU 2-Dec 0.00 MMSCFD 15 11 30

11 TN-H12 SPU 2-Dec 0.00 MMSCFD 15 10.5 3112 TN-I9 NPU 2-Dec 0.00 MMSCFD 5 9.4 0

13 TN-Kx23 NPU 2-Dec 0.25 MMSCFD 40 7.9 35

14 TN-TMx30 SPU 2-Dec 1.20 MMSCFD 80 13 46

15 TN-Dx20 SPU 2-Dec 0.00 MMSCFD 100 107 0

16 TN-M18 NPU 2-Dec 3.69 MMSCFD 60 10 50

17 TN-I1 NPU 2-Dec 0.00 MMSCFD 0 10 0


19 TN-Lx41 NPU 2-Dec 0.52 MMSCFD 40 12 33

TOTAL (12) ells flowing 15.25 MMSCFD 956 L/D

1.27 MMSCFD/ Well flowingin Network Total

SPU 8.60 MMSCFD 500 L/D 620 L/DNPU 6.65 MMSCFD 316 L/D 336 L/D

Pilot Phase 6.84 MMSCFD 325 L/D

Indus. Phase 8.41 MMSCFD 631 L/D


7 wells are still shut in due to DHSV packing leaking, work over, plug due to rig activity and

pressure build up


11/21

DESIGN FEATURES

To keep down-hole safety valve installation

To reach target injection depth (3000 ~ 5000 m)

To avoid gas through inside capillary string

To be able to inject 150 L/D whilst maintaining DHSV

open



12/21

INSTALLATION PROCEDURE

12

WIRELINE PREPARATION:

RIH Dummy CS Hanger

RIH Memory P/T Survey

CAPILLARY STRING:

RIH Capillary String with Bottom Injection

valve to target depth

Cut Capillary String at surface

WIRELINE/BRAIDED LINE:

Connect CS with Hanger

Deploy CS with Hanger using Braided line

Function test the CS Installation

DOWNHOLE EQUIPMENT SCHEMATIC



13/21

Pressure up Control lineSTART OPEN DHSV AT 2000 PSICRACK TOP INJECTION VALVE AT

3200 PSI

CRACK BOTTOM INJECTION

VALVE AT 4000 PSI

2.81 DHSV Inside CS

Hanger. Opening

pressure 2000 psi

Top Injection Valveinside CS Hanger.

Crack pressure 3200

psi

Bottom Injection

Valve

3/8 CS

Max 4800 lbs

TEPI CAPILLARY STRING COMPLETION

INDUSTRIALIZATION PHASE


14/21

CHALLENGES

Down-hole equipment reliability

To simplify installation process

Running use CS Unit & deploy still

utilizes Braided line

Reduce crane dependency



15/21151515

Surfactant Injection Surface Facility

Overview and Design Basis

Well Location

- Scattered Location Around Tunu Area

- Instrument Gas is The Main Motive/Control Fluid

- Limited Electrical Power (in some area is not available at all)

Design Basis

- Injection Pressure : 159332 Barg

- Injection Flowrate : 10150 LPD

- Positive Displacement Pump (Pneumatic Driven) Selection Based on API-675



16/21

1616


Injection Package - Simplified Block Diagram

Safety Equipment

(Surfactant Injection

Isolation Valve)

Safety Equipment

(Pressure Protection)Safety Equipment

(Instrument Gas Supply

Isolation Valve)

Pump, Regulator

and Filter



17/21

17

Surface facilities package

Surface facilities package will be

removable. Once the capillarywell is finished, the package will be

used for the other well



18/21

1818


Challenges

Modification on Existing Infrastructure/Facilities

- Various Type of Structure and Configuration

- Portable Injection Facilities (Structure/Platform, Tank and Injection Package)

Surfactant Liquid Compatibility

- Corrosion Issues

- Instrument Seal vs Surfactant Liquid Compatibility

- Surfactant as Safety Valves (DHSV) Motive Fluid

Engineering and Design Condition

- Required Injection Pressure and Flowrate (Sensitive to Wells Characteristic)

- Instrument Gas Issues (Low Pressure, Condensation)

Alternative Solution : Gas Amplifier ?, Local Gas Scrubber ?, Electric Driven Pump (by

Solar Panel + Battery)?


D l f f b h


19/21

Development of surfactant test bench

Sign of chemical

degradation

If chemical

degrade, end of

story !!

Onsite



20/21

FOAMING & EMULSION ISSUE

20

NMP3 SC

M M M

FLOTATOR

M

TO FOSTTO DISPOSAL

TUBE

DEFOAMER

INJECTION LINE

SAMPLING POINT

REVERSE

DEMULSIFIER

INJECTION

SURFACTANT

INJECTION

7.9 7.8 8.2 8.3 8.7 7.9 7.1 7.3 7.8 7.2 8.6 8.1 7.8 7.9 9.3 9.1

32.9

19.6 17.29.1 9.0

0 0 0 0 0 0

80 80

50

100

40

240

260

1 40 1 40

230

3 80 3 80

330

230

9910

10433

10219

8965

9259

96459426

8939

5318

6334

7013

8029

4162

3386

2972

3243 3190 31442922

6782

0

2000

4000

6000

8000

10000

12000

-50

0

50

100

150

200

250

300

350

400

450

20-Sep-12

21-Sep-12

22-Sep-12

23-Sep-12

24-Sep-12

25-Sep-12

26-Sep-12

27-Sep-12

28-Sep-12

29-Sep-12

30-Sep-12

1-Oct-12

2-Oct-12

3-Oct-12

4-Oct-12

5-Oct-12

6-Oct-12

7-Oct-12

8-Oct-12

9-Oct-12

10-Oct-12

ProducedWater(bbl/d)

Water Oil Content (ppm)

SurfactantInjec tion (L/d)

Defoamer Injection (L/d)

Produced Water (bbl/d)



21/21

Conclusions & Way forward

The Capillary String project is profitable. The additional gas production is obtained and

can sustain/prolong the life of liquids loaded wells.

Foaming & emulsions issue shall be solved asap to maintain project delivery.

Continue learning process to get comprehensive understanding about capillary foaming

technology.

21TEPI VICO Capillary String Workshop

tepi - vico capillary string workshop

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