an advancing sand control chemistry to increase maximum sand

Presented by Martin Grainger

Authors: Nataliya Ludanova, Pratyush Singh, Kern Smith

Weatherford International Inc.

An Advancing Sand Control Chemistry to Increase Maximum Sand Free Rate in Failed Gravel Pack Wells

SPE Sand Management Forum March 2014

© 2009 - 2012 Weatherford. All rights reserved.

Sand Control

1

Sand Control

Re-Active Passive

Mechanical Methods

• Frac packs

• HRWP/HRWF

• Horizontal GP

• Open hole GP

• Expandable screens

• Stand alone screens

Chemical Methods

• Sand consolidation

• Sand conglomeration

– ZPAS

• Other

Mechanical Methods

• Oriented perforating

• Selective perforating

• Controlled drawdown

Pro-Active


What is ZPAS

• Unique and advanced patented chemical solution

• A proactive sand control method

• Alters zeta potential of solid surfaces to the optimum

range of agglomeration

• Disperses and coats sand grains and formation fines

when added to aqueous solutions

• Provides a strengthened attraction between the particles

without causing substantial damage to permeability

2


Zeta Potential – Where do we need to be

Zeta Potential [mV] Stability behavior of the colloid

+3 to -5 Maximum agglomeration

-5 to -10 Strong agglomeration

-10 to -15 Medium to weak agglomeration

-16 to -30 Threshold

-31 to -100 Low to excellent dispersion

-47.85

-1.58

-28.37

1.194

-50

-40

-30

-20

-10

0

10

UntreatedSilica

TreatedSilica

UntreatedCoal

TreatedCoal

Ze

ta P

ote

ntia

l (m

V)

Zeta Potential (mean) before and after SandAid™ treatment


Sand Conglomeration

• Untreated

4

• Treated

© 2009 - 2012 Weatherford. All rights reserved. 5

Blank 40X

Treated 40X

Treated 150X

Sand Conglomeration


Agglomeration Test Result

6

Untreated Sand

Treated Sand

Murky: Sand/ fines dispersed Clear: Sand/Fines settled

• On Inverting Sand will move as plug

• Turbulence will disrupt plug but will

settle again in few minutes


Formation Damage Test Actual field core 3rd Party Lab (Single phase @ 95 0F)

Sand A Sand B K (mD)

Initial 131

K (mD)

returned 143

K (mD)

Initial 442

K (mD)

returned 505


Formation Damage Test Results (Actual Field Core @ 65 deg F)

8

2500.00

2600.00

2700.00

2800.00

2900.00

3000.00

0 100 200 300 400 500 600 700 800

P

e

r

m

e

a

b

i

l

i

t

y

m

D

Flow rate ml/hrs

Permeability of 3% KCl before and after Treatment with 7% ZPAS in 3% KCl (w/ 0.5 % Surfactant) (Sample ID 4)

Initial Permeability Regain Permeability

Initial Permeability = 2657 mD (average)

Final Permeability = 2754 mD (average)

Percent Regain Permeability = 103% (average)


Sand Retention Test

9

• Blank or Untreated Sand Sample were tested – leads to

catastrophic failure.

• Treated Sand sample with ZPAS shows almost negligible

sand production


Application

In existing wells, SandAid technology can be pumped through

current tubular, flow line or coiled tubing.

Service

packer

Well

screens

Zone treated

with ZPAS Perforations

Optional

additional

zones

Production

tubing or

workstring

Zone treated

with ZPAS

Production

tubular or

workstring

Service

packer

Optional

additional

zones

Gravel or Frac

pack treated

with ZPAS

Remedial New Wells and Workovers


Benefits

• No significant reduction in permeability

• Pumped downhole as a matrix treatment – relatively

simple to apply

– Can be mixed in fresh water, brines and seawater

• Compatibility testing may be required

– Fairly long zones can be treated

– Bull head down production tubing, CT and flow lines

• Remains ductile – Adapt to changing reservoir conditions

• Re-agglomerates – Allows to explore MSFR


Current Update

• Around 280+ wells treated to date

• Success ratio: more than 90%

• Maximum Sand Free Rate (MSFR) increased in all

successful wells

• Treatment life > 3 years for some wells

– Longevity varies from few weeks to several years

12


Case History - West Africa

13

FIELD NAME ZATCHI MARINE

WELL NAME ZAM 104 ST (SLOT2)

DATE: Account

SINGLE COMPLETION VERTICAL DEVIATED HORIZONTAL SELECTIVE

ICGP OHGP GRAVEL SIZE: 20/40 40/60

String w eight up [t] Casing Size: [in] Type of packer f luid:

String w eight dow n [t] Top: [m] Bottom: [m] Density: [kg/l]

Make up report yes [y/n]

DRILLING PERIOD

RIG USED

RT/TIE DOWN

WELL HEAD RATING

TOTAL DEPTH SHEAR RELEASE VALUE: -lbs.

TOP CMT PLUG SHEAR RELEASE VALUE: lbs.

BRIDGE PLUG

ANNULUS FLUID

BTM CHECKED ON

GEOG COORD LAT

GEOG COORD LONG Nom. O.D. Thread lb/ft Steel Gr. %

X-MAS TREE

BONNET MAKE UP TORQUE : GREASE :

BACK PRES, VALVE REF Tools

15.40

X/O370m

Thd S. Grade Top (m)

CSG/LIN OD

TOP AT mt

SHOE AT mt

CEM UP mt

LINER HANGER :

LINER HANGER :

LINER HANGER :

CASINGS CHARACTERISTICS

OD NOM

531.23

531.61

Top (mMD) Bottom (mMD)

TYPE OF GUNS :

TYPE OF CHARGE :

SHOOT DENSITY :

Top (m) Bottom (m)

Top (mMD) Bottom (mMD)

TELL TALE SCREEN 4"NU SLOT 8

M-18 COLLET SEAL LOCATOR NOTES : 589.50

Perforated Intervals

586.00 C

Level

Level

583.50

565.50 568.10 C

570.50

F. Pounga.

J. Uwatse / A. Savioli

Superintendant

Rig SupervisorsJOB PURPOSE

542.25

TOP CENTRALIZER. W/ 2-7/8" CS BOX x EUE PIN 2.441 6.496

X-O. SIZE 2-7/8" EUE BOX x 2-3/8" EUE PIN. 1.900 3.362

25

Level

26

4.25

EXTENSION HOUSING

M-21 DOWELL PACKER 7 5/8" 26,4-33#

COLLAR

SEAL HOUSING

5.00

6.53 537.73

538.91

540.27

563.02

544.47

589.32

X-O 4 1/2" NU BOX- 4 NU PIN

SCREENS SLOT 8 W/CENTRALIZERS N° 4 587.50

4.50

2.47

4.50

4.72

LOCATING COLLAR

M-18 SUMP PACKER 3.26 6.31WORKOVER

37

4.44

2.52

2.875

4.50

4.69

2.875

2.312

2.875

4.500

N/A

2.441

2.441

2.441

N/A

3.75

3.7524

17.34

2.875

530.8

154.98

498.68

523.71

516.82

504.62

520.49

516.09

7-5/8"

3708-5/8"

11.000

3.700

2.875

4.000

BTC

ISOLATED INTERVAL

16"

10-3/4" BTC

BTC 195.6

173.8

89

161

396 40.5

Welded

BTC

NA

379.4

1" thick

75

26"

1.900

2.441

17

13

N/A

21

Dow n to

516,09mL-80

1 TBG HGR DP4-H5 2-7/8" EUE TOP x HYD-CS BOTT.

6.5hyd.cs

SIZE

API 5A-2

ID OD

14.00

ESP

I.D. Depth

1.03

Manufact. Model type

0

Eni Congo

24/05/88 - 09/07/88 Nom. O.D.

GENERAL INFORMATIONS

2.400

2

11º25'28",495 - E

4º31'42",704 - S

ADJUSTABLE UNION W/ 2-7/8" HYD-CS PIN x PIN

2,875"

2200 ftlb

WELL HEAD DESCRIPTION

11" x 2-9/16" 3,000-psi Clamped

Size 2½" Type TSB2

2-9/16" x 2-9/16" x 11" 3,000-psi Composed

11" DP4-H5-MS EU UP * VAM DOWN

PRODUCTION CASING

8-5/8"

16 ¾" * 3K Breda Unitized

TUBING HANGER

WHD

Bottom (m)

370

BTC 26.47-5/8"

WELL HEAD

Nom OD lb/ft

BTC 36

TO m

WHD

695

16" 10"3/4

WHD

STEEL

161

24/02/2000

NAVIFOR-2

14

1.03-Kg/lt f iltered Sea-Water

840 - mMDORKB

NA

3,000 - psi w orking pressure

Tubing

COMPLETION STRING

Packer

Filtered Sea-Water

Well deviation [max.]:mMDorkb Well deviation @ BPL depth: -mMDORKB

ARPO 20 / C

695

370

8-5/8" 7-5/8"

WHD

370

lbf/ft

Sea Bed

370

THRD

396

ID mm

15

20

251.3

19

16

26.4

695 14

PKR M 18 DOWELL 773.5

DISCHARGE HEAD W/ 2-3/8" EUE BOX UP.

12 TBG 2 7/8" EU 6,5# L-80 N° 1

9

11

36

4.94

34

33

581.00 C

36

540.67

540.83

5.00

3.81

14.19

151.815.000

2.441

2.441

2.875

2.875

2.441

2.875

148.94

2.441

516.47

506.53

PUP JOINT 2 7/8" HYD.CS 153.03

501.63

2.875

18

6.496

2.362

7

PUP JOINT 2 7/8" HYD.CS

DPGTA - DB. CARRIER MANDREL.10

8 TBG 2 7/8" HYD. CS 6,5# L-80 N° 36


GAS SEPARATOR: FRSTZ H6 FER B AR.

516.974.000

587.69

521.85

542.52

GRAVEL PACK ASSEMBLY

23

22

562.86

542.05

543.94

542.72

4.000

4.000

4.50

4.88

4.60

3.50

31

32

5.00

SAFETY SHEAR COLLAR

30

LOCATING COLLAR

4.00

3.50 5.0029

EXTENSION HOUSING 3.81

35 O-RING SEAL SUB 4" NU

3.50

3.18

4.72

27

28

2.441

PUMP: 400PMSND H6 STD PNT. TYPE 104 P12. N/A

3

4.00

SEAL SECTION: FSB3DB FER HL AB/AB H6PF N/A

2.441

3.50

MOTOR: FMH-A 85HP/ 1078V/ 54A/ 50HZ.

PORTED HOUSING W/CLOSING SLEEVE

3.56

N/A

COMPLETION STRING BOTTOM.

LOCATOR EXTENSION

BLANK PIPES W/CENTALIZERS

3.81

29 July 2008

BOTTOM CENTRALIZER

LK-5 INJECTION VALVE


4 TBG 2 7/8" HYD. CS 6,5# L-80 N°14

5 PUP JOINT 2 7/8" HYD.CS

SAFETY VALVE. BAKER TME-5.6

COMPLETION SKETCH

Offshore CHGP ESP completion

• K = 2000 md

• Φ = 30%

• BHT = 104°F

• Workover in July 2008, increasing

levels of sand

• Well shut in Oct 2008

Worked over Dec 2010

• Sand cleanout and ZPAS job

• Positive response ~120 days prod

• Post Production reached 950 BOPD

(compared to 63 BOPD)

• ZERO Sand

• 3 failed GP wells treated with 100%

successful results


Case History - GOM

14

Offshore CHGP completion

• K = 1000 md

• Φ = 30%

• BHT = 157°F

• Net perfs = 25 ft

• Initial completion in 2004

• Well shut in due to sand

production

• Two GP zones are shut in

Worked over in March 2011

• 1st trial well for this customer

• Was tested to fail

• After success is proved, the

customer used ZPAS in other

wells in different regions


Case History - GOM

15

Offshore CHGP completion

• K = 200 md

• Φ = 27%

• BHT = 170°F

• Net perfs = 70 ft

• Early 2012 initial GP completion

• Well shut in due to excessive

sand production within few

weeks of initial completion

Worked over in May 2013

• Sand cleanout and ZPAS job

• Post Production reached 300

BPD

• ZERO Sand Presence

• Eliminating the need of

expensive re-completion


Case History - South America

16

CHGP + ZPAS completion

• K = 1060 md

• Φ = 24%

• BHT = 191 F

• Perforation = 6 ft

• Oil Well

• Fines Production was

observed

• Sand cleanout and ZPAS

treatment

• 2 wells were treated after GP

failure (fines production)

• 20 wells treated in 2013 using

ZPAS + GP as a preventative

measure

• All jobs are producing at

increased MSFR


Case History – Egypt

• Offshore Completion – Cased &

Perforated

• Gas Well

• PLT run and Isolated water

producing zone

• Kliquid = 45 md

• Φ = 18%

• BHT = 275 F

• Net Perforations = 90 ft

(Gross Interval = 174 ft)

• Worked over April 2013

• Sand cleanout and Tagged TOS

• SRT & Placement analysis

conducted

• SandAid treatment (followed by 16

hrs shut-in)

• Positive well response ~ 8 months

production

• Increased MSFR by almost 70%

17


Conclusions

• Zeta Potential Altering Technology, provides an advanced chemical

method that reliably increases the Maximum Sand Free Rate

– MSFR is increased in (almost) all wells

– Fines production is eliminated or significantly reduced

• Internal and external laboratory testing confirmed:

– No significant reduction in permeability

– Increase in Sand Free rate

• Easy to apply

– Most jobs can simply be bullheaded down the production tubing or work

string

– Allows for long intervals to be treated.

– Can be used to repair existing and/or failed mechanical sand control

methods, such as gravel pack, sand screens, etc.

19

an advancing sand control chemistry to increase maximum sand

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