23 Critical velocity reduction system for LL gas wells ... · PDF fileScott Campbell - Rocky Mountain Sales Manager 720-946-1365- Denver Office CVR System Critical Velocity Reduction

Scott Campbell - Rocky Mountain Sales Manager

720-946-1365- Denver Office

CVR SystemCritical Velocity Reduction

Combination of Dead Strings, Capillary Injection Foamer and Plunger Lift

1© 2006 Weatherford. All rights reserved.

Critical Flow Rates

0

500

1,000

1,500

2,000

2,500

3,000

3,500

4,000

0 100 200 300 400 500 600 700 800 900 1,000

Wellhead Pressure (psi)

Flo

w R

ate

(m

cf/

d)

1.00"/0.826"

1.25"/1.076"

1.50"/1.310"

2.0"/1.78"

1.90/1.61

2 1/16"/1.75

2 3/8"/1.995

2 7/8"/2.441

3.5"/2.867

4.5 11.6 lb/ft

5.5 20 lb/ft

7.0" 26 lb./ft

4.5" Casing w / 2 3/8" Tubing



1.00-in. OD/0.826-in. ID CT

1.25-in. OD/1.076-in. ID CT

1.50-in. OD/1.310-in. ID CT

2.00-in. OD/1.780-in. ID CT

1.90-in. OD/1.610-in. ID API Tubing

2 1/16-in. OD/1.750-in. ID API Tubing



3.50-in. OD/2.867-in. ID API Tubing

4.5-in., 11.6-lb/ft Casing

5.5-in., 20-lb/ft Casing

7-in., 26-lb/ft Casing

4.5-in. Casing w/2 7/8-in./ Tubing




Typical Completion:

2 3/8” Production Tubing

4 ½” Casing 11.6# Casing

200 PSI Line Pressure

Extended Perforation Interval


Critical flow requirements assuming

200-psi WHBP(FTP):

CFR for 2-3/8” = 406 mcf/dCFR for 4-1/2” = 1.63 MMcf/d

Typical Completion

• Production String: 2-3/8”, 4.7 lb/ft

• Casing: 4-1/2”, 11.6 lb.ft

– 4.000-in. ID

– 3.875-in. drift

– Flow area: 12.5683 in.2

2 3/8”tubing

Extended

perforation

interval

4 ½” casing

A B


4 ½” Casing, 2 7/8” Dead String

2 3/8”X-LOC nipple

2 3/8” perforated sub36- ¾” holes

2 3/8” X-nipplew/ retrievable plug

2 3/8” X 2 7/8”crossover

2 7/8” tubing “dead string”

2 3/8” tubing

Shear-out safety jt.

4 ½”., 11.6-lb/ft casing

• Production String: 2 3/8”

• Dead String: 2 7/8” ULTRA FLUSH

– NO couplings = 2 7/8” = 2.875” OD

• Casing: 4-1/2”, 11.6 lb/ft


• Annular flow area, 2-7/8” inside 4-1/2”


Critical flow requirements assuming 200-psi WHBP:

CFR for 2-3/8” = 406 mcf/dCFR for 4-1/2” x 2 7/8” annulus = 790 mcf/d

(was 1.63 MMcf/d with open 4 ½” casing)


Casing Size

O.D.= 4 ½”

I.D. = 4.00”

Tubing Size

O.D.= 2 7/8”

I.D. = 2.441”

Annulus Area, in2

6.0768

4 ½” Casing, 2 7/8” Tubing


2 3/8” perforated sub36- ¾” holes

2 3/8” X 2 7/8”crossover

2 3/8” tubing

2 3/8” X-nipplew/ retrievable plug

¼” capillary injection string

injection valve and mandrel

Shear-out sub

2 7/8” dead string

4 ½” casing

• Production String: 2-3/8”

• Dead String: 2 7/8” ULTRA FLUSH

• Casing: 4 ½”, 11.6-lb/ft casing


• Annular Flow Area: 2-7/8” inside 4-1/2”


Critical flow requirements assuming 200-psi WHBP:

2 3/8” = 168 mcf/d with foam(was 406 mcf/d without foam)

4 ½” x 2 7/8” annulus = 327 mcf/d with foam

(was 790 mcf/d without foam)

(was 1.63 MMcf/d without Dead String)

4 ½” Casing, 2 7/8” Dead Stringwith Capillary String for Foamer Injection


Bumper Spring

Perforation Interval

THREE ARTIFICIAL LIFT SYSTEMS WORKING TOGETHER:

– Area Reduction (Dead String)

– Surface Tension and Density Reduction (Foamer)

– Plunger Lift (Mechanical Interface)


Heavy-Wall Flow Sub with Isolation

Sleeve

Kobe knockout

equalization plug

Seal ring packing

WX-LOK dogs

Internal fishing neck

Heavy-Duty Flow Sub

2 3/8” tubing, 36 ¾” holes

OD = 3.063”

ID = 1.995”

Top sub w/ WX

1.875” profile

Over 5 times

the flow area

of 2 3/8”

tubing

1.875” polished bore

Pressure equalization

knockout plug

Isolation Sleeve

OD = 1.75”

ID = 0.98”

Seal ring packing


FWHP = 200 PSI

9.1757

12.3120

6.0768

14.3683

8.1360

18.7978

12.5683

7.0315

4.6800

3.1262

Flow Area

(in.2 )

168.4406.70

6.5015.70

0.021712 3/8-in., 4.7-lb/ft tubing

252.1608.800.032502 7/8-in., 6.5-lb/ft tubing

378.8914.700.048833 1/2-in., 9.20-lb/ft tubing

676.91,634.900.087284 1/2-in., 11.6-lb/ft casing

1,012.52,445.400.130545 1/2-in., 17-lb/ft casing

494.21,193.700.063723 1/2-in. tubing and 5 1/2-in. casing


327.2790.300.042202 7/8-in. tubing and 4 1/2-in. casing


438.31,058.500.056502 3/8-in.tubing and 4 1/2-in. casing

CFR with

Foam

(mcf/d)

CFR with

Water

(mcf/d)

CV with

Foam,

(ft /sec)

CV with

Water,

(ft /sec)

Flow Area

(ft2)

Flow Pattern

CV = Critical velocity, ft/secCFR = Critical flow rate, mcf/dFlowing surface temperature = 70°FDensity of water = 8.4 lb/galZ = 0.97


4 ½” Casing with 2 7/8” Dead String with 2 3/8” Production Tubing


Installation Pictures

and

Production Data


4 1/2" , 11.6#, HCP-110 set at 11,600' w/1,930 sx

2 3/8" , 4.7#, N-80, tubing w/"XN" nipple (1.87") and 22.5' tubing below nipple

EOT--10,732' cut off with chemical cutter

Tubing joint cut off - 22.5' long

XN Nipple @ +/-10,709'

10,746' - 10,752' 10,810' - 10,818' Frac w/1486 bbl Primefrac 30 w/30% N2

10,756' - 10,762' 3SPF 120 Deg. 6,077# 100 mesh and 116,847 # 20-40 Econoprop

Upper & Lower Lewis tested after frac 550mcf/d@150psi

10,878' - 10,881' 10,908' - 10,916' Frac #1 w/429 bbl x-link gell and 6,500# 100 mesh--RAN OUT of crosslinker

3SPF 120 Deg. Frac # 2 wPrimefrac 30, 30% N2, 6,705# 100 mesh and 7,276# Econoprop - Screened out

11,206' - 11,208' 11,299' - 11,301'

11,216' - 11,218' 11,305' - 11,310' Frac w/1,826 bbl Primefrac 30 w/30% N2

11,238' - 11,240' 11,314' - 11,319' 6,899# 100 mesh and 175,962# 20-40 Econoprop

11,254' - 11,256' 11,323' - 11,328' Middle & Lower Almond test after frac 856mcf/d@240psi

2SPF 120 Deg.

11,401' - 11,409' 11,445' - 11,453' Frac Lower Almond w/1,160 bbl Primefrac-30 w/30% N2,

3 SPF 5,500# 100 mesh and 90,231 # 20-40 Econoprop

9' tubing, 2' bit sub and 3-7/8" bit pushed to 11,456'

PBTD 11,516'

FLOAT COL. 11,553'

SHOE 11,600'

TD 11,620'

Lower Lewis

Upper Lewis

Middle Almond

Lower Almond

Example Well “A”Wamsutter, Wyoming

Before Installation


4 1/2" , 11.6#, HCP-110 set at 11,600' w/1,930 sx

2 3/8" , 4.7#, N-80 Tubing - 334 Joints

10,746' - 10,752' 10,810' - 10,818' Frac w/1486 bbl Primefrac 30 w/30% N2

10,756' - 10,762' 3SPF 120 Deg. 6,077# 100 mesh and 116,847 # 20-40 Econoprop

Upper & Lower Lewis tested after frac 550mcf/d@150psi

10,878' - 10,881' 10,908' - 10,916' Frac #1 w/429 bbl x-link gell and 6,500# 100 mesh--RAN OUT of crosslinker

3SPF 120 Deg. Frac # 2 wPrimefrac 30, 30% N2, 6,705# 100 mesh and 7,276# Econoprop - Screened out

11,206' - 11,208' 11,299' - 11,301'

11,216' - 11,218' 11,305' - 11,310' Frac w/1,826 bbl Primefrac 30 w/30% N2

11,238' - 11,240' 11,314' - 11,319' 6,899# 100 mesh and 175,962# 20-40 Econoprop

11,254' - 11,256' 11,323' - 11,328' Middle & Lower Almond test after frac 856mcf/d@240psi

2SPF 120 Deg.

11,401' - 11,409' 11,445' - 11,453' Frac Lower Almond w/1,160 bbl Primefrac-30 w/30% N2,

3 SPF 5,500# 100 mesh and 90,231 # 20-40 Econoprop

End of 2 3/8" Tubing --10,709.5' -- 334 Joints

End of Weatherford Assembly -- 10722.8'

Weatherford Assembly

- 2 3/8" Heavy Duty Perforated Flow Sub -- 4.8' -- 36 3/4" holes

- X-Nipple - 1.87" Profile - 1.0'

- 2 3/8" CM1CI -- 4.5'

- XN-Nipple -- 1.0'

- 2 3/8" Sheer out safetly joint - Set at 27,000# - 0.8'

- Crossover -- 1.2'

End of 2 7/8" Dead String -- 11349.2'

9' tubing, 2' bit sub and 3-7/8" bit pushed to 11,456'

PBTD 11,516'

FLOAT COL. 11,553'

SHOE 11,600'

TD 11,620'

Lower Lewis

Upper Lewis

Middle Almond

Lower Almond


After Installation

NOT TO SCALE-

End of 2 3/8” Tubing @ 10,709’

End of 2 7/8” Dead String @ 11,349’

650’ of 2 7/8” UFJ


CUSTOMER:CUSTOMER:CUSTOMER:CUSTOMER:COMPANY REP:COMPANY REP:COMPANY REP:COMPANY REP:WCS REP:WCS REP:WCS REP:WCS REP:LEASE:LEASE:LEASE:LEASE:WELL NAME AND NUMBER:WELL NAME AND NUMBER:WELL NAME AND NUMBER:WELL NAME AND NUMBER:CASING SIZE AND WEIGHT:CASING SIZE AND WEIGHT:CASING SIZE AND WEIGHT:CASING SIZE AND WEIGHT:LINER SIZE AND WEIGHT:LINER SIZE AND WEIGHT:LINER SIZE AND WEIGHT:LINER SIZE AND WEIGHT:TUBING SIZE AND WEIGHT:TUBING SIZE AND WEIGHT:TUBING SIZE AND WEIGHT:TUBING SIZE AND WEIGHT:DEAD STRING SIZE AND WEIGHT: DEAD STRING SIZE AND WEIGHT: DEAD STRING SIZE AND WEIGHT: DEAD STRING SIZE AND WEIGHT: STATE:STATE:STATE:STATE:COUNTY:COUNTY:COUNTY:COUNTY:

DATE:DATE:DATE:DATE:

ITEMITEMITEMITEM DEPTH

AAAA

B 10,709.50'

C 10,714.30'

D 10,715.30'

E 10,719.80'

F 10,720.80'

G 10,721.60'

H 10,722.80'

I 11,349.20'

650' of 2 7/8" Ultra Flush Joint Tubing

2 3/8" EUE X 2 7/8" X-Over Sub

2 7/8" "Dead String"

4 1/2" 11.6# HCP-1104 1/2" 11.6# HCP-1104 1/2" 11.6# HCP-1104 1/2" 11.6# HCP-110

2 3/8" Mechanical Shear Out Safety

Example Well "B"Example Well "B"Example Well "B"Example Well "B"Wamsutter, WyomingWamsutter, WyomingWamsutter, WyomingWamsutter, WyomingScott CampbellScott CampbellScott CampbellScott Campbell

N/AN/AN/AN/A2 3/8" 4.7# N-802 3/8" 4.7# N-802 3/8" 4.7# N-802 3/8" 4.7# N-80

1/4" Stainless Steel Chemical Injection

Tubing 10,719' Installed

2 7/8" Ultra Flush Joint2 7/8" Ultra Flush Joint2 7/8" Ultra Flush Joint2 7/8" Ultra Flush JointWyomingWyomingWyomingWyomingSweetwaterSweetwaterSweetwaterSweetwater

2 3/8" 4.7# N-80 Production Tubing

2 3/8" X 1.875" WX Profile Nipple With

"XX" Blanking Plug In Place

2 3/8" "CM-1 CI" Chemical Injection Sub

Joint

2 3/8" X 1.875" WXN Nipple

2 3/8" Heavy Duty Perforated Flow Sub

Low er

Almond

11,401'

11,453'

Middle

Almond

11,206'

11,328'

Lower

Lewis

10,878'

10,916'

Upper

Lewis

10,746'

10,762'

A

B

C

D

E

F

G

H

I

PBTD 11,516.00'



Wamsutter, Wyoming WCVR Install

0

100

200

300

400

500

600

700

800

900

1000

1100

1200

1300

1400

1500

1600

1-Sep-0

515-S

ep-05

1-Oct-

0515 -O

ct-0

5

1-Nov-0

515-N

ov-05

1-Dec-0

515-D

ec-05

1-Jan -0

615-Ja

n-06

1-Feb-0

615-F

eb-06

1-Mar-0

615 -M

ar-06

1-Apr-0

615-A

pr-06

1-May-

0615 -M

ay-06

1-Jun-0

611-Ju

n-06

Date

Pro

du

cti

on

Gas Casing Line

Foamer and plunger

WCVR InstallNatural Flow

Compressor Problems

Foamer Only


Example Well B


Example Well C


Example Well D


Example Well D


Example Well E


WCVR Presentation Summary

• The WCVR System is specifically designed for Extended

Perforation Interval Liquid Loading Gas Wells

• The WCVR System is a creative combination of three

generally accepted methods used to combat liquid loading in

gas wells; area reduction, foamer, plunger lift

• As of this presentation, over 130 WCVR’s have been installed


Scott Campbell - Rocky Mountain Sales Manager

720-946-1365 Denver, Colorado Office

CVR SystemCritical Velocity Reduction

Combination of Dead Strings, Capillary Injection Foamer and Plunger Lift

Thank You!

Any Questions?

Documents

23 Critical velocity reduction system for LL gas wells ... · PDF fileScott Campbell - Rocky Mountain Sales Manager 720-946-1365- Denver Office CVR System Critical Velocity Reduction