James Wagener Presentation

Transcription

East Texas SPE Meeting
James Wagener – Weatherford ALS Sales
10-11-11
© 2006 Weatherford. All rights reserved.
Austin, Texas & Beyond
Source:
IHS
MS Streets
& Trips
Rob
SuttonMarathon
2
U.S. Gas Well Production
U.S. Historical Gas Well Facts
70,000
700
Well Count
Avg Daily Production, MMCFD
60,000
Avg Well Rate
600
50,000
500
40,000
400
30,000
300
20,000
200
10,000
100
Source:
IHS
Rob
Sutton© 2006 Weatherford. All rights reserved.
Marathon
0
1965
1970
1975
1980
1985
3
1990
1995
2000
2005
0
2010
Well Count, 000's or Avg Gas Rate, MCFD/Well
Production
What is Deliquification?
“Gas Well Deliquification, also referred to as
“ Gas Well Dewatering”, is the general term for
technologies used to remove water or condensate
build-up from producing gas wells.”
Dr. James (Jim) Lea
History of a Gas Well – Loss of Velocity Over Time
Stable Flow
Surface Condition
Unstable Flow
Stable Flow
Initial
Production
RATE
Well
Dead
Decreasing Gas Rate with Decreasing Reservoir Pressure
COP Slide
5
TIME
Liquid Loading: Coleman Equation
Lower pressures P < 1,000 psi
Vc = 1.593
σ1/4(ρLiquid-ρGas)1/4
ρGas1/2
Standard Assumptions that “Simplify” Turner
Equation:
Water Droplet
Gravity
•
•
•
•
•
•
60 dynes/cm surface tension for water
20 dynes/cm surface tension for condensate
67 lbm/ft3 water density
45 lbm/ft3 condensate density
0.6 gas gravity
120 of gas temperature
“Simplified” Turner Equation:
(ρLiquid-0.0031p)1/4
Vc = C
Gas Flow
(0.0031p)1/2
C = 5.321, water C= 4.043, condensate, p>=1,000 psi.
6
Critical Velocity to Critical Flow Rate
“Critical Flow Rate” can be calculated once we have “Critical Velocity”
3.06PVcA
Tz
Q(MMCFPD) =
P
Vc
A
T
Z
Flowing Tubing Pressure
Critical Velocity
X-Area Tubular Flow Path
Flowing Temp oR
Z Factor
Critical Flow Rate Equation
Critical Flow rate is the flowing gas rate (volume) necessary
to maintain Critical Velocity
7
Critical Flow Rates
4000
3500
1.00"/0.826"
1.25"/1.076"
3000
1.50"/1.310"
2.0"/1.78"
1.90/1.61
Flo w Rate
2500
2 1/16"/1.75
2 3/8"/1.995
2000
2 7/8"/2.441
3.5"/2.867
4.5 11.6 lb/ft
1500
5.5 20 lb/ft
7.0" 26 lb./ft
4.5" Casing w / 2 3/8" Tubing
1000
500
0
0
100
200
300
400
500
600
700
Wellhead Pressure
8
800
900
1000
Your Operators / Clients Might Tell You……..
• “My Production Dropped Below the Decline Curve”
• “This Well Can Flow for Several Days, Then it Dies”
• “This Well Comes Right Back After Dropping Soap Sticks”
• “I Have to Swab This Well After Unexpected Shut Downs”
• “My Casing and Tubing Pressures Fluctuate Daily”
• “The Production on This Well is Very Inconsistent”
• “My Well is NOT Loaded, It Does Not Make ANY Water”
9
Plunger Lift Overview
Solar Panel
Controller
Lubricator
Catcher
Usually Your First Choice for a Gas Well
Lowest Cost Solution
Uses Well’s Own Energy to Lift Liquids
Specifically Designed for Dewatering Gas Wells
Ideal for Isolated Areas
Dual “T” Pad
Plunger
Bumper
Spring
Goals of the System
Remove Accumulated Liquids
Lowest Possible 24 Hour Average Bottom Hole Pressure
Optimize on Gas Production (usually)
Plunger Lift Animation Video
Plunger Lift
Lifting fluid with
compressed gas
to drive a free
piston (plunger)
from the bottom of
the tubing string to
the surface.
12
Plunger Types
RapidFlo Plungers
Spiral
RapidFlo
Brush
RapidFlo
Padded
RapidFlo
• No or Reduced Off Time
• Fall Through Flow
• Higher Gas Velocities Needed
Conventional Plungers
Pad x Pad
Spiral
Brush
• Minimum Off Time Required Based on Depth
• Can Not Fall Through Flow
• Differential Pressure Required
Conventional Plungers
TYPE
Pad
Brush
Solid Ring
CHARACTERISTICS
APPLICATIONS
High efficiency, even after
cycling for months
Very low solid movement
(sand, scale)
Metal/metal seal
Maximum seal necessary to
move liquid
Fiber seal
Sand movement
Initially efficient seal
Some cases necessary for
efficiency
Turbulent seal
Scales application
Least-efficient seal
Dry-trip potential
Poor monitoring in field
(no moving parts)
14
14
Plunger Lift in Deviated Wells
• > 8” Length
– 4°/100 ft.
– 40° of total deviation
• < 8” Length
– 5.5°/100 ft
– 55° of total deviation
• Types of plungers for deviated wells
– Padded
– Solid Spiral
– RapidFlo
Good Candidate Selection
• Well is slugging.
• Well is shut in for a period of time to build up and unload.
• Having to blow well to the tanks.
• Well has a GLR of 500 scf / bbl / 1000’
– Well is making 100 mcfd, 10 bfpd, at 10,000’
• 100 000 scf/day / 10 bbls / 10 = 1000 scf/bbl/1000
feet and a likely candidate
Capillary Technologies
….The Latest Liquid Loading Solution from Weatherford…
Weatherford’s Cap Tech Equipment…
The most advanced in the industry
General Overview of a Capillary Install
Capillary
Hanger
Capillary
Injection
String
CC1-A
Chemical
Injection
Valve
Chemical Inj.
Manifold
Chemical
Pump
Chemical Tank
The capillary string system is snubbed into the well under live flowing
conditions with a capillary coiled tubing unit connected to a chemical
tank and pump on the surface, and left as a conduit for precision
chemical application.
• CC1-A valve: custom pressure adjusted to well conditions and only
permits chemical injection with a positive stroke on the surface with the
chemical injection pump.
• Capillary String: usually stainless steel alloys in either ¼” or 3/8” OD.
The 3 main alloys applied are Alloy 825, Alloy 625, and Super Duplex
2205. These are usually always annealed to a yield strength exceeding
90,000 psi. There is usually 50-100 ft. excess left on the surface for
facilitation and versatility with future well intervention.
• Capillary Hanger: mechanically holds the cap string in place,
hydraulically seals the cap string in the flow path so that no production is
vented or spilled on the ground.
• Chemical Injection Manifold: provides connection / pressure monitoring
for the injected chemical from the chemical pump.
Capillary and Chemical Applications
• Liquid Loading
• Corrosion Control
• Scale Control
• Salt Control
• Paraffin Control
• H2S Control
• Combination Products
Capillary Injection is a
Chemical Delivery System
USE OF CAPILLARY INJECTION STRING TO
UNLOAD GAS WELL
Capillary Injection String
*The principle benefit of foam as a gas-well
deliquefication method is that liquid is held in the
bubble film and exposed to more surface area,
resulting in less gas slippage and a low-density
mixture (Brown)
Formation
Range of Application for “Foam” Lift
“Rule of Thumb” – Reduces Fc by factor of +/- 3
Gas W ell De-Liquification
C ritical Flow R ate
2-3/8" T B G
1,000
900
800
Gas Rate (MCFD)
700
"C RITIC AL R E G IO N" W ATE R
600
500
400
"C RITICAL RE G IO N " FO AM
300
200
BE LO W "C RITICAL R E G IO N "
100
-
100
200
300
400
500
F tp (psi)
600
700
800
900
1,000
Corrosion & Metallurgy
Which metallurgy is appropriate?
Standard Metallurgies
Duplex 2205 (Low chlorides, low pH, Low temps)
Duplex 2507 (Low chlorides, low pH, Low temps)
Alloy 825 (higher chlorides, low pH, higher temps)
Alloy 625 (high chlorides, higher pH high temps)
• Considerations
– Partial pressures of H2S & CO2
– Chlorides, temperature, pH
– Depth
22
Capillary Injection String Considerations
Typical Range
Operating
Depth
2,000 --10,000’ TVD
18,000’ TVD*
Operating
Volume
5 - 100 BPD
Depends on well
Operating
Temperature
250 - 350° F
450° F
70 °
<12°/100’
Build Angle
90°
Wellbore
Deviation
<12°/100’
Build Angle
Corrosion Handling
Excellent
Gas Handling
Excellent
Solids Handling
Fair to Good
Application
*Depends on treatment needed
Servicing
Workover or Capillary Unit
Prime Mover Type
Offshore Application
Maximum*
Wells own energy
Good
Horizontal and Extended Perforation Wells
• CVR System
• iCVR System
• Xtra Lift Gas Lift
Extended Perforation Completion Challenges
• Production String: 2-3/8”, 4.7 lb/ft
2 3/8”
tubing
• Casing: 4-1/2”, 11.6 lb.ft
2 3/8”
tubing
4 ½” casing
– 4.000-in. ID
– Flow area: 12.5683 in.2
Critical Flow Requirement:
Extended
perforation
interval
200-psi WHBP(FTP):
CFR for 2-3/8” = 406 mcf/d
CFR for 4-1/2” = 1.63 MMcf/d
25
Dead String Application
2 3/8”
tubing
• Dead String: 2 7/8” Flush Joint
4 ½” casing
• Casing: 4-1/2”
– Flow Area: 12.5683 in.2
2 3/8” Flow Sub
• Annular flow area, 2-7/8” inside 4-1/2”
– Flow Area: 6.0768 in.2
2 3/8” WXN
Plug
Critical Flow Requirement @ 200-psi WHBP:
CFR for 2-3/8” = 406 mcf/d
2 7/8” Tubing
“Dead String”
CFR for 4-1/2” x 2 7/8” Annulus = 790 mcf/d
CFR for 4 -½” = 1.63 mmcfd
26
WCVR System:
Area Reduction, Foam Injection and Plunger Lift
¼” Capillary Injection
String
Critical Flow Requirement @ 200-psi WHBP:
2 3/8” = 406 mcf/d
Flow Sub
2 3/8” = 168 mcf/d with foam
4 ½” Casing = 1.63 Mmcf/d
4 ½” x 2 7/8” annulus = 790 mcf/d
WXN Retrev. Plug
4 ½” x 2 7/8” annulus = 327 mcf/d FOAM
Injection Mandrel
Dead String
Patent
# Weatherford.
US 7,409,998
B2
© 2006
All rights reserved.
27
THREE ARTIFICIAL LIFT SYSTEMS WORKING TOGETHER:
– Area Reduction (Dead String)
– Surface Tension and Density Reduction (Foamer)
– Plunger Lift (Mechanical Interface)
• Due to the cyclic nature of conventional plunger lift
operations, the well will require shut in for build up, then
cycled on achieving high instantaneous flow rate allowing the
well to unload in the perforated intervals around the dead
string.
Patent # US 7,409,998 B2
Perforation
Interval
28
iCVR+ System Overview
• Internally Installed Capillary Tubing
• Allows for Snubbing Complete Installation
• Single Trip System:
– Lands in Open Tubing
Or
– Lands in WX or WXN Nipple
• Built-In Pressure Equalization Features
• Capable of Hanging up to 4,000’ of
Capillary Tubing Below the Cap-Connect
Tool.
Patent
# US 7,409,998 B2
29
Extended Perforation Interval Lift Options
CVR
iCVR+
XtraLift
30
Design Input Parameters
31
XtraLift Extended Perforation Interval Gas Lift Option
Results From Crossover Packer Application
On gas lift
300 MCF/day
300 MCF/day
Loaded Up
50 - 100 MCF/day
33
Results From Crossover Packer Application
On gas lift
Loaded Up
200 MCF/day
50 - 100 MCF/day
34
Production Results- CVR Installation
Redefine the Decline Curve!
35
Unique Applications of Capillary
iCVR+ Capillary Injection Tool / Area Reduction
Barnett Shale
2 3/8” tubing
Perforated sub
3/8” capillary
Injection
valve
Model R Packer
iCVR+ Tool
37
Perforated sub
(bull plugged)
iCVR Capillary Injection + Velocity String
Barnett Shale
Results
• Gas production stabilized
• Water unloading rate doubled
• Discontinued gas lift compression
38
iCVR Capillary Foam Lift
Barnett Shale
Before
After
(Gas Lift)
(iCVR Capillary Foam)
50%
Production
Increase
82%
200 MCFPD
10 BWPD
OPEX
Decrease
Compression = $5000/mo
300 MCFPD
20 BWPD
Chemical = $900/mo
39
Plunger Lift Foam / Corrosion Options
Many Lift Options Available
Reciprocating Rod Pump Options
Corrosion / Solids Control
Sucker Rods
Production Enhancement
Chemicals Include:
Packer Optional
Fresh Water – Salt / Solids
Corrosion Inhibitor
H2S Scavenger
Foamer
Steam
Tubing Anchor
Plunger
Bumper
Spring
Injection Sub
Insert Recip
Pump
Injection Sub
Standing Valve
Tubing Anchor
The Trico R Hydraulic Anchor
– Ability to pass ¼” Capillary
Injection String around the
slips / dogs
Any Questions?

James Wagener Presentation

Transcription

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