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Acoustic Liquid- -Level Determination of Level Determination of - - PowerPoint PPT Presentation

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Gas Well De-Liquification Workshop Adams Mark Hotel, Denver, Colorado March 5 - 7, 2007 Acoustic Liquid- -Level Determination of Level Determination of Acoustic Liquid Gradients and BHP in Flowing Gas Wells Gradients and BHP in Flowing Gas

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SLIDE 1

Gas Well De-Liquification Workshop

Adams Mark Hotel, Denver, Colorado March 5 - 7, 2007

Acoustic Liquid Acoustic Liquid-

  • Level Determination of

Level Determination of Gradients and BHP in Flowing Gas Wells Gradients and BHP in Flowing Gas Wells

  • O. Lynn Rowlan
  • O. Lynn Rowlan –

– Echometer Company Echometer Company

  • A. L. Podio
  • A. L. Podio –

– University of Texas at Austin University of Texas at Austin James N. McCoy James N. McCoy – – Echometer Company Echometer Company http://www.nitrolifttechnologies.com/

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SLIDE 2
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 2

Introduction Introduction

1. 1.

Many Studies done on Critical Rates and Gradients Many Studies done on Critical Rates and Gradients

2. 2.

Flow Regime Maps, Critical Velocity Curves, and S Flow Regime Maps, Critical Velocity Curves, and S-

  • Curves all Relate to Gas & Liquid Flow Rates

Curves all Relate to Gas & Liquid Flow Rates

3. 3.

Acoustic Measurement of Mist Gradients Possible Acoustic Measurement of Mist Gradients Possible When Well Flowing Above Critical Rate. When Well Flowing Above Critical Rate.

4. 4.

Gradients Below the Liquid Level is a Function of Gradients Below the Liquid Level is a Function of the Gas Flow Rate in Liquid Loaded Wells the Gas Flow Rate in Liquid Loaded Wells

5. 5.

Field Developed Correlation Determines Gradient Field Developed Correlation Determines Gradient Below the Liquid Level in Liquid Loaded Wells Below the Liquid Level in Liquid Loaded Wells

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SLIDE 3
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 3

Critical Gas Velocity Occurs at

Instability Point on Tubing Capacity Curves

Critical Gas Velocity Occurs at

Instability Point on Tubing Capacity Curves

Drag from flowing gas tending to lift the droplet Drag from flowing gas tending to lift the droplet Buoyant weight of droplet in suspended gas Buoyant weight of droplet in suspended gas Liquid droplet suspended in flowing gas Liquid droplet suspended in flowing gas

R a te Pressure I n flo w O u tflo w

Flowing Gas Rate

Tubing Parameters GLR

Inflow Gas Well

Qg < Qc Qg < Qc VSL = 0 VSL = 0 Qg > Qc Qg > Qc Instability Instability Loaded Loaded Can Can Flow Flow

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SLIDE 4
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 4

If Well Flow Rate Exceeds Minimum Critical If Well Flow Rate Exceeds Minimum Critical Velocity, then No Liquid Loading Predicted Velocity, then No Liquid Loading Predicted

Gas Velocity Gas Velocity Removes Liquid Removes Liquid Liquid Loading Liquid Loading Predicted Predicted Qg > Qc Qg > Qc Qg < Qc Qg < Qc

Loaded Gradient ~ 0.08 psi/ft

Flowing Pressure (Psia) Flowing Pressure (Psia)

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SLIDE 5
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 5

Depth & Liquid Rate Depth & Liquid Rate

Guo Guo, B.: , B.: “ “A Systematic Approach to Predicting Liquid A Systematic Approach to Predicting Liquid Loading in Gas Wells Loading in Gas Wells“ “, SPE94081 POS 04/17/05 , SPE94081 POS 04/17/05

Well Depth and Liquid Well Depth and Liquid Production Rate May Production Rate May Impact Critical Rate Impact Critical Rate

1.

  • 1. Coleman 20% Adjustment

Coleman 20% Adjustment to Turner Under Predicts to Turner Under Predicts Critical Rate Critical Rate 2.

  • 2. Bottomhole

Bottomhole Conditions Conditions Control Critical Rate Control Critical Rate 3.

  • 3. Liquid Flow Rate NOT

Liquid Flow Rate NOT Considered in Critical Q? Considered in Critical Q?

V VSG

SG > 10

> 10 V VSL

SL

= = MscfD MscfD

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SLIDE 6
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 6

Range of Gradients in a Gas Well Range of Gradients in a Gas Well

Qg = 0 Qg = 0 Qg < Qc Qg < Qc

2.375 2.375” ” Tubing, 0.7 Tubing, 0.7-

  • SG Gas, 300 Psia Wellhead Pres

SG Gas, 300 Psia Wellhead Pres

0.08 psi/ft

Qg > Qc Qg > Qc

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SLIDE 7
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 7

Coleman ”Liquid Removed from the Well when Qgas Exceeds Qcritical, Loading Occurs when Qg<Qc”

SPE20801 " Understanding Gas Well Load up Behavior" S. B. Colema SPE20801 " Understanding Gas Well Load up Behavior" S. B. Coleman n JPT, March 1991 JPT, March 1991

Qg = 0 Qg = 0 Qg < Qc Qg < Qc Qg > Qc Qg > Qc

Gas Gradient >0.02 psi/ft Loaded Gradient 0.08 to 0.04 psi/ft

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SLIDE 8
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 8

Flow Pattern Map Flow Pattern Map

Govier Govier G.W. and G.W. and Aziz Aziz, K: "The Flow of Complex Mixtures in , K: "The Flow of Complex Mixtures in Pipes" Robert E. Pipes" Robert E. Drieger Drieger Publishing Co. Huntington, N. Y. Publishing Co. Huntington, N. Y. 1977 1977

Gas Velocity Impacts Gas Velocity Impacts Flow Regime Flow Regime 1.

  • 1. Below Critical Velocity:

Below Critical Velocity:

  • V

VSL

SL= 0

= 0

  • Liquid Stays in Well

Liquid Stays in Well 2.

  • 2. Above Critical Velocity:

Above Critical Velocity:

  • VSG > 10 ft/sec

VSG > 10 ft/sec

  • High Gas Velocity

High Gas Velocity Well Lifts Liquid Out Well Lifts Liquid Out

V VSG

SG > 10

> 10 V VSL

SL

= = Qg < Qc Qg < Qc

0.08 psi/ft 0.433 psi/ft 0.018 psi/ft

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SLIDE 9
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 9

Echometer S-Curve Q/A = Velocity @ P&T Determines Gaseous Liquid Loaded Column Gradient Below Liquid Level Qg < Qc VSL = 0 Echometer Echometer S S-

  • Curve

Curve Q/A = Velocity Q/A = Velocity @ P&T @ P&T Determines Determines Gaseous Gaseous Liquid Loaded Liquid Loaded Column Column Gradient Gradient Below Below Liquid Level Liquid Level Qg Qg < Qc < Qc V VSL

SL = 0

= 0

Actual Field Collected Data Points V VSL

SL = 0

= 0 Loaded Loaded Qg Qg < Qc < Qc

0.08 psi/ft 0.433 psi/ft

Mist { Mist {Qg Qg > Qc} > Qc}

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SLIDE 10
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 10

Physical set-up on a Gas Well

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SLIDE 11
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 11

Fluid Level

  • n Gas Well

Fluid Level

  • n Gas Well

Gas Velocity Impacts Result of Gas Velocity Impacts Result of Acoustic Liquid Level Shot: Acoustic Liquid Level Shot: 1.

  • 1. Below Critical Velocity:

Below Critical Velocity:

  • Usually see liquid level

Usually see liquid level above bottom of Tubing above bottom of Tubing 2.

  • 2. Above Critical Velocity:

Above Critical Velocity:

  • May not see a liquid level

May not see a liquid level because liquid droplets because liquid droplets may fill tubing and absorb may fill tubing and absorb all energy from shot all energy from shot

  • May see bottom of tubing

May see bottom of tubing and/or perforations due to and/or perforations due to small amount of liquid small amount of liquid

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SLIDE 12
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 12

1) 1) Liquid Liquid being produced with the gas being produced with the gas

  • r condensing due to temperature
  • r condensing due to temperature

and pressure changes is and pressure changes is uniformly uniformly distributed in the wellbore distributed in the wellbore. . 2) 2) Gas velocity is sufficient to Gas velocity is sufficient to continuously carry continuously carry liquid as a fine liquid as a fine mist mist or small droplets to the surface

  • r small droplets to the surface

(Above Critical). (Above Critical). 3) 3) Gas velocity is Gas velocity is sufficient to sufficient to establish a relatively low and establish a relatively low and fairly fairly uniform flowing pressure gradient uniform flowing pressure gradient. .

Mist { Mist {Qg Qg > Qc} (High Gas Velocity) > Qc} (High Gas Velocity)

Imagine a fine mist cloud in Tubing Imagine a fine mist cloud in Tubing

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SLIDE 13
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 13

Procedure for Acquisition Procedure for Acquisition

  • Stop flow at the Surface
  • Acquire Fluid Level Measurement
  • Observe the depression of the gas/liquid interface

and the increase in wellhead pressure.

  • Acquire Multiple Fluid Level Shots
  • Measurements should be taken (preferably at

constant time intervals of about 3-5 minutes)

  • Use pressure at the gas/liquid interface to establish

the gaseous column gradient

  • Extrapolate the PBHP
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SLIDE 14
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 14

Fluid Level Measurements After Shut Fluid Level Measurements After Shut-

  • in

in

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 Sec 316.2 mV 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 Sec 316.2 mV 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 Sec 316.2 mV 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 Sec 316.2 mV 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 Sec 100.0 mV 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 Sec 100.0 mV

Fluid level below tubing Fluid level below tubing

Multi Multi-

  • Shots Down Tubing

Shots Down Tubing Mist { Mist {Qg Qg > Qc} > Qc}

(High Gas Velocity) (High Gas Velocity)

Shots taken at approximate 5 minute intervals Shots taken at approximate 5 minute intervals Should see Mist Gradient below Fluid Level Should see Mist Gradient below Fluid Level

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SLIDE 15
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 15

Tubing Head Pressure Increased at Constant 1.72 Psi/Min Rate During Time Acoustic Surveys were Acquired

Type 1 Flowing Gas Well

psi = 1.7217*min + 643.23 R2 = 0.9978

640 650 660 670 680 690 700 0.00 5.00 10.00 15.00 20.00 25.00 30.00 35.00

Time, minutes Tubing Pressure, psi

Mist { Mist {Qg Qg > Qc} (High Gas Velocity) > Qc} (High Gas Velocity)

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SLIDE 16
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 16

Liquid Level Depth for Mist {Qg > Qc} Gas Well

Liquid Level vs. Time - Gas Well 34

1000 2000 3000 4000 5000 6000 7000 0.00 5.00 10.00 15.00 20.00 25.00 30.00 35.00

Time, minutes Gas/Liquid Interface Depth, feet

Fall Rate= 146 ft/min Fall Rate= 192 ft/min

Closed in Flow at Surface and Gas/mist Interface was Closed in Flow at Surface and Gas/mist Interface was pushed down the tubing (Speed varied between 146 and 192 ft/min) pushed down the tubing (Speed varied between 146 and 192 ft/min). .

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SLIDE 17
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 17

Use of Gas/Liquid Interface Depression Test

Gaseous Column Height vs. Pressure from Fluid Level Data Gas Well 34 Regression Equation Column Height = -33.968*Pressure + 27293

500 1000 1500 2000 2500 3000 3500 4000 4500 660.0 680.0 700.0 720.0 740.0 760.0 780.0 800.0 820.0

Gas/Liquid Interface Pressure, psi Height of Gaseous Liquid Column, feet

Gaseous Column Gradient = 0.029 psi/ft PBHP = 804 psi

Mist { Mist {Qg Qg > Qc} (High Gas Velocity) > Qc} (High Gas Velocity)

1) 1) Dry Gas Gradient Above Liquid Level = 0.0179 psi/ft Dry Gas Gradient Above Liquid Level = 0.0179 psi/ft 2) 2) Mist Gradient Below Liquid Level = 0.029 psi/ft (6% Liquid) Mist Gradient Below Liquid Level = 0.029 psi/ft (6% Liquid) 3) 3) Producing BHP is Extrapolated to = 804 psi Producing BHP is Extrapolated to = 804 psi

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SLIDE 18
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 18

1) 1) Gas velocity is not HIGH enough to lift Gas velocity is not HIGH enough to lift liquids to the surface (Below critical) liquids to the surface (Below critical) 2) 2) Liquid accumulates in bottom of well. Liquid accumulates in bottom of well. 3) 3) Flowing pressure gradient shows: Flowing pressure gradient shows:

  • Light gradient above gas/liquid

Light gradient above gas/liquid interface (close to gradient of interface (close to gradient of flowing gas) flowing gas)

  • Heavier gradient below Liquid Level.

Heavier gradient below Liquid Level. 4) 4) Below Liquid Level (zero net liquid flow) Below Liquid Level (zero net liquid flow) with gas bubbles or slugs percolating with gas bubbles or slugs percolating through the liquid through the liquid 5) 5) As the gas rate decreases, the As the gas rate decreases, the concentration of liquid at the bottom of concentration of liquid at the bottom of the well increases. the well increases.

Liquid Loaded Gas Well (V Liquid Loaded Gas Well (VSL

SL = 0 &

= 0 & Qg Qg < Qc) < Qc)

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SLIDE 19
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 19

Acoustic Fluid Level Survey in a Well Loaded With Liquid Acoustic Fluid Level Survey in a Well Loaded With Liquid

Depth

Gas Gradient Above Fluid Level Gaseous Liquid Gradient Below Gas Bubbles or Slugs Move up through Liquid Column Fluid Level

(VSL = 0 (VSL = 0 Qg Qg < Qc) < Qc)

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SLIDE 20
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 20

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 Sec 100.0 mV

Concurrently Shot Fluid Levels & Ran Bomb

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 Sec 100.0 mV 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 Sec 100.0 mV

Before Running Tools Before Running Tools Gas/Liquid Interface = 3626 Gas/Liquid Interface = 3626’ ’ Tools at 2500 ft Tools at 2500 ft Gas/Liquid Interface = 3332 Gas/Liquid Interface = 3332’ ’ Tools at 5000 ft Tools at 5000 ft Gas/Liquid Interface = 3165 Gas/Liquid Interface = 3165’ ’ Acoustic Velocity Determined from Tubing Collar Recess Echoes Ve Acoustic Velocity Determined from Tubing Collar Recess Echoes Very ry Similar to the Acoustic Velocity Determined From Echo at Top of Similar to the Acoustic Velocity Determined From Echo at Top of Tool Tool

Acoustic Velocity Determined Acoustic Velocity Determined From Echo at Top of Tool From Echo at Top of Tool

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SLIDE 21
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 21

Gradient Stop Pressures from W ireline Gage

200 220 240 260 280 300 320 12.9 13 13.1 13.2 13.3 13.4 13.5 13.6 Time Pressure, psi Tool @ 7000 ft Tool @ 6000 ft

Average = 224.88 psi Average = 303.8 psi

Average pressures Gradient = 0.0782 psi/ft Gradients of individual samples = 0.07776 psi/ft Maximum computed gradient = 0.09292 psi/ft Minimum computed gradient = 0.06816 psi/ft

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SLIDE 22
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 22

Average Pressure Gradients Above Tool Change as Wireline Tool Lowered Into Well

BMT 35 - Pressure-Depth Traverse Before Shut-in

1000 2000 3000 4000 5000 6000 7000 8000 50 100 150 200 250 300 350

Presssure, Psi Depth Feet

Shot #1 @ 09:16:55 FL(3753) NO Tool Shot #3 @ 10:30:41 FL(3204) Tool(5000) Shot #4 @ 10:50:06 FL(2575) Tool(6000) Shot #5 @ 11:09:12 FL(2316) Tool(7000) Shot #6 @ 11:25:08 FL(2434) Tool(7150) Average Gradient Line Below Tool

Average Gradient Above the Tool 0.0501 psi/ft Average Gradient Below the Tool 0.0719 psi/ft

Gas Gradient Above Liquid Level 0.00184 psi/ft

Fluid Level Rise of Fluid Level Rise of 1218 1218’ ’ “ “Suggests Suggests” ” Conditions N Conditions Non

  • n-
  • Steady

Steady

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SLIDE 23
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 23

Variation in Depth of the Gas/Liquid Interface

Liquid Level Depth vs Time BMT35

1000 2000 3000 4000 5000 6000 7000

  • 150.000
  • 100.000
  • 50.000

0.000 50.000 100.000 150.000 200.000

Time, minutes Depth, feet Before disturbing wellbore Shut in wellhead valve Lowering Wireline Bomb

1) Before shutting in the Well 2) While the Tool was Being Run 3) During Pressure Buildup

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SLIDE 24
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 24

Sequential Acoustic Records During Shut-in

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 Sec 100.0 mV 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 Sec 100.0 mV 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 Sec 100.0 mV 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 Sec 100.0 mV 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 Sec 100.0 mV 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 Sec 100.0 mV

Shut-in 5 minutes Shut-in 10 minutes Shut-in 15 minutes Shut-in 20 minutes Shut Shut-

  • in 30 minutes

in 30 minutes Gas/liquid interface dropped from 2392 to 6523 feet (4131 ft in Gas/liquid interface dropped from 2392 to 6523 feet (4131 ft in 24.5 min.) 24.5 min.) LL=2392 LL=2926 LL=3632 LL=4233 LL=4967 LL=6148

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SLIDE 25
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 25

After Shut-in Surface & BH Pressures Build as Gaseous Liquid Column Collapses

BMT 35 Pressure-Depth Traverses After Shut-in

1000 2000 3000 4000 5000 6000 7000 8000 50 100 150 200 250 300 350 400 450

Pressure, psi Depth, ft

Shut-in 1 Shut-in 2 Shut-in 3 Shut-in 4 Shut-in 5 Shut-in 6 Shut-in 7 Shut-in 8 Shut-in 9 Shut-in 14

Gas Gaseous Column Pressure at 7150 ft

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SLIDE 26
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 26

1) 1) Initial Acoustic Fluid Levels Most Initial Acoustic Fluid Levels Most Accurate in Determining Flowing BHP Accurate in Determining Flowing BHP 2) 2) Echometer Annular S Echometer Annular S-

  • curve:

curve:

  • Developed Using Field Measurements

Developed Using Field Measurements

  • Use Down Tubing When Stabilized

Use Down Tubing When Stabilized Liquid Loaded Conditions Exist Liquid Loaded Conditions Exist

  • Does Not Calculate the Correct

Does Not Calculate the Correct Gaseous Column Gradient After the Gaseous Column Gradient After the Valve Is Closed for an Extended Period Valve Is Closed for an Extended Period

  • f Time.
  • f Time.

Liquid Loaded Gas Well (VSL = 0 & Liquid Loaded Gas Well (VSL = 0 & Qg Qg < Qc) < Qc)

Wells Flowing Below Critical Rate: Wells Flowing Below Critical Rate:

  • Light Gas on Top

Light Gas on Top

  • Uniform Stabilized Gaseous Liquid Gradient Exist

Uniform Stabilized Gaseous Liquid Gradient Exist Below Liquid Level Below Liquid Level

  • Liquid Accumulates in Bottom of Well.

Liquid Accumulates in Bottom of Well.

Conclusions: Conclusions:

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SLIDE 27
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 27

1) 1) After Well Is Shut After Well Is Shut-

  • in for a Period of Time:

in for a Period of Time:

  • Flow Regime in the Tubing Is

Flow Regime in the Tubing Is Disturbed Disturbed

  • Liquid Falls Back Toward the Bottom

Liquid Falls Back Toward the Bottom

  • f the Tubing.
  • f the Tubing.

2) 2) Acoustic Fluid Level Surveys Acquired Acoustic Fluid Level Surveys Acquired While the Liquid Is Falling May Result In: While the Liquid Is Falling May Result In:

  • Too Heavy of Gaseous Gradient

Too Heavy of Gaseous Gradient

  • Too High Flowing Bottom Hole.

Too High Flowing Bottom Hole. 3) 3) Shutting in the Well for Extended Period Shutting in the Well for Extended Period

  • f Time or Running a Wire Line:
  • f Time or Running a Wire Line:

1) 1) Disturbs the Flow Regime Disturbs the Flow Regime 2) 2) Can Result in Calculating Inaccurate Can Result in Calculating Inaccurate Bottom Hole Pressures from Fluid Bottom Hole Pressures from Fluid Levels Levels

Liquid Loaded Gas Well ( Liquid Loaded Gas Well (VSL = 0 &

VSL = 0 & Qg Qg < Qc < Qc)

)

Conclusions (Continued): Conclusions (Continued):

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SLIDE 28
  • Mar. 5 - 7, 2007

2007 Gas Well De-Liquification Workshop Denver, Colorado 28

Disclaimer

The following disclaimer may be included as the last page of a Technical Presentation

  • r Continuing Education Course. A similar disclaimer is included on the front page of

the Gas Well Deliquification Web Site.

The Gas Well Deliquification Steering Committee Members, the Supporting Organizations and their companies, the author(s) of this Technical Presentation or Continuing Education Course, and their company(ies), provide this presentation and/or training at the Gas Well Deliquification Workshop "as is" without any warranty of any kind, express or implied, as to the accuracy of the information or the products or services referred to by any presenter (in so far as such warranties may be excluded under any relevant law) and these members and their companies will not be liable for unlawful actions and any losses or damage that may result from use of any presentation as a consequence of any inaccuracies in, or any omission from, the information which therein may be contained.