gas-lift application on low pressure gas well with … · gas-lift application on low pressure gas...

Gas Well Deliquification WorkshopSheraton Hotel, Denver, Colorado

February 23 - 26, 2009

Gas-Lift Application on Low Pressure Gas Well with Solid Production ProblemsPeter Oyewole

Adesola Adegoke

Louis Vigil

Jason Jones

Feb. 23 - 26, 2009 2009 Gas Well Deliquification Workshop Denver, Colorado

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Outline

Historical background on a CBM Well Gas Lift Configuration Downhole Sensor Package (Cable-to-Surface) Case Study Real Time Data Capture Conclusion


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Why Gas Lift and CTS?

Liquid loading problems Pump failures due to coal fines sticking pumps Low reservoir pressures

Concerns about low Pwf & backpressure on the formation

Aid in removal of significant amounts of coal fines

Coal filters @ the inlet of separator

Installation of the gas lift requires real time monitoring and surveillance


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Prevent coal fines from clogging valve/orifices Minimize flowing bottom hole pressure

CBM reservoir requires very low flowing BHP to maximize production rates

Monitor Gas Lift System with downhole sensors.

obtain temperature and pressure measurements to optimize production and injection.

allows for performance evaluation

Completion Objectives


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Design Limitations/Requirements Pressure

– Surface Injection pressure available: Less than 300 PSI

– Static bottom hole pressure = Low (less than 200 psi)

– Flowing bottom hole pressure = As Low as possible

Wellbore Configuration– 5 ½”

15.5# Liner & 7”

Casing– Perf. Depth 2845’

–

3200’– Injection rates of 1500+ MCF/D may be required


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Completion and GL Design Interaction Annular flow GL design

prevents valve pluggingenables CTS application w/downhole sensorsgas injection through tubing wellbore fluid + injected gas produced up the annulus

Gas lift valve placement in the tubingOrifice valve w/check valve run deep into the perforations to

minimize formation backpressure & maximize productionDual Orifice valve setup to allow for high injection volumes with

less pressure + back up valve. IPO valve ( TRO =280#)

run above orifices as contingency + initial Well Kick Off

IM Mandrel


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Tubing size selection

2 3/8”

tubing inside of 5 1/2”

Liner & 2 7/8”

in 7”

casing with Bull plug

Annular flow will prevent coal fines from entering valves

Temperature/Pressure Monitor

Measure pressure in the tubing and casing @ the same depth

Placed near operating valve to measure ΔP across orifice

Completion and GL Design Interaction


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Surface set-up for Annular Gas Lift on Low Reservoir pressure well with lots of coal fines

Coal Fine Filter Bank


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Data

Two downhole pressure points & two surface pressure points

Production Conduit Gradient: as low as 0.013psi/ft (CP =14.4#, DHCP=56.8#)

Injection Gas Gradient: ~0.008psi/ft

Pressure drop across orifice: as low as 67psi during gas injection.

Actual data close to model results


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Phoenix Select Sensor –

Gas Lift

• Annulus Pressure• Tubing Pressure• Temperature• Vibration(x,y,z)• Current Leakage

Maximize draw down

Enables pressure build up transient analysis

Analyze injection point in real time

Single Pressure

Dual Pressure


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Case Study


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Down

hole

Repa

ir Co

sts

Repaired and Pump Failed

(after few days)

Historical Production Data & Repair CostInstalled Rod

PumpPump Failed Repaired

PumpPump Failed Annular Gas Lift

+ CTS gaugeConverted to Flow w/Flow

Controller

Po Boy Gas Lift


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Downhole Repair Costs

Cum. Production in 15months

-

Decrease in repair cost -

Decrease in production downtime

-

Increase in average revenue from cum. production

180,000 Mcfd


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What is behind Advanced Lifting Service?Trend From: 14/3/04 to: 10/9/04

0

200

400

600

800

1000

1200

1400

1600

1800

2000

14-Mar-04 0:00 03-Apr-04 0:00 23-Apr-04 0:00 13-May-04 0:00 02-Jun-04 0:00 22-Jun-04 0:00 12-Jul-04 0:00 01-Aug-04 0:00 21-Aug-04 0:00 10-Se

IOPo

int V

alue

Intake Pressure Discharge Pressure

k = 98 mdSkin = +3

SurveillanceLIFTWatcher*

• Reduce downtime• Find Production

Opportunities• Minimize liquid loading• Maximize sales gas rates.

Inflow Analysis• Formation damage• Reservoir pressure• Field Optimization

1700

1900

2100

2300

2500

2700

2900

Tota

l Liq

uid

Rate

s [ST

B/D

]

0 100 200 300 400Time (days)

0

10000

20000

30000

40000

50000

60000

70000

80000

90000

100000

Oil

Cum

Pro

duct

ion

Oil Cum Production 500.00ft (STB)Oil Cum Production 400.00ft (STB)Oil Cum Production 300.00ft (STB)Oil Cum Production 200.00ft (STB)Oil Cum Production 100.00ft (STB)

ProCADE*

*Mark of Schlumberger

Single Layer Forecast: Sensitized Oil Cum Productions vs Time

AethonNEVU 13-1Simulated11/15/2004

0 100 200 300 400 500 600 700 8000

00

200

300

400

500

600

700

800

900

000

Liquid Rate, Bbl/D Not Used

t Used Not Used t Used Not Used

11 2

Skin Sensitivity(1) 4.000(2) 0.000

Match Point – Skin =4

Q=475 BLPD

Production Prediction, Skin=0

Q=700 BLPD

0 100 200 300 400 500 600 700 8000

00

200

300

400

500

600

700

800

900

000

Liquid Rate, Bbl/D Not Used

t Used Not Used t Used Not Used

11 2

Skin Sensitivity(1) 4.000(2) 0.000


Q=475 BLPD


Q=700 BLPD


Q=475 BLPD


Q=700 BLPD

25 bopd

Production Improvement• Recommend remedial actions• Predict associated production

Diagnostic Analysis• Alarm Based• Event Based• Proactive Opportunity

Outflow AnalysisPipesim*

• Appropriate valve sizing• GL Method Selection• Optimize injection rates

Advanced Lifting Services consists of expertise (people and processes) and technology focused on improving production.


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• Green

well is operating within acceptable range• Yellow

well is operating, but some measurement has deviated outside acceptable range

• Red

well is down• Cross Sign

well has not reported in more than 26 hrs

Real Time Web Interface


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Real Time Gas Lift Trends


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Modeling: Sensitivities on Flow Correlation

• Sensitivities on correlations to match measured data were with the output results

• Ansari flow correlation matches best with measured data and accurately predicts the inlet (static bottomhole) pressure more than other correlations.


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Nodal Analysis


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Sales Gas & Injection Gas Rates


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Inflow Analysis

Downhole Production Pressure

Test Type Build Up

Reservoir Model HomogenousInfinite Acting

Ext.Reservoir

Pressure (psia) @ gauge depth

(3,145’

MD)

150

Effective Permeability (md)

60

Total Skin ~0


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Conclusions

Maximized injection gas rates while maintaining production

Cum Gas Production for given period with Gas Lift Application is higher than that of Rod Pump as a result of pump failure and downtime (~180 MMcf

more).

Significant rod pump repair costs of ~$300K eliminated by converting to gas lift

CTS gauge provided data for well performance monitoring and optimization in real time


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QUESTION S


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Other uses of this presentation are prohibited without the expressed written permission of the company(ies) and/or author(s) who own it and the Workshop Steering Committee.


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gas-lift application on low pressure gas well with … · gas-lift application on low pressure gas...

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