Case Histories Gas Lifting Gas Wells

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1 Case Histories Gas Lifting Gas Wells Boots Rouen US Land Gas Lift Schlumberger

2 Continuous Lift 2 RR A relatively low ratio of gas is injected continuously into the producing fluid column to aerate or lighten it above the point of injection. For all practical purposes, in-flow to the well bore will be at a stable rate.

3 Advantages of Gas Lift Good performance in High GLR wells Good performance in sandy wells Not affected by wellbore deviation Performs well in deep wells System is flexible Can be used in multiple completions Suited for inaccessible well sites 3 RR

4 Advantages of Gas Lift Most flexible form of artificial lift Low operational cost High volume system (Also Low) Forgiving system Can best handle sand/gas/well deviation 4 RR

5 Case Histories Deep C/T Plunger Assist Gas Lift Dual Annulus Gas Lift Snubbing G/L Valves Tail Pipe Install 2 3/8 X 4 ½ Casing Flow High Draw Down Well Low Liquid Rate 5 RR Horizontal Completion

6 6 RR

7 7 RR

8 Previous Production High Maintenance Shut In/Blow down Dropping Soap Sticks 10 MCF/D Below Packer CT Gas Lift 1 1/4" CT Annular Flow South Texas Current Production 25 B/D Water 400 MCF/Day Pcsg = 900 Psi Ptbg = 100 Psi Injecting 400 MCF/Day 1 1/4" Coiled Tubing 2 7/8" Tubing 7 5/8" Casing 1" GLV's Perfs 9658' ' Depth 8450' 9800' 8 RR 10900'

9 9 RR 34 JJ 2/17/2004

10 Previous Production 1 BBL/D Oil 4 BWPD 53 Net MCF/D Current Production 3 BBL/D Oil 8 BWPD 100 Net MCF/D Plunger Assist Gas Lift East Texas 2 3/8" Tubing 5 1/2" Casing 1" GLV's Injection was decreased from 220 MCF/D to only 44 MCF/D Decreased injection over 5 MMCF last month 6700' Conventional Mandrel 7350' Plunger Bumper/Collar Stop Side Pocket Mandrel X Nipple w/ Standing Valve 6' Pup Joint 7380' Packer 10 RR

11 Previous Production 0-5 BWPD Water MCF/Day Dual Annular Gas Lift Sonora, Texas Current Production BWPD Water MCF/Day Injecting 250 MCF/Day 1 1/4" Coiled Tubing 2 7/8" Tubing 5 1/2" Casing 1" GLV's Perfs 5777' ' Depth 5600' 6050' 6400' 6710' 11 RR 5 1/2" 15.5# J-55 Casing Bull 6740' 2 7/8" 6750'

12 2 3/8" Tubing 4 1/2" Casing 1" GLV's Well Head Pressure: 500 psi Snubbing GLV's South Texas ' 2 3/8" Internal Mount Mandrels ' ' 3/16 Ports ' ' ' ' 1/4 Ports ' ' Screened 9900' 12 RR Bull 10000'

13 Snubbing GLV s Production Data Compressor Problems Projected Decline Curve 13 RR

14 4-1 1/2" Conv. Mandrels and GLV'S 5250' 6400' Tail Pipe Hang Off East Texas Well #12 Previous Production 71 MCF/D 6 B/D Fluid 7350' 8200' Current Production 174 MCF/D 61 B/D Fluid 2 3/8" SPM 1" BK 8610' 1 Joint of Tbg 2 3/8" Tbg 2 3/8" to 2 7/8" X over 2 7/8" Ported Sub to Hang off 1" Pipe 1" Pipe Inside 2 7/8" 2 7/8" Pup Joint 6' 2 7/8" X 5 1/2" Full Bore 8650' 14 RR Appx. 550' of 1" 10 RD IJ Tbg 1" to 1 1/4" X Over 1 1/4" IM Mandrel W/ S/O 3/16" 9170' 1 1/4" to 1" X Over 1 Joint Tbg 1" 1" Bull 9200'

15 Tail Pipe Hang Off Production Data 200 Well # Production Tail Pipe Installed 12/21/03 Formation Gas Production Fluid Production Casing Pressure (PSI) Tubing Pressure Casing Pressure Dec 13-Dec 15-Dec 17-Dec 19-Dec 21-Dec 23-Dec 25-Dec 27-Dec 29-Dec Date 15 RR

16 2 3/8" Casing Flow South Texas Depth 1700' Previous Production 50 BWPD 30 MCF/Day 3325' 4800' 6100' Current Production BWPD 100 MCF/Day Injecting 700 MCF/Day 7225' 8200' 9025' 2 3/8" Tubing 4 1/2" Casing 1" GLV's Perfs 8076' ' 9650' 10150' 10525' 16 RR

17 High Drawdown Barnett Shale 1550' 2950' 4150' Well Information FBHP 792 PSI SBHP 3450 PSI PI B/D Reservoir Drawdown =77% 5150' 6000' 2 3/8" Tubing 5 1/2" Casing 1 1/2" GLV's Perfs 7898' ' 6700' 7300' 7800' 17 RR 7843'

18 High Drawdown Pressure Survey Pressure (PSI) Flowing Pressure Casing Pressure Depth (ft) Fluid Slug Lifting from bottom Valve at RR

19 High Drawdown Temperature Survey 0 Temperature Flowing Temperature Depth (ft) Injection Point RR

20 Pwh = 250psi Pso = 1100psi Horizontal Design Completion above Horizontal Section Depth T.R.O. 2000' ' ' ' 935 Barnett Shale 2 3/8" 8rd Tubing 7" 23# Casing 1 1/2" GLV's Perfs 8063' ' & 8550' ' Max Angle ' ' 915 Previous Production Flowed back for a short time then loaded up 5300' ' ' 885 Current Production 300 BWPD 150 Net MCF/D 6825' S/O 20 RR 7000' MD 6925' TVD Total Depth: 9448' MD 7048' TVD

21 Pwh = 50 PSI Pso = 800 PSI Low Liquid Rate - Low BPH No. Lousiana #1 Low Fluid Rate / Low BPH Average Production 5 B/D 99% Water MCF/Day Pcsg = 125 Psi Ptbg = 50 Psi Inj. MCF = 90 FBHP = 115 Psi FST = 74 BHT = 1.91/100 FT BHP = +/- 240 Psi 2 7/8" Tubing 5 1/2" Casing 1" GLV's Well Salts up - Dump 5 lbs. Frewshwater - Shut well in for a few hours and it comes back on. Fresh water bleeds thru S/O 7000' Conventional Mandrel w/ 700 psi TRO 7725' Screened Orifice 1 Joint 7755' 7854' '

22 Injection Gas Sources Central Compression Onsite Compression High Pressure Sales Line Nearby High Pressure Wells 22 RR

23 Summary When reservoir energy is depleted some form of artificial lift is required. Gas lift is one of the most widely used artificial lift methods. Gas Lift operates by reducing the fluid density. Systems analysis which incorporates flow performance of all the components is required for optimal design 23 RR

JESSE HERNANDEZ: ARTIFICIAL LIFT ENGINEER WITH 35 YEARS IN ARTIFICIAL LIFT AND SUPPORT OF NEW TECHNOLOGY IN COUNTRIES ALL AROUND THE WORLD.

JESSE HERNANDEZ: ARTIFICIAL LIFT ENGINEER WITH 35 YEARS IN ARTIFICIAL LIFT AND SUPPORT OF NEW TECHNOLOGY IN COUNTRIES ALL AROUND THE WORLD. LUIS DIAZ: PROFESSIONAL PETROLEUM ENGINEER WITH OVER 35 YEARS IN THE OIL AND GAS INDUSTRY. LEADER FOR TEAMS RESPONSIBLE FOR DRILLING, PRODUCTION AND WORKOVER FOR SEVERAL MAJOR OIL COMPANIES. GIVEN THE