Horse Casing Slipstream
Transcript of Horse Casing Slipstream
Casing Slipstreamers – From Idea to Reality
Leland Horse Area – Deep Basin Rob McPike C.E.T.
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Area of Interest:Canadian Map
B.C. SASK.
Pacific Ocean
Deep Basin South
Area of Interest
ALBERTA
Karr
Placid
Wild
Resthaven
Horse
Olsen/Pinto
41 Prod Wells Average 60% WI Net Sales of 27 mmscfd
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Remote Operations Area – Limited Access to Well Sites
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Deep Basin South:Multi-zone Potential
5-22-58-2w6 CRDZ
8-16-58-2w6 Thrusted
CRDM sand
Dunvegan
Bsl Dunvegan
Cadotte
lower FLHR
CDMN
• Thrusted Cardium : middle to upper shoreface sands. Productive formation in Smokey
• Dunvegan : middle shoreface sands of prograding delta. Regionally mappable and seismically definable and local production
• Cadotte : upper shoreface sands. Regional defined• Falher : channel deposits to shoreface sands Falher F and
Falher E locally and regionally defined, seismically mappable (Falher F)
• Bluesky : Delta sands marks regional transgression• Gething : Upper and Lower fluvial channels regionally
mappable and locally productive.• Cadomin : Alluvial plain to braided channel deposits with
fracture enhancement. Regionally mappable near offset gas test.
885
m
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102/7-2-59-25W5M Well Summary Sheet
WELL SUMMARY SHEET Perforations
Well Name: U W I: Profiled Nipple w / No-Go
Purpose Lat.(N): 54°04'18.08" Long.(W): 117°47'13.033" KB: (m) 1174.69
By/ Date: KB-THF: (m) 5.00 PBTD: (mKB) 3097.0 GE: (m) 1168.40 PSN
Status: KB-CF: (m) 7.24 TD: (mKB) 3128.0 KB-GE: (m) 6.29
Hole Details: On/Off / Saw tooth Collar
Bit Size: (mm) Bit description Interval (mKB)
Surf: 311.0 GE 631.0 Packer
Prod: 200.0 631 3128.0 Casing Details: Sliding Sleeve
Surf: Size: (mm) 244.5 Weight: kg/m 53.7 Grade: J-55 Lt&c Depth: (mKB) 631.0
Prod: Size: (mm) 139.7 Weight: kg/m 25.3 Grade: L80 Lt&c Depth: (mKB) 3128.0 Bridge Plug
Cement:
Surf.csg: 36 T G + .5% CaCL2 5m³ good cement returns 2002-12-11
Prdn.csg: (47.5T 1:1:2G+1%CFR+2%FWCA+.1%LTR)+(19TExpandomixG+.35%LTR)no returns,logged top:1700mKB 2003-01-31 TCP Gun
Perforations:
Intervals, mKB Density - spm Chg.size, gm description Status Date
17 25gm TAG 101.6 mm EXHSC 60°ph CDMN 2003-02-13
20 26gm 86mm Innicor Stim Gun, 60°ph GTNG 2005-07-30
17 25gm CDTT 2005-08-14 Dropped Gun
Tubing String Details: Include packer compression/tension details
Size: (mm) 60.3 Weight: kg/m 6.99 Grade: J-55 Make:
No. Description Length (m) Depth mKB Remarks
3072.80 PC Pump
1 0.15 3072.65
2 0.66 3071.99
3 0.38 3071.61
4 3.09 3068.52
5 0.33 3068.19
6 0.66 3067.53 Standard Top Hold Dow n
7 9.27 3058.26 Pump
8 9.00 3049.26
9 345.08 2704.18
10 9.00 2695.18 Standard Bottom Hold Dow n
11 2671.71 23.47 Pump
12 7.38 16.09
13 9.58 6.51 Tubing Anchor
14 0.25 6.26
15 5.00 1.26 RA Collar
Casing Patch
External Casing Packer
2003-02-17
2005-08-07 Perforated Pup/Flow /Fill
2005-08-17Cross Over
Rod Strings
opposite Cadotte
(3) Blast joints 77.7mm OD, EUE
(279) Tubing joints 60.3mm, EUE
(3)Tubing pup joints - 60.3mm EUE
KB - THF
2698.5 - 2703.5
101.6mm, ERHSC, Owen 3375-3C, 60°ph
(3) Blast joints 77.7mm OD, EUE
opposite Lower Gething
(36) Tubing joints 60.3mm, EUE
Tubing pup joint - 60.3mm EUE
Frac'd Gething with 23T in formation
(1) Tubing joint 60.3mm EUE
3051.0 - 3056.0
Frac'd Cadotte with 30T in formation
Frac'd Cadomin with crosslinked gelled water based fluid, 21T in formation
3051.0 - 3056.0
(1) Tubing joint 60.3mm EUE
Tubing hanger
Tubing pup joint - 60.3mm EUE
1700.0
Otis X nipple
Tubing pup joint - 60.3mm EUE
Otis XN nipple 47.63mm XN, 45.5mm no go
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102/07-02-059-26W5/0 lic.#: 276188
3074.0 - 3077.5
Re-entry guide - 77mm OD, EUE
631.0
2698.5 - 2703.5
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DEVON 7C LELAND 7-2-59-26
Add new zones
D.Stokes 2005/09/02
on production
Tubing – 2 3/8”
Casing - 5 ½”
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Area History
• Original Leland Horse wells (100% WI) originally started out at production rates of up to 450 e3m3/d producing both the tubing and casing in a competitive drainage reservoir
• Once critical lift was reached flowing the casings they were shut in and only tubings were produced with a noticeable production loss (30 e3m3/d) due to tubing friction
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Critical Rate Graph for 60.3 mm TBG& 139.7mm CSG producing @ 3000 kPa Critical Rate to Lift Water
Based on Turner, et al
0.1
1.0
10.0
100.0
1000.0
100 1000 10000Flow ing Wellhead Pressure (kPaa) add 100 kPa to gauge pressure
Z=0.95, T=15°C
Qc=
Cri
tica
l Rat
e (1
0³m
³/d
)
60.3 mm tbg
139.7/60.3 mm Annulus
Casing critical rate 100e3m3/d
Tubing critical rate24 e3m3/d
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102/7-2-59-26W5M IPR / Tubing Performance Curve
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How can we mitigate the production loss?
PROBLEM
• Reduced flow up tubing due to friction
• Maintaining critical rate up tubing flow path to lift liquids
SOLUTIONS
6) Do nothing and accept the reduced production – not an option as this is a competitive drainage reservoir
7) Investigate methods of producing the casing without liquids loading the well bore
What is casing slipstreaming?
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Theory of Casing Slipstreaming
• Produce the maximum amount of gas the well can deliver without entering a liquids loaded condition
• Intermittently produce the casing to allow “extra” production that is “trapped”, due to friction losses in the tubing, to flow up the casing while constantly maintaining critical rate up the tubing string to not enter a liquids loaded condition
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Simplified Flow Schematic
To Separator Package
Top View of 2 3/8" TBG in 5 1/2" CSG
tubing flow
casing slipstream flow
FCV1500
FE1500
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102/7-2-59-26W5M Gas Production
Incremental Volume
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Attempted to find solutions to this production loss
•First attempt was to tie in casing with 1” piping and control flow with a globe valve
•This failed due to liquids loading of the tubing because there was no monitoring of the critical rate
•This experience determined that the tubing flow needed to be monitored to maintain critical rate up the tubing and that the flow from the casing needed to be controlled with some degree of automation due to remote locations
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Developing A Solution
• Current casing spool to be modified to incorporate all of the required equipment.
• AGA quality flow measurement for the casing not required as it was only a reference flow
• Wet fuel gas instrument lines have been an issue in the past - led to investigating an electric actuated controller
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Control Philosophy
• Use simple cost effective meter run to measure casing flow
• Continually monitor tubing flow to insure it is above critical rate – no access for swabbing equipment 8 months a year
• Utilize SCADA control and all automation available due to remote locations
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Simplified Casing Slipstreamer P&ID
To Separator Package
WELLHEAD
FCV1500
FI150
FE1500
FT150 ESDV
1500
selfcontained hydraulicmodule
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102/7-2-59-25W5M prior to piping modifications
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Overview of the 102/7-2-59-26W5M site.
RTU and Solar Panels
Separator Package
Line heater
Thermoelectric Generator(use propane for added reliability)
Casing Slipstreamer assembly
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102/7-2-59-25W5M after required piping modifications
Orifice flanges-simple meter run
Baker choke withElectronic actuator
Bristol Flow Computer
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SCADA Wellsite Overview Page
Casing Flow
Tubing + Casing Flow
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SCADA Casing Flow Controller Screen
Calculated TBG Critical Rate
Control Setpoint
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Casing Slipstreamer Approximate Costs
- $2800 actuator assembly- $2000 orifice plate and required flanges- $4000 choke assembly- Upgraded the Bristol 3305 RTU to a Control
Wave Micro (most expensive cost @ $18,000) - Piping modifications $8000
Total estimated costs = $40,000Total estimated costs = $40,000
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Valuation
• Current net back- $3.60/mcf
• 25 3eme/d of “extra” production = $3180/day
• Potential added “extra” revenue of 1,160,777 over the course of a year.
• Cost of installation approximately $40,000.
PROJECT PAYOUT OF LESS THAN PROJECT PAYOUT OF LESS THAN
13 DAYS13 DAYS
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TODAY AT LELAND HORSE
• Currently there are 17 wells equipped with casing slipstreamers in the Horse Field
• The added incremental production has been between 5 e3m3/d and 25 e3m3/d
• Now standard on all new Horse wells – facilities installation
• Have recently installed in Resthaven area with similar success
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Conclusions and Learning's
• There are production gains to be had – TIMING IS CRITICAL
TO TAKE ADVANTAGE OF ANY PRODUCTION GAINS.
Equipment needs to be in place before critical rate
becomes a factor to maximize return
• CANDIDATE SELECTION
- Tubing / Casing differential pressures
– IPR curves
- Tubing performance curves
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Conclusions and Learning's
• Sites must be as automated as possible due to remoteness of location
• The electric actuator has been a huge success – investigating other possible applications
• Proven method of increasing production
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QUESTIONS?
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THANK YOU
Special thanks to Dave Stokes who was a huge believer and proponent of this project