horse casing slipstream

Casing Slipstreamers – From Idea to Reality

Leland Horse Area – Deep Basin Rob McPike C.E.T.

NYSE: DVN www.devonenergy.com page 2

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


Remote Operations Area – Limited Access to Well Sites


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


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


1700.0

Otis X nipple


Otis XN nipple 47.63mm XN, 45.5mm no go

13

12

102/07-02-059-26W5/0 lic.#: 276188

3074.0 - 3077.5

Re-entry guide - 77mm OD, EUE

631.0

2698.5 - 2703.5

15

6

14

10

3

4

11

9

8

7

5

DEVON 7C LELAND 7-2-59-26

Add new zones

D.Stokes 2005/09/02

on production

Tubing – 2 3/8”

Casing - 5 ½”


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


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


102/7-2-59-26W5M IPR / Tubing Performance Curve


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?


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


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


102/7-2-59-26W5M Gas Production

Incremental Volume


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


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


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


Simplified Casing Slipstreamer P&ID

To Separator Package

WELLHEAD

FCV1500

FI150

FE1500

FT150 ESDV

1500

selfcontained hydraulicmodule


102/7-2-59-25W5M prior to piping modifications


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


102/7-2-59-25W5M after required piping modifications

Orifice flanges-simple meter run

Baker choke withElectronic actuator

Bristol Flow Computer


SCADA Wellsite Overview Page

Casing Flow

Tubing + Casing Flow


SCADA Casing Flow Controller Screen

Calculated TBG Critical Rate

Control Setpoint


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


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


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


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


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


QUESTIONS?


THANK YOU

Special thanks to Dave Stokes who was a huge believer and proponent of this project

horse casing slipstream

Documents

tubing joints

tubing pup joints

upper shoreface sands

delta sands

blast joints

shoreface sands falher

casing details

mappable falher fbluesky