case histories of water injection utilizing re-injection icds - schlumberger

Sand Management Services

Case Histories of Water Injection Utilizing ResInject* ICD Screens

Stephen L. Ward Sr Engineering ManagerSchlumberger (Reslink)

Sand Management Services 2 SLW1/8/2008

© 2007 Schlumberger. All rights reserved.

An asterisk is used throughout this presentation to denote a mark of Schlumberger. Other company, product, and service names are the properties of their respective owners.


Presentation Overview

Sand and Injection control solutionsResInject introductionResInject case histories

Discussions


ResFlow* versus ResInject

ResInject needs an energy absorbing chamber down side of the nozzles.The nozzle design is the same for both ICD solutions.

Nozzles are positioned in the preferred flow direction for optimal performance.

ResFlow should not be used in the injection mode over long time, especially if erosive particles are present.ResInject can be used for both injectors and producers


ResInject for Injection WellsResInject compensates for injectivity contrasts in the formation.


ResInject Controls the Flux Into the Reservoir

The purpose of ResInject™ is to balance the water injection profile by restricting water inflow to high productive zones.

The risk of early water breakthrough in a producing well is reduced.

The risk for by-passing reserves is minimized.

Without ResInject™ ResInject™


Water Injection Well – Statoil Results

Installed ICD screens in March 2006ResInject with 10x4mm/joint22 joints 5 1/2”, 250 micron screen slot width gravel packed with resin coated gravelTested 3 rates

Qw = 3316 m3/d at WHP=207 barQw = 4662 m3/d at WHP=253 barQw = 5274 m3/d at WHP=262 bar

Current injection rate 28,300 BWPD


ICD Design for the Statoil Injection WellICD injector was evaluated for two options.

First option used a different configuration per zone.Second option used the same configuration along entire well length.

Option two with the same configuration was selected.Simulations supported max. injection into the upper zones.The ICD system would minimize the potential of fracturing the formation.


Simulations and Sensitivity AnalysisGiven matrix injection, the ICD injector reduces the peak flow by approximately 50%.

Water flux from well to reservoir; Blue: Base Case Screen vs. Pink: Base Case ICD


Screen Only with 20D Fracture in FormationInflux into the fracture dominates injection.The rate into the fracture increases 5 times !There is minimal injection into the rest of the reservoir.

Water flux from well to reservoir;Blue: Base Case Screen vs.Pink: Screen with a 20D fracture

Water flow rate in tubing; Blue: Base Case Screen vs.Yellow: Screen with a 20D fracture


ICD Screen with 20D Fracture in FormationMatrix injection is maintained by the ICD.The ICD allows an increase in flux of approx. 30%; thereby deferring the water front.

Water flux from well to reservoir; Blue: Base Case ICD vs.Pink: ICD with a 20D fracture


Actual Field Data and ICD PerformanceA minor change in injectivity between the tests indicates that fractures are not dominating the total injection rates.

IPR ICD Injector Actual vs. Simulated performance

350

375

400

425

450

475

500

0 1000 2000 3000 4000 5000 6000 7000

Injection Rate (Sm3/d)

Pres

sure

(Bar

)

Stær ICD Well testdata October 2006,Preservoir 340 bar

Stær ICD Skin 16,Preservoir 340 bar

Stær GP, Skin 16,Preservoir 340 bar

Stær ICD Well testdata Mars 2006,Preservoir 378 bar

Stær ICD Skin 20,Preservoir 378 bar

Stær GP Skin 20,Preservoir 378 bar


Water Injection Well – NigeriaFirst ResInject installed in June 2007.

7 joints of 5 1/2” ResInject installed: 3 with 16x4mm/joint, 2 with 4x4mm/joint and 2 with 12x4mm/joint.

Annular packers for isolating and fewer nozzles used to minimize injection into high perm interval in middle of formation.

Initial test indicated high injection pressure similar to what had been seen in other offset wells with screen and GP. Acidizing needed to clean mud filtercake from formation face. Four wells with Resinject installed to date.


Water Injection Well – AlaskaFirst installation in Alaska occurred in July 2007.

15 joints of 3 1/2” ResInject installed: 1 with 2x2.5mm/joint inside 7” casing, 14 with 3x2.5mm/joint in 3000’ of 6.25” openhole.

There were 8 annular swell packers installed to isolate 2 faultsand compartmentalize the open hole section.

Screens were run in clean Solids Free FloPro. Bleach was pumped through screens to break down viscous fluid on formation face once screens were on bottom.

Latest test 1250 BWPD with 950 psi WHP


Injection Profile Results

Zonal Injection Rate at 750 BWPD

05

101520253035404550

1 2 3 4 5

Screen # starting from Top

Inje

ctio

n (%

)



Zonal Injection Rate at 1250 BWPD

05

10

1520253035

404550

1 2 3 4 5


Inje

ctio

n (%

)



Zonal Injection Rate at 1990 BWPDField

05

101520253035404550

1 2 3 4 5


Inje

ctio

n (%

)


Questions/Discussion

case histories of water injection utilizing re-injection icds - schlumberger

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