r&d solutions

Capabilities Products and Services

Product Catalogue

T + 61 8 6140 1820 Fax +61 8 9429 3098 ABN No 38 138 827 915 R&D Solutions Pty Ltd, Suite 6, Level 3, 1111 Hay Street, West Perth WA 6005 Australia

R&D Solutions

R&D Solutions Pty Ltd. Suite 6, Level 3, 1111 Hay Street, West Perth WA 6005 AustraliaT + 61 8 6140 1820 Fax +61 8 9429 3098 ABN No 38 138 827 915

Table of Contents

1. Index

2. Company Profile

3. Packers Plus Technology

4. Centraliser Selection

5. Reamer Shoe

6. Advanced Polymer Guide Noses

7. Cementing Equipment

8. Hammerhead Guide Shoe/Drive Shoe

9. Maxtube Duoline 20

10. Metal To Metal Seal Technology

11. High Expansion Shifting Tool

12. Indexing Muleshoe

13. Caledyne Balance Pump

14. Hydraulic Anchor Catcher and Subsurface Barriers

15. Retrievable Bridge Plug

16. Training Facilitation – Overview by Bob Taylor

17. Pioneer Petrotech Gauges

18. ST Sensortran Fiber Optic Gauges

19. Control Line Cross Coupling Clamps

20. R&D Solutions QHSE Policy

Company Profile:R&D Solutions was formed in September 2009 by Russell Furner and Doug Gillespie both based in Perth West Australia.The company has a combined experience level of over 55 years providing equipment and services to the oil Industry.

With an office in Hay St West Perth, Australia R&D Solutions are available 24hrs per day to assist with standard and nichetechnology or equipment procurement, tool design and training needs.

Vision:Our vision in R&D Solutions is to become the primary contact for equipment design solutions, equipment sales enquiriesand hard to get technologies for the energy sector.

Services:R&D Solutions has from the outset recognised the fast paced environment which is the oil industry today. Manycompanies do not often have time or resources to spend tracking down equipment and personnel. Moreover for one offtool purchase, tool design or personnel training it can become a very costly exercise tracking down exactly what yourorganisation and staff needs.

R&D Solutions recognising these challenges offers the following:

Tool design and build to meet your needs

Track down and deliver your Drilling and Completion Equipment requirements

Facilitate Training using local facilities

Provide locally built tools using engineering capabilities in Australia and the Asia Pacific Region

Representative Agreements:

Sledgehammer: www.sledgehammerasia.comR&D are representatives for this API, ISO accredited company and has sold its products here in Australia, NewZealand and Asia. Sledgehammer offers a full range of centraliser and cementing products as well as placementmodelling. In addition they will soon launch a reamer shoe product on the market.

Matrix: www.matrixap.com.auR&D Solutions hold the distributorship for Matrix, next generation polymer centraliser and snap lock stop collar.Matrix is one of the largest suppliers of riser buoyancy polymer products in the world. Matrix listed on the stockexchange last year and move to new purpose built facilities in Henderson later this year.

Max Tube: www.maxtube.comThis company offer fibre glass linings for tubing which can extend the life of production tubing to asmuch as 25 to 30 years or more. Chevron has run this product in the recent past, and is currentlyconsidering it for operations on Barrow Island. R&D Solutions has been working closely with Chevronfor this application.

Page 1

R&D Solutions Pty Ltd, Suite 6 Level 3, 1111 Hay St, West Perth WA 6005 AustraliaT +61 8 6140 1820 F +61 8 9429 3098 ABN 38 138 827 915

R&D Solutions

www.sledgehammerasia.com

www.matrixap.com.au

www.maxtube.com

Packers Plus: www.packersplus.comThis company has been awarded a contract with a value of over 4-1/2 Million Dollars USD$ by a locally basedoperator as a direct result of efforts from R&D. This is for the supply of niche packer equipment and liner hangerssuitable to work in 300C and 11,500 psi. Packers Plus took on all development costs to make sure they retain allintellectual rights to the technology. Locally R&D supported technical requirements and so forth as and whenrequired.

CaledyneInnovation and Integrity by Design www.caledyne.com

Caledyne:Caledyne provide state of the art flow control equipment, locks plugs and packers for standard and HPHT wells.In addition they have built and tested metal to metal seal elements for HPHT environments which can beretrofitted to most packers and plugs of other suppliers. R&D Solutions has recently introduced this technologyinto Woodside for remedial equipment needs and to other service companies for day to day operations.

Sensortran: www.sensortran.comA company currently providing state of the art fibre optic equipment to the oil, gas and geothermal industry.Sensortran supplied equipment has been used for pressure and temperature monitoring in oil and gas wells aswell as in pipelines for leak detection, storage vessels for the same and importantly under storage vessels toensure there are no base leaks. A further unique application has been on power lines in the States to monitor anyhot spots which may occur and cause fires. For in well and surface facilities there are a multitude of areas wherethis technology can help to prevent issues occurring. It is simple to use, fast and can be set up to send an e-mailas issues arise. R&D Solutions has proposed this technology for Geothermal and HPHT applications in SouthAustralia.

Pioneer Petrotech Services Inc www.pioneerps.comPioneer manufactures and services a wide range of oil filed instruments including down hole pressure gauges,surface readout gauges and wellhead loggers. State of the art equipment produced with an automatic calibrationcapability.

Design Engineering:R&D Solutions has already committed to design work for a major service companies in Perth and as mentioned inthis document can assist with special tool development needs.

People:R&D Solutions understands that a company’s greatest assets are its people and the environment they work in, the oldstory is certainly true, ‘a happy team is a productive team’ we wish to provide both. As R&D Solutions grows it willcontinue to place emphasis on local staff content and ‘train rather than hire’ people into roles rewarding dedication, loyaltyand commitment.

Directors:Russell Furner is a ‘Managing Partner’ in R&D Solutions, with over 30 years in the industry World Wide Russell is wellknown locally for having a ‘can do’ attitude and getting the job done. Moreover he has extensive experience in managingand growing successful companies. Prior to joining R&D Solutions Russell has held management posts in BBL Ltd. andWeatherford International.

Russell is responsible for capital expenditure, strategic business direction, finance and operations. In addition, he assistswith sales growth in Australia and Asia Pacific. Russell can be contacted on +61 433 606 555

Page 2

R&D Solutions Pty Ltd, Suite 6, Level 3, 1111 Hay St, West Perth WA 6005 AustraliaT +61 8 6140 1820 F +61 8 9429 3098 ABN 38 138 827 915

R&D Solutions

www.packersplus.com

www.caledyne.com

www.sensortran.com

www.pioneerps.com

Directors Contd:Doug Gillespie is a partner in R&D Solutions. With over 15 years experience in Norway, the UK and Australia, Doug hasgained extensive experience in sales and marketing. Prior to joining R&D Solutions Doug worked for OCRE Scotland,Aker Maritime and Weatherford International. Doug is responsible for business development, sales, marketing,engineering design support and training facilitation. Doug can be contacted on +61 433 332 365

Accounts and office Administration:Ronda Swinbourn is responsible for accounts, bookkeeping, logistics and support required for the smooth flow of a busyworkplace. Ronda has worked with both Russell and Doug previously in BBL, Weatherford, and now in R&D Solutions.

Sales and Operations Executive:Craig Stampfli has recently joined the Team from Weatherford to fulfill this role. Craig comes with over 15 yearsexperience in the oil and gas industry having been with Weatherford twice and ABB. Craig’s duties will also see him servein an operational capacity as needed. Craig can be contacted on +61 425 830 720

Operations:Using its vast network of operational contact R&D Solutions can provide personnel with proven background to run andinstall the equipment listed.

R&D Solutions has an excellent working relationship with Premium Casing Services ‘PCS’ based at Bibra Lakes Perth. Itbecame clear to R&D that they should not duplicate existing make up and torque services but should instead should letthose who are experts in this field continue to do what they are good at. This approach has allowed the company to focuson time in front of its customers comfortable in the knowledge that this business aspect is being taken care of.

Logistics:For Logistics R&D Solutions uses Pentagon Freight Services known to the R&D Solutions management team for the lastten years. Based in 23 Ballantyne Rd Kewdale under the management team of Ashley Taylor Pentagon has taken care ofall our day to day logistics needs both domestically and internationally.

Summary:With the above list of respected ISO accredited companies R&D solutions can provide all the well jewellery andmonitoring equipment needed for a modern successful completion. Further it can source crossovers, nipple profiles,sliding sleeves and other technologies as needed.

In conclusion R&D Solutions is able to offer a complete suite of state of the art and standard technology to meet yourneeds. We pride ourselves on quick reaction, being able to source and provide the right tools for the job in a timelymanner.

Page 3

R&D Solutions Pty Ltd, Suite 6, Level 3, 1111 Hay St, West Perth WA 6005 Australia

R&D Solutions

T +61 8 6140 1820 F +61 8 9429 3098 ABN 38 138 827 915

StackFRAC®

Multi-Stage Fracturing Systems

Extended Reach Stimulation

StackFRAC® stimulation systems allow stimulation throughout the entire

horizontal wellbore regardless of depth. The StackFRAC® system provides

complete control of well stimulation in regards to depth and placement,

maximizing well production and minimizing production costs.

Extended Reach Horizontal Stimulation

Coiled Tubing Stimulation

Coil Tubing StimulationLimitations

Extended Reach Stimulation

StackFRAC®


Packers Plus is a high value provider of technology-based solutions to

the oil and gas industry. We specialize in open hole, HPHT, high pressure

retrievable packers, and specialty service tools.

Packers Plus®, StackFRAC®, and RockSEAL® are trademarks of Packers Plus Energy Services Inc.

website: www.packersplus.com • email: [email protected]

StackFRAC®


Packers Plus® is a pioneer of open hole fracturing stimulation systems.

StackFRAC® stimulation systems are designated for open and cased hole

stimulation in sandstone, carbonate, shale, coal, naturally fractured

formations, and in critical sour and HPHT environments. This innovative,

field-proven system greatly increases the effectiveness of fracturing

operations by mechanically isolating selective intervals designated for

treatment and producing a distributed placement of stimulation fluids

throughout the desired area. The StackFRAC® system allows for full

fracturing coverage of the wellbore and improved production inflow.

Packers Plus takes great pride in the fact that our products are designed to

handle even the most challenging completions, whether deep, critical sour,

or extended horizontal.

The StackFRAC® system is designed to reduce your well costs, improve

production and maximize your profits.

Applications • Sandstone,carbonate,shaleandcoalformations

• Openholehorizontalandverticalwells

• Criticalsour,highpressure/hightemperatureenvironments

• Extendedreachhorizontalwells

Benefits/Features• Simplifiedpumpingoperations

• Improvedproductionresults

• Reducedcompletiontime

• Improvedaccesstonaturalfractures

• Fullcoverageinextendedreachhorizontalwellapplications

• Customstimulationoftheentirewellbore

• MechanicalisolationwithfieldprovenRockSEAL®OpenHolePackers

Performance

Stage 1

Stage 2

Stage 3

Stage 4

Stage 5

Stage 6

Stage 7

Distance West - East (m)

0 250 500-500-750-1000200

1000

1800

2600

3200

Dis

tan

ce S

ou

th -

No

rth

(ft

)

Dis

tan

ce S

ou

th -

No

rth

(m

)

100

300

500

700

900

Distance West - East (ft)0 1000 2000-1000-2000-3000

-250 750

Stage 1

Stage 2

Stage 3

Stage 4

Stage 5

Stage 6

Stage 7

Y Axis (ft)010002000

0250

30002000

500

0

1000

750

0

1000

2000

X Axis (ft)

Y Axis (m)

X Axis (m)

1000

Top View

3D View

Microseismic Fracture MappingMicroseismic fracture mapping

provides an image of fractures by

detecting microseisms or micro-

earthquakes that are triggered by

shear slippage on bedding planes

or natural fractures adjacent

to the hydraulic fracture. The

fracture mapping graphs shown

here prove out key features of the

StackFRAC® Multi-Stage Fracturing

System which include:

• Fractureinitiationbetween

packers thus proving

mechanical isolation

• Fullfraccoverageofthe

wellbore with multi-placed,

specifically located stimulation

• Improvedproductioninflow

across the entire horizontal

section

Do It Once Do It Right™

Some or all of the systems, methods or products discussed herein may be covered by one or more patents, or patents pending.

Copyright © 2009 Packers Plus Energy Services Inc. All rights reserved. USA-30-Jul-09

Packers Plus® Case Study

BackgroundWhen the Barnett Shale in northeast Texas

was discovered in the mid-1950s, the

technology to exploit this very tight gas

reserve (0.0009 to 0.008 mD) didn’t exist.

Not until 2001, when multi-stage fracturing

technology began to be applied to horizontal

wells, did activity in this play expand.

The ChallengeAn operator working in the Denton County

area of the Barnett Shale had utilized the

conventional “plug and perf” method to

segregate and isolate their horizontal wellbores

into individual stimulation sections. Due to the

numerous operations and equipment required

for the plug and perf method, the operator

sought a more effective multi-stage fracturing

solution. The challenge was to create a system

that not only saved time and reduced costs,

but also increased production from their

horizontal wells to improve their overall

return on investment.

The SolutionThe operator chose to use a 5- and 7-stage

Packers Plus StackFRAC® Multi-Stage

Fracturing System to complete two of their

wells in the Barnett. This system increases

the effectiveness of fracturing operations

by mechanically isolating selective intervals

producing a distributed placement of

stimulation fluids throughout the horizontal

wellbore. RockSEAL® II open hole packers

are used to segment the wellbore and

FracPORT™ sleeves are located between

each set of packers creating isolated stages.

Actuation balls of increasing size are

dropped from the surface during pumping

to allow for hydraulic activation of the

FracPORT sleeves in succession and isolate

previously fractured zones. Because of this

innovative design, the operator was able

to stimulate all stages of each completion

string in less than a day.

The Results A detailed analysis was done to compare the

production results from two StackFRAC wells to

two parallel offset plug and perf wells. In both

cases, the StackFRAC system outperformed the

conventional plug and perf method. One-year

cumulative production values were 80 to 143%

higher for the StackFRAC completed wells versus

the plug and perf wells (Figures 1 and 2).

The Packers Plus StackFRAC Multi-Stage

Fracturing System has enabled economical

production from unconventional reservoirs such

as shale and tight sand plays. Packers Plus has

run over 3,700 StackFRAC systems worldwide

in a variety of formations and conditions.

1. ThisinformationwasoriginallypresentedattheAADENationalTechnicalConference&ExhibitionheldinNewOrleans,LA,March31–April2,2009.©2009AmericanAssociationofDrillingEngineers.

Packers Plus StackFRAC technology outperforms conventional “plug and perf” completions in the Barnett Shale1

0

50,000

100,000

150,000

200,000

250,000

300,000

350,000

660

600

540

480

420

360

300

240

180

1206030 700

StackFRACPr

oduc

tion

(Mcf

)

Plug and Perf

Time (Days)

Figure2.Cumulativeproductionforoffsetwells#3and#4.

0

100,000

200,000

300,000

400,000

500,000

600,000

700,000

800,000

900,000

1,000,000

450

390

330

270

210

1509030

StackFRAC

Prod

uctio

n (M

cf)

Plug and Perf

Time (Days)Figure1.Cumulativeproductionforoffsetwells#1and#2.



Some or all of the systems, methods or products discussed herein may be covered by one or more patents pending.

Copyright © 2009 Packers Plus Energy Services Inc. All rights reserved. USA-30-Aug-09

BackgroundThe Bakken Shale encompasses an area of

25,000 square miles and is located within the

Williston Basin, which is the United States’

largest onshore sedimentary basin. This play

stretches from the northeastern section of

Montana across to the northwestern corner

of North Dakota and up into Saskatchewan,

Canada. The USGS reports the Bakken holds

a mean 3.65 billion bbl of oil and 1.85 Tcf

of gas. Technological advances, such as the

Packers Plus multi-stage fracturing systems,

have allowed for deeper and longer

horizontal wells resulting in improved

exploitation of this reservoir.

The ChallengeAn operator working in the Bakken Shale

was interested in maximizing the efficiency

of their production to improve economics.

To optimize production and to lower costs,

longer laterals were key to meeting their

operational objectives.

Packers Plus realized that to meet the

operator’s needs, the current open hole

stage design would require additional

stages for the longer laterals. Additionally, to

keep costs down, the number of days on the

wellsite needed to be kept to a minimum.

The SolutionThe new Packers Plus StackFRAC® HD™

“High Density” system, with improved

staging technology, provided the ideal

solution. A 15-stage, 4 ½” StackFRAC HD

system was designed for a 6” open hole,

horizontal well in North Dakota. The

completion string design was for a total

depth of 8,350 ft, a lateral length of 4,775 ft,

and the average length between stages was

approximately 300 ft.

The ResultsAll 15 stages were fractured and completed

in one day resulting in cost savings to

the operator. The fracture procedure was

designed for 130,000 pounds of proppant

per stage at a maximum rate of 30 barrels

per minute using a 24-pound, crosslinked gel.

Operationally, the completion went smoothly

and ball action was seen on all ball-actuated

stages. Because of this success, the operator

plans to continue using StackFRAC HD for

their Bakken wells.

StackFRAC HD a success in the Bakken Formation15-Stage StackFRAC HD Multi-Stage Fracturing System maximizes efficiency

A 15-stage horizontal, open hole StackFRAC HD system.

Saskatchewan

Nebraska

Rapid City

MontanaBillings

Wyoming

Manitoba

Winnipeg

Red Deer

Edmonton

AlbertaCalgary

Pembina

Bakken Shale

Williston Basin

Regina

S. Dakota

N. DakotaBismarck

Saskatchewan

Nebraska

Rapid City

MontanaBillings

Wyoming

Manitoba

Winnipeg

Red Deer

Edmonton

AlbertaCalgary

Pembina

Bakken Shale

Williston Basin

Regina

S. Dakota

N. DakotaBismarck




Copyright © 2009 Packers Plus Energy Services Inc. All rights reserved. USA-30-Aug-09

BackgroundThe Devonian Shale is located around the

Appalachian Basin, which has the longest

drilling history in the U.S. Natural gas

was found in 1815 near Charleston, West

Virginia and since then thousands of wells

have been drilled in this region; however,

most of these wells were shallow. Estimates

of natural gas are high in the Devonian

Shale, but this has been tempered by low

recovery rates in the range of only 10%.

The introduction of new technology, such

as the Packers Plus multi-stage fracturing

systems, has allowed for deeper and longer

horizontal wells improving recovery rates

and overall exploitation of this reservoir.

The ChallengeAn operator working in the Devonian

Shale was looking to prove out multi-stage

completions technology in preparation for

drilling and completing longer laterals in the

area. Extending the reach of their open hole

laterals was necessary to meet the operator’s

objectives of optimizing production and

lowering costs.

The challenge was to find a multi-stage

completions system with the capacity for

additional stages to cover the entire length

of the extended reach laterals.

The SolutionPackers Plus recently launched their

new StackFRAC® HD™ “High Density”

Multi-Stage Fracturing System, which has

improved staging technology allowing for

more stages in a single system. With several

successful runs both in Canada and the U.S.,

Packers Plus knew that StackFRAC HD would

provide the ideal solution for the operator.

An 18-stage, 4 ½” StackFRAC HD system

was designed for a 6 ¼” open hole

horizontal well. The well design was for a

total depth of 6,325 ft, a lateral length of

3,425 ft, and the average length between

the stages was approximately 200 ft.

The Results All 18 stages were fractured and completed in

one day. These were gas fractures using half a

million standard cubic feet of nitrogen per stage.

The operator was pleased with the outcome and

as a result, Packers Plus will be running additional

StackFRAC HD systems for this operator in the

Devonian Shale.

StackFRAC HD a success in the Devonian Shale 18-Stage StackFRAC HD Multi-Stage Fracturing System increases reservoir access in Kentucky

Wisconsin

WestVirginia

Virginia

Texas Dallas

HoustonAustin

Tennessee

South Carolina

Pennsylvania

Oklahoma

Tulsa

Ohio

North Carolina

New York

Nebraska

Missouri

MS

Michigan

ONTARIO

MD

Louisiana

Kentucky

Kansas

Wichita

Iowa

Indiana

Illinois

Georgia

Arkansas

Alabama

Appalachian Basin

Devonian Shale

AppalachianBasin

Devonian Shale

An 18-stage horizontal, open hole StackFRAC HD system.




Copyright © 2009 Packers Plus Energy Services Inc. All rights reserved. CAN-30-Aug-09

BackgroundSince its discovery in the 1950s, the Bakken

formation has seen a progression of

completions to allow increasing production

of light oil from this resource play. Currently,

the Packers Plus StackFRAC® Multi-Stage

Fracturing System has become the

completions method of choice in the Bakken

because of its simplified operation and

excellent production results. This field-

proven success has operators working in

the Bakken looking for technology that will

allow for more stimulation stages to further

increase production from their open hole

horizontal wellbores.

The ChallengeAn operator working in the Bakken

formation in southeast Saskatchewan

wanted to increase the number of fracs

in their horizontal open hole wells to

enhance access to the reservoir. Currently,

StackFRAC systems are run with seven to

eight stimulation stages on average, with the

maximum number of stages being dependant

on the liner size. The challenge was to design

a system capable of more stimulation stages

without increasing the liner/frac string size,

which would increase cost.

The SolutionPackers Plus designed the StackFRAC HD™

system with improved staging technology.

This particular well used a 4 ½” liner, which

would normally have a maximum of 11 stages.

With the StackFRAC HD technology they

were able to run a 20-stage system with an

average of 65 m between stages along the

1,375 m open hole lateral.

The ResultsThe first eleven stages were treated in one

day, followed by the remaining nine stages

the next day. Stimulation was performed at

low flow rates of ~0.65 m3/min with between

3 - 5 tonnes of sand injected per stage.

Treatment pressure readings indicated that

all actuation balls landed on seat allowing for

the FracPORTTM sleeves to open. No pressure

fluctuation was noted ahead of the ball

seating indicating that the balls were able to

run through the upstream seat.

Overall, the StackFRAC HD system was an

operational success for the operator who is

continuing to use this system in the Bakken.

The benefits of this system are that it allows

for increased production through longer

laterals and shorter stage lengths, while

keeping costs down through the ability to use

smaller frac strings and liner sizes.

20-stage StackFRAC HD system run in the BakkenNew technology increases access to reservoir and production capacity

A 20-stage horizontal, open hole StackFRAC HD system.

Saskatchewan

Nebraska

Rapid City

MontanaBillings

Wyoming

Manitoba

Winnipeg

Red Deer

Edmonton

AlbertaCalgary

Pembina

Bakken Shale

Williston Basin

Regina

S. Dakota

N. DakotaBismarck

Saskatchewan

Nebraska

Rapid City

MontanaBillings

Wyoming

Manitoba

Winnipeg

Red Deer

Edmonton

AlbertaCalgary

Pembina

Bakken Shale

Williston Basin

Regina

S. Dakota

N. DakotaBismarck


Some or all of the systems, methods or products discussed herein may be covered by one or more patents, or patents pending.

Copyright © 2009 Packers Plus Energy Services Inc. All rights reserved. USA-07-Dec-09


BackgroundOne of the only operators working in the

Cottage Grove sandstone formation in

Dewey County, Oklahoma required multi-

stage completion in one leg of a dual-lateral

well. They wanted to finalize the completion

and move on to production in the minimum

amount of time with the least amount of

cost. The fewer days spent working on

completing the project, the better their

bottom line.

The ChallengeThe operator wanted to mill out the ball seats

directly post-stimulation as they planned to

cut the pipe, eliminating the possibility for

future operations. The challenge was to keep

the number of days on wellsite to a minimum.

Having completed 11 wells in three other tight

formations in Oklahoma with the StackFRAC®

system, the operator knew Packers Plus could

provide superior tools and service. Packers Plus

also recognized the value of working together

with other service companies to accomplish

the operator’s goal.

The SolutionPackers Plus designed a 7-stage, 4 ½”

StackFRAC system for the 6 ⅛” open hole

horizontal lateral. The fracture procedure

was designed for 92,000 pounds of

proppant per stage at an average rate

of 40 barrels per minute using CO2 and

crosslinked gel. The completion was

successful and ball action was seen on all

ball-actuated stages.

The Results The combination of Packers Plus’ experience

and technology not only allowed all seven

stages to be fractured and completed in one

day, but also allowed for the ball seat mill out

procedure to be a quick process saving the client

valuable time and, in turn, reducing costs. The

proven consistency with which Packers Plus

manufactures its tools enabled the time savings

during the milling operation resulting in the well

coming on production at least a day sooner than

the operator expected.

PE

NN

SY

LV

AN

IAN

Gr

an

ite

Wa

sh

Packers Plus StackFRAC Gets Well on Production Fast StackFRAC Multi-Stage Fracturing System Key to Successful Completion in Oklahoma

KansasColorado

Oklahoma

Texas

New Mexico

HoustonAustin

Missouri

ArkansasAnadarko Basin

Dewey County

Stratigraphic Guide to the Greater Anadarko Basin and Shelf


Some or all of the systems, methods or products discussed herein may be covered by one or more patents, or patents

pending, including US patent numbers 6,907,936; 7,134,505; 7,108,067; 7,543,634; 7,431,091; 7,021,384; 7,353,878.

Copyright © 2009 Packers Plus Energy Services Inc. CAN-04-Jan-10


Smo

ky G

roup

Kas

kap

au

Wapiti

Puskwaskau

Badheart

Muskiki

Cardium

Howard Creek

Pouce Coupe

Doe Creek

Dunvegan

NORTHWEST PLAINS

UP

PE

R C

RE

TA

CE

OU

S

SaskatchewanBritish Columbia

Edmonton

Alberta

Calgary

Hythe Field

DU

NVE

G A

N S

HO

RE

LIN

E

BackgroundThe Doe Creek Member of the Kaskapau

shale formation is a light oil-bearing

sandstone associated with the Dunvegan

delta in northwest Alberta. An operator

working in the Hythe area, just west of

Grande Prairie has discovered a new pool in

the Doe Creek formation at 1,000 m with

an estimated 10 million barrels of original

oil in place. Based on analog pools in the

area, the recover factor is expected to be

in the range of 19% and average porosity

and permeability measurements range from

19-23% and 200-700 mD, respectively.

The ChallengeBased on vertical well production, the

Doe Creek formation was classified as

marginally economic. However, with recent

technological advancements in horizontal

drilling, multi-stage fracturing and liquefied

petroleum gas (LPG) fracturing, a junior

operator decided to evaluate the potential

of these transformative technologies to

enhance initial production rates, ultimate

recovery and overall production economics

of the Doe Creek formation.

The SolutionHaving successfully used the StackFRAC®

system to target reserves in the Dunvegan

and deeper Cadomin formations in the

Hythe area, the operator decided to work

with Packers Plus. A 6-stage StackFRAC

system was installed to a total depth of

2,115 m at a total vertical depth of 1,125 m

to target the Doe Creek formation. The

horizontal open hole accessed 950 m of

pay and used gelled LPG to fracture the

formation and place the proppant.

The Results The successful application of multi-stage

fracture stimulation using the Packers Plus

StackFRAC system and LPG fracturing

has achieved economic success from an

interval that was historically only marginally

economic. Overall, this program has validated

these exploitation technologies, which the

company now plans to apply to other areas.

Packers Plus technology opens up a new pool in the Doe Creek StackFRAC multi-stage system enhances production for economic recovery

Packers Plus® Product Overview


Some or all of the systems, methods or products discussed herein may be covered by one or more patents, or patents pending,

including US patent numbers 6,907,936; 7,134,505; 7,108,067; 7,543,634; 7,431,091; 7,021,384; 7,353,878. PRO-21-Dec-09

OverviewThe RockSEAL® II packer is a dual

element, solid body, hydraulic-set open

hole packer that combines the sealing

strength of a mechanical element with

the setting force of a dual-piston cylinder

and mechanical body-lock system. The

packer has a specially designed elastomer

with the largest possible cross section to

provide excellent expansion ratios to set in

oversized holes. The packer is also designed

with anti-preset features that allow it to

be pushed through tight spots in the well

without pre-setting or shearing the packer.

Applications/Benefits• Vertical or horizontal completions

• Open or cased hole

• Isolation of individual zones

• Water and gas shut-off

• Retrievable bridge plug uses

• Production control

• Production testing

OperationThe RockSEAL II packer is run in the open

hole and set via hydraulic pressure. The

elements are expanded by mechanical

compression securing the packer against the

formation. If the packer needs to be retrieved

it can be released with straight pull on the

tubing string, cut to release or other methods

depending upon specific requirements.

Features• Dual element/piston design

• High expansion ratios

• Anti-preset features for running in hole

• Adjustable setting and releasing forces

• Minimum running outer diameter

• Elastomer package available for cased hole

applications

• Available in HPHT and sour service formats

• Various application-specific elastomer types

Advantages• In service since 2000

• Proven isolation through microseismic

mapping

• Dual sealing elements work together as

pressure transfers force from one element

to the other distributing the load and

further energizing the elements

• Not affected by temperature cycling –

the RockSEAL II packer holds 10K even

after a major drop in temperature

• Allows for long-term isolation

RockSEAL II Packer

RockSEAL II Packer

R&D Solutions Pty Ltd. Suite 6, Level 3, 1111 Hay Street , West Perth WA 6005 AustraliaT + 61 8 6140 1820 F + 61 8 9429 3098 ABN No 38 138 827 915

MATRIX

LOW FRICTION ADVANCED POLYMER CENTRALISER

LATEST GENERATION, ADVANCED POLYMER TECHNOLOGY HIGH PERFORMANCE, VERY LOW FRICTION CO-EFFICIENT ULTRA HIGH DENSITY, HIGH ABRASION RESISTANT MATERIAL TOTALLY NON-METALLIC CONSTRUCTION HIGHEST STRENGTH, NON-METALLIC CENTRALISER IN THE INDUSTRY AVAILABLE IN SPIRAL & STRAIGHT BLADE CONFIGURATION THERMALLY STABLE MANUFACTURED IN AUSTRALIA, TO THE HIGHEST ASTM STANDARDS,

IN A NEW, ADVANCED POLYMER MANUFACTURING PLANT


R&D Solutions

Centraliser 4-1/2” for 6” Open HoleSlip on Solid Body Aluminium Alloy

Unit ID 4.625” Sleeve Drift 4.562” Sleeve OD 5.000” Vane OD 5.750” Vane Width 1.000” Vane Degree 27 Degree No of Vane 4 x Spiral Length 8.000” Annulus Area 12.870 Sq Inch Turb Area 4.585 Sq Inch Bypass Area 7.785 Sq Inch Material Alloy Aluminium LM-6


R&D Solutions

7” x 8-1/4” for 8-1/2” Open HoleSlip on ‘Solid Body Steel Centraliser’

Unit ID 7.125” Sleeve Drift 7.062” Sleeve OD 7.50” Vane OD 8.25” Vane Width 1.10” Vane Degree 22 Degree No of Vane 4 x Spiral Length 8.000” Annulus Area 8.261 Sq Inch Turb Area 6.782 Sq Inch Bypass Area as % 62.86 % Material Cast Steel


R&D Solutions

9-5/8” x 11-3/4” for 12-1/2” Open HoleSlip on ‘Solid Body Steel Centraliser’

Unit ID 9.875” Sleeve Drift 9.750” Sleeve OD 10.375” Vane OD 11.75” Vane Width 1.25” Vane Degree 22 Degree No of Vane 8 x Spiral Length 10” Annulus Area 45.099Sq Inch Turb Area 30.272Sq Inch Standoff % 80.95% Bypass Area as % 67.12% Material Cast Steel


R&D Solutions

Bow Spring Centraliser Selection

Hinged Non Welded Hinged Non-Welded Hinged Welded Slip On WeldedSpring Bow Centraliser Stainless Steel Centraliser Bow Spring Centraliser Bow Spring Centraliser

SH01 SS01 SHOP SH03

Hinged Non-Welded Hinged Welded Slip on Welded Welded RotatingBow Spring Turbolizer Bow Spring Turbolizer Bow Spling Turbolizer Centraliser

SH04 SHIM SH06 SH07

MULTIPLE OPTION TYPES AVAILABLE API CERTIFIED FULL ISO TRACEABILITY 9001 – 2000 COMMON SIZES AVAILABLE RANGE OF STOP COLLARS TO SUIT MATERIAL RANGE TO SUIT CASING AND TUBING MADE IN THE REGION


R&D Solutions

Hinged Non Weld Bow Spring Centraliser

Sizes Hole Size No of Bows Height Restoring Force3-1/2” 6” 4 21” 696LBF4-1/2” 6” 4 21” 742LBF5-1/2” 8-1/2” 4 21” 930LBF7” 8-1/2” 6 21” 2150LBF9-5/8” 12-1/4” 6 24” 3300LBF13-3/8” 17-1/2” 8 24” 2450LBF16” 19” 12 24” 2080LBF20” 26” 12 24” 2820LBF

Material Spring Bow ASTM A682/AISI 1600 or EquivalentASTM A366/A569 or Equivalent


R&D Solutions

Centraliser Selection



R&D Solutions

Centraliser Selection

Slip on Slip on Heavy Duty Slip on Heavy Duty Slip On WeldedWelded Centraliser Positive Spiroliser Centraliser Cement Basket

SH12 SH13 SH14 SH15



R&D Solutions

Centraliser Stop Collar Selection

MULTIPLE OPTION TYPES ACCORDING TO REQUIREMENTS SIMPLE INSTALLATION API CERTIFIED FULL ISO TRACEABILITY 9001 – 2000 COMMON SIZES AVAILABLE RANGE OF STOP COLLARS TO SUIT MATERIAL RANGE TO SUIT CASING AND TUBING MADE IN THE REGION


R&D Solutions

Hinged Steel Nail Stop Collars

Sizes Part No Unit ID Max OD Width Sliding Force3-1/2” SC01-0312 3.625” 4.580” 3.543” 4200 LBF4-1/2” SC01-0412 4.625” 5.580” 3.543” 4200 LBF5-1/2” SC01-0512 5.625” 6.580” 3.543 9900 LBF7” SC01-0700 7.125” 7.720” 3.543” 14800 LBF9-5/8” SC01-0958 9.750” 10.74” 3.543” 16600 LBF13-3/8” SC01-1338 13.56” 14.51” 3.543 19400 LBF

Material ASTM A 366/A569 or Equivalent, Press Steel ComponentCoating as per requirement


R&D Solutions

‘Cyclone’ Reamer Shoe

ECCENTRIC SHAPE ALUMINIUM OR POLYMER NOSE CUTTING EDGE SPIRAL BLADES SINGLE OR DUAL FLOAT VALVE OPTIONS COMMON SIZES AVAILABLE “EASY DRILL” INTERNALS, CEMENT AND PHENOLICS MADE IN AUSTRALIA


R&D Solutions

Concentric ‘Bullet Nose’ Guide Shoe

CONCENTRIC NOSE COMMON SIZES AVAILABLE “EASY DRILL” CONCENTRIC POLYMER NOSE THREADS CUT LOCALLY TO MEET REQUIREMENTS MADE IN AUSTRALIA


R&D Solutions

Eccentric Guide Shoe

ECCENTRIC NOSE COMMON SIZES AVAILABLE “EASY DRILL” POLYMER NOSE SINGLE OR DOUBLE FLOAT VALVES AVAILABLE THREADS CUT LOCALLY TO MEET REQUIREMENTS MADE IN AUSTRALIA


R&D Solutions

Cementing Equipment

Float Shoe SH1B Float Collar SH1Q Guide Shoe SH20

MULTIPLE OPTION TYPES ACCORDING TO REQUIREMENTS.

FULL ISO TRACEBILITY 9001 – 2000

COMMON SIZES AVAILABLE

AVAILABLE WITH SINGLE OR DOUBLE FLOAT VALVES

MATERIAL RANGE TO SUIT CASING AND TUBING

MADE IN THE REGION


R&D Solutions

Cementing Equipment

Top and Bottom Plugs with Rotating and Non-Rotating Options.

• COMMON SIZES AVAILABLE.• MULTIPLE OPTION TYPES ACCORDING TO

REQUIREMENTS• FULL ISO TRACEBILITY 9001 – 2000• MATERIAL RANGE TO SUIT CASING AND TUBING• MADE IN THE REGION


R&D Solutions

Float Shoe

TWIN DISCHARGE PORTS RESILIENT PDC DRILLABLE COMPOSITE MATERIAL EASY DRILL ECCENTRIC POLYMER NOSE COMMON SIZES AVAILABLE THREADS CUT TO REQUIREMENTS MADE IN AUSTRALIA


R&D Solutions“Hammerhead” Guide Shoe / Drive Shoe

CAN BE RUN AS A CONVENTIONAL GUIDE SHOE ORHAMMERED IN AS A DRIVE SHOE

“EASY DRILL” POLYMER OR ALLOY NOSE OPTIONS

ECCENTRIC OR CONCENTRIC NOSE AVAILABLE

SPECIFIC SIZES AND THREADS AVAILABLE ON REQUEST

MADE IN AUSTRALIA


R&D Solutions“Hammerhead” Guide Shoe / Drive Shoe

Testing Run Example

SHOE SHOWN WAS RUN AND HAMMERED FOR 15HRS SOLID

NO FAILURE OF THE MAIN BODY OF THE SHOE

SHOE SUCCESSFULLY RECOVERED

MINIMAL BODY DAMAGE OBSERVED

WHEN RUN AS A DRIVE SHOE, THERE IS NO DRILLING OFINTERNALS, ONLY THE NOSE

MADE IN AUSTRALIA

Increasing Tubular

Life & Performance www.maxtube.com

Over 30 years of

proven field history

Rig time & cost

Manpower time & cost

Costly Chemical Treatments

Workover time & cost

Expensive chrome or alloy completions

Design Features Product Description

DUOLINE 20 is a GRE (glass reinforced

epoxy) composite liner engineered with

a special resin system developed

exclusively for Duoline Technologies in

1971.

The DUOLINE 20 liner is manufactured

using a filament winding and high

temperature cure process.

DUOLINE 20 is then inserted inside

carbon steel tubing, combining the high

strength of steel with the inert properties

of fibreglass to provide effective, long

lasting corrosion protection.

DUOLINE provides the following SAVINGS:

API & Premium Downhole Connections

Wireline Resistant

Holiday Free

High Hoop Strength

Special Epoxy Resin

No Special Handling Necessary

Can be installed in New & Used Pipe

Lining can be carried out in any location

Increases tubular life and performance

Cost effective

When corrosion starts in downhole tubing, the string soon fails. The result is downtime and

increased operation costs for workovers and tubing pulls.

The DUOLINE system, developed by Duoline Technologies in 1965, has proven to be the

most successful solution for the prevention of downhole tubular corrosion. The DUOLINE

system ensures the isolation of corrosive oilfield fluids and gases from the steel, thereby

preventing corrosion of steel tubing and line pipe. DUOLINE is the only fibreglass-epoxy lining

system in the market place today with over 30 years of accumulated field history and over

80 million feet installed worldwide.

INCREASING TUBULAR LIFE & PERFORMANCE

Over 80 million feet

installed worldwide

DUOLINE 20 has an outstanding

performance history, both onshore and

offshore, in demanding environments

containing produced fluids and gasses

with CO and H S.

Applications

CO Injection Fields (WAG)

Waterflood Injection Fields

Deep Gas Production Wells

Gas Lifted Oil Production Wells

Shallow Brine Water Disposal Wells

Deep-Hot-Gas Production Wells

Chemical Disposal Wells

Sour Gas Services

Application Criteria

The criteria listed below are the minimum

information required by MaxTube to

select the correct DUOLINE product for

any proposed applications.

Tubing size

Tubing connection

Well fluid

H S content

CO content

BHT

DUOLINE products offer an unsurpassed record for

prevention of corrosion in very demanding conditions.

Performance Capabilities

Temperature: Up to 250 F / 121 C

Working Pressure: Full working pressure of

the lined steel pipe

MaxTube has transformed the DUOLINE

installation process by making it

completely portable with the MaxTube

Portable Lining Units (PLUs). No purpose

built facility is required. MaxTube can line

pipe throughout the world in any location,

including customer’s own yards and

facilities or directly at the mill.

PLU’s Benefits include:

Portable Lining Units (PLUs)

Eliminates the need for pipe to be sent

to specific locations

Reduces transport time and costs

Allows companies to utilise their

existing pipe stock or used pipe

DUOLINE is available in several grades,

including DUOLINE 20 and DUOLINE 35.

All are designed to provide a solution for

all oil and gas field corrosion problems.

In addition, we also offer the revolutionary

Weldshield® system, which allows the

DUOLINE range of lining systems to be

used in welded pipelines and flowlines.

Please visit www.maxtube.com or contact

us for a DUOLINE Selection Form.

Running/ Pulling

DUOLINE products in

the well

Inspection of

DUOLINE stock or

used DUOLINE joints

22

2

2

2

MaxTube's field service:

Duoline has a better flow profile than

steel pipe.

The very smooth internal bore of

Duoline causes much less overall friction

loss than that of new bare steel;

“Hazen & Williams” C-Factor: C=150

API Connections Modified PremiumConnections

www.maxtube.com

Corrosion Barrier Ring - Duoline

Technologies manufactures metal

reinforced elastomer rings for API

Connections.

DUOLINE is available

in several grades

Corrosion Barrier Rings - glass

reinforced PTFE rings are available

for all Modified Premium

Connections.

Premium Connections

The Duoline DL-Ring System is a

revolutionary new system which

allows lining of all Premium

Connections without the need for

modification of the connection

Liner

Grout

Flare

Reference Band

or Mark

Corrosion Barrier Ring

Extended Flare

Standard Flare

Grout

Liner

Corrosion Barrier Ring

B C t

Pipe Size and

Weight/foot

Fibreglass Liner

Inside Diameter

Fibreglass Flare

Inside Diameter

Fibreglass Liner

Nominal Thickness

Normal Lining

Weight lb/Ft

3.2ppf

4.7ppf

6.5ppf

9.3ppf

11.6ppf

15 ppf

18 ppf

15.5ppf

17/20ppf

23ppf

23ppf

26ppf

29/32ppf

60.7ppf

1.500”

1.810”

2.251”

2.750”

3.691”

4.142”

4.010”

4.675”

4.520”

4.395”

6.091”

5.900”

5.800”

9.170”

1.430”

1.750”

2.195”

2.670”

3.600”

4.032”

3.900”

4.550”

4.400”

4.275”

5.976”

5.785”

5.685”

9.010”

0.040”

0.040”

0.040”

0.045”

0.060”

0.065”

0.065”

0.075”

0.075”

0.075”

0.095”

0.095”

0.095”

0.155”

0.40

0.50

0.50

0.80

1.50

1.65

1.65

1.80

1.80

1.80

2.50

2.50

2.50

6.50

2-1/16”

2-3/8”

2-7/8”

3-1/2”

4-1/2”

5”

5”

5-1/2”

5-1/2”

5-1/2

7”

7”

7”

10-3/4”

FG Flare

Premium ThreadAPI ThreadC

t B

Gro

ut

FG

Lin

er

Common DUOLINE Tubing Sizes (other sizes also available)

Maximum Drift Diameter:

For API Connections with Duoline Technologies CBR: 1/4” less than Flare Diameter

For Premium Connections with PTFE CBR: 1/8” less than Flare Diameter

DUOLINE 20 Dimensions and Weights

www.maxtube.com

PO Box 17319

Jebel Ali

Dubai

U.A.E

Tel: + 971 4 881 7712

Fax: + 971 4 881 3354

Email: [email protected]

Riverview Business Centre

Centurion Court

North Esplanade West

Aberdeen

United Kingdom

Tel : + 44 1224 572 222

Fax : + 44 1224 584 488

Email: [email protected]

ANADARKO

AMERADA HESS

BHP

BP

BRITISH GAS

CHEVRONTEXACO

CANADIAN NATIONAL RESOURCES

EXXONMOBIL

KHALDA PETROLEUM

KUWAIT OIL COMPANY

NORSK HYDRO

OCCIDENTAL

PETROLEUM DEVELOPMENT OMAN

QARUN PETROLEUM

SAKHALIN ENERGY INVESTMENTS COMPANY

SAUDI ARAMCO

SHELL

STATOIL

Major DUOLINE users include :

Metal to Metal Seal System

Unit A, Hydropark Tern Place

Bridge of Don Aberdeen AB23 8JX

Tel: +44(0)1224 826827 Fax: +44(0)8704 602155

[email protected]

CaledyneInnovation and Integrity by Design

Introduction

The Caledyne MTM seal has been developed as a direct replacement of traditional rubber sealing technologies on a wide range of oilfield equipment, enhancing the performance of the tools. Initially designed to replace rubber elements on packers and bridge plugs, the applications have been further extended to include liner hangers, sliding sleeves, subsea sealing applications, subsea flange seals, tubing hangers and casing hangers.

The CMTM is fully retrievable and can be fitted to most existing tool chassis. Incorporating an extremely wide operating range and immune to most chemicals, it exceeds the capabilities of elastomeric materials, making it ideal for the future oilfield developments in HPHT and Heavy Oil steam flood. Other typical applications include wells with high levels of H2S and CO2 and well abandonment. When fitted to a standard bridge plug, it will provide a complete metal barrier in the well solving well integrity problems with its extreme durability and reliability.

The CMTM opens up the potential to complete hotter and more aggressive wells using this seal rather than conventional elastomeric seals.

The CMTM has several key advantages over rubber seals:

Temperature rating The design and composition of the CMTM seal provides a standard temperature rating of 316°C (600°F). Outstripping all but the highly fluorinated elastomers and silicones. Higher temp rated seals are available on request.

Chemical compatibilityThe CMTM has an entirely metal outer surface, which comes into contact with the well environment. The metal’s chemical compatibility with well fluids and gases is far broader than an elastomer. The recent industry trend for swelling elastomers, where the affinity of certain elastomeric compounds for oil or water affects their bulk modulus. The incompatibility of the elastomer to the fluid triggers a reaction in the material. While this is desirable in this instance, the thrust of the elastomer development is to make the materials stable in wider ranges of fluids and gases. The individual CMTM seal therefore has a wider potential application than any elastomer equivalent. This provides a further cost saving to operators as a single CMTM is suitable for any well environment regardless of temperature, pressure, chemicals etc radically reducing stock levels.

For example, compatibility with methanol is limited on some commonly used materials. However methanol is used in standard well procedures. If a downhole tool is fitted with an elastomer that is affected by methanol, the options available to the operator are limited for the entire duration that the tool is in their well. Pressure RatingThe CMTM has a standard differential pressure rating of 10,000 psi. By increasing the thickness of the metal skin the CMTM is able to resist higher differential pressures, providing the perfect solution for extreme high pressure development up to 25,000 psi in for example the GOM.

The Caledyne Metal to Metal Seal

Sliding Sleeve

CRBP


SwabbingWhen running tools into a well the run in speed should be as high as possible to reduce the time taken to get the tool to the desired depth. The speed of the fluid rushing past an elastomeric seal can cause the seal to “swab”, to lift or detach from the tool which is also apparent when circulating fluids past a downhole tool for cementing or well clean up operations. Due to the metal construction of the CMTM this can not happen, resulting in increased run in speed and improved well cleanup operations. This becomes particularly apparent on applications such as liner hangers, where the running clearance is minimal and the cross section available for the seal is small to give a large through bore on the tool. Liner Hangers still require high circulating rates during cementing and well clean up to generate turbulent flow increasing the fluid velocity and making the CMTM an ideal candidate for installation on liner hangers.

RetrievabilityThe CMTM seal offers improvements in retrievability over both conventional elastomer packer seals and solid metal seals. Elastomers, as a natural product are susceptible to age hardening. In certain downhole applications, with high or moderately temperatures, this process is accelerated and an elastomer seal can get “cooked” with the seal hardening in the expanded position. In cases where the seal is set below a tubing restriction, this makes recovery difficult. When the tool is released, it is expected that the “memory” inherent in the elastomeric material makes the seal return to its original shape, allowing it to be easily pulled out of the well.

The CMTM seal is retrieved by stretching it out, pulling through the metal skin. While some elastomer seals are connected to the structure of the retrieval mechanism of the tool, pulling through a hardened rubber seal may result in the seal disintegrating. This regularly results in parts of the rubber seal being lost downhole during the retrieving process potentially causing problems or blockages later on in the well life.

A recent example of the CMTM’s integrity was the retrieval of a Caledyne Retrievable Bridge Plug for Talisman in Malaysia with large amounts of debris on top. The amount of debris was of such an extent that the operator had to mill through the debris to reach the plug. Once this was achieved the plug was retrieved and the CMTM retracted leaving no further debris in the well.

As the CMTM seal has a lower setting load than solid metal seals, it also has a lower retrieving load allowing the seal to be retrieved with industry standard tools.

Applications

The seal can be fitted to virtually any oilfield tool. It has an extremely wide operating range and provides a durable and reliable sealing solution regardless of changing donwhole conditions, temperature, pressure and the concentration levels of H2S and CO2. Initially designed to replace static elastomeric elements it is now finding solutions in dynamic applications as a replacement of v-packing stacks in sliding sleeves, PBRs and seal stems.

Other applications for the CMTM are away from the downstream oilfield market segment. They include sealing solutions for compressors, chemical storage tanks, water boilers and storage tanks and even the automotive industry has shown an interest. It is not unthinkable that as we move further into the 21st century and technology requirements change, the Caledyne Metal-to-Metal seal has the potential to supersede all elastomeric sealing technologies across a wide range of industries.

Experience

The Metal seal is still regarded as a new technology which is rapidly gathering a track record. The seal is sold either independently to service companies utilising it on their own downhole tools or by Caledyne as part of a full assembly, mainly bridge plugs and packers. The current size ranges available are 5”, 5.1/2”, 6.5/8”, 7”, 7.5/8” and 9.5/8” with further sizes under development. Operators that have been most supportive of the technology and are front runners in utilising it are BP, Shell, Chevron, Total and Talisman although a number of smaller operators are also successfully utilising the technology in the North Sea, mainland Europe, CIS and Canada.

Caledyne Packer

Crown Plug

FACT053© Caledyne 2009

Metal to Metal Seal SystemThe Caledyne Metal-to-Metal seal system gives a large performance envelope across a wide range of environments. By avoiding the use of elastomers within the seal system, temperature limitations and chemical compatibility concerns are no longer an issue. The standard element will have a maximum temperature rating of 300 deg Celsius and a pressure rating of 10,000 psi, but higher pressure and temperate ratings can be achieved with minimal modifications.

Key Benefits

Seals on mandrel and casing providing a true metal-to-metal seal

Simple construction. The sleeves act as a backup system to the flexible core

The composite design avoids the problems with purely metal structures, which require high activation loads

Setting loads within the range of standard setting tools

Certification

Each Caledyne design undergoes a comprehensive internal qualification programme prior to release to a customer.

For further details of our test programme please contact your nearest Caledyne representative

Application

Permanent and retrievable packers

Permanent and retrievable bridge plugs

Liner Hangers

Water shut off

Sliding Sleeves

Crown plugs


Issue A Prepared by: DLS Number:

Date 11/01/10 Approved by: MRM Technical Manual

0000007019

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1 © �� 2010 T18 issue 1

High Expansion Shifting Tool Size: 3.000” Description

The Caledyne High Expansion Shifting Tool (HEST) is an ultra slim shifting tool, which may be used to operate down hole tools having a significantly larger ID than the restriction above. The HEST is run and operated on coil tubing. Various key sets may be used to configure the tool to operate in profiles from 5” to 6” tubing.

Key Benefits Keys expand out to all 5” to 6” nominal profiles. Bi-directional key sets. No need to modify the tool for open/close operations. Field replaceable choke nozzle to vary pump pressure required to activate keys. Emergency shear facility to collapse keys if the keys do not retract.

Applications Coil Tubing deployed shifting tool

Certification

In house qualification programme. Any particular customer requirements may be accommodated in the development process. We welcome customer involvement in the qualification programme. Contact Caledyne for details.



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2 © �� 2010 T18 issue 1

Technical Specification

Parameter Value To set in tubing size 5“ – 6”

ODmax 3.000” (76.20mm) IDmin N/A

Length 53.6” (1.36m) Top connection 1.500” AMMT

Bottom connection Bullnose Metallurgy AISI4140-45 18-22Rc 80ksi per NACE MR0175 Elastomer VITON 70HD

Temperature range 32-250°F (0-121°C) Tensile 82,650 lbf

Bill of Material Item Description Qty Part number

1 Top Sub 1 0000007018 2 Piston Chamber 2 0000007017 3 Piston 2 0000007014 4 Shear Mandrel 2 0000007013 5 Shear Sub 2 0000007012 6 Main Housing 1 0000007016 7 Return Spring 6 0000004184 8 Flow tube 1 0000007010 9 7.0mm Orifice 1 0000007011 10 Bottom Sub 1 0000007015 11 ¼” UNC Set Screw x 3/16” Long 4 0000005225 12 ¼” UNC x ¼” Long Brass Shear Screw 24 0000001371 13 Size 113 V75 O-ring 2 0000005349 14 Size 117 V70 O-ring 1 0000004774 15 Size 225 V70 O-ring 2 0000001540 16 Size 228 V70 O-Ring 2 0000002928 17 Key Set 1 REFER TO TABLE

Sundry Equipment

N/A Redress Kit F/3.000” HEST - 0000007355

N/A Test Kit F/ 3.000" HEST W/ AMMT BOX - 0000011111

N/A Orifice W/ 5mm dia hole - 0000011110




N/A ¼” UNC x ¼” Long Mild Steel Shear Screw - 0000003022



0000007019

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3 © �� 2010 T18 issue 1

Assembly

Shifting profile

‘B’ ‘CM’

4.000” - - 4.125” - - 4.312” - 4.562” 0000007319 0000007025 5.250” - -



0000007019

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4 © �� 2010 T18 issue 1

Assembly & Factory Acceptance Test Procedure Prior to assembly, all parts should be checked for burrs, swarf or any signs of excessive wear or damage. Pay particular attention to threads and seal surfaces. A suitable grease such as Shell Albida should be used to aid assembly.

1. Assembly

a. Grip Main Housing (item 6) in a suitable vice at either end leaving the slots clear.

b. Assemble the Upper and Lower Keys into sets by inserting 2 of the Return Springs (item 7) through the end windows on each key to locate in the Key slots.

c. Feed upper end of Upper Key through slot and feed up into Main Housing bore far enough to allow lower end of Lower Key to be inserted into lower Main Housing bore. Centralize Keys in slot. Repeat until all Key sets are in position.

d. Feed Flowtube (item 8) through Main Housing and Upper and Lower Keys until it is approximately centralized.

e. Assemble two sets of shear subassemblies by assembling Shear Mandrels (item 4) to Shear Subs (item 5) with Shear Screws (item 12). The load to shear off in case of emergency is set at this point. Shear screws can be left out to define shear load. NB. Only one shear subassembly will shear.



0000007019

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5 © �� 2010 T18 issue 1

f. Insert the shear subassemblies over the ends of the Flowtube and into the upper and lower ends of the Main Housing to butt against the ends of the Keys.

g. Make up Piston Chambers (item 2) to upper and lower end of Main Housing and retain with Set Screws (item 11).

h. Assemble O-rings (items 13 & 15) to Pistons (item 3) and fit Pistons over ends of Flowtube and into Piston Chambers.

i. Fit O-ring (item 16) to Top Sub (item 1) and make up to upper end of Main Housing and retain with Set Screw (item 11).

j. Fit O-ring (item 14) to Orifice (item 9) and insert into Bottom Sub (item 10).

k. Fit O-ring (item 16) to Bottom Sub and make up to lower end of Main Housing and retain with Set Screw (item 11).

�� Factory Acceptance Testing�

a. Assemble as per assembly instructions above, replacing the Orifice (item 9) with the Test Plug.

b. Make up the 1.500” AMMT Test Cap and connect to the test pump.

c. Slide the appropriate Gauge Ring for the required Key Set over the body of the tool.

d. Apply pressure and monitor to ensure HEST Keys inflate correctly and lock into the Gauge Ring.

e. Bleed off pressure and disconnect from pump and remove test cap.

�� Reassemble with the correct Orifice.��

�� Disassembly�

a. Disassembly is the reversal of the assembly procedure.

b. When disassembling the tool, set screws must be removed before attempting the break a connection.

c. The seals and shear stubs should be disposed of. Visually inspect all parts for any signs of damage, deformation or wear. Replace any damaged or worn parts and all seals.

4. Shipping/Storage Preparations

• Fit thread protector to the upper connection.

• Place in a suitable shipping crate. Ensure that Silica Gel is included in the crate.



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6 © �� 2010 T18 issue 1

Care and Maintenance

1. The tool should be stored in a dry warehouse environment and protected from possible damage and corrosion until it is required for use. The tool should be inspected before dispatch to rig-site and before deployment.

2. After the tool has been used, it should be stripped, cleaned and inspected then rebuilt using the appropriate redress kit (0000007355).

3. O-rings should be replaced every 9 months regardless of use.

Operational Procedures

These procedures are for guidance only and all operational requirements for a particular application should be considered in advance and incorporated into a suitable programme of operations.

1. Assemble HEST to appropriate coiled tubing BHA.

2. Prior to running in hole circulate through coil to confirm operation of HEST and establish circulation pump flow-rate and pressure required to inflate the Keys fully (the orifice size may be changed and retested if required).

3. RIH as per standard coiled tubing procedure.

4. When approaching target depth, slow down running speed and begin pumping to inflate HEST.

5. Pick up and set down to establish drag weights.

6. Run to target depth and monitor for increase in loading when profile is located.

7. Shift profile sleeve up or down as required.

8. Reduce circulating rate to deflate HEST.

9. Re-inflate HEST and run through profile in required shift direction to confirm shift if desired.

10. Deflate HEST and POOH.

Contingency Measures HEST does not auto-release

1. In the event that the tool does not auto-release, the tool may be sheared out by pulling/pushing to shear the shear screws and then pulled to surface (see assembly instructions for shear load).



0000007019

��

7 © �� 2010 T18 issue 1

Operational Calculations

The chart on the previous page depicts typical working flow rate values for a 3.0” HEST. The chart is read by finding the point where the operating (black) line intersects with the orifice size being used and reading across to see the estimated flow rate required to run the HEST. These charts change with different key sizes, fluid viscosity, temperature, etc so should only be used as a rough guide.

This is an approximate guideline only, prior to every job, it is recommended to follow the procedures below.

1. With the gauge ring around the HEST, start and increase the pump rate until the keys are fully inflated and the gauge ring is secure but still free to move, record this pump rate in the box provided.

2. Continue increasing the pump rate until the keys over expand and lock the gauge ring solid, record this pump rate in the box provided.

3. To work out the optimal running pump rate use the equation.

Running pump rate = inflation pump rate + [(maximum pump rate - inflation pump rate)/4].

Enter the running pump rate in the box below

Running pump rate

BBL/min

For example:

5mm Orifice

Inflation pump rate Maximum pump rate

.07 BBL/min 0.32 BBL/min

Recommended running pump rate = inflation pump rate + [(maximum pump rate - inflation pump rate)/4].

= 0.07+(0.32-0.7)/4 = 0.13 BBL/min

Running pump rate

0.13 BBL/min

Inflation pump rate Maximum pump rate

BBL/min BBL/min

Caledyne Ltd Innovation and Integrity by Design

Caledyne Limited Registered in Scotland SC249478

Tool Location Application CommentNumberof Runs

HEST Brazil Open/close CBVCustomer purchased tool, third partydeployment

TBC

HEST CanadaSIT. Open/Close SlidingSleeves

Open and close 5 times each way.Successful deployment.

5

HEST CanadaOpen/close slidingsleeves

Successful deployment 1






Third party deployment, keys assembledback to front. Key buckled under excessiveloading. All components retrieved fromwell. No requirement for fishing.

1


Successful deployment w/ replacementkeys

1














Customer purchased tool, third partydeployment

TBC

HEST KuwaitOpen/close slidingsleeves

Standard tool dressed with brass shearscrews. Load to open sleeves too high. Toolsheared out.

1


Standard tool dressed with brass shearscrews. Load to open sleeves too high. Toolsheared out.

1


Dressed tool with steel screws. Successfuldeployment. Max load for coil applied.Sliding Sleeve stuck. All equipmentretrieved.

1



1



1

Caledyne Ltd Innovation and Integrity by Design

Caledyne Limited Registered in Scotland SC249478



1


Dressed tool with steel screws. Successfuldeployment. Sleeve opened successfully.All equipment retrieved.

1


Dressed tool with steel screws. Successfuldeployment. Sliding Sleeve stuck. Allequipment retrieved. Job cancelled due tostuck sliding sleeves.

1

HEST North Sea Contingency RequirementCustomer purchased tool, third partydeployment

TBC

HEST Thailand Contingency RequirementCustomer purchased tool, third partydeployment

TBC

HEST ThailandOpen/close slidingsleeves










HEST UKSIT. Manipulation ofMIV/CBV.

Open and close 5 times each way.Successful deployment.

5

HEST USAOpen/close slidingsleeves
















HEST USA SIT. Manipulation of CBV.Open and close 5 times each way.Successful deployment.

5

Issue A Number:

Date 13-04-10 Product Information Sheet

0000011673

��

© �� 2010 Page 1 of 2 www.caledyne.co.uk

Caledyne Indexing Muleshoe

Size 5-1/2” 17# Description The Caledyne Indexing Muleshoe facilitates stab in of seals into seal bores, even in deviated wells. The work string does not need to be rotated to orientate the muleshoe. Axial movement of the work string against an obstruction rotates the muleshoe. If it still fails to enter the bore, the work string is lifted to re-engage the internal j-mechanism and the muleshoe will again rotate when set down load is applied.

Key Benefits Protected Spring. Spring is not exposed either in the inner or outer portion of the tool. Spring cannot be overstressed, as set down weight is taken through a load shoulder in the tool. Internal bearings prevent spring wind-up during the indexing process.

Application • Stabbing in seals into seal bore in deviated wells.

Certification Consult your Caledyne representative.

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Issue A Number:


0000011672

��


Caledyne Indexing Muleshoe

Size 7” 29# Description The Caledyne Indexing Muleshoe facilitates stab in of seals into seal bores, even in deviated wells. The work string does not need to be rotated to orientate the muleshoe. Axial movement of the work string against an obstruction rotates the muleshoe. If it still fails to enter the bore, the work string is lifted to re-engage the internal j-mechanism and the muleshoe will again rotate when set down load is applied.

Key Benefits Protected Spring. Spring is not exposed either in the inner or outer portion of the tool. Spring cannot be overstressed, as set down weight is taken through a load shoulder in the tool. Internal bearings prevent spring wind-up during the indexing process.

Application • Stabbing in seals into seal bore in deviated wells.


Issue A Number:


0000011672

��


Illustration 0000011672

Technical Information

Parameter Size 7” BOM Top Connection 7” 29# VAM TOP HT pin Item Description

Lower Connection ½ muleshoe 1 Spring Maximum OD 189.23 (7.450”) 2 J-Pin

IDmin 156.03mm (6.143”) 3 Body Length (open) 1060mm (41.7”) 4 Muleshoe

Set-down rating 325,000lb 5 Plain Bearing Metallurgy 13% Cr. 80ksi

Unit A, Hydropark Tern Place, Denmore Road Bridge of Don, Aberdeen AB23 8JX Tel: +44(0)1224 826827, Fax: +44(0)8704 602155, http://www.caledyne.co.uk

Rev - AFACT SHEET - 055Copyright 2009


Caledyne Balance PumpThe Caledyne Balance Pump is a hydraulically actuated reciprocating low volume pump, which may be used to remove water from gas producing wells. The pump is operated by two hydraulic lines, one oil filled, the other water filled. At the pump, the differential hydrostatic pressure between the water and oil acts to move the internal piston downwards. Application of pressure to the oil line drives the piston upwards, lifting the water trapped above the travelling check and drawing water into the lower chamber.

®

Key Benefits

Simple construction. Static and travelling check valves are used to lift the water.

Check valve ball, seat design and materials mirrored on standard rod pump applications.

The travelling check valve is operated by two control lines, mounted concentrically or side-by-side.

Certification

Consult your Caledyne representative for details on type approvals.

Application

Low Volume Gas well de-watering

Parameter 2.2" Balance PumpUpper Connection Compression fittingLower Connection N/AMax OD 2.2"Length 82"Temperature Range

100C

Elastomer VITONPressure Rating 5000 PSIMetallurgy As RequiredMax Production Depth dependent, 10 bbls/day

nominally


Contact Caledyne for details on all available sizes and Technical Manuals

Oil LineWater Line

Water

Oil

Travelling Ball

Standing Ball

Sand Screen

Anti lockShroud

Portable Surface Actuator

Caledyne

The surface control unit is a low voltage, compact unit that minimises the footprint at surface. Key features include:• 24V Electric Motor• 5,000psi Pump Pressure• Atex approval• Powered by rig supply, gas, air, solar power, wind power• Compact size for minimum footprint• Automatic adjustment of cycle time based on gas/water production ratesAdditional features include:• Automatic Optimization• Remote Access to control system• RS232 Digital Output

Balance Pump



Tel: +44(0)1224 826827 Fax: +44(0)8704 602155

[email protected]


Caledyne Balance PumpThe Caledyne Balance Pump is a hydraulically actuated reciprocating pump, which may be used to remove water from gas producing wells. It can also be utilised in low volume oil producing applications as a direct replacement for rod pumps in deep or deviated wells (See FACT-062) The pump is operated by two hydraulic lines, one oil filled, the other water filled. At the pump, the differential in hydrostatic pressure between the water and oil acts to move the internal piston downwards. Application of pressure to the oil line drives the piston upwards, lifting the water trapped above the travelling check and drawing water into the lower chamber.

Key Benefits

Zero tubing wear from rod movement in deviated sections.

Can be installed deeper than most standard pumps.

Shearable connection to umbilical in event that the pump gets stuck during retrieval.

External fishing neck to facilitate fishing.

Gas anchor included to eliminate gas locking.

Sand screen to filter larger particles from intake

Low friction, wear resistant seals with excellent fluid compatibility to increase pump life

Certification

Consult your Caledyne representative for details on type approvals.

Application

Low volume gas well dewatering

Low volume oil production (See FACT-062)

Parameter 2.25” Balance PumpOD 2.25” (57.15mm)Length 228” (5795mm)Upper Connection 1.375” External Fishing NeckLower Connection N/APressure Rating 5,000psiTemperature Rating

Dependent on Elastomer Selection

Max Production Depth Dependent – 12bbls/day @ 10,000ft



Oil LineWater Line

Water

Oil

Travelling Ball

Standing Ball

Sand Screen

Gas Anchor

®


Umbilical

The balance pump is driven from surface using encapsulated control lines. Two control lines provide hydraulic power to the pump and a conduit for the produced water to return to surface. A high-tension cable is included to take the weight of the control lines, encapsulation, balance pump and fluids.

The umbilical can take the form of flatpack – with the lines side-by-side – or cylindrical – with the lines helically wound to ensure simplified spooling.

Parameter 2.25” Balance Pump UmbilicalEncapsulation Type Flatpack CylindricalOverall Dimensions 2.087” x 0.867” (53mm x 22mm) 1.5” OD (38.1mm)

Encapsulation Material PolyolefinControl Line Size 5/8” x 0.080” wall thicknessControl Line Material 316Ti stainless steel welded, calibrated and annealed tubeCable Details 16mm OD galvanised or PVC coated

Components Standard Environment Corrosive Environment Severe Corrosive EnvironmentManufactured Metalwork

AISI 4140-45 18-22Rc L-80

AISI 420 18-22Rc 13%Cr Inconel 718

API11A Components

Carbon Steel & Stainless Steel

Stainless Steel & Cobalt Alloy or Titanium Carbide

Tungsten carbide & Nickel Carbide or Silicon Nitride

Fittings Carbon Steel 316 St. Stl. MonelElastomer Viton Viton AflasPlastic Turcon T-19 Turcon T-19 Turcon T-19

Material Selection

Surface Termination

In gas well deliquification installations, the balance pump is suspended from surface by the umbilical. The umbilical is supported at surface using inward facing slips that clamp onto the control lines and cable. This mechanism is situated in a hanger designed to land in a nipple profile – either the back pressure valve profile, or a profile in a new spool piece. Exact details of the system will be dependent on the existing surface infrastructure at the well site. Please contact Caledyne to discuss in greater detail.

Encapsulated Control Line

Dual Control Line Hanger

®


Optional Control and Reporting Systems

Control systems can be included as an optional extra on request. Pressure sensors and flow meters monitor the pump performance to ensure that the pump is not run dry and to detect leaking seals in the hydraulic system triggering warning systems on site or reporting to remote locations. The unit can be linked in to the operators production systems allowing remote monitoring of pump performance and giving the operator the option to stop/start the pump on demand as well as remote emergency shutdown. Contact Caledyne for details.

Parameter 2.25” Balance Pump Surface Control UnitOverall Dimensions(SCU)

L = 1m, W = 1m, H = 1m

Overall Dimensions(Accumulator Bank)

L = 0.9m, W = 0.75m, H = 2.7m

Reservoir Volume 100LAccumulator Volume(Per Bank)

54 @ 6,000psi

Minimum Air Requirements

260scfm @ 125psi 123L/s @ 8.6bar

Minimum Power Requirements

400V, 3 phase, 20kW

Surface Control Unit

A Surface Control Unit provides the hydraulic power to actuate the Balance Pump. The unit can be hydro-pneumatic - comprising of dual air driven pumps, or electro-hydraulic - comprising of a single motor driven pump, charging a separate accumulator bank, which in turn provide the pressurised hydraulic oil to downhole. Hydraulic oil is circulated from a reservoir within the unit. Automatic timer valves are manually adjustable to optimise the Balance Pump cycle time for each well.

The unit is built into a certified frame for lifting/handling. Pressures within the system are displayed on panel-mounted pressure gauges and all switches are covered to eliminate accidental operation of the system. An ESD switch cuts off the power or air supply to the unit, closing off all valves to downhole and bleeding all pressure from the accumulator bank and manifold to the reservoir to ensure safety for those working in the immediate area.

Key Benefits

All components certified to the appropriate Atex Zone Ratings, Pressure Equipment Directive and Machinery Directive

Adjustable timer valves to optimise cycle time limit for each well

Certified frame for ease of handling

Separate Accumulator bank for ease of handling. Accumulator banks can be stacked dependent on system requirements for each well.

Panel mounted operator controls and pressure gauges

Pumps are sized to run at optimum level minimizing wear and extending pump life.

Emergency Shutdown System closes all valves to downhole and bleeds all pressure to the reservoir for safety.

Optional offsite communication to allow adjustment of cycle times and system monitoring

System monitors water production rate and hydraulic circuit pressure to detect leaks and put the system on stand-by if water level drops below pump intake.

Tel: +44 (0) 1224 826827Email: [email protected]: www.caledyne.co.uk

Caledyne LtdUnit A, HydroparkTern PlaceBridge of DonAberdeenAB23 8JX

Surface Control Unit


®


FACT-061-SP-ACopyright 2009

Subsurface Barrier Valves

Parameter 3-1/2” x 7” 4-1/2" x 7-5/8" 5-1/2" x 9-5/8" 5-1/2" x 9-5/8" (Large Bore)

OD max 5.515”(140.08mm)

6.027"(153.08mm)

8.043"(204.28mm)

8.378"(212.8mm)

ID min 2.824”(71.73mm)

3.247"(82.47mm)

4.561"(115.85mm)

4.747"(120.57mm)

Upper Connection 3-1/2” 9.2# NEW VAM Pin 4-1/2" 15.1# NEW VAM Pin

5-1/2" 23# NEW VAM Pin 5-1/2” 23# NEW VAM Pin

Lower Connection 3-1/2” 9.2# NEW VAM Pin 4-1/2” 15.1# NEW VAM Pin

5-1/2” 23# NEW VAM Pin 5-1/2” 23# NEW VAM Pin

Pressure Rating across Ball

5,000psi 5,000psi 5,000psi 5,000psi

Pressure Rating across Housing

10,000psi 10,000psi 10,000psi 10,000psi

Temperature Rating

0-150 °C

Tensile Rating (80 ksi Material)

172,500lbf NEW VAM Yield

(1.2 F of S)


(1.2 F of S)


(1.2 F of S)


(1.2 F of S)

Metallurgy AISI 4140-45 18-22 Rc 80ksi / AISI 420 18-22Rc 80 ksi 13%Cr / Inconel 718 (UNS N07718) / per NACE MR0175

Elastomer As required, Viton as standard

Ball seat Proprietary PEEK compound

Technical Information for MIV and CBV

Ancillary Equipment

The following section details shifting tools that can be used to manipulate all of the valves covered in this brochure

1. The Caledyne High Expansion Shifting Tool (HEST) is an ultra slim shifting tool, which may be used to operate down hole tools having a significantly larger ID than the restriction above. The HEST is run and operated on coil tubing.

Various key sets may be used to configure the tool to operate in common sizes of profiles from 2-3/8” to 5-1/2” tubing.

2. The Caledyne WP shifting tool is designed to engage with a shifting profile in a down-hole tool. The spring-loaded keys collapse through restrictions and fully expand to engage the relevant profile. Once the tool has been shifted the keys auto release from the profile. The tool has a shear out facility in the event that the down-hole tool cannot be actuated. The large through bore allows for fluid to be circulated through the tool, making it ideal for use on wash strings.

The WP shifting tool is designed to operate in Otis B style profiles, but keys can be provided for alternate profiles.

3. The MIV/CBV Stinger is fitted to the bottom of the upper completion and is used to lock open the MIV/CBV in the same trip as installation of the upper completion. It will automatically close the MIV/CBV when removed.

1 2 3



Tel: +44(0)1224 826827 Fax: +44(0)8704 602155

[email protected]


FACT009© Caledyne 2009


Introduction Caledyne have a wide range of sub surface barrier valves that can be split into two main product lines. The Fluid Loss Valve is an unidirectional barrier, designed to hold pressure from above. The Mechanical Isolation Valve and Completion Barrier Valve are bidirectional barrier valves, forming a complete barrier in the well. The Fluid Loss Valve (FLV) is an ISO28781 type AA valve used to hold pressure from above and used in pre and post-production pressure applications such as to protect the formation when the pump is switched off. The Mechanical Isolation Valve (MIV) and Completion Barrier Valve (CBV) are ISO28781 type BB valves used to hold pressure from below and used in pre and post-production pressure applications such as isolating lower completions.

Mechanical Isolation Valve / Completion Barrier Valve (patent applied for) Description

The Caledyne Mechanical Isolation Valve (MIV) is a mechanically actuated ball valve, which may be used to isolate the formation during installation of the upper completion or other such operations. The valve is actuated by a shifting tool, which may be attached to the lower end of a wash string. When the wash string is removed, the valve is then automatically closed. The shifting tool may be re-orientated and used to open the valve. Alternatively, a stinger attached to the upper completion, which opens the valve when the upper completion is installed, may actuate the tool. When the upper completion is removed, the stinger automatically closes the valve as it is being removed. An equalising feature may be incorporated to ensure pressure is balanced across the ball prior to opening. The Caledyne Completion Barrier Valve (CBV) is a variant of the MIV which features a remote opening mechanism allowing the CBV to be opened remotely by applying tubing pressure cycles, which actuate an opening mechanism at the top of the tool. The CBV may be mechanically opened and closed with a shifting tool both before and after it is cycled open.

Key benefits

Bi-directional seal acts as a down hole barrier.• Forces due to pressure differentials across the ball do not affect the open/close • mechanism or the remote opening module.Equalising feature operates across the ball and does not equalise to the annulus, • therefore the MIV/CBV may be run above a packer.Unlimited mechanical open or close cycles.• Optimised design to reduce part count and complexity.• Smooth internal bore with a minimal number of locations for debris to collect.• Remote opening module can be replaced for different actuation modules or to vary the • number of pressure cycles to open.Multiple remote opening modules may be fitted without increasing the tool length, • giving full redundancy across this part of the tool.Remote opening mechanism can be independently tested prior to assembling inside • the valve.

Applications

• Formation isolation when installing the upper completion• Packer setting valve• Bi-directional barrier valve• Fluid loss valve• Well suspension

Parameter 69 x 125 mm 3 1/2" x 7" SC 3 1/2" x 7" 4 1/2" x 7 5/8" 5 1/2" x 9 5/8"Maximum OD 4.924"

(125.08mm)5.200"

(132.08mm)5.500"

(139.70mm)6.000"

(152.40mm)8.349"

(212.06mm)

Minimum ID 2.713"(68.91mm)

2.874"(73.00mm)

2.874"(73.00mm)

3.250"(82.55mm)

4.75"(120.65mm)

Length 67”(1702.0mm)

69”(1752.6mm)

69"(1752.6mm)

78"(1981.2mm)

109"(2768.6mm)

Upper connection 3 1/2" 9.2# premium box

3 1/2" 9.2# premium box



5 1/2" 17# premium box

Lower Connection 3-1/2" 9.2# premium pin

3-1/2" 9.2# premium pin

3-1/2” 9.2# premium pin

4 1/2" 12.6# premium pin

5 1/2" 17# premium pin

Pressure Rating 5000psi

Temperature Rating 0-150 °C

Maximum hang off weight 46,500lbf 44,500lbf 214,500lbf 118,000lbf 192,000lbf

Metallurgy AISI 4140-45 18-22 Rc 80ksi / AISI 420 18-22Rc 80 ksi 13%Cr / Inconel 718 (UNS N07718) / per NACE MR0175

Elastomer As required, viton as standard

Ballseat Peek compound

Technical Information for FLV

Caledyne FLV

Description

The Caledyne Fluid Loss Valve (FLV) is designed as a cost effective solution for ESP completions, to protect the formation when the pump is switched off. Installed below the pump, the FLV is open when the pump is in operation and closes as soon as backflow activates the piloting mechanism. A lock open facility gives the option to carry out operations below the FLV.

Key Benefits

Proven technology. The primary seal is a ball, with a non-elastomeric ball seat.• Optimised design to reduce part count and complexity.• Secondary dome seal pilots from open to closed to form a temporary restriction to activate the • primary seal.Lock open facility to allow bull heading or intervention.• Minimal pressure drop. The piloting mechanism is effectively invisible when producing.• Pull up to open and close facilitates use of coil tubing to lock open and reset the FLV.•

Applications

Installed in conjunction with ESP completions. When the pump is off, backflow activates the FLV, • preventing fluid loss into the formation and loss of fluid in the pump.Under-balanced drilling. The valve allows the completion to be installed without causing damage • to the formation.Packer setting. The FLV is installed below a hydraulically set sump packer. Pressuring up the • tubing against the FLV sets the packer.

Contact Caledyne for details on all available sizes and Technical Manuals FLV CBV MIV

Issue A Number:


0000011767

��


Hydraulic-Set Tubing Anchor Catcher

Size 5-1/2” 15.5#-17# x 2-7/8” 6.5# Description The Caledyne Hydraulic-Set Tubing Anchor Catcher is a retrievable anchor catcher designed to hold the tubing string in tension or compression. No tubing manipulation is needed to set the anchor. Applying tubing pressure against a temporary plug run below the anchor catcher sets the catcher. Once set, bi-directional slips anchor the tubing to prevent upward or downward movement during rod-pumping and to prevent tubing from falling should it part. The anchor catcher is released by straight pull shear. Key Benefits

• Sets in tension or compression • Bi-directional slips anchor the tubing to prevent upward or

downward movement • Straight-pull shear release • Simple design

Application

• Rod pump installations • To anchor tubing in tension or compression

Technical Data

Size 5-1/2” 15.5#-17# x 2-7/8” 6.5# ODmax 4.508” (114.50mm) IDmin 2.441” (62.00mm)

Length 58” (1476mm) Metallurgy AISI 4140-45 18-22Rc L-80 Connection 2-7/8” 6.5# EU-E Box x Pin


FACT-050-ACopyright 2009


Metal to metalRetrievableBridge Plug300°C -10,000 psi - Any environment



Tel: +44(0)1224 826827 Fax: +44(0)8704 602155

[email protected]




1. Retrievable Bridge Plug 2. Setting Adaptor3. Setting tool4. Pulling Adapter5. CDIV-2 Injection Valve6. Gauge Hanger

The Caledyne Retrievable Bridge Plug (CRBP) is a product, which provides new levels of integrity and ease of retrieval in the area of well plugging. The patented metal expanding seal is the core of the design, giving a large performance envelope across a wide range of environments. By using this seal, the CRBP becomes a complete metal barrier, i.e. it does not use an elastomeric packing element to form the seal against the tubing.

2 4

5

1

6

3

Key Benefits

•The CRBP chassis design uses proven design features such as caged slips, a body lock ring to lock in setting forces, simple body construction to ensure maximum reliability and ease of use and an equalising port to facilitate retrieval.

•The simple equalizing assembly, utilising an industry standard premium connection has only one potential leak path, incorporating a metal-to-metal seal.

•The plug utilises industry standard setting tools, such as the BOT E4-20. The only requirement is that the setting tool must be capable of imparting sufficient load to shear off the setting adaptor.

Certification

As per customer requirement, typically ISO 14310 level V3.

Application

•Well plugging or temporary abandonment.•Gauge hanging•Injection wells in corporation with the Caledyne CDIV-2 Injection valve •Screen hanging



Installation and RetrievalThe CRBP is installed and retrieved using industry standard tools such as the Baker Oil Tools E4 pyrotechnic setting tool or the Omega hydrostatic setting tool. Caledyne adapter kit standard E4 interface to cross over to the CRBP.

Suitable Setting Tools BOT E4-20 • Omega hydrostatic setting tool • SLB CPST • Halliburton DPU• Any hydraulic setting tool with an • E4 style interface and at least 8” of stroke, capable of producing at 55,000lbs setting force

Adapter KitsThe setting adapter kit is made up to the setting tool and stabbed into the CRBP. An adjustment ring is then used to remove any slack between the CRBP and the setting tool.

The retrieval adapter kit switches over the motion to release the CRBP fishing neck, release the slips and stretch out the sealing element. Using a power setting tool to retrieve the CRBP greatly simplifies the overall design, as there is no requirement for an anchoring point to the casing to release the CRBP and stretch the sealing element.

Caledyne CDIV-2Caledyne developed the CDIV-2 in response to industry requests to provide a water injection valve at a reasonable cost, but with improved functionality over rate dependent tools. The CDIV-2 is a poppet piloted valve, which has a flapper as the primary seal. It is non-rate dependent, has no flow restricting choke and is fully field redressable.

The award winning Metal-to-Metal seal (Winner of the 2009 Hearts E&P Meritorious Award for Engineering Excellence in the Increased Oil Recovery category) replaces standard elastomeric packing elements with a full metal-to-metal barrier in the well. The standard seal has been designed to operate in well environments up to 315°C (600°F) and 15,000psi differential pressure, as well as being completely inert to the vast majority of well fluids. The seal can be manufactured from alternative materials/fillers in order to further expand this working range.

Ancillary Equipment

Tubing size OD max (in) ID min (in)2-3/8” 1.875 1.650 0.9432-7/8” 2.313 2.303 1.3223-1/2” 2.750 2.600 1.486

4” 3.313 3.250 1.8504-1/2” 3.813 3.500 2.000

5” 4.313 3.800 2.1885-1/2” 4.437 4.400 2.500



5” CRBP TECHNICAL DETAILSPressure rating 10,000psiTemperature rating 300°CMaximum OD 95.25mm (3.75”)Minimum ID 37.9mm (1.375”)Length (with equalization sub) 1375mm (54.1”)Setting range 102.72-108.6mm (4.044-4.276”)Metallurgy Minimum 80ksi (typically AISI 4140-45 18-22

Rc, 420 stainless or better)

5-1/2” CRBP TECHNICAL DETAILSPressure rating 10,000psiTemperature rating 300°CMaximum OD 107.9mm (4.25”)Minimum ID 44.45mm (1.75”)Length (with equalization sub) 1461mm (57.5”)Setting range 118.62-124.25mm (4.670-4.892)Metallurgy Minimum 80ksi (typically AISI 4140-45 18-22


6-5/8” CRBP TECHNICAL DETAILSPressure rating 10,000psiTemperature rating 300°CMaximum OD 140mm (5.152”)Minimum ID 63.12mm (2.548”)Length (with equalization sub) 2220mm (87.4”)Setting range 144.2-150.40mmMetallurgy Minimum 80ksi (typically AISI 4140-45 18-22


7” CRBP TECHNICAL DETAILSPressure rating 10,000psiTemperature rating 300°CMaximum OD 144.91mm (5.705”)Minimum ID 63.12mm (2.485”)Length (with equalization sub) 1975mm (77.75”)Setting range 147.34-155.52 (5.801-6.123”)Metallurgy Minimum 80ksi (typically AISI 4140-45 18-22



R&D Solutions

R&D Solutions Pty Ltd Suite 6, Level 3, 1111 Hay Street, West Perth WA 6005 Australia T + 61 8 6140 1820 Fax + 61 8 9429 3098 ABN No 38 138 827 915

“Simple Software and Smart Gauges”


Pioneer Petrotech Services Inc. manufactures and services Pioneer Petrotech Services Inc. manufactures and services

a wide range of oilfield instruments, including electronic a wide range of oilfield instruments, including electronic

downhole pressure gauges, surface readout gauges, perma-downhole pressure gauges, surface readout gauges, perma-

nent installation systems, and wellhead pressure loggers.nent installation systems, and wellhead pressure loggers.

Pioneer Petrotech Services instruments are designed and Pioneer Petrotech Services instruments are designed and

manufactured with the most recent state of the art technol-manufactured with the most recent state of the art technol-

ogy. Our products are produced with automatic calibration ogy. Our products are produced with automatic calibration

systems to assure our customers to obtain accurate data. systems to assure our customers to obtain accurate data.

Pioneer Petrotech Services Inc. has received world wide rec-Pioneer Petrotech Services Inc. has received world wide rec-

ognition due to quality, commitment, and unequalled cus-ognition due to quality, commitment, and unequalled cus-

tomer services. tomer services.

Calgary, Alberta, Canada Phone: 403-282-7669 Fax: 403-282-0509

Toll Free Phone in USA & Canada: 1-888-PP-GAUGE(774-2843) www.pioneerps.com Email: [email protected]

MMEMORYEMORY C CAPACITYAPACITY Standard memory capacity is 1,000,000 data sets. Each data set includes time, pressure, and temperature. Optional larger memory capacity is also available (up to 4M data sets).

LLOWOW P POWEROWER C CONSUMPTIONONSUMPTION ANDAND L LONGONG B BATTERYATTERY L LIFEIFE The PPS series of gauges will work continuously over a long period of time utilizing low power consumption. One single C size lithium battery pack will power some models over one year at 30 second sampling rate.

RRELIABLEELIABLE P PERFORMANCEERFORMANCE Innovative mechanical and electronic design make the gauges resistant to vibration and in-terference. With the advanced technology, PPS series of gauges are one of the slimmest, high precision, high pressure measuring instruments available on the market. The PPS gauges will work consistently for a long period of time under high temperature and high pressure conditions.

SSIMPLEIMPLE TOTO U USESE S SOFTWAREOFTWARE The gauge system is complete with software. The simple software is very user friendly as there is no need to re-program the gauges after every run, providing you are on the same sample rate. Reports can be generated within 30 minutes from download directly into a PDF file for emailing or to the printer.

EEASEASE OFOF O OPERATIONPERATION The PPS series of gauges are designed to be compact and lightweight for convenient han-dling and space limited applications. All the gauges are designed to be run by Wireline/Service personnel with limited computer knowledge or experience in running downhole gauges.

AADVANTAGESDVANTAGES OFOF PPS PPS SERIESSERIES OFOF E ELECTRONICLECTRONIC G GAUGESAUGES


Toll Free Phone in USA & Canada: 1-888-PP-GAUGE (774-2843) www.pioneerps.com Email: [email protected]


HHIGHIGH S SENSITIVITYENSITIVITY Silicon-sapphire or quartz crystal transducers provide high sensitivity for accurate data acquisition.

PPS25 Electronic Memory Gauge

The PPS25 silicon-sapphire electronic downhole memory gauge are designed to be run by Wireline/Service personnel with limited computer knowledge or experience in running Memory Gauges. There is no need to re-program the gauges after every run, providing you are on the same sample rate and the simple software allows you to download and generate a report or ASCII file for emailing with ease.

Pressure Build-up Tests Production Tests Pressure Gradients Post Stimulation Evaluation Interference Tests Frac Monitoring Injection Pressure Monitoring Coil Tubing Operation

APPLICATIONSAPPLICATIONS::

SPECIFICATIONSSPECIFICATIONS

Sensor Type Silicon-Sapphire

Pressure Ranges Up to - 20,000 PSI

Pressure Accuracy ±0.03% (full scale)

Pressure Resolution 0.0003%

Pressure Drift <3 psi / year

Temperature Rating 125oC(257oF) / 150°C(302°F) / 177°C(351°F)

Temperature Accuracy ±0.5°C

Temperature Resolution 0.01°C

Power Source One AA or C lithium pack

Communications USB/RS232

Data Set Contents Time / pressure / temperature

Memory Capacity 1M data sets, larger memory optional

Outside Diameter 0.75”(19.1mm) / 1.0”(25.4mm) / 1.25”(31.8mm)

Overall Length 9” (229mm), 11”(279mm)

Service H2S

Housing Material Inconel 718 / Stainless Steel 17-4

Sample Rate 1 second to 18 hours per sample




PPS25-XM Critical Memory Gauge

The PPS25-XM is designed for critical well conditions by welding the sapphire sensor with the housing, so there is no potential leaking pass between sensor and the housing. Both metal to metal and elastomer seals are used to secure the sealing between battery hous-ing and electronic section. Six pin with locking mecha-nism connector is used to provide dual power chan-nels and prevent battery disconnection during opera-tions.

Pressure Build-up Tests Pressure Gradients Post Stimulation Evaluation Interference Tests Frac Monitoring








Temperature Rating 150°C(302°F) / 177°C(351°F)



Power Source One CC lithium pack




Outside Diameter 1.27”(32.3mm), 1.5”(38.1mm)

Overall Length 11.7”(297mm)

Service H2S

Housing Material Inconel 718





PPS26 Surface Read-Out Pressure Gauge

The PPS26 silicon-sapphire electronic downhole sur-face readout gauge is designed with state of the art surface read-out technology. The gauge sends pressure and temperature data from downhole to surface on the real time basis through one single conductor cable. Up to four gauges can be used for one testing job. PPS26 gauges have been successfully operated at well depth up to 6000m (19685 ft).

Pressure Gradients Pressure Build-up Drill Stem Testing Injection Pressure Monitoring Interference Tests

AAPPLICATIONSPPLICATIONS::


Sensor Type Silicon-Sapphire Pressure ranges Up to - 20,000 psi Pressure Accuracy ±0.03% (full scale) Pressure Resolution 0.0003% Pressure Drift <3 psi / year Temperature Rating 125oC(257oF) / 150°C(302°F) / 177°C (351°F) Temperature Accuracy ±0.5°C Temperature Resolution 0.01°C Power Source 12 V DC Communications USB/RS232 Data Set Contents Time / pressure / temperature Outside Diameter 1.0”(25.4mm) / 1.25” (31.8 mm) Overall Length 5.5” (140 mm) Work Mode SRO Service H2S service Housing Material Inconel 718 / Stainless Steel 17-4 Sample Rate 1 second to any longer period




PPS27 Permanent Monitoring System

The PPS27 permanent system is designed to monitor downhole reservoir pressure and temperature in production optimization and management of oil and gas assets. Customers can choose either single gauge single channel or multi-gauge multi-channel configura-tions. The real time downhole data can be stored in the surface box at well sites or can be transmitted to a remote location. To accommodate different applications and budgets, the gauge sensor can be either silicon sapphire or quartz.

TTHEHE W WHOLEHOLE S SYSTEMYSTEM I INCLUDESNCLUDES:: • Downhole Pressure Gauge • Gauge Carrier • Electric Cable • Cable Protectors • Cable Head Adapter and Seal Accessories • Surface Data Acquisition System


Production optimization Monitoring of observation wells Pump systems monitoring Well Testing Reservoir Management

SPECIFICATIONSSPECIFICATIONS Sensor Type Silicon-Sapphire Quartz Pressure Accuracy ±0.03% (full scale) ±0.015% (full scale) Temperature Accuracy ±0.5°C ± 0.15oC Overall Length 8” (203 mm) 15”(381 mm) Pressure Ranges Up to - 20,000 psi Pressure Resolution 0.0003% Pressure Drift < 3 psi / year Temperature Rating 125oC (257oF) / 150°C (302°F) / 177°C (351°F) Temperature Resolution 0.01°C Power Source 12 V DC Communication USB/RS232 Data Set Contents Time / pressure / temperature Display Mode liquid crystal Outside Diameter 0.75” (19.1 mm) / 1.0” (25.4 mm) / 1.25” (31.8 mm) Work mode SRO Service H2S service Housing Material Inconel 718 / Stainless Steel 17-4 Sample rate 1 second to any longer period




PPS28 Quartz Electronic Memory Gauge

The PPS28 Quartz Memory Gauges are devel-oped for critical well testing and are designed to be run by Wireline/Service personnel with limited computer knowledge or experience in running memory gauges. There is no need to re-program the gauges after every run, providing you are on the same sample rate and the simple software allows you to download and generate a report or ASCII file for emailing with ease.

Pressure Gradients Pressure Build-up Drill Stem Tests Production Tests Post Stimulation Evaluation Interference Tests Frac Monitoring Injection Pressure Monitoring Perforation Monitoring




Sensor Type Quartz Pressure Ranges Up to - 20,000 psi Pressure Accuracy ±0.02% (full scale), ±0.015% (full scale) Typically Pressure Resolution 0.00006% F.S. Pressure Drift < 0.02% psi/ year, F.S. Temperature Rating 150°C (302°F), 177°C (351°F)

Temperature Accuracy ±0.2°C Temperature Resolution 0.01°C Power Source 1 or 2 AA or CC lithium packs Communications USB/RS232 Data Set Contents Time / pressure / temperature Memory Capacity 1M data sets, larger memory optional

Outside Diameter 0.75”(19.1 mm)/1.0”(25.4 mm) / 1.25”(31.8 mm) Overall Length 23” (584 mm) with 1CC pack

Housing Material Inconel 718 / Stainless Steel 17-4 Service H2S service Sample Rate 0.1 second to 18 hours per sample

SPECIFICATIONS SPECIFICATIONS




PPS28-200C Quartz Electronic Memory Gauge

The PPS28-200C Quartz Memory Gauges are developed for critical well testing in hostile well conditions. The latest innovative hybrid technolo-gies are applied to greatly extend gauge life at high temperature. The gauge uses six pin with locking connector to provide dual power chan-nels and prevent battery disconnection. The same simple to use PPS SmartView software is used for programming, downloading and con-ducting data processing.

Pressure Build-up Drill Stem Tests Production Tests Post Stimulation Evaluation Interference Tests Frac Monitoring


Sensor Type Quartz Pressure Ranges Up to - 25,000 psi Pressure Accuracy ±0.02% (full scale), ±0.015% (full scale) Typically Pressure Resolution 0.00006% F.S. Temperature Rating 200°C (392°F) Temperature Accuracy ±0.2°C Temperature Resolution 0.01°C Power Source 1 or 2 CC lithium battery pack Communications USB/RS232 Data Set Contents Time / pressure / temperature Memory Capacity 1M data sets, larger memory optional Outside Diameter 1.27” (32.3 mm) Overall Length 23” (584 mm) Housing Material Inconel 718 Service H2S service

Sample Rate 0.1 second to 18 hours per sample Seal type Metal to Metal and Elastomer

SPECIFICATIONS SPECIFICATIONS




PPS31 Wellhead Pressure Logger

The PPS31 logger is a wellhead digital pressure and temperature monitoring instrument. The radio trans-mission allows operators to receive real-time data which is also stored in its built in memory chip. Pressure and temperature can also be directly read from the LCD (liquid crystal display). The intrinsically safe design permits the logger to be used in critical environments. The same easy to use SmartView software is used for programming, downloading, and processing data.



Sensor Type Silicon-Sapphire Pressure Ranges Up to - 15,000 psi Pressure Accuracy ±0.03% (full scale) Pressure Resolution 0.0003% Pressure Drift <3 psi / year Temperature Rating -40°C (-40°F) to 80°C (176°F) Temperature Accuracy ±0.5°C Temperature Resolution 0.01°C Power Source 2 D lithium cells, up to one year usage Data Set Contents Time / pressure / temperature Memory Capacity 1,000,000 data sets Display Mode liquid crystal Data Receiving Mode Wireless (915MHz, ISM) Wireless Transmission Distance 328 ’ (100m)

Outside Diameter of Indicator Dial 4.625” (117.5 mm) Overall Length 10” (254 mm) Work Mode MRO / SRO Service H2S service Sample Rate 1 seconds to 18 hours per sample Connection 1/2” NPT/Autoclave Safety Rating C.S.A. / Class 1, Division 1, CE Marking

Transmission Power + 10 dbm



Gas Well Wellhead Build-up Stimulation Monitoring Pipeline monitoring Frac Monitoring Wellhead Monitoring Injection Pressure Monitoring Perforation Monitoring Workover Monitoring




PPS31M Wellhead Pressure Logger

The PPS31M Wellhead Logger is equipped with two pressure channels and one RTD probe, so users could monitor both casing and tubing pressures with a RTD probe to offer more accurate line temperature. The Bluetooth wireless package allows users to pro-gram sampling rate, configure logger, download data or receive real time data upto 100 meters (330 feet). The two D size batteries are installed in the back en-closure for easy replacement. The same simple to use PPS SmartView software is used for data proc-essing.

Sensor Type Silicon-Sapphire/RTD Pressure Ranges Up to - 15,000 psi Pressure Accuracy ±0.03% (full scale) Pressure Resolution 0.0003% Pressure Drift <3 psi / year Temperature Rating -40°C (-40°F) to 80°C (176°F) Temperature Accuracy ±0.3°C Temperature Resolution 0.01°C Power Source 2 D lithium cells, up to six months Data Set Contents Time / pressure / temperature Memory Capacity 1M data sets on flash memory, SD card. Display Mode liquid crystal Data Transmission Mode Bluetooth/USB Wireless Transmission Distance 100m (328 ft)

Outside Diameter of Indicator Dial

4.625” (117.5 mm)

Overall Length 10” (254 mm) Work Mode MRO / SRO Service H2S service Sample Rate 1 seconds to 18 hours per sample Connection 1/2” NPT/Autoclave Safety Rating C.S.A. / Class 1, Division 1, CE Marking




Gas Well Wellhead Build-up Stimulation Monitoring Pipeline monitoring Frac Monitoring Wellhead Monitoring Injection Pressure Monitoring Perforation Monitoring Workover Monitoring




PPS33 Multi-Sensor Wireless System

The PPS33 Multi-Sensor Wireless System is devel-oped for applications requiring simultaneous multi-point pressure, temperature and/or flow monitoring such as wellhead, well testing, and pipeline opera-tions. ZigBee wireless package allows a master data logger to receive data from up to 60 individual sen-sors within 100 meter (328 feet) range. The system can also work with customer SCADA or satellite/cell phone transmission system to offer real time information to engineers working in offices. PPS RemoteWatcher software is used for handling the system.

Sensor Type Silicon-Sapphire/RTD/Turbine Pressure Ranges Up to - 15,000 psi Pressure Accuracy ±0.03% (full scale) Pressure Resolution 0.0003% Pressure Drift <3 psi / year Temperature Rating -40°C (-40°F) to 80°C (176°F) Temperature Accuracy ±0.3°C Temperature Resolution 0.01°C Power Source 2 D lithium cells, up to six months Data Set Contents Time / pressure / temperature/Flow Memory Capacity 2M data sets on flash memory, SD card. Display Mode liquid crystal Data Transmission Mode ZigBee/Modbus/USB Wireless Transmission Distance 100m (328 ft)

Outside Diameter of Indicator Dial

4.625” (117.5 mm)

Overall Length of sensors 10” (254 mm) Work Mode MRO / Real Time Service H2S service Sample Rate 1 seconds to 18 hours per sample Connection 1/2” NPT/Autoclave Safety Rating C.S.A. / Class 1, Division 1, CE Marking




Wellhead Build-up Wellhead Production Monitoring Pipeline monitoring Frac Monitoring Well Testing Monitoring Injection Pressure Monitoring Perforation Monitoring Workover Monitoring




PPS51 Short Memory Gauge

The PPS51 gauge is designed for applications with length limitations. The most common usage is for building this gauge into other downhole tools, such as water injection and plunger lift equipment. It is also used for general pressure survey for gradient or build up tests. The gauge length is only 4.8 inches, including one half AA lithium battery pack. The same easy to use SmartView software is used for programming, downloading and processing data.




Pressure Ranges Up to - 15,000 psi


Pressure Resolution 0.0003% Pressure Drift <3 psi / year Temperature Rating 150°C (300°F) Temperature Accuracy ±0.5°C Temperature Resolution 0.01°C Power Source One 1/2 AA battery pack Data Set Contents Time / pressure / temperature Memory Capacity 1,000,000 data sets Communications USB/RS232 Outside Diameter 0.75”(19.1 mm) Overall Length 4.8” (122 mm) Service H2S Housing Material Inconel 718 / Stainless Steel 17-4 Sample Rate 1 second to 18 hours per sample



Stimulation Monitoring Pipeline monitoring Frac Monitoring Injection Pressure Monitoring Perforation Monitoring Workover Monitoring




PPS52 1/2” Memory Gauge

TThe PPS52 gauge is designed for applications with gauge OD challenge. The half inch outside diameter of this model allows users to run this tool in tight OD space conditions. The most common usage is for pressure and tem-perature measurement with small ID coiled tubing.








Coiled Tubing Operations Drill Stem Tests Gradient Survey Pressure Build Up Workover Monitoring Stimulation Monitoring




Pressure Resolution 0.0003% Pressure Drift <3 psi / year Temperature Rating 150°C (300°F) Temperature Accuracy ±0.5°C Temperature Resolution 0.01°C Power Source One AAA battery cell pack

Data Set Contents Time / pressure / temperature Memory Capacity 1,000,000 data sets Communications USB/RS232 Outside Diameter 0.50”(12.7 mm) Overall Length 8.75” (222 mm) Service H2S Housing Material Inconel 718 / Stainless Steel 17-4 Sample Rate 1 second to 18 hours per sample

PPS53 Side Pocket Mandrel Gauge

The PPS53 Side Pocket Mandrel Gauge utilizes our robust electronic design with silicon-sapphire technol-ogy to measure pressure and temperature by working as a gas lift valve. The gauge housings are designed according to conventional 1” and 1.5” gauge lift valves, therefore, they can be set and retrieved by using stan-dard side pocket mandrel tools. These gauges still use the very simple, but powerful PPS SmartView software that all our other gauges use.

Stimulation Monitoring Long Term Flowing Monitoring Post Stimulation Evaluation Interference Tests Frac Monitoring Water Injection Monitoring








Temperature Rating 125oC(257oF) / 150°C(302°F) / 177°C(351°F)



Power Source One AA lithium battery pack




Outside Diameter 1.0”(24.5mm), 1.5”(38.1mm)

Overall Length 12.31” (312.7mm), 19.50” (495.3mm)

Service H2S






PPS55 Fast Sampling Gauge

The PPS55 gauge offers a great opportunity to catch sharp pressure changes, such as the pressure break-ing point for reservoir fracturing or perforation opera-tions. The gauge can record up to 500 data points per second. The large memory capacity of 4 million data points, al-lows operators to have sufficient downhole running time during job operations .






Stimulation Monitoring Injection Pressure Monitoring Perforation Monitoring Workover Monitoring




Pressure Resolution 0.01 psi

Pressure Drift <3 psi / year Temperature Rating 150°C(302°F) / 177°C(351°F) Temperature Accuracy ±0.5°C

Temperature Resolution 0.05°C Power Source One AA or sub CC lithium pack

Communications USB/RS232 Data Set Contents Time / pressure / temperature Memory Capacity 4,000,000 data sets Outside Diameter 0.75” (19.1mm)/1.25”(31.8 mm)

Overall Length 9” or 12” Service H2S Housing Material Inconel 718 / Stainless Steel 17-4 Sample Rate Up to 500 data sets/ second

PPS58 Memory-SRO Combo Gauge

The PPS58 Memory-SRO Combo Gauge offers ei-ther memory or SRO working mode for customers who want to have the flexibility in gauge operations. The gauge can be used as a standard memory gauge or a SRO gauge with an adapter installed on the gauge to connect to a cable head. SmartView software is used for memory gauge appli-cations and PPS SRO software is used for SRO op-erations.

Pressure Build-up Tests Production Tests Pressure Gradients Post Stimulation Evaluation Interference Tests Frac Monitoring Injection Pressure Monitoring Coil Tubing Operation











Power Source One C lithium pack/12V for SRO




Outside Diameter 1.0”(25.4mm) / 1.25”(31.8mm)

Overall Length 11”(279mm)

Service H2S



Working Mode Memory or SRO




PPS61 Temperature Gauge

The PPS61 gauge is for applications that require a fast response to temperature changes. It allows ana-lysts to quickly diagnose downhole problems such as tubing or casing leakage. It can also be used for monitoring stimulation operations to see which zones are more effective. Using the same highly integrated design principles, the tool can be operated in limited space areas. The same simple to use SmartView software is used for programming, downloading and processing date.



Sensor Type RTD

Pressure Ranges Housing design for up to 20,000 PSI




Power Source One AA or C lithium pack


Data Set Contents Time / temperature


Outside Diameter 0.75”, 0.875”, 1” or 1.25”

Overall Length 10”(254mm)

Service H2S





Stimulation Monitoring Casing leak detection Pipeline leak detection Injection Monitoring Perforation Monitoring Temperature logging




PPS62 External RTD Memory Gauge

The PPS62 External RTD Memory Gauge combines piezo resistive technology with RTD sensor to allow users to obtain fast temperature responses. This product is primarily designed for detecting tubing and casing leakage problem. It could also be used for other operations such as gradients and build up tests. The same simple to use PPS SmartView software is used for programming gauges and conducting data processing. All files are in ASCII data format.

Pressure Build-up Tests Production Tests Pressure Gradients Tubing and Casing Leakage Checking Interference Tests Injection Pressure Monitoring Coil Tubing Operation





Sensor Type Piezo Resistive/RTD








Power Source Dual AA or C lithium pack



Memory Capacity 1M data sets, Larger memory optional

Outside Diameter 0.75”(19.1 mm) / 1.25”(31.8 mm)

Overall Length 16” (406 mm)

Service H2S






PPS71 Geothermal Memory Gauge

The PPS71 Geothermal Memory Gauge is designed for extreme higher temperature downhole conditions. Our robust electronics combined with vacuum flask technology allow this product to perform at up to 600 deg.F (315 deg.C). As a general reference, this tool could operate up to 6 hours at 300 deg.C environ-ment. The same simple to use PPS SmartView software is used for programming, downloading and conducting data processing. All files are in ASCII data format.

Geothermal Well Tests Steam Injection Dowhole Tests. Pressure Build-up Tests Pressure Gradients Tubing and Casing Leakage Checking





Sensor Type Piezo Resistive





Temperature Rating 315°C (600°F)



Power Source Single AA lithium pack



Memory Capacity 1M data sets, Larger memory optional

Outside Diameter 1.75” ( 44.45 mm)

Overall Length 49.2” (1250 mm)

Service H2S

Housing Material Inconel 718 / Stainless Steel 316

Sample Rate 0.5 second to 18 hours per sample




Gauge Carrier

PPS gauge carriers are machined from one solid metal bar to hold one to four gauges. The carriers are designed for measuring internal and/or external pressures.



Outside Diameter 5” (127mm)

Inside Diameter 2.25” (57 mm) Length 76” (1930 mm) Pressure Rating Burst: 22,000 psi (150 MPa

Collaps: 21,000 pis (145 MPa) Tensile Strength 470,000 lbs (220,000 kgf) Material AISI 4140 Thread Type 3 1/2” IF Box x 3 1/2” IF Pin Weight 237 lbs (108 kg)



Drill Stem Testing Stimulation Monitoring Well Testing Injection Monitoring Reservoir Studies Perforation Monitoring

Other sizes and/or types of carriers are also available upon request.




AACCESSORIESCCESSORIES

LubricantLubricant

Battery TesterBattery Tester Battery PackBattery Pack

SRO Surface BoxSRO Surface Box Gauge CarrierGauge Carrier

Weather Proof CaseWeather Proof Case



USB InterfaceUSB Interface

CrossoverCrossover OO--ringring




Optical Fiber Probes, Connections Accessories and Deployment

Probes, Cables, & Accessories

Product Data Sheet

SensorTran offers a wide range of

optical fiber and accessory products

that complement their range of

Distributed Temperature Sensing

(DTS) systems.

Because our DTS systems are

designed for use with standard

telecommunication-grade optical

fiber, we can easily supply custom

and/or specialized designs to meet

project requirements.

We offer fiber optic probes that

operate in temperatures from -185°

[-301°F] to +600°C [+1112°F] for

deployment above-ground,

underground, sub-sea, and in

hazardous areas, as well as harsh

H2 and radiation environments.

We offer a wide range of connection

accessories, including multi-core

fiber-optic transit cable, connectors,

and fiber-optic junction boxes.

SensorTran has also developed

application-specific probe

deployment techniques to suit

individual application needs.

Overview

Optical fiber Fiber coating

Gel

compound

Inner protective sheath

Primary protective sheath

Secondary fiber

coating

Outer protective

sheath

Probe Construction

For every project, the probe construction, deployment method,

and associated accessories must be carefully designed and

selected for the application and duties required.

Probes are available with either acrylate or polyimide fiber

coating with a range of secondary coatings and protective

sheaths including metallic types (fiber-in-metal tube – FIMT).

The diagram below highlights the typical components of

constructed probes.

Version 4.2

Optical Fiber

The optical fiber is standard telecommunications grade. It is available as either 50/125µm graded-index multimode or 9/125µm step-index singlemode, for compatibility with either the DTS5100-M Series (multimode systems) or DTS5100-S Series (singlemode systems) respectively. Single or multiple fibers can be constructed into the probe.

Fiber Coating

Arcylate coated fibers are good for applications where the probe is exposed to a continuous temperature range of -20°C [-4°F] to +80°C [+176°]. Polyimide coated fibers are good for applications where the probe is exposed to a continuous temperatures of -185°C [-301°F] to +350°C [+662°F]. The operating temperatures of the optical fibers can be increased when used in conjunction with metallic primary protective sheaths such as stainless steel. In these cases the following maximum operating temperatures can be achieved: Acrylate coated: + 90°C [+194°F] Polyimide coated: +400°C [+752°F]

Secondary Fiber Coating An additional carbon coating can be added to ensure longer-term operation within harsh environments, such as when high H2 levels are present. Carbon coating is only suitable for environment temperatures up to 150°C [302°F]. Other metallic and rare-metal secondary coatings are also available such as aluminium and gold. These materials allow probes to operate in temperatures up to +600°C [+1112°].

Gel Compound Gel compound aids the thermal conductance between an outer metallic sheath and the optical fibers. However, this compound suffers from accelerated aging when exposed to temperatures above +85°C [+185°F] and should be avoided at elevated temperatures. A probe with a metallic protective sheath with no gel compound is often referred to as a “loose tube” construction.

Inner Protective Sheath The inner protective sheath is usually a metallic tube made either of aluminium or stainless steel. This inner sheath provides additional mechanical and chemical protection when used in conjunction with a metallic primary protective sheath. In such a case, the construction is often referred to as a “tube-in-tube” construction. The benefit of an aluminium inner protective sheath is that it provides additional protection to the optical fiber(s) when used in high H2 environments. As an alternative, non-metallic probe constructions can be provided where the inner protective sheath is a semi-loose buffer tube.

Probe Specification

Primary Protective Sheath The primary protective sheath is typically a stainless steel tube (304, 316 or 316Ti grade) which provides excellent mechanical and chemical protection, while allowing heat to be conducted to the optical fibers. The use of a metallic protective sheath is often referred to as FIMT (fiber-in-metal-tube) construction. These can be supplied in various tube diameters, typically 3.2mm [¼”] or 6.4mm [½”], with a typical wall thickness of 0.5mm [0.020”] and [0.035”] respectively. As an alternative, we offer non-metallic probe constructions in which the primary protective sheath is an aramid yarn to provide the mechanical strength.

Outer Protective Sheath The outer protective sheath is normally a poly-plastic material which can be supplied to meet flame retardant, low-smoke, and/or zero-halogen requirements. This outer sheath can also be required in order to reduce the risk associated with sparking where the main protective sheath is metallic.

Special Constructions SensorTran can also supply multi-fiber steel-wired or steel-strip armored optical fiber probe constructions to meet specific project requirements. These constructions may be necessary for subsea or underground constructions, or for situations needing high-levels of mechanical protection. A range of “air-blown” probe constructions is also available upon request.

Optical Junction Boxes and Connectors

SensorTran offers a range of optical fiber junction boxes suitable for indoor, outdoor, and hazardous/explosion areas. Our range of optical connectors includes diamond push-fit, screw, and bayonet types. For sub-sea applications, SensorTran can also supply a range of wet-mate connectors to exacting specifications.

Deployment Methods and Installation Services

SensorTran provides complete optical

fiber design, engineering, deployment,

system installation, testing, and

commissioning services worldwide for

both onshore and offshore installations.

Probes with customized configurations,

layouts, and forms are available either

pre-constructed or constructed at site,

together with highly developed

attachment methods and techniques.

SensorTran also provides on-site

optical fiber deployment using a

variety of developed techniques for

installation within, for example,

existing or supplied conduit and control

lines.

Specialized and qualified welding

techniques and low-loss optical splicing

methods are employed as required.

Distributed Monitoring Solutions

SensorTran, a NASA technology spin-off, is committed to supplying its customers with

smart distributed monitoring solutions. SensorTran’s systems are conceived to have a

low lifetime cost of ownership (LCO) by way of efficient design, superior engineering,

and reliable construction. SensorTran’s team is dedicated to providing “best-in-industry”

customer care from project conception to the development of specifications, through

installation, training, and beyond.

Contact

Corporate HQ & Manufacturing International Sales Office

4401 Freidrich Lane, Suite 307 Austin, TX 78744

USA

Regus House, George Curl Way Southampton, SO 18 2RZ England, United Kingdom

+1-512-583-3520 +1-866-333-2861 (toll free domestic)

+44 1202 859159

e-mail inquiries to [email protected]

www.sensortran.com

SensorTran has made every effort to ensure information contained in this document is accurate at the time of printing, however, product specifications and features are subject to change without notice.

The SensorTran Advantage

Advanced DTS Solution for Cryogenic Plant Monitoring

LNG/Cryogenic

Plant Monitoring

Application Note

SensorTran’s range of advanced

cryogenic plant monitoring solutions is

based on their new generation and

leading edge fiber optic Distributed

Temperature Sensing (DTS) technology.

These solutions provide continuous,

autonomous, on-line temperature

monitoring of storage tanks and pipelines

to provide tank and pipeline integrity

monitoring, tank base temperature

control and pipeline cool-down monitoring.

Temperature data with fine resolution and

high accuracy in real-time for up to

40,000 discrete measurement points are

provided along optical fibers.

Such systems have an open-

communications architecture allowing for

reliable and easy interfacing with 3rd party

systems and networks over, for example,

Ethernet, OPC and SCADA.

SensorTran’s specifically developed

application software presents the data in

a meaningful, representative and intuitive

graphical form to the operator.

Intelligent alarm types and configurations

can be readily tailored to each specific

project to alert the operator to both

potential and present undesirable

temperature and health events.

Overview

Version 4.0

Better Decisions from Better Data

• Accurately detects and locates small leaks in

storage tanks and pipelines

• Information rich cost effective data delivery

unparalleled by RTD technology

• Monitors tank base heat distribution allowing

higher value control information

• Provides real-time temperature data allowing

effective control of pipeline cool-down

operations

• Data display HMI panels offers site specific

plant visualisation providing clear information

• Suitable for use in hazardous areas

• SIL 2 package available

• Fiber probes tested and qualified to -196°C Applications

o LNG

o LPG

o Ethylene

o Buried or above ground storage tanks

o Single and double-wall tanks

o On-shore and ship installations

o Ammonia

o Oxygen, etc.

o Pipelines

System Features and Benefits

SensorTran’s intelligent solutions provide a wealth of features and benefits:

⇒ Up to 50 fiber-optic channels available to provide plant-wide monitoring from a single DTS

unit

⇒ Open-communications architecture provides reliable and easy interfacing with 3rd party

systems and networks (Ethernet, OPC, SCADA, etc) together with flexible remote control

and data output/input capabilities

⇒ Intelligent and multiple alarm types and configurations can be readily tailored to each specific

project to alert the operator to both potential and present temperature events and

undesirable anomalies

⇒ Each asset can be defined into unlimited zones with individual alarm types and set-points for

each zone, allowing alarms to fully reflect the characteristics of each part of the asset

⇒ Specifically developed application software presents the data in a meaningful, representative

and intuitive graphical form to the operator

⇒ Wide range of cabinet packages available to meet exacting project requirements

⇒ On-board and expandable data storage provides for historical data archiving

⇒ Extensive on-board self diagnostics and autonomous operation with safe shut-down and auto

-start-up capabilities

Installation and System Configuration

The configuration of the optical fiber itself is selected depending on the duty expected. It is normally

contained either within a stainless tube or within an armoured construction to provide mechanical, chemical

and moisture protection while allowing good thermal conductance to the fibers. Single or multiple fibers can

be deployed to allow redundancy or dual-measurement by a back-up DTS unit. Such fiber configuration can

withstand temperatures of up to -196°C.

Single or Double Ended? The DTS units can be configured to measure the fiber in single-ended or double-ended configuration.

Double-ended measurement describes a method by which both ends of the fiber are connected to the DTS

unit in a loop configuration. An advantage of double-ended measurement is that in the unlikely event of a

fiber-break, since the fiber is being addressed from both ends the system can continue to provide full

monitoring.

The configuration example below shows a typical LNG plant with two storage tanks and an import/export line.

A fiber is installed in the annulus of each double-wall storage tank to monitor for leaks through the inner wall.

Fiber is also shown running in the conduits within the concrete slab bases to provide temperature distribution

data to the heating control system.

The trunk lines have fiber installed not only to monitor for leaks but also to provide dynamic temperature data

along their full length for cool-down monitoring.

Single or multiple DTS units can be provided within a single cabinet (backup controllers are aimed at achieving

SIL2 redundancy levels).

DTS networks can be readily implemented providing expanded coverage for plant-wide solutions.

Typical Installation Example

Remote control and data input: Ethernet, OPC,

SCADA, RS232, RS485, etc

Cabinet

Monitor

Pull-out keyboard

DTS unit

UPS

2

1. Data output and remote control via Ethernet, OPC, SCADA RS232, RS485, GPIB,

relay contacts (alarm data only), etc

2. Specially developed application software

3. Multi-core fiber-optic transit cable

4. Field optical junction box

5. Fiber-optic cable for tank leak detection

6. Fiber-optic cable for tank-heat monitoring

7. Fiber-optic cable for pipeline leak detection and temperature monitoring

KEY


SensorTran, a NASA technology spin-off, is committed to supplying its customers with smart

distributed monitoring solutions. SensorTran’s systems are conceived to have a low lifetime cost of

ownership (LCO) by way of efficient design, superior engineering and reliable construction.

SensorTran’s team is dedicated to providing “best-in-industry” customer care from project conception

to the development of specifications, through installation, training and beyond.

Contact


4401 Freidrich Lane, Suite 307 Austin, TX 78744

USA

Regus House, George Curl Way Southampton, SO 18 2RZ

England

+1-512-583-3520 +44 2380 30 2705

e-mail inquiries to [email protected]

www.sensortran.com

SensorTran has made every effort to ensure information contained in this document is accurate at the time of printing, however, product specifications and features are subject to change without notice.

Cryogenic Plant Monitoring Software

The SensorTran Advantage

To complement DTS Manager Software,

SensorTran has developed specific

application displays for the monitoring of

storage tanks and pipelines.

This provides the human-machine-

interface (HMI) to present the temperature

and alarm information to the operator in a

clear, precise and intuitive manner.

These HMIs are tailored to suit specific

project requirements so that they provide

an accurate mimic of the installation.

In addition to displaying real-time data, the

versatility of these systems also allow for

the playback of historical data. Playback

direction and review speed is provided by a

single control.

By mapping the fiber to the physical asset,

the temperature data can be displayed in a

graphical format as shown.

The temperature profile and status (both

as graphical and temperature trace

representations) as well as trend plots for

specific points are clearly displayed for

multiple vessels.

Multiple data and system health alarms are

also displayed.

Active “Plug & Play”

SensorTran’s advanced software capabilities, combined with proprietary technologies included within Gemini™ (PerfectVision™) and the Calibration Module enable the industry’s first true “Plug & Play” DTS system. For DTS, “Plug & Play” refers to the ability of the system to automatically and continuously maintain calibration ‐ even as the characteristics of the fiber optic probe change over time.

With manual calibration, highly skilled technicians must make multiple iterative DTS measurements during the commissioning process ‐ which calibrate the system to the characteristics of the fiber at the time of deployment. As the fiber changes over time, it is necessary for operators to recalibrate to new conditions ‐ which are often not detected until there is a shift significant enough to potentially impact the temperature readings.

Active “Plug & Play” continuously and dynamically calibrates each of 20,000 or more temperature points along the complete length of fiber ‐ eliminating the need for manual intervention and significantly reducing downtime and potential data effects associated with the system being out of calibration.

SensorTran Software Suite

Overview

SensorTran’s software suite runs on a Windows® XP platform and is comprised of four different product offerings as follows:

DTS Commander™ DataViewer™ AssetViewer™ DataFuser™

DTS Commander™ houses all the command and control functions for the DTS system and provides for basic data visualization. DTS Commander™ is required for operation and ships standard with all units. Each of the other software offerings work in conjunction with DTS Commander™ to provide advanced data display and data integration functionality.

Features

The SensorTran software suite provides a powerful, user‐friendly, interface for DTS configuration and operation. Aside from command and control functions and data visualization, the software includes several special features. Recalculation Tools allow the user to simulate scenarios in advance of making changes to compare outcomes. The Historical Playback feature allows users to review standard temperature traces over time using the data control facility. All SensorTran software can be accessed, upgraded, and worked on remotely by users and/or SensorTran personnel as required. The Remote Access features are the cornerstone of SensorTran’s superior field support services ‐ as they allow for in‐situ customization and configuration by highly experienced DTS engineers. Finally, SensorTran’s sophisticated software suite enables the industry’s only true “Active Plug & Play” capabilities. Active Plug & Play allows for continuous, auto‐correcting calibration and fast, accurate field set‐up, eliminating many hours of tedious

Standard Software

Available Upgrades

DTS Commander™ DataViewer™ AssetViewer™

DTS Commander™ + DataFuser™

N/A

DTS Commander™ DataViewer™

DTS Commander™ DataViewer™

Lynx

Gemini

Gemini

Product/Software Offerings

OEM Only


An Intuitive, Easy‐to‐Use Package

SensorTran DTS Commander™ serves as the primary control interface for all SensorTran distributed monitoring systems. Running on Microsoft® Windows XP, each SensorTran DTS unit is supplied with DTS Commander™ software as standard. SensorTran DTS Commander™ is the primary application needed to set up, configure, calibrate, and manage SensorTran DTS systems. The product also includes basic data visualization and recalculation tools. The visualization functionality in DTS Commander™ allows for the simultaneous automatic update and display of multiple traces, one for each channel.

DTS Commander™

Functions

DTS set up and system configuration

Scheduling of temperature readings

Defining of zones and alarms, and setting of system alarms

Management of restart capabilities and diagnostic tools

Oversight of password administration

Intuitive visual calibration

Controls communication

Conducts system self‐diagnostics

Triggers conditions‐base alarms

Allows autonomous operation

Provides basic data display functions

Temperature Plot in DTS Commander™

DTS Commander™ Screenshot

Full Asset Mapping Capability AssetViewer™ is an optional software product that provides a graphical visualization of the temperature – mapping the data directly to the asset being monitoring. Temperature data is dynamically scaled to match the current asset view. This feature set has all the functionality of DataViewer™ with the additional ability to see not just a temperature zone, but the actual underlying features and characteristics of the asset being monitored. The AssetViewer™ has a library of “drag and drop” graphics that allow users to quickly and accurately render even complex installations. “Drag and drop” assets include those related to downhole and reservoir monitoring, pipelines, T&D power cables, storage tanks and process vessels. In addition, SensorTran has the capacity to build custom visualizations to better illustrate the status of key assets. For example, satellite imagery‐based visualizations will provide a view of an entire oil field, substation or other geographical area where it is desirable to monitor multiple assets with a single interface.

Zonal or 3‐D Visualization

DataViewer™ is offered as an optional upgrade and houses two main feature sets. First, it allows users to visualize data for various zones along the length of the fiber probe ‐ allowing users to interpret temperature information in meaningful groupings. DataViewer™ is automatically configured from the settings with the DTS Commander™ software and requires no additional setup. The software displays multiple temperature profiles at once, summary temperature data, and alarm status information for each zone. The second main function of DataViewer™ is to provide 3‐D plotting capabilities. The 3D plots allow for a richer view of the data across time and the various channels.

AssetViewer™

DataViewer™

Zonal Temperature Plot in DataViewer™

3‐D Data Representation in DataViewer™

Animation and historical playback functionality ‐ providing the ability to view temperature data over time and distance • “Drag & drop” management via a modular, fully customizable interface • Extensive analysis tools to help DTS data exploration and manipulation utilizing techniques such as thresholding, standard deviation, averaging, etc.

Features

Zoom in or out on Plot and Asset

Multiple Traces

Display Multiple Assets or History

Various Asset Views &

BookmarksSet Alarm Conditions

Single Point Temp over 30-day time (Video play)

Customer Logo

Textures, Legend, &

Icons


Multiple Traces



BookmarksSet Alarm Conditions


Customer Logo

Textures, Legend, &

Icons

AssetViewer™ Configured for Power Cable Monitoring

DTS & FBG Data in a Single Interface

DataFuser™ is the software package that comes standard with the Lynx™ integrated hybrid Distributed Temperature Sensing / Fiber Bragg Grating (DTS/FBG) system. DataFuser™ is not available for use with any other SensorTran system. DataFuser™ software pulls data from both the DTS and FBG systems to synchronize, archive, and display all sensor information. DataFuser™ software has all the features of the DTS Commander™, DataViewer™, and AssetViewer™. Once an asset is created using the library of components, data from each of the sensors (DTS and FBG) is mapped to its corresponding location on the asset.


4401 Freidrich Lane, Bldg. 307 Austin, TX 78744

USA

Southampton, England United Kingdom

+1‐512‐583‐3520 +1‐866‐333‐2861 (toll free domestic)

+44 1489 576648

e‐mail inquiries to [email protected]

www.sensortran.com

Features

Accurate Synchronization of Sensing Data

Single Interface for Set‐Up, Control, and Communications

Real‐time Visualization of Combined Data

Fully Integrated Alarms for All Sensors

Reduced Footprint and Power Consumption

SensorTran is ISO 9001 Certified

Rev 5.0

DataFuser™ for Lynx™


Mark Distance



Bookmarks

Set Alarm Conditions


Customer Logo

Textures, Legend, &

Icons


Mark Distance



Bookmarks

Set Alarm Conditions


Customer Logo

Textures, Legend, &

Icons

AssetViewer™ Configured for a Wellbore Monitoring Application

DataFuser™ Configured for a Wellbore Monitoring Application

Screenshots showing how FBG data is incorporated into the DataFuser™ interface


Control Line Cross Coupling Clamps (CLCCC)

Premium Control Line Clamps built in the US since 1998

Quality Manufacture with Proven Global Track Record

Wide Range of 50+ Global Customers

Over 75,000 units run in over 30 Countries

Extensive range to suit Multiple Downhole Applications


Control Line Cross Coupling Clamps (CLCCC)

HD – Heavy Duty Protector High strength All Cast Body with No Welded Parts. Broad cable guard with wide range of configurations. Interlocking fastening mechanism with Hex or Allen Heads. 75 ton axial & 75 ton lateral load rating. < 30 second make up time. Side ribs reduce potential hang-up running through BOP's.

LT – LiTe Protector Lighter than HD with 30 ton axial & lateral load rating. “Standard Industry Protector” for routine applications Interlocking fastening mechanism with Hex or Allen Heads. High strength All Cast Body with No Welded Parts. Accommodates a multitude of line configurations. Captivated and pre-engaged fasteners.

LC – Line Clamp Protector Weight reduced design For basic line configurations : 1/4” & 11mm Interlocking fastening mechanism. Cost effective All Cast manufacture. 30 ton axial & 30 ton lateral load rating. < 30 second make up time.

SL – Slim Line Protector Low profile straps with side ribs and central pillar. Side ribs reduce potential hang-up running through BOP's. Reduced OD is ideal for completions with tight clearances. 30 ton axial & 30 ton lateral load rating. Interlocking fastening mechanism with Allen heads. Project specific designs. < 30 second make up time.

BC – Banded Cover Protector 20 ton axial & 20 ton lateral load rating. Designed for shallow wells with little or no deviation. Straddles & shoulders on the collar. Superior axial & lateral loads compared to Polymer & Folded

Sheet steel covers. Accommodates several standard line configurations. < 45 seconds make up time

R&D Solutions Pty Ltd. Suite 6, Level 3, 1111 Hay Street, West Perth WA 6005 AustraliaT + 61 8 6140 1820 F + 61 8 9429 3098 ABN No 38 138 827 915

QHSE Policy

The aim of R&D Solutions Quality Health and Safety Policy is to satisfy and exceed the expectations of our clientsand our employees by providing a quality service, therefore our ultimate aims are:

Provide a management system that is integrated and complies with applicable ISO and Australian Occupa-tional Health and Safety (AOHS) requirements thereby leading to continual improvement in all areas of the ser-vices we provide.

To clearly define all of our aims and objectives.

Train and develop our personnel to the highest standards delivering a first class service to our clients whilecontinuously demonstrating our commitment to QHSE requirements and expectations.

Ensure at all times confidentiality between R&D Solutions and its customers.

Comply with all relevant w o r k p l a c e a n d o t h e r s i m i l a r legislation that covers our scope of servicesand associated work.

Continually assess the environmental impact of our work place structure, products and services.

Careful use of resources and materials to keep waste to a minimum and prevent pollution.

Provide a safe, healthy and happy working environment for our staff in the workplace.

By continuous evaluation, develop an evolving health and safety culture within R&D Solutions and its relatedgroups ensuring best practice in line with legislative requirements and beyond.

Ensure that our systems and culture, fully embraces any sub-contractors in our employ and covers any otherparties who may be affected by our work.

Conduct all of our activities in a responsible manner with the primary focus on protection of our staff, the publicand the environment.

Ensure that our employees are fully aware of their statutory duties and that they take reasonable care ofthemselves, others and the environment in which we all work and live.

R&D Solutions will achieve these aims and meet our business objectives through: Raising our standards andprofile, Training our Staff and Sustaining its ethics and practices. Raise, Train, Sustain.

Signed: Date: 24th May, 2010

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