R&D Solutions by Craig Stampfli

Capabilities Products and Services

Product Catalogue

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

R&D Solutions 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 â&#x20AC;&#x201C; 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 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

Page 1

R&D Solutions 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 niche technology 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 enquiries and 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. Many companies do not often have time or resources to spend tracking down equipment and personnel. Moreover for one off tool purchase, tool design or personnel training it can become a very costly exercise tracking down exactly what your organisation 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:



Matrix:



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

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

www.matrixap.com.au R&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 stock exchange last year and move to new purpose built facilities in Henderson later this year.

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

Page 2

R&D Solutions 

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

Packers Plus:

Caledyne Innovation 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 be retrofitted to most packers and plugs of other suppliers. R&D Solutions has recently introduced this technology into Woodside for remedial equipment needs and to other service companies for day to day operations.



www.sensortran.com

Sensortran:

A 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 as well as in pipelines for leak detection, storage vessels for the same and importantly under storage vessels to ensure there are no base leaks. A further unique application has been on power lines in the States to monitor any hot spots which may occur and cause fires. For in well and surface facilities there are a multitude of areas where this technology can help to prevent issues occurring. It is simple to use, fast and can be set up to send an e-mail as issues arise. R&D Solutions has proposed this technology for Geothermal and HPHT applications in South Australia. 

Pioneer Petrotech Services Inc www.pioneerps.com Pioneer 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 calibration capability.



Design Engineering: R&D Solutions has already committed to design work for a major service companies in Perth and as mentioned in this 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 old story is certainly true, ‘a happy team is a productive team’ we wish to provide both. As R&D Solutions grows it will continue to place emphasis on local staff content and ‘train rather than hire’ people into roles rewarding dedication, loyalty and commitment.

Directors: Russell Furner is a ‘Managing Partner’ in R&D Solutions, with over 30 years in the industry World Wide Russell is well known locally for having a ‘can do’ attitude and getting the job done. Moreover he has extensive experience in managing and growing successful companies. Prior to joining R&D Solutions Russell has held management posts in BBL Ltd. and Weatherford International. Russell is responsible for capital expenditure, strategic business direction, finance and operations. In addition, he assists with sales growth in Australia and Asia Pacific. Russell can be contacted on +61 433 606 555 R&D Solutions Pty Ltd, Suite 6, Level 3, 1111 Hay St, West Perth WA 6005 Australia T +61 8 6140 1820 F +61 8 9429 3098 ABN 38 138 827 915

Page 3

R&D Solutions Directors Contd: Doug Gillespie is a partner in R&D Solutions. With over 15 years experience in Norway, the UK and Australia, Doug has gained 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 busy workplace. 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 years experience in the oil and gas industry having been with Weatherford twice and ABB. Craig’s duties will also see him serve in 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 and install the equipment listed. R&D Solutions has an excellent working relationship with Premium Casing Services ‘PCS’ based at Bibra Lakes Perth. It became clear to R&D that they should not duplicate existing make up and torque services but should instead should let those who are experts in this field continue to do what they are good at. This approach has allowed the company to focus on 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 last ten years. Based in 23 Ballantyne Rd Kewdale under the management team of Ashley Taylor Pentagon has taken care of all 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 and monitoring 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 your needs. We pride ourselves on quick reaction, being able to source and provide the right tools for the job in a timely manner.

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

StackFRAC®

Multi-Stage Fracturing Systems

Extended Reach Stimulation Coiled Tubing Stimulation

StackFRAC

Multi-Stage Fracturing Systems

Coil Tubing Stimulation Limitations

Extended Reach Horizontal Stimulation

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 Extended Reach Stimulation

retrievable packers, and specialty service tools.

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.

website: www.packersplus.com • email: info@packersplus.com Packers Plus®, StackFRAC®, and RockSEAL® are trademarks of Packers Plus Energy Services Inc.

StackFRAC®

Multi-Stage Fracturing Systems

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

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

StackFRAC® stimulation systems are designated for open and cased hole

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

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

or extended horizontal.

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

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

Top View

3200

-3000

Distance West - East (ft) 0 -1000

-2000

1000

production and maximize your profits.

operations by mechanically isolating selective intervals designated for

Microseismic fracture mapping

900

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

Applications

fracturing coverage of the wellbore and improved production inflow.

• Sandstone, carbonate, shale and coal formations • Open hole horizontal and vertical wells

Distance South - North (ft)

treatment and producing a distributed placement of stimulation fluids

Microseismic Fracture Mapping

2000

2600 700 1800

1000

• Critical sour, high pressure/high temperature environments • Extended reach horizontal wells

Benefits/Features • Simplified pumping operations

200

500

Stage 1 Stage 2 Stage 3 Stage 4 Stage 5 Stage 6 Stage 7

300

-750

X Axis (ft) 2000

-500

0 -250 Distance West - East (m)

3000

250

750

500

3D View

Y Axis (ft) 2000 1000

X Axis (m) 2000

1000 0

• Custom stimulation of the entire wellbore • Mechanical isolation with field proven RockSEAL® Open Hole Packers

earthquakes that are triggered by shear slippage on bedding planes or natural fractures adjacent fracture mapping graphs shown here prove out key features of the StackFRAC® Multi-Stage Fracturing System which include: • Fracture initiation between mechanical isolation

• Reduced completion time

• Full coverage in extended reach horizontal well applications

detecting microseisms or micro-

packers thus proving

• Improved production results

• Improved access to natural fractures

provides an image of fractures by

to the hydraulic fracture. The 100

-1000

Distance South - North (m)

field-proven system greatly increases the effectiveness of fracturing

Performance

• Full frac coverage of the

Stage 1 Stage 2 Stage 3 Stage 4 Stage 5 Stage 6 Stage 7

1000

wellbore with multi-placed, specifically located stimulation • Improved production inflow 750

500 Y Axis (m)

250

across the entire horizontal section

Packers Plus® Case Study

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

are used to segment the wellbore and

When the Barnett Shale in northeast Texas

FracPORT™ sleeves are located between

was discovered in the mid-1950s, the

each set of packers creating isolated stages.

900,000

technology to exploit this very tight gas

Actuation balls of increasing size are

800,000

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

dropped from the surface during pumping

Not until 2001, when multi-stage fracturing

to allow for hydraulic activation of the

technology began to be applied to horizontal

FracPORT sleeves in succession and isolate

wells, did activity in this play expand.

previously fractured zones. Because of this

400,000

innovative design, the operator was able

300,000

to stimulate all stages of each completion

200,000

string in less than a day.

100,000

sought a more effective multi-stage fracturing

conventional plug and perf method. One-year

solution. The challenge was to create a system

cumulative production values were 80 to 143%

that not only saved time and reduced costs,

higher for the StackFRAC completed wells versus

but also increased production from their

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

horizontal wells to improve their overall

The Packers Plus StackFRAC Multi-Stage

return on investment.

Fracturing System has enabled economical

The Solution

production from unconventional reservoirs such

Fracturing System to complete two of their

as shale and tight sand plays. Packers Plus has run over 3,700 StackFRAC systems worldwide in a variety of formations and conditions.

Production (Mcf)

Time (Days) Figure 1. Cumulative production for offset wells #1 and #2.

350,000 300,000

StackFRAC

250,000 200,000 Plug and Perf 150,000 100,000 50,000 0

Time (Days) Figure 2. Cumulative production for offset wells #3 and #4.

wells in the Barnett. This system increases the effectiveness of fracturing operations by mechanically isolating selective intervals producing a distributed placement of

450

cases, the StackFRAC system outperformed the

390

for the plug and perf method, the operator

330

two parallel offset plug and perf wells. In both

270

production results from two StackFRAC wells to

numerous operations and equipment required

210

into individual stimulation sections. Due to the

150

A detailed analysis was done to compare the

Plug and Perf

segregate and isolate their horizontal wellbores

Production (Mcf)

conventional “plug and perf” method to

The Results

Packers Plus StackFRAC® Multi-Stage

500,000

area of the Barnett Shale had utilized the

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

600,000

An operator working in the Denton County

StackFRAC

700,000

30 60 120 180 240 300 360 420 480 540 600 660 700

The Challenge

1,000,000

1. This information was originally presented at the AADE National Technical Conference & Exhibition held in New Orleans, LA, March 31 – April 2, 2009. © 2009 American Association of Drilling Engineers.

stimulation fluids throughout the horizontal wellbore. RockSEAL® II open hole packers

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

StackFRAC HD a success in the Bakken Formation 15-Stage StackFRAC HD Multi-Stage Fracturing System maximizes efficiency Background

stage design would require additional

stages. Because of this success, the operator

The Bakken Shale encompasses an area of

stages for the longer laterals. Additionally, to

plans to continue using StackFRAC HD for

25,000 square miles and is located within the

keep costs down, the number of days on the

their Bakken wells.

Williston Basin, which is the United States’

wellsite needed to be kept to a minimum.

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 Challenge An 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.

The Solution The new Packers Plus StackFRAC® HD™ “High Density” system, with improved staging technology, provided the ideal solution. A 15-stage, 4 ½”

Pembina Pembina StackFRAC HD

system was designed for a 6” open hole, horizontal well in North Dakota. The

Edmonton Edmonton

Red Deer Red Deer

Calgary Calgary

Alberta Alberta

Saskatchewan Saskatchewan

Manitoba Manitoba

Regina Regina

completion string design was for a total

Winnipeg Winnipeg

depth of 8,350 ft, a lateral length of 4,775 ft, and the average length between stages was approximately 300 ft.

The Results

Montana MontanaBillings Billings

All 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

Bismarck Bismarck

N. N. Dakota Dakota S. S. Dakota Dakota Rapid City Rapid City

Wyoming Wyoming

Nebraska Nebraska

per stage at a maximum rate of 30 barrels per minute using a 24-pound, crosslinked gel.

Packers Plus realized that to meet the

Operationally, the completion went smoothly

operator’s needs, the current open hole

and ball action was seen on all ball-actuated

Bakken Bakken Shale Shale Williston Williston Basin Basin

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

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

Packers Plus® Case Study

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

The challenge was to find a multi-stage

as a result, Packers Plus will be running additional

The Devonian Shale is located around the

completions system with the capacity for

StackFRAC HD systems for this operator in the

Appalachian Basin, which has the longest

additional stages to cover the entire length

Devonian Shale.

drilling history in the U.S. Natural gas

of the extended reach laterals.

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

The Solution Packers Plus recently launched their new StackFRAC® HD™ “High Density” Multi-Stage Fracturing System, which has more stages in a single system. With several Nebraska

Iowa

provide the ideal solution for the operator.

and overall exploitation of this reservoir.

was designed for a 6 ¼” open hole

Shale was looking to prove out multi-stage

Michigan

Packers Plus knew that StackFRAC HD would

An 18-stage, 4 ½” StackFRAC HD system

An operator working in the Devonian

Wisconsin

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

horizontal wells improving recovery rates

The Challenge

ONTARIO

improved staging technology allowing for

Appalachian Basin

Ohio Indiana

Illinois

horizontal well. The well Kansasdesign was for a

West Virginia

Missouri

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

Kentucky

3,425 ft, and the average length between the stages was approximately 200 ft.

Devonian Shale

Virginia

Tulsa

completions technology in preparation for drilling and completing longer laterals in the

The Results

area. Extending the reach of their open hole

All 18 stages were fractured and completed in

laterals was necessary to meet the operator’s

one day. These were gas fractures using half a

objectives of optimizing production and

million standard nitrogen per stage. Texascubic feet ofDallas

lowering costs.

The operator was pleased with the outcome and

Tennessee

Arkansas

North Carolina

Oklahoma

Alabama

South Carolina

Georgia

Louisiana

Austin

Houston Devonian Shale AppalachianBasin

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

Pennsylva

Packers Plus® Case Study

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

a system capable of more stimulation stages

Overall, the StackFRAC HD system was an

Since its discovery in the 1950s, the Bakken

without increasing the liner/frac string size,

operational success for the operator who is

formation has seen a progression of

which would increase cost.

continuing to use this system in the Bakken.

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 fieldproven 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 Challenge An 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

The benefits of this system are that it allows

The Solution

for increased production through longer

Packers Plus designed the StackFRAC HD™

laterals and shorter stage lengths, while

system with improved staging technology.

keeping costs down through the ability to use

This particular well used a 4 ½” liner, which would normally have a maximum of 11 stages. With the StackFRAC HD technology they

smaller frac strings and liner sizes.

Edmonton Edmonton

Pembina Pembina

were able to run a 20-stage system with an average of 65 m between stages along the 1,375 m open hole lateral.

Red Deer Red Deer

Calgary Calgary

Alberta Alberta

Saskatchewan Saskatchewan

Manitoba Manitoba

Regina Regina Winnipeg Winnipeg

The Results The 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 m /min with between 3

Montana MontanaBillings Billings

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

Bismarck Bismarck

N. N. Dakota Dakota S. Dakota S. Dakota Rapid City Rapid City

Wyoming Wyoming

Nebraska Nebraska

fluctuation was noted ahead of the ball seating indicating that the balls were able to run through the upstream seat.

Bakken Bakken Shale Shale Williston Williston Basin Basin

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

Packers Plus® Case Study

Packers Plus StackFRAC Gets Well on Production Fast StackFRAC Multi-Stage Fracturing System Key to Successful Completion in Oklahoma Background One of the only operators working in the Cottage Grove sandstone formation in

Colorado

Kansas

Missouri

Dewey County, Oklahoma required multistage 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

New Mexico

cost. The fewer days spent working on

Dewey County Oklahoma

Anadarko Basin

Arkansas

completing the project, the better their bottom line.

Texas

The Challenge The operator wanted to mill out the ball seats

The Solution

The Results

directly post-stimulation as they planned to

Packers Plus designed a 7-stage, 4 ½”

The combination of Packers Plus’ experience

cut the pipe, eliminating the possibility for

StackFRAC system for the 6 ⅛” open hole

and technology not only allowed all seven

future operations. The challenge was to keep

horizontal lateral. The fracture procedure

stages to be fractured and completed in one

the number of days on wellsite to a minimum.

was designed for 92,000 pounds of

day, but also allowed for the ball seat mill out

Having completed 11 wells in three other tight

proppant per stage at an average rate

Houston procedure to be a quick process saving the client

formations in Oklahoma with the StackFRAC®

of 40 barrels per minute using CO2 and

valuable time and, in turn, reducing costs. The

system, the operator knew Packers Plus could

crosslinked gel. The completion was

proven consistency with which Packers Plus

provide superior tools and service. Packers Plus

successful and ball action was seen on all

manufactures its tools enabled the time savings

also recognized the value of working together

ball-actuated stages.

during the milling operation resulting in the well

Austin

with other service companies to accomplish

coming on production at least a day sooner than

the operator’s goal.

the operator expected.

Granite Wash

P E N N S Y LVA N I A N

Stratigraphic Guide to the Greater Anadarko Basin and Shelf

Do It Once Do It Right™

Packers Plus® Case Study

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

The Solution

The Doe Creek Member of the Kaskapau

operator decided to evaluate the potential

Having successfully used the StackFRAC®

shale formation is a light oil-bearing

of these transformative technologies to

system to target reserves in the Dunvegan

sandstone associated with the Dunvegan

enhance initial production rates, ultimate

and deeper Cadomin formations in the

delta in northwest Alberta. An operator

recovery and overall production economics

Hythe area, the operator decided to work

working in the Hythe area, just west of

of the Doe Creek formation.

with Packers Plus. A 6-stage StackFRAC

Grande Prairie has discovered a new pool in

system was installed to a total depth of

the Doe Creek formation at 1,000 m with

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

NORTHWEST PLAINS

an estimated 10 million barrels of original

to target the Doe Creek formation. The

and permeability measurements range from 19-23% and 200-700 mD, respectively.

The Challenge Based on vertical well production, the Doe Creek formation was classified as marginally economic. However, with recent technological advancements in horizontal

pay and used gelled LPG to fracture the formation and place the proppant.

Puskwaskau Smoky Group

in the range of 19% and average porosity

horizontal open hole accessed 950 m of Wapiti

Kaskapau

area, the recover factor is expected to be

U P P E R C R E TA C E O U S

oil in place. Based on analog pools in the

drilling, multi-stage fracturing and liquefied

The Results

Badheart

The successful application of multi-stage

Muskiki

fracture stimulation using the Packers Plus

Cardium

StackFRAC system and LPG fracturing

Howard Creek

has achieved economic success from an

Pouce Coupe

interval that was historically only marginally economic. Overall, this program has validated

Doe Creek

these exploitation technologies, which the

Dunvegan

company now plans to apply to other areas.

DU N

ELI

petroleum gas (LPG) fracturing, a junior

Hythe Field

Edmonton

British Columbia

Alberta

Saskatchewan

Calgary

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

Do It Once Do It Right™

Packers Plus® Product Overview

RockSEAL II Packer Overview

Operation

Advantages

The RockSEAL® II packer is a dual

The RockSEAL II packer is run in the open

• In service since 2000

element, solid body, hydraulic-set open

hole and set via hydraulic pressure. The

• Proven isolation through microseismic

hole packer that combines the sealing

elements are expanded by mechanical

strength of a mechanical element with

compression securing the packer against the

the setting force of a dual-piston cylinder

formation. If the packer needs to be retrieved

and mechanical body-lock system. The

it can be released with straight pull on the

packer has a specially designed elastomer

tubing string, cut to release or other methods

with the largest possible cross section to

depending upon specific requirements.

provide excellent expansion ratios to set in

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 –

Features

the RockSEAL II packer holds 10K even

with anti-preset features that allow it to

• Dual element/piston design

after a major drop in temperature

be pushed through tight spots in the well

• High expansion ratios

without pre-setting or shearing the packer.

• Anti-preset features for running in hole

oversized holes. The packer is also designed

Applications/Benefits

• Adjustable setting and releasing forces

• Vertical or horizontal completions

• Minimum running outer diameter

• Open or cased hole

• Elastomer package available for cased hole

• Isolation of individual zones • Water and gas shut-off • Retrievable bridge plug uses

• Allows for long-term isolation

applications • Available in HPHT and sour service formats • Various application-specific elastomer types

• Production control • Production testing

RockSEAL II Packer

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, 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

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

R&D Solutions Centraliser 4-1/2” for 6” Open Hole Slip on Solid Body Aluminium Alloy

Unit ID Sleeve Drift Sleeve OD Vane OD Vane Width Vane Degree No of Vane Length Annulus Area Turb Area Bypass Area  Material           

4.625” 4.562” 5.000” 5.750” 1.000” 27 Degree 4 x Spiral 8.000” 12.870 Sq Inch 4.585 Sq Inch 7.785 Sq Inch Alloy Aluminium LM-6

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

R&D Solutions 7” x 8-1/4” for 8-1/2” Open Hole Slip on ‘Solid Body Steel Centraliser’

Unit ID Sleeve Drift Sleeve OD Vane OD Vane Width Vane Degree No of Vane Length Annulus Area Turb Area Bypass Area as %  Material           

7.125” 7.062” 7.50” 8.25” 1.10” 22 Degree 4 x Spiral 8.000” 8.261 Sq Inch 6.782 Sq Inch 62.86 % Cast Steel

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

R&D Solutions 9-5/8” x 11-3/4” for 12-1/2” Open Hole Slip 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 Pty Ltd. Suite 6, Level 3, 1111 Hay Street , West Perth WA 6005 Australia T + 61 8 6140 1820 F + 61 8 9429 3098 ABN No 38 138 827 915

R&D Solutions Bow Spring Centraliser Selection

Hinged Non Welded Spring Bow Centraliser SH01

Hinged Non-Welded Bow Spring Turbolizer SH04

Hinged Non-Welded Stainless Steel Centraliser SS01

Hinged Welded Bow Spring Turbolizer SHIM

Hinged Welded Bow Spring Centraliser SHOP

Slip On Welded Bow Spring Centraliser SH03

Slip on Welded Bow Spling Turbolizer SH06

Welded Rotating Centraliser 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 Pty Ltd. Suite 6, Level 3, 1111 Hay Street , West Perth WA 6005 Australia T + 61 8 6140 1820 F + 61 8 9429 3098 ABN No 38 138 827 915

R&D Solutions Hinged Non Weld Bow Spring Centraliser

Sizes Hole Size 3-1/2” 6” 4-1/2” 6” 5-1/2” 8-1/2” 7” 8-1/2” 9-5/8” 12-1/4” 13-3/8” 17-1/2” 16” 19” 20” 26”

No of Bows 4 4 4 6 6 8 12 12

Height 21” 21” 21” 21” 24” 24” 24” 24”

Restoring Force 696LBF 742LBF 930LBF 2150LBF 3300LBF 2450LBF 2080LBF 2820LBF

Material Spring Bow ASTM A682/AISI 1600 or Equivalent ASTM A366/A569 or Equivalent R&D Solutions Pty Ltd. Suite 6, Level 3, 1111 Hay Street , West Perth WA 6005 Australia T + 61 8 6140 1820 F + 61 8 9429 3098 ABN No 38 138 827 915

R&D Solutions Centraliser Selection

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

R&D Solutions Centraliser Selection

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

R&D Solutions Centraliser Selection

Slip on Welded Centraliser SH12

Slip on Heavy Duty Positive Spiroliser SH13

Slip on Heavy Duty Centraliser SH14

Slip On Welded Cement Basket SH15

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

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

R&D Solutions Hinged Steel Nail Stop Collars

Sizes 3-1/2” 4-1/2” 5-1/2” 7” 9-5/8” 13-3/8”

Part No SC01-0312 SC01-0412 SC01-0512 SC01-0700 SC01-0958 SC01-1338

Unit ID 3.625” 4.625” 5.625” 7.125” 9.750” 13.56”

Max OD 4.580” 5.580” 6.580” 7.720” 10.74” 14.51”

Width 3.543” 3.543” 3.543 3.543” 3.543” 3.543

Sliding Force 4200 LBF 4200 LBF 9900 LBF 14800 LBF 16600 LBF 19400 LBF

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

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

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

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

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

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

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

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

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



CAN BE RUN AS A CONVENTIONAL GUIDE SHOE OR HAMMERED 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 Pty Ltd. Suite 6, Level 3, 1111 Hay Street , West Perth WA 6005 Australia T + 61 8 6140 1820 F + 61 8 9429 3098 ABN No 38 138 827 915

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 OF INTERNALS, ONLY THE NOSE



MADE IN AUSTRALIA

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

Increasing Tubular Life & Performance

www.maxtube.com

Over 30 years of proven field history

When corrosion starts in downhole tubing, the string soon fails. The result is downtime and increased operation costs for workovers and tubing pulls. DUOLINE provides the following SAVINGS: Rig time & cost Manpower time & cost Costly Chemical Treatments

Workover time & cost Expensive chrome or alloy completions

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.

Design Features 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

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.

Over 80 million feet installed worldwide MaxTube's field service: Running/ Pulling DUOLINE products in the well Inspection of DUOLINE stock or used DUOLINE joints

Performance Capabilities Temperature:

Up to 250 F / 121 C

Working Pressure: Full working pressure of the lined steel pipe

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

Portable Lining Units (PLUs) 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: 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.

Applications DUOLINE 20 has an outstanding performance history, both onshore and offshore, in demanding environments containing produced fluids and gasses with CO2 and H2 S. CO2 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 H2 S content CO2 content BHT Please visit www.maxtube.com or contact us for a DUOLINE Selection Form.

DUOLINE products offer an unsurpassed record for prevention of corrosion in very demanding conditions.

INCREASING TUBULAR LIFE & PERFORMANCE

DUOLINE is available in several grades

Liner Grout

Reference Band or Mark Liner

Extended Flare Corrosion Barrier Ring Corrosion Barrier Ring Flare Standard Flare

Grout

Premium Connections

API 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

Corrosion Barrier Ring - Duoline Technologies manufactures metal reinforced elastomer rings for API Connections.

Modified Premium Connections Corrosion Barrier Rings - glass reinforced PTFE rings are available for all Modified Premium Connections.

www.maxtube.com

DUOLINE 20 Dimensions and Weights

API Thread

Premium Thread

Grout FG Liner

FG Flare

Common DUOLINE Tubing Sizes B Pipe Size and Weight/foot

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”

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

Fibreglass Liner Inside Diameter

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”

C Fibreglass Flare Inside Diameter

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”

(other sizes also available)

t Fibreglass Liner Nominal Thickness

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”

Normal Lining Weight lb/Ft

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

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

Major DUOLINE users include : 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

PO Box 17319 Jebel Ali Dubai U.A.E

Riverview Business Centre Centurion Court North Esplanade West Aberdeen United Kingdom

Tel: + 971 4 881 7712 Fax: + 971 4 881 3354 Email: info@maxtube.com

Tel : + 44 1224 572 222 Fax : + 44 1224 584 488 Email: info@maxtube.com

www.maxtube.com

Metal to Metal Seal System

Caledyne Innovation and Integrity by Design

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

Caledyne Innovation and Integrity by Design

The Caledyne Metal to Metal Seal 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 316Â°C (600Â°F). Outstripping all but the highly fluorinated elastomers and silicones. Higher temp rated seals are available on request. Chemical compatibility The CMTM has an entirely metal outer surface, which comes into contact with the well environment. The metalâ&#x20AC;&#x2122;s chemical compatibility with well fluids and gases is far broader than an elastomer.

Sliding Sleeve

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 Rating The 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.

CRBP

Swabbing When 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. Retrievability The 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

Caledyne Packer

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. Crown Plug

Caledyne Innovation and Integrity by Design

Metal to Metal Seal System The 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

Application Permanent and retrievable packers Permanent and retrievable bridge plugs Liner Hangers Water shut off Sliding Sleeves Crown plugs

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

FACT053 ÂŠ Caledyne 2009

Issue

Prepared by:

DLS

Date

11/01/10

Approved by:

MRM

Technical Manual

Number: 0000007019

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.

1 ©

2010

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Approved by:

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Parameter To set in tubing size ODmax IDmin Length Top connection Bottom connection Metallurgy Elastomer Temperature range Tensile

Number:

Technical Manual

0000007019

Technical Specification

Value 5“ – 6” 3.000” (76.20mm) N/A 53.6” (1.36m) 1.500” AMMT Bullnose AISI4140-45 18-22Rc 80ksi per NACE MR0175 VITON 70HD 32-250°F (0-121°C) 82,650 lbf

Item 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17

Bill of Material Qty Top Sub 1 Piston Chamber 2 Piston 2 Shear Mandrel 2 Shear Sub 2 Main Housing 1 Return Spring 6 Flow tube 1 7.0mm Orifice 1 Bottom Sub 1 ¼” UNC Set Screw x 3/16” Long 4 ¼” UNC x ¼” Long Brass Shear Screw 24 Size 113 V75 O-ring 2 Size 117 V70 O-ring 1 Size 225 V70 O-ring 2 Size 228 V70 O-Ring 2 Key Set 1

N/A

Sundry Equipment 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

Orifice W/ 6mm dia hole

0000011107

N/A

Orifice W/ 8mm dia hole

0000011108

N/A

Orifice W/ 9mm dia hole

0000011109

N/A

¼” UNC x ¼” Long Mild Steel Shear Screw

0000003022

Description

Part number 0000007018 0000007017 0000007014 0000007013 0000007012 0000007016 0000004184 0000007010 0000007011 0000007015 0000005225 0000001371 0000005349 0000004774 0000001540 0000002928 REFER TO TABLE

2 ©

2010

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Issue

Prepared by:

DLS

Date

11/01/10

Approved by:

MRM

Technical Manual

Number: 0000007019

Assembly

Shifting profile 4.000” 4.125” 4.312” 4.562” 5.250”

‘B’

‘CM’

0000007025 -

0000007319 -

3 ©

2010

T18 issue 1

Issue

Prepared by:

DLS

Date

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Approved by:

MRM

Technical Manual

Number: 0000007019

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.

4 ÂŠ

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Prepared by:

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Date

11/01/11

Approved by:

MRM

Technical Manual

Number: 0000007019

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).

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

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.

5 ©

2010

T18 issue 1

Issue

Prepared by:

DLS

Date

11/01/11

Approved by:

MRM

Technical Manual

Number: 0000007019

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.

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

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.

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).

RIH as per standard coiled tubing procedure.

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

Pick up and set down to establish drag weights.

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

Shift profile sleeve up or down as required.

Reduce circulating rate to deflate HEST.

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).

6 ÂŠ

2010

T18 issue 1

Issue

Prepared by:

DLS

Date

11/01/11

Approved by:

MRM

Technical Manual

Number: 0000007019

Operational Calculations The chart on the previous page depicts typical working flow rate values for a 3.0â&#x20AC;? 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. Inflation pump rate

Maximum pump rate

BBL/min

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

7 ÂŠ

2010

T18 issue 1

Innovation and Integrity by Design

Caledyne Ltd Tool

Location

HEST Brazil HEST Canada HEST Canada HEST Canada HEST Canada

HEST Canada

HEST Canada HEST Canada HEST Canada HEST Canada HEST Canada HEST Canada HEST Canada HEST Canada

Application Open/close CBV SIT. Open/Close Sliding Sleeves Open/close sliding sleeves Open/close sliding sleeves Open/close sliding sleeves Open/close sliding sleeves Open/close sliding sleeves Open/close sliding sleeves Open/close sliding sleeves Open/close sliding sleeves Open/close sliding sleeves Open/close sliding sleeves Open/close sliding sleeves Open/close sliding sleeves

HEST Kuwait

Open/close sliding sleeves

HEST Kuwait

Open/close sliding sleeves

HEST Kuwait

Open/close sliding sleeves

HEST Kuwait

Open/close sliding sleeves

HEST Kuwait

Open/close sliding sleeves

Comment Customer purchased tool, third party deployment Open and close 5 times each way. Successful deployment.

Number of Runs TBC 5

Successful deployment

Third party deployment, keys assembled back to front. Key buckled under excessive loading. All components retrieved from well. No requirement for fishing. Successful deployment w/ replacement keys

Successful deployment

Customer purchased tool, third party deployment Standard tool dressed with brass shear screws. Load to open sleeves too high. Tool sheared out. Standard tool dressed with brass shear screws. Load to open sleeves too high. Tool sheared out. Dressed tool with steel screws. Successful deployment. Max load for coil applied. Sliding Sleeve stuck. All equipment retrieved. Dressed tool with steel screws. Successful deployment. Max load for coil applied. Sliding Sleeve stuck. All equipment retrieved. Dressed tool with steel screws. Successful deployment. Max load for coil applied. Sliding Sleeve stuck. All equipment retrieved.

Caledyne Limited Registered in Scotland SC249478

TBC 1

Innovation and Integrity by Design

Caledyne Ltd HEST Kuwait

Open/close sliding sleeves

HEST Kuwait

Open/close sliding sleeves

HEST Kuwait

Open/close sliding sleeves

HEST North Sea

Contingency Requirement

HEST Thailand

Contingency Requirement

HEST Thailand HEST Thailand HEST Thailand HEST Thailand HEST Thailand HEST UK HEST USA HEST USA HEST USA HEST USA HEST USA HEST USA HEST USA HEST USA HEST USA

Open/close sliding sleeves Open/close sliding sleeves Open/close sliding sleeves Open/close sliding sleeves Open/close sliding sleeves SIT. Manipulation of MIV/CBV. Open/close sliding sleeves Open/close sliding sleeves Open/close sliding sleeves Open/close sliding sleeves Open/close sliding sleeves Open/close sliding sleeves Open/close sliding sleeves Open/close sliding sleeves SIT. Manipulation of CBV.

Dressed tool with steel screws. Successful deployment. Max load for coil applied. Sliding Sleeve stuck. All equipment retrieved. Dressed tool with steel screws. Successful deployment. Sleeve opened successfully. All equipment retrieved. Dressed tool with steel screws. Successful deployment. Sliding Sleeve stuck. All equipment retrieved. Job cancelled due to stuck sliding sleeves. Customer purchased tool, third party deployment Customer purchased tool, third party deployment

TBC TBC

Successful deployment

Open and close 5 times each way. Successful deployment.

Successful deployment

Open and close 5 times each way. Successful deployment.

Caledyne Limited Registered in Scotland SC249478

Issue

Date

13-04-10

Product Information Sheet

Number: 0000011673

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.

2010

Page 1 of 2

www.caledyne.co.uk

13-04-10

Date

2010

Parameter Top Connection Lower Connection Maximum OD IDmin Length (open) Set-down rating Metallurgy

Issue

Page 2 of 2

Technical Information Size 5-1/2” 5-1/2” 17# JFE BEAR pin ½ muleshoe 149.86mm (5.900”) 124.00mm (4.882”) 800mm (31.5”) 189,000lb 13% Cr. 80ksi

Illustration 0000011673

Product Information Sheet

Item 1 2 3 4 5

www.caledyne.co.uk

BOM Description Spring J-Pin Body Muleshoe Plain Bearing

0000011673

Number:

Issue

Date

13-04-10

Product Information Sheet

Number: 0000011672

Caledyne Indexing Muleshoe Size 7” 29#

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

Certification Consult your Caledyne representative.

2010

Page 1 of 2

www.caledyne.co.uk

Issue

Date

13-04-10

Number:

Product Information Sheet

0000011672

Illustration 0000011672 Parameter Top Connection Lower Connection Maximum OD IDmin Length (open) Set-down rating Metallurgy ©

2010

Technical Information Size 7” 7” 29# VAM TOP HT pin ½ muleshoe 189.23 (7.450”) 156.03mm (6.143”) 1060mm (41.7”) 325,000lb 13% Cr. 80ksi Page 2 of 2

Item 1 2 3 4 5

BOM Description Spring J-Pin Body Muleshoe Plain Bearing

www.caledyne.co.uk

Caledyne Innovation and Integrity by Design

Water Line

Oil Line

Key Benefits

Caledyne Balance Pump The 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.

Water

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.

Oil

Application Low Volume Gas well de-watering

Certification Consult your Caledyne representative for details on type approvals. Travelling Ball

Technical Information Parameter

2.2" Balance Pump

Upper Connection

Compression fitting

Lower Connection

N/A

Max OD

2.2"

Length

82"

Temperature Range Elastomer Pressure Rating Metallurgy Max Production

Caledyne

100C

Portable Surface Actuator

VITON 5000 PSI As Required Depth dependent, 10 bbls/day nominally

Contact Caledyne for details on all available sizes and Technical Manuals

Standing Ball Sand Screen

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 rates Additional features include: • Automatic Optimization • Remote Access to control system • RS232 Digital Output

Anti lock Shroud

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

Balance Pump

Caledyne Innovation and Integrity by Design

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

Caledyne

Innovation and Integrity by Design

Water Line

Caledyne Balance Pump The 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.

Oil Line

Key Benefits Zero tubing wear from rod movement in deviated sections. Water

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.

Oil

Sand screen to filter larger particles from intake Low friction, wear resistant seals with excellent fluid compatibility to increase pump life

Technical Information Parameter

2.25” Balance Pump

2.25” (57.15mm)

Length

228” (5795mm)

Upper Connection

1.375” External Fishing Neck

Lower Connection

N/A

Pressure Rating Temperature Rating Max Production

Travelling Ball

Application Low volume gas well dewatering

5,000psi

Low volume oil production (See FACT-062)

Dependent on Elastomer Selection Depth Dependent – 12bbls/day @ 10,000ft

Certification

Contact Caledyne for details on all available sizes and Technical Manuals

Consult your Caledyne representative for details on type approvals.

Standing Ball Sand Screen

Gas Anchor

Caledyne

Innovation and Integrity by Design Material Selection Components

Standard Environment

Corrosive Environment

Severe Corrosive Environment

Manufactured 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.

Monel

Elastomer

Viton

Aflas

Plastic

Turcon T-19

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 sideby-side – or cylindrical – with the lines helically wound to ensure simplified spooling. Encapsulated Control Line

Parameter

2.25” Balance Pump Umbilical

Encapsulation Type

Flatpack

Cylindrical

Overall Dimensions

2.087” x 0.867” (53mm x 22mm)

1.5” OD (38.1mm)

Encapsulation Material Control Line Size Control Line Material Cable Details

Polyolefin 5/8” x 0.080” wall thickness 316Ti stainless steel welded, calibrated and annealed tube 16mm OD galvanised or PVC coated

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.

Dual Control Line Hanger

Caledyne ÂŽ

Innovation and Integrity by Design

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.

Caledyne Innovation and Integrity by Design

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. Surface Control Unit

Parameter

2.25â&#x20AC;? Balance Pump Surface Control Unit

Overall Dimensions (SCU)

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

Overall Dimensions (Accumulator Bank)

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

Reservoir Volume Accumulator Volume (Per Bank) Minimum Air Requirements Minimum Power Requirements

100L 54 @ 6,000psi 260scfm @ 125psi 123L/s @ 8.6bar 400V, 3 phase, 20kW

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

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.

Caledyne Ltd Unit A, Hydropark Tern Place Bridge of Don Aberdeen AB23 8JX

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.

Subsurface Barrier Valves

Technical Information for MIV and CBV 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

Pressure Rating across Ball

5,000psi

Pressure Rating across Housing

10,000psi

398,000lbf NEW VAM Yield (1.2 F of S)

Temperature Rating Tensile Rating (80 ksi Material)

0-150 °C 172,500lbf NEW VAM Yield (1.2 F of S)

294,000lbf NEW VAM Yield (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

Contact Caledyne for details on all available sizes and Technical Manuals

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.

FACT009 © Caledyne 2009

Caledyne Innovation and Integrity by Design

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

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 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.

Caledyne FLV

An equalising feature may be incorporated to ensure pressure is balanced across the ball prior to opening.

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.

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

• • •

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.

Key benefits • • • • • • •

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.

• •

Technical Information for FLV 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)

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

4 1/2" 12.6# premium box

5 1/2" 17# premium box

Lower Connection

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

118,000lbf

192,000lbf

Pressure Rating

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

5000psi

Temperature Rating Maximum hang off weight

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.

The Fluid Loss Valve (FLV) is an ISO28781 type AA valve used to hold pressure from above and used in pre and postproduction pressure applications such as to protect the formation when the pump is switched off.

• • •

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

0-150 °C 46,500lbf

44,500lbf

214,500lbf

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

Contact Caledyne for details on all available sizes and Technical Manuals

FLV

CBV

MIV

Issue

Date

22-04-10

Product Information Sheet

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 rodpumping 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 ODmax IDmin Length Metallurgy Connection

5-1/2” 15.5#-17# x 2-7/8” 6.5# 4.508” (114.50mm) 2.441” (62.00mm) 58” (1476mm) AISI 4140-45 18-22Rc L-80 2-7/8” 6.5# EU-E Box x Pin

Certification Consult your Caledyne representative.

2010

Page 1 of 1

www.caledyne.co.uk

Metal to metal Caledyne Retrievable Innovation and Integrity by Design Bridge Plug 300째C -10,000 psi - Any environment

Caledyne Innovation and Integrity by Design

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. 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. 5

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

Certification As per customer requirement, typically ISO 14310 level V3.

1. Retrievable Bridge Plug 2. Setting Adaptor 3. Setting tool 4. Pulling Adapter 5. CDIV-2 Injection Valve 6. Gauge Hanger

Caledyne Innovation and Integrity by Design

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 Installation and Retrieval The 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.

Adapter Kits The 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.

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

Caledyne CDIV-2 Caledyne 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.

Tubing

size

OD max (in)

ID min (in)

2-3/8”

1.875

1.650

0.943

2-7/8”

2.313

2.303

1.322

3-1/2”

2.750

2.600

1.486

4”

3.313

3.250

1.850

4-1/2”

3.813

3.500

2.000

5”

4.313

3.800

2.188

5-1/2”

4.437

4.400

2.500

Caledyne Innovation and Integrity by Design

5” CRBP TECHNICAL DETAILS Pressure rating

10,000psi

Temperature rating

300°C

Maximum 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 DETAILS Pressure rating

10,000psi

Temperature rating

300°C

Maximum 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 Rc, 420 stainless or better)

6-5/8” CRBP TECHNICAL DETAILS Pressure rating

10,000psi

Temperature rating

300°C

Maximum OD

140mm (5.152”)

Minimum ID

63.12mm (2.548”)

Length (with equalization sub)

2220mm (87.4”)

Setting range

144.2-150.40mm

Metallurgy

Minimum 80ksi (typically AISI 4140-45 18-22 Rc, 420 stainless or better)

7” CRBP TECHNICAL DETAILS Pressure rating

10,000psi

Temperature rating

300°C

Maximum 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 Rc, 420 stainless or better)

Contact Caledyne for details on all available sizes and Technical Manuals

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”

â&#x20AC;&#x153;Simple Software and Smart Gaugesâ&#x20AC;?

Pioneer Petrotech Services Inc. manufactures and services a wide range of oilfield instruments, including electronic downhole pressure gauges, surface readout gauges, permanent installation systems, and wellhead pressure loggers. Pioneer Petrotech Services instruments are designed and manufactured with the most recent state of the art technology. Our products are produced with automatic calibration systems to assure our customers to obtain accurate data. Pioneer Petrotech Services Inc. has received world wide recognition due to quality, commitment, and unequalled customer 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: infopps@pioneerps.com

ADVANTAGES OF PPS SERIES OF ELECTRONIC GAUGES EASE OF OPERATION

The PPS series of gauges are designed to be compact and lightweight for convenient handling 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.

SIMPLE TO USE SOFTWARE

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.

RELIABLE PERFORMANCE

Innovative mechanical and electronic design make the gauges resistant to vibration and interference. 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.

LOW POWER CONSUMPTION AND LONG BATTERY LIFE

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.

HIGH SENSITIVITY

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

MEMORY CAPACITY

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).

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: infopps@pioneerps.com â&#x20AC;&#x153;Simple Software and Smart Gaugesâ&#x20AC;?

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.

SPECIFICATIONS Sensor Type

Up to - 20,000 PSI

Pressure Accuracy

±0.03% (full scale) 0.0003%

Pressure Resolution Pressure Drift

<3 psi / year o

125 C(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 Service

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

Silicon-Sapphire

Pressure Ranges

Temperature Rating

APPLICATIONS:

9” (229mm), 11”(279mm) 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 housing and electronic section. Six pin with locking mechanism connector is used to provide dual power channels and prevent battery disconnection during operations.

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

SPECIFICATIONS Sensor Type

Silicon-Sapphire

Pressure Ranges

Up to - 25,000 PSI

Pressure Accuracy

±0.03% (full scale) 0.0003%

Pressure Resolution Pressure Drift Temperature Rating

<3 psi / year 150°C(302°F) / 177°C(351°F)

Temperature Accuracy

±0.5°C

Temperature Resolution

0.01°C

Power Source

One CC lithium pack

Communications

USB/RS232

Data Set Contents

Time / pressure / temperature

Memory Capacity

1M data sets, larger memory optional

Outside Diameter

1.27”(32.3mm), 1.5”(38.1mm)

Overall Length Service

11.7”(297mm) H2S

Housing Material Sample Rate

Inconel 718 1 second to 18 hours per sample

PPS26 Surface Read-Out Pressure Gauge The PPS26 silicon-sapphire electronic downhole surface 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).

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

SPECIFICATIONS Sensor Type

Silicon-Sapphire

Pressure ranges

Up to - 20,000 psi

Pressure Accuracy

±0.03% (full scale)

Pressure Resolution Pressure Drift Temperature Rating

0.0003% <3 psi / year 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 Work Mode Service

5.5” (140 mm) SRO H2S service

Housing Material Sample Rate

Inconel 718 / Stainless Steel 17-4 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 configurations. 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.

THE WHOLE SYSTEM INCLUDES: • • • • • •

Downhole Pressure Gauge Gauge Carrier Electric Cable Cable Protectors

APPLICATIONS:

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

Cable Head Adapter and Seal Accessories Surface Data Acquisition System

SPECIFICATIONS Sensor Type Pressure Accuracy Temperature Accuracy Overall Length Pressure Ranges Pressure Resolution Pressure Drift Temperature Rating Temperature Resolution Power Source Communication Data Set Contents Display Mode Outside Diameter Work mode Service Housing Material Sample rate

Silicon-Sapphire Quartz ±0.03% (full scale) ±0.015% (full scale) ±0.5°C ± 0.15oC 8” (203 mm) 15”(381 mm) Up to - 20,000 psi 0.0003% < 3 psi / year 125oC (257oF) / 150°C (302°F) / 177°C (351°F) 0.01°C 12 V DC USB/RS232 Time / pressure / temperature liquid crystal 0.75” (19.1 mm) / 1.0” (25.4 mm) / 1.25” (31.8 mm) SRO H2S service Inconel 718 / Stainless Steel 17-4 1 second to any longer period

PPS28 Quartz Electronic Memory Gauge The PPS28 Quartz Memory Gauges are developed for critical well testing and are designed to be run by Wireline/Service personnel with limited computer knowledge or experience in running memory gauges.

APPLICATIONS:

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.

SPECIFICATIONS Sensor Type Pressure Ranges Pressure Accuracy Pressure Resolution Pressure Drift Temperature Rating Temperature Accuracy Temperature Resolution Power Source

Quartz Up to - 20,000 psi ±0.02% (full scale), ±0.015% (full scale) Typically 0.00006% F.S. < 0.02% psi/ year, F.S. 150°C (302°F), 177°C (351°F) ±0.2°C 0.01°C 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 Housing Material Service

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

23” (584 mm) with 1CC pack Inconel 718 / Stainless Steel 17-4 H2S service

Sample Rate

0.1 second to 18 hours per sample

Calgary, Alberta, Canada Phone: 403-282-7669 Fax: 403-282-0509 Calgary, Alberta, Canada Toll Free Phone in 403-282-7669 USA & Canada: Fax: 1-888-PP-GAUGE (774-2843) Phone: 403-282-0509 www.pioneerps.com Email: 1-888-PP-GAUGE infopps@pioneerps.com Toll Free Phone in USA & Canada: (774-2843) “Simple Software and Smart Gauges” www.pioneerps.com Email: infopps@pioneerps.com

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 technologies are applied to greatly extend gauge life at high temperature. The gauge uses six pin with locking connector to provide dual power channels and prevent battery disconnection. The same simple to use PPS SmartView software is used for programming, downloading and conducting data processing.

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

SPECIFICATIONS Sensor Type Pressure Ranges Pressure Accuracy

Quartz Up to - 25,000 psi ±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

Seal type Sample Rate

Metal to Metal and Elastomer 0.1 second to 18 hours per sample

PPS31 Wellhead Pressure Logger The PPS31 logger is a wellhead digital pressure and temperature monitoring instrument. The radio transmission 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.

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

SPECIFICATIONS Sensor Type Pressure Ranges Pressure Accuracy Pressure Resolution Pressure Drift Temperature Rating Temperature Accuracy Temperature Resolution Power Source Data Set Contents Memory Capacity Display Mode Data Receiving Mode Wireless Transmission Distance Transmission Power Outside Diameter of Indicator Dial Overall Length Work Mode Service Sample Rate Connection Safety Rating

Silicon-Sapphire Up to - 15,000 psi ±0.03% (full scale) 0.0003% <3 psi / year -40°C (-40°F) to 80°C (176°F) ±0.5°C 0.01°C 2 D lithium cells, up to one year usage Time / pressure / temperature 1,000,000 data sets liquid crystal Wireless (915MHz, ISM) 328 ’ (100m) + 10 dbm 4.625” (117.5 mm) 10” (254 mm) MRO / SRO H2S service 1 seconds to 18 hours per sample 1/2” NPT/Autoclave C.S.A. / Class 1, Division 1, CE Marking

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 program 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 enclosure for easy replacement. The same simple to use PPS SmartView software is used for data processing.

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

SPECIFICATIONS Sensor Type Pressure Ranges Pressure Accuracy Pressure Resolution Pressure Drift Temperature Rating Temperature Accuracy Temperature Resolution Power Source Data Set Contents Memory Capacity Display Mode Data Transmission Mode Wireless Transmission Distance Transmission Power Outside Diameter of Indicator Dial Overall Length Work Mode Service Sample Rate Connection Safety Rating

Silicon-Sapphire/RTD Up to - 15,000 psi ±0.03% (full scale) 0.0003% <3 psi / year -40°C (-40°F) to 80°C (176°F) ±0.3°C 0.01°C 2 D lithium cells, up to six months Time / pressure / temperature 1M data sets on flash memory, SD card. liquid crystal Bluetooth/USB 100m (328 ft) + 10 dbm 4.625” (117.5 mm) 10” (254 mm) MRO / SRO H2S service 1 seconds to 18 hours per sample 1/2” NPT/Autoclave C.S.A. / Class 1, Division 1, CE Marking

PPS33 Multi-Sensor Wireless System The PPS33 Multi-Sensor Wireless System is developed for applications requiring simultaneous multipoint pressure, temperature and/or flow monitoring such as wellhead, well testing, and pipeline operations. ZigBee wireless package allows a master data logger to receive data from up to 60 individual sensors 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.

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

SPECIFICATIONS Sensor Type Pressure Ranges Pressure Accuracy Pressure Resolution Pressure Drift Temperature Rating Temperature Accuracy Temperature Resolution Power Source Data Set Contents Memory Capacity Display Mode Data Transmission Mode Wireless Transmission Distance Transmission Power Outside Diameter of Indicator Dial Overall Length of sensors Work Mode Service Sample Rate Connection Safety Rating

Silicon-Sapphire/RTD/Turbine Up to - 15,000 psi ±0.03% (full scale) 0.0003% <3 psi / year -40°C (-40°F) to 80°C (176°F) ±0.3°C 0.01°C 2 D lithium cells, up to six months Time / pressure / temperature/Flow 2M data sets on flash memory, SD card. liquid crystal ZigBee/Modbus/USB 100m (328 ft) + 10 dbm 4.625” (117.5 mm) 10” (254 mm) MRO / Real Time H2S service 1 seconds to 18 hours per sample 1/2” NPT/Autoclave C.S.A. / Class 1, Division 1, CE Marking

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.

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

SPECIFICATIONS Sensor Type

Silicon-Sapphire

Pressure Ranges

Up to - 15,000 psi

Pressure Accuracy

±0.03% (full scale)

Pressure Resolution Pressure Drift Temperature Rating Temperature Accuracy Temperature Resolution Power Source

0.0003% <3 psi / year 150°C (300°F) ±0.5°C 0.01°C 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

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 temperature measurement with small ID coiled tubing.

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

SPECIFICATIONS Sensor Type

Silicon-Sapphire

Pressure Ranges

Up to - 10,000 psi

Pressure Accuracy

±0.03% (full scale)

Pressure Resolution Pressure Drift Temperature Rating

0.0003% <3 psi / year 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 technology 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 standard side pocket mandrel tools.

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

These gauges still use the very simple, but powerful PPS SmartView software that all our other gauges use.

SPECIFICATIONS Sensor Type

Silicon-Sapphire

Pressure Ranges

Up to - 15,000 PSI

Pressure Accuracy

±0.03% (full scale) 0.0003%

Pressure Resolution Pressure Drift Temperature Rating

<3 psi / year 125oC(257oF) / 150°C(302°F) / 177°C(351°F)

Temperature Accuracy

±0.5°C

Temperature Resolution

0.01°C

Power Source

One AA lithium battery pack

Communications

USB/RS232

Data Set Contents

Time / pressure / temperature

Memory Capacity

1M data sets, larger memory optional

Outside Diameter

1.0”(24.5mm), 1.5”(38.1mm)

Overall Length Service

12.31” (312.7mm), 19.50” (495.3mm) H2S

Housing Material

Inconel 718 / Stainless Steel 17-4

Sample Rate

1 second to 18 hours per sample

PPS55 Fast Sampling Gauge The PPS55 gauge offers a great opportunity to catch sharp pressure changes, such as the pressure breaking point for reservoir fracturing or perforation operations. The gauge can record up to 500 data points per second. The large memory capacity of 4 million data points, allows operators to have sufficient downhole running time during job operations .

APPLICATIONS: Stimulation Monitoring Injection Pressure Monitoring Perforation Monitoring Workover Monitoring

SPECIFICATIONS Sensor Type

Silicon-Sapphire

Pressure Ranges

Up to - 15,000 psi

Pressure Accuracy

±0.1% (full scale)

Pressure Resolution Pressure Drift Temperature Rating Temperature Accuracy Temperature Resolution Power Source

0.01 psi <3 psi / year 150°C(302°F) / 177°C(351°F) ±0.5°C 0.05°C 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 Service

9” or 12” H2S

Housing Material Sample Rate

Inconel 718 / Stainless Steel 17-4 Up to 500 data sets/ second

PPS58 Memory-SRO Combo Gauge The PPS58 Memory-SRO Combo Gauge offers either 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 applications and PPS SRO software is used for SRO operations.

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

SPECIFICATIONS Sensor Type

Silicon-Sapphire

Pressure Ranges

Up to - 20,000 PSI

Pressure Accuracy

±0.03% (full scale) 0.0003%

Pressure Resolution Pressure Drift Temperature Rating

<3 psi / year 150°C(302°F) / 177°C(351°F)

Temperature Accuracy

±0.5°C

Temperature Resolution

0.01°C

Power Source

One C lithium pack/12V for SRO

Communications

USB/RS232

Data Set Contents

Time / pressure / temperature

Working Mode

Memory or SRO

Memory Capacity

1M data sets, larger memory optional

Outside Diameter

1.0”(25.4mm) / 1.25”(31.8mm)

Overall Length Service

11”(279mm) H2S

Housing Material

Inconel 718 / Stainless Steel 17-4

Sample Rate

1 second to 18 hours per sample

PPS61 Temperature Gauge The PPS61 gauge is for applications that require a fast response to temperature changes. It allows analysts 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.

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

SPECIFICATIONS Sensor Type Pressure Ranges Temperature Rating

RTD Housing design for up to 20,000 PSI 150°C(302°F) / 177°C(351°F)

Temperature Accuracy

±0.1°C

Temperature Resolution

0.01°C

Power Source

One AA or C lithium pack

Communications

USB/RS232

Data Set Contents

Time / temperature

Memory Capacity

1M data sets, larger memory optional

Outside Diameter

0.75”, 0.875”, 1” or 1.25”

Overall Length Service

10”(254mm) H2S

Housing Material

Inconel 718 / Stainless Steel 17-4

Sample Rate

1 second to 18 hours per sample

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.

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

SPECIFICATIONS Sensor Type

Piezo Resistive/RTD

Pressure Ranges

Up to - 20,000 PSI

Pressure Accuracy

±0.03% (full scale) 0.0003%

Pressure Resolution Pressure Drift Temperature Rating

<3 psi / year 150°C(302°F) / 177°C(351°F)

Temperature Accuracy

±0.3°C

Temperature Resolution

0.01°C

Power Source

Dual 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”(19.1 mm) / 1.25”(31.8 mm)

Overall Length Service

16” (406 mm) H2S

Housing Material

Inconel 718 / Stainless Steel 17-4

Sample Rate

1 second to 18 hours per sample

Calgary, Calgary, Alberta, Alberta, Canada Canada Phone: 403-282-7669 Phone: 403-282-7669 Fax: Fax: 403-282-0509 403-282-0509 Toll Free Phone in USA & Canada: 1-888-PP-GAUGE Toll Free Phone in USA & Canada: 1-888-PP-GAUGE (774-2843) (774-2843) www.pioneerps.com Email: infopps@pioneerps.com www.pioneerps.com Email: infopps@pioneerps.com “Simple Software and Smart Gauges”

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 environment.

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

The same simple to use PPS SmartView software is used for programming, downloading and conducting data processing. All files are in ASCII data format.

SPECIFICATIONS Sensor Type

Piezo Resistive

Pressure Ranges

Up to - 20,000 PSI

Pressure Accuracy

±0.03% (full scale) 0.0003%

Pressure Resolution Pressure Drift Temperature Rating

<3 psi / year 315°C (600°F)

Temperature Accuracy

±0.3°C

Temperature Resolution

0.01°C

Power Source

Single AA lithium pack

Communications

USB/RS232

Data Set Contents

Time / pressure / temperature

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 Sample Rate

Inconel 718 / Stainless Steel 316 0.5 second to 18 hours per sample

Gauge Carrier APPLICATIONS: 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.

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

SPECIFICATIONS Outside Diameter

5” (127mm)

Inside Diameter

2.25” (57 mm)

Length

76” (1930 mm)

Pressure Rating Tensile Strength

Burst: 22,000 psi (150 MPa Collaps: 21,000 pis (145 MPa) 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)

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

ACCESSORIES

Battery Pack

Lubricant

Crossover

USB Interface

SRO Surface Box

O-ring

Battery Tester

Gauge Carrier

Weather Proof Case

Probes, Cables, & Accessories Product Data Sheet Optical Fiber Probes, Connections Accessories and Deployment

Overview 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.

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.

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.

Gel compound Secondary fiber coating Fiber coating Optical fiber

Inner protective sheath Primary protective sheath Outer protective sheath

Version 4.2

Probe Specification Optical Fiber The optical fiber is standard telecommunications grade. It is available as either 50/125µm graded-index multimode or 9/125µm stepindex 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.

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.

The SensorTran Advantage 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. 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.

Contact

Distributed Monitoring Solutions

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 sales@sensortran.com www.sensortran.com

LNG/Cryogenic Plant Monitoring Application Note Advanced DTS Solution for Cryogenic Plant Monitoring Overview 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 opencommunications 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. Applications

o LNG o LPG o Ethylene

o Ammonia o Oxygen, etc. o Pipelines

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

o Buried or above ground storage tanks o Single and double-wall tanks o On-shore and ship installations

Version 4.0

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.

Typical Installation Example 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.

Remote control and data input: Ethernet, OPC, SCADA, RS232, RS485, etc 2

Cabinet Monitor Pull-out keyboard DTS unit UPS

KEY

1. 2. 3. 4. 5. 6.

Data output and remote control via Ethernet, OPC, SCADA RS232, RS485, GPIB, relay contacts (alarm data only), etc Specially developed application software Multi-core fiber-optic transit cable Field optical junction box Fiber-optic cable for tank leak detection Fiber-optic cable for tank-heat monitoring Fiber-optic cable for pipeline leak detection and temperature monitoring

Cryogenic Plant Monitoring Software To complement DTS Manager Software, SensorTran has developed specific application displays for the monitoring of storage tanks and pipelines. This provides the human-machineinterface (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.

The SensorTran Advantage 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. 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.

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

+1-512-583-3520

+44 2380 30 2705

e-mail inquiries to sales@sensortran.com Distributed Monitoring Solutions

www.sensortran.com

SensorTran Software Suite Overview

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

Product/Software Offerings

   

Standard Software

Available Upgrades

Gemini

DTS Commander™

DataViewer™ AssetViewer™

Lynx

DTS Commander™ + DataFuser™

N/A

DTS Commander™

DataViewer™

DTS Commander™

DataViewer™

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



OEM Only

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.

Distributed Monitoring Solutions

DTS Commander™ 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™ Screenshot

Functions           

Temperature Plot in DTS Commander™

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

DataViewer™ 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.

Zonal Temperature Plot in DataViewer™

AssetViewer™ 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.

3‐D Data Representation in DataViewer™

Features 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.

Zoom in or out on Plot and Asset

Textures, Legend, & Icons Multiple Traces Set Alarm Conditions

Display Multiple Assets or History Single Point Temp over 30day time (Video play)

Various Asset Views & Bookmarks

Customer Logo

AssetViewer™ Configured for Power Cable Monitoring

DataFuser™ for Lynx™ 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.

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

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

Zoom in or out on Plot and Asset

Textures, Legend, & Icons

Mark Distance

Various Asset Views & Bookmarks

Set Alarm Conditions

Display Multiple Assets or History Single Point Temp over 30day time (Video play)

Customer Logo

DataFuser™ Configured for a Wellbore Monitoring Application

AssetViewer™ Configured for a Wellbore Monitoring Application

SensorTran is ISO 9001 Certified

Corporate HQ & Manufacturing

International Sales Office

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 sales@sensortran.com www.sensortran.com

Rev 5.0

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

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

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 Australia T + 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 clients and 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 Occupational Health and Safety (AOHS) requirements thereby leading to continual improvement in all areas of the services 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 while continuously 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 services and 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 related groups 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 other parties 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 public and the environment.



Ensure that our employees are fully aware of their statutory duties and that they take reasonable care of themselves, 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 and profile, Training our Staff and Sustaining its ethics and practices. Raise, Train, Sustain.

Signed:

Date:

24 May, 2010

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