Casing Isolation

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Casing IsolationCATALOGUE VERSION 1.0 JUL 2021

ContentsSPECIFICATIONSPage 05 Sizing InformationPage 06 UMS Flowell Tubing Thread PropertiesPage 09 Standard Metallic Material Options And CodesPage 10 Standard Seal Material Options And CodesPage 13 Completion Design Considerations

EQUIPMENTPage 22 Pod System (Encapsulated ESP)Page 24 Pod Hanger AssemblyPage 26 Pod Hanger Seal Sleeve & Lockdown Ring AssemblyPage 28 Offset UnionPage 30 Tubing Adjustable UnionPage 32 Flow Management Diverter Valve - StandardPage 34 Flow Management Diverter Valve - HydraulicPage 36 Pod Casing JointsPage 38 Pod Bottom Crossover AssemblyPage 40 Pod Tailpipe Nipple AssemblyPage 42 Pod Casing Clamps (Flush Joint Casing)

HANDLING EQUIPMENTPage 44 Pod WorktablePage 46 Pod Sleeve Handling Tool & Pressure Test ToolPage 48 Lift Nubbin For Flush Joint CasingPage 50 Pod Well Control SubPage 52 Pod Hanger Stabbing Guide

CASING ISOLATIONPage 14 Single Pod (Sealed Encapsulated ESP)Page 16 Dual Pod For RedundancyPage 18 Dual Boost - Pumps Operating In Series

CASING ISOLATION WITH RESERVOIR ACCESSPage 20 Y-Tool Inside a Pod

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Sizing Information

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Well Casing Size Maximum POD Casing Size Maximum ESP Series

7” 5-1/2” 456

7-5/8” 5-1/2” 456

8-5/8” 7” 562

9-5/8” 7-5/8” 562

10-3/4” 8-5/8” 562

13-3/4” 10-3/4” 738

The following sizing information is a guide relating to well casing and ESP sizes.

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FCJ (Flowell Coupled Joint)

Dimensional Data Make Up Data L80 Grade Performance Properties L80 Grade

Pipe OD (in)

Nominal Weight (lb/ft)

WallThickness(in)

Pipe ID (in)

Drift (in)

Make Up Loss (in)

Min(ft-lbs)

Optimum(ft-lbs)

Max(ft-lbs)

Burst (psi)

Collapse (psi)

Tensile (kips)

Compression (kips)

1.900 3.64 0.200 1.500 1.406 2.267 420 560 700 14,737 15,069 85 85

2.375 4.6 0.190 1.995 1.901 2.517 810 900 990 11,200 11,776 104 104

2.875 6.4 0.217 2.441 2.347 2.771 1,530 1,700 1,870 10,567 11,165 145 145

3.500 9.2 0.254 2.992 2.867 3.060 2,610 2,900 3,190 10,160 10,540 207 207

4.500 12.6 0.271 3.958 3.833 3.253 3,500 3,940 4,380 8,431 7,501 288 288

F2J (Flowell Flush Joint)

Dimensional Data Make-Up Data L80 Grade Performance Properties L80 Grade

Pipe OD (in)

Nominal Weight (lb/ft)

Wall Thickness (in)

Pipe ID (in)

Swaged Pin ID (in)

Drift (in)

Make Up Loss (in)

Min(ft-lbs)

Optimum(ft-lbs)

Max(ft-lbs)

Burst (psi)

Collapse (psi)

Tensile (kips)

Compression (kips)

1.050 1.5 0.154 0.742 0.704 - 1.28 *80 *100 *120 *7,700 *7,409 *5.9 *3

2.125 2.4 0.157 1.811 - 1.717 2.00 - - - - - *17**28

*9**15

2.375 2.6 0.109 2.157 - 2.063 1.282 - - - - - *13 *7

2.375 4.6 0.190 1.995 1.957 1.901 2.19 250 300 350 11,200 11,776 47 19

2.750 4.4 0.160 2.430 - 2.336 2.00 - - - - - **27 **14

2.875 6.4 0.217 2.441 2.377 2.347 2.60 400 500 600 10,567 11,165 67 28

2.875 6.4 0.217 2.441 - 2.400 2.00 - - - - - 64 26

4.250 10.0 0.248 3.756 - 3.631 3.25 - - - - - **78 **40

5.500 15.5 0.275 4.950 - 4.825 3.50 - - - - - 170 80

5.500 15.5 0.275 4.950 4.875 4.825 3.50 2,400 2,600 2,800 7,000 4,990 170 80

UMS Flowell Tubing Thread Properties

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* Figures based on 316 stainless steel seamless tube 30ksi minimum yield.** Figures based on grade E355 carbon steel seamless tube 50ksi minimum yield.All other make up and performance properties based on 80ksi base material.Items with a drift of 1.717” and above are suitable for a standard 1-11/16” (1.6875”) OD Production Logging Tool.Items without torque figures, and without burst and collapse ratings are non-sealing connections used as a conduit tube only.Performance properties based on API 5C3 calculations.

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Standard Metallic Material Options And Codes

Part Type

Part Number Suffix Material Type Tubing Machined Components Castings

13CR 13% Chrome stainless steel API 5CT L80 13CR AISI 410/420MOD 80KSIMinimum yield, 22RCMaximum hardness

ASTM A487 Grade CA6NM Class B, 23RC Maximum hardness

L801 Low alloy steel API 5CT L80 Type 1 - -

4140 Low alloy steel API 5CT L80 Type 1 AISI 4140 80KSI minimum yield, 22RC maximum hardness

-

4130 Low alloy steel - - AISI 4130 80KSI 22RCMaximum hardness

Material Max. pH2S Max. pCO2 Upper Temp Limit (°F)

Min PH Max. Chlorides (ppm)

Typical pCO2/pH2S

DominantCorrosion

13CR 1.5 psi 1450 psi 302 5.5 100000 >500 CO2

Low alloy steel Unlimited 15 psi 475 5.5 100000 <20 H2S

UMS Flowell standard metallic materials are NACE MR-0175 compliant. A list of common standard materials used for our downhole equipment is shown below.

13Cr material is generally used for dominant C02 corrosion applications, and the low alloy steel (L80 Type 1) is used for applications where high concentrations of H2S can potentially cause sulphide stress corrosion cracking. Limitations are shown in the table below.

Partial pressure of gas = system total absolute pressure (downhole pressure) x mole fraction of gas present.

For example, if the mole fraction of C02 was 0.2 and the bottom hole pressure was 3,000psi, the partial pressure of C02 (pCO2)= 0.2x3000 = 600psi, and the mole fraction of H2S was 0.0002, partial pressure of H2S (pH2S) = 0.0002x 3000 = 0.6psi.

The bottom hole temperature is 275°F. The dominant corrosion would be CO2 and 13Cr material should be selected.

Other factors may affect material selection, and where appropriate you should consult the customer, and/or with a suitable corrosion engineering expert.

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Some exceptions to the above are;1) Structural downhole standard fastener material – Inconel 718 120KSI minimum yield, 40 RC maximum.2)Non structural downhole fastener material - 316 or 304 stainless steel3)Non API stainless tubing – 316 stainless steel.4) Non API carbon steel tubing – EN 10296-1-2003 grade E235 or E355

5) Downhole service tools such as isolation tools, coil tubing plugs and stinger assemblies are 17-4 PH stainless steel 105ksi minimum yield, 35RC maximum hardness.6) All downhole service tools such as standing valves, isolation tools, wireline logging plugs and coil tubing plugs are provided in stainless steel as standard to increase service and storage life. These parts are not offered in a low alloy steel unless otherwise requested by a customer.

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Standard Seal Material Options And CodesUMS Flowell standardise elastomers in Fluoroelastomers (FKM) material which is commonly known as the trade name Viton. Other elastomers are available and in some applications non elastomeric seals are provided.

Elastomer Material

Environment HNBR Viton* Aflas*

Maximum recommended temperature 325°F 400°F 400°F

Minimum recommended temperature Minus 40°F 40°F 75°F

Crude oil OK OK OK

Natural gas w/ condensate OK OK OK

Formation or injected water Up to 300°F Up to 300°F OK

H2S Up to 100ppm Up to 300°F OK

CO2 Gas OK OK OK

Water based mud Up to 300°F Up to 300°F OK

Oil based mud OK OK OK

Ester containing mud NO OK OK

Diesel OK OK OK

Brine completion fluid, pH <9 OK Up to 300°F OK

Brine completion fluid, pH >9 NO NO OK

Sea water OK OK OK

Zinc bromide NO Up to 300°F OK

Amine based inhibitors Up to 300°F Up to 200°F OK

Hydraulic oil, mineral oil OK OK OK

Hydraulic oil, approved synthetic OK OK OK

Water glycol hydraulic fluid, pH <9 Up to 200°F Up to 200°F OK

Water glycol hydraulic fluid, pH >9 NO NO OK

Hydrocarbon solvents, aliphatic eg Hexane, Kerosene

Up to 325°F OK OK

Hydrocarbon Solvents, aromatic eg Xylene, Toluene

Up to 300°F OK OK

Hydrocarbon solvents, chlorinated OK OK OK

Hydrocarbon solvents, oxygenated Up to 300°F Up to 300°F OK

Methanol, dry Up to 300°F Up to 300°F OK

HCl acid Up to 300°F Up to 300°F Up to 400°F

HF/HCl Up to 275°F Up to 300°F Up to 400°F

Acetic acid Up to 275°F Up to 300°F OK

Steam NO NO OK

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Completion Design Considerations

Select Pod casing wall thickness and grade to suit well conditions and

parameters. Due to well drawdown, Pod casing collapse rating is an important

consideration.

Select the Pod casing size relating toWell Casing size and ESP

Where necessary, increase the pod casing size depending on flow rate and Motor Lead Extension (MLE) size.

Perform a tubing stress analysis. Due to well drawdown, the piston effect on the seal bore packer puts an increased tensile load on the production tubing. This can be minimised using a

larger seal bore on the packer or spacing out the No-Go locator.

A tubing stress analysis can assist with determining space out. Preventing tubing stretch by space out may also create buckling failure. Where necessary, increasing the pod hanger connection

may be required to improve the mechanical properties (size, weight per foot, grade).

Select the cable connector type. Where a pod hanger concentric tubing connection or a large as possible tubing connection is required, use a split phase cable connector or an inverted packer

penetrator.

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Single Pod(Sealed Encapsulated ESP)CASING ISOLATION

Encapsulated ESPs (or pods) are commonly used in ESP well completions as an alternative to using ESP packers.

The ESP is installed inside a sealed unit with a packer style cable connector at the Pod hanger. With an ESP pod completion, the tailpipe below the pod has a seal assembly that engages the seal bore packer.

This then isolates the production casing above the packer from the produced well fluids, protecting your casing from potential corrosion and erosion of the production casing at the pump intake.

Workover can be achieved with an isolation valve to prevent damage to the formation with kill fluids.

Advantages:

• Isolates the production casing from produced well fluids

• ESP packer is replaced with a seal bore packer

• Workovers can be done without killing the well and damaging the well perforations with kill fluid

• Used in ESP Drill Stem Tests (DST) where annulus pressure is applied to actuate DTS tools

Disadvantages:

• No access to the well reservoir

ESP Assembly PackerFMDV

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ProductionZone

Pod Casing Clamps

Tailpipe Tubing ConnectionSeal Bore PackerLower Pod Crossover Assembly

Pod Casing

1

2

3

4

5

ESP Gauge6

ESP Motor7

MLE Protector8

MLE Cable

ESP Pump IntakeESP Pump

9

11

12

ESP Seal Protector10

Discharge Pressure Sub13

34567891081112413815416

FMDV15

Pod Hanger Assembly16

14

Discharge Head14

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Dual PodFor RedundancyCASING ISOLATION

Normally the upper ESP is run until failure. Once failed, production can be resumed by starting the lower ESP.

This extends production time and to allows a workover to be planned to eliminate deferred production. The switchover between ESPs is achieved using diverter valves above the pump discharge on the primary and backup ESP.

Advantages:

• Redundancy, should the primary ESP fail


• ESP packer is replaced with a seal bore packer

• Workovers can be done, without killing the well and damaging the well perforations with kill fluid

Disadvantages:


Pod Casing Clamps


Pod Casing

1

2

3

4

5

ESP Gauge6

ESP Motor7

MLE Protector8

MLE Cable


9

11

12



FMDV15


ProductionZone

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Upper ESP Assembly Lower ESP AssemblyUpper FMDV Lower FMDV Seal Bore Packer

3

4

56791011121315

44444

88

8

88

8

356791011121315 1616 1414

Discharge Head14

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Dual Boost – Pumps OperatingIn Series CASING ISOLATION

By operating both ESPs simultaneously in series, the dual boost system provides a high horsepower system to create large drawdown, to provide the necessary boost for wells with depleted reservoir pressure.

Use of diverter valves provides flexibility to run one or both ESPs in the event of failure or using one ESP during well early life and both ESPs in well late life.

Advantages:

• Increased horsepower and pressure boost within well casing constraints, for increased production


Disadvantages:


Pod Casing Clamps


Pod Casing

1

2

3

4

5

ESP Gauge6

ESP Motor7

MLE Protector8

MLE Cable


9

11

12



FMDV15


ProductionZone

12

Upper ESP Assembly Lower ESP AssemblyUpper FMDV Lower FMDV Seal Bore Packer

3

4

56791011121315

44444

88

8

88

8

356791011121315 1616 1414

Discharge Head14

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ProductionZone (ESP)

Y-Tool Inside A PodCASING ISOLATION WITH RESERVOIR ACCESS

The Y-tool and Pod system can be combined as a single unit, to provide access to the reservoir through the Y-Tool bypass tubing, and provide casing isolation from the produced well fluids by having the y-tool bypass system inside the Pod.

The system eliminates the requirements for an ESP packer and removes the bypass tubing and ESP from being the weak point with high tailpipe loads below the ESP.

This is an advantage for ESP completions stabbing into a lower completion, or ESP drill stem tests (DSTs) where the DST tools are used, and protects the ESP when firing Tubing Conveyed Perforating (TCP) guns.

Access through the bypass tubing allows for production logging of the well.

Advantages:

• Provides production casing isolation as well as access to the reservoir

• Allows for high loads below the ESP

• Ideal for ESP Drill Stem Tests that require production logging as part of the programme

Disadvantages:

• Size constraints of ESP and bypass tubing

Pod Casing


Wireline Entry Guide (or X-over)

1

2

3

4

5

Motor Base Plug6

Bypass Tubing Clamp7

ESP Gauge8

Flush Joint Bypass Tubing

ESP Pump Intake

9

13

ESP Motor10

ESP Pump14


Discharge Head16

ESP Assembly (Lower Production Zone)Y-Tool Assembly Seal Bore Packer

12345

6

78910777 11121314

1517

Pump Sub17

18

Telescopic Swivel18

19

Bypass Nipple & Blanking Plug19

20

Y-Tool20

21

Top Nipple21

22


23

MLE Cable11

24

Production Tubing Connection24

Handling Sub22

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Minimum Well Casing Size Maximum POD Casing Size ESP Series Bypass Tubing Size (in)

8-5/8” 7” 26# 387 2.125

8-5/8” 7” 26# 375 2.375

9-5/8” 7-5/8” 29.7# 387 2.875

9-5/8” 7-5/8” 29.7# 456 2.125

10-3/4” 8-5/8” 40# 540 2.125

10-3/4” 8-5/8” 44# 456 2.875

13-3/8” 9-5/8” 47# 562 2.875

13-3/8” 9-5/8” 53.5# 562 2.375

13-3/8” 10-3/4” 60.7# 562 3.500

13-3/8” 10-3/4” 60.7# 675 2.375

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Pod System(Encapsulated ESP)

Cable Penetrator & Connector

ESP Power CablePod Hanger AssemblyLockdown Ring

Motor Lead Extension (MLE)

1

2

3

5

6

Discharge Head7

MLE Protector8


ESP Pump

ESP Motor

10

12

ESP Pump Intake10


Seal Sleeve Assembly4

Pod CasingESP MotorESP Gauge

13

14

15

Pod Bottom Crossover Assembly

16

Tailpipe Nipple Assembly17

Encapsulated ESPs - or Pods - are commonly used in ESP well completions, as an alternative to using ESP packers.

With an ESP pod completion, the tailpipe below the pod has a seal assembly that engages the seal bore packer. This then isolates the production casing above the packer from the produced well fluids, protecting your casing from potential corrosion and erosion of the production casing at the pump intake.

The UMS Flowell pod system comprises of the following items;

• Pod hanger assembly, complete with production tubing handling sub, optional nipple profile for testing the production tubing string, a sealing port for an ESP cable penetrator, and a tubing pup joint and offset union for make up to the pump discharge head

• Pod hanger seal sleeve and lock down ring, with a pin thread for make up to the pod casing

• Pod casing joints (coupled or flush joint)• Box x pin bottom crossover assembly to make up to the

tailpipe assembly• Tailpipe nipple assembly for pressure testing the pod

casing prior to installing the ESP• Pod sleeve handling and pod pressure test tool• Swivel lift nubbin for handling flush joint pod casing• Pod work table for installing the ESP inside the pod• MLE and discharge pressure line protector clamps• Standing valve for setting in the tailpipe nipple, for

pressure testing the pod prior to installing the ESP inside the pod, and for the optional nipple in the pod hanger assembly, for testing the production tubing

Technical Specifications

Pod Hanger Assembly

ESP Pump Intake

Discharge Head & Discharge Pressure Sub

ESP Gauge

Pod Bottom Crossover Assembly

Well Casing Size POD Casing Size Maximum ESP Series

7” 5-1/2” 456

7-5/8” 5-1/2” 456

8-5/8” 7” 562

9-5/8” 7-5/8” 562

10-3/4” 8-5/8” 562

13-3/8” 10-3/4” 738

7

98

10

11

8

8

12

14

15

13

16

17

2

1

3

4

5

6

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Pod HangerAssemblyThe UMS Flowell Pod Hanger Assembly is completely torqued, assembled, and pressure tested, ready to make up to the ESP and the production tubing. The pod hanger assembly comprises of:

• 6ft handling sub with a top connection to suit the customer’s production tubing

• Optional nipple for testing the production tubing above the pod hanger assembly

• 8ft pup joint above the pod hanger to allow for deflection due to the hanger offset bore. This also provides space for a packer style electrical connector

• Pod hanger • 6ft pup joint below the pod hanger• Optional offset union to accommodate for the offset

production bore due to the electrical connector penetration

• 6ft or 15ft pup joint depending if an offset union is used• Crossover if required for the pump discharge head• Available with ISO 14310 V0 and V3 Qualification

Part Number Pod Size Top Connection Bottom Connection ESP Connector connection

PS-5500-0057 5-1/2” 3-1/2” 9.3# EUE BOX 2-3/8” 4.7# EUE PIN 3 X 3/8” NPT FOR SPLIT PHASE CONNECTOR

PS-5500-0058 5-1/2” 2-7/8” 6.5# EUE BOX 3-1/2” 9.3# EUE PIN 3 X 3/8” NPT FOR SPLIT PHASE CONNECTOR

PS-7625-0127 7”/7-5/8” 3-1/2” 9.3# EUE BOX 3-1/2” 9.3# EUE PIN 2-3/8” EUE BOX


PS-7625-0086 7”/7-5/8” 4-1/2” 12.6# VAM TOP BOX 3-1/2” 9.2# VAM TOP PIN BIW FIELD ATTACHABLE

PS-7625-0098 7”/7-5/8” 3-1/2” 9.2# TENARIS BLUE BOX 3-1/2” 9.2# TENARIS BLUE PIN 2-3/8” NUE PIN

PS-7625-0105 7”/7-5/8” 5-1/2” 17# VAM TOP BOX 4-1/2” 12.6# VAM TOP PIN 3 X 3/8” NPT FOR SPLIT PHASE CONNECTOR

PS-7625-0115 7”/7-5/8” 3-1/2” 9.2# VAM TOP BOX 3-1/2” 9.2# VAM TOP PIN 2-3/8” EUE BOX


PS-7625-0124 7”/7-5/8” 4-1/2” 12.6# VAM TOP BOX REDA 562 PUMP DISCHARGE HEAD 1.900” NUE BOX INVERTED PACKER PENETRATOR

PS-7625-0125 7”/7-5/8” 3-1/2” 9.2# VAM TOP BOX 3-1/2” 9.2# VAM TOP PIN 2-3/8” NUE BOX

PS-7625-0129 7”/7-5/8” 4-1/2” 12.6# VAM TOP BOX 3-1/2” 9.2# VAM TOP PIN 3 X 3/8” NPT FOR SPLIT PHASE CONNECTOR

PS-7625-0164 7”/7-5/8” 4-1/2” 12.6# VAM TOP BOX 3-1/2” 9.2# VAM TOP PIN (concentric) 3 X 3/8” NPT FOR SPLIT PHASE CONNECTOR

PS-8625-01 8-5/8” 4-1/2” 13.5# TENARIS BLUE BOX 4-1/2” 13.5# TENARIS BLUE PIN 1.900” NUE BOX INVERTED PACKER PENETRATOR

PS-10750-07 10-3/4” 5-1/2” 23# VAM TOP BOX 4-1/2” 12.6# VAM TOP PIN 2-3/8” NUE BOX INVERTED PACKER PENETRATOR


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Pod Hanger Seal Sleeve & Lockdown Ring AssemblyThe UMS Flowell Pod Hanger Seal Sleeve and Lockdown Ring Assembly are located at the top of the pod casing.

The seal sleeve provides a profile for landing and sealing the pod hanger, to create a barrier between the well and the well casing.

The lockdown ring mechanically secures the pod hanger assembly to the pod, to make the pod hanger assembly an integral part of the production string.

A 10ft long casing pup joint made up to the pod hanger seal sleeve acts as a saver sub. The complete assembly is lifted using the pod sleeve handling and pod pressure test tool.

FEATURES & BENEFITS• Seal profile for pod hanger• Landing shoulder for pod hanger• 5-1/2”, 7”, 7-5/8” and 10-3/4” pod casing sizes available• Various Thread connections available to meet customer

requirements• Matched strength with production tubing

SPECIFICATIONS• Low alloy steel or 13Cr material options• 5000psi MWP as standard

Technical SpecificationsPart Number Pod Size OD (in) Bottom Connection

PS-5500-0038 5-1/2” 5.915 5-1/2” 15.5# API BUTTRESS PIN

PS-5500-0041 5-1/2” 5.930 5-1/2” 15.5# VAM TOP HC PIN

PS-5500-0050 5-1/2” 5.915 5-1/2” 17# API BUTTRESS PIN

PS-7000-02 7” 7.852 7” 38# VAM TOP PIN

PS-7000-08 7” 7.800 7” 26# JFE BEAR PIN

PS-7000-18 7” 7.800 7” 29# JFE BEAR PIN

PS-7000-19 7” 7.812 7” 29# VAM TOP PIN

PS-7000-28 7” 7.800 7” 26# TENARIS BLUE PIN

PS-7000-31 7” 7.800 7” 26# VAM FJL PIN

PS-7000-43 7” 7.800 7” 26# API BUTTRESS PIN

PS-7625-0013 7-5/8” 7.811 7-5/8” 33.7# TENARIS BLUE NEAR FLUSH PIN

PS-7625-0031 7-5/8” 7.811 7-5/8” 29.7# ATLAS BRADFORD ST-L PIN

PS-7625-0040 7-5/8” 7.800 7-5/8” 33.7# ATLAS BRADFORD ST-L PIN

PS-7625-0047 7-5/8” 7.800 7-5/8” 29.7# TENARIS 3SB PIN

PS-7625-0050 7-5/8” 7.800 7-5/8” 33.7# TENARIS WEDGE 513 PIN

PS-7625-0076 7-5/8” 7.811 7-5/8” 29.7# VAM FJL PIN

PS-7625-0090 7-5/8” 7.800 7-5/8” 29.7# VAM FJL PIN (L80 TYPE 13CR)

PS-7625-0102 7-5/8” 7.800 7-5/8” 29.7# VAM FJL PIN (L80 TYPE 1)

PS-7625-0107 7-5/8” 7.800 7-5/8” 33.7# VAM TOP PIN

PS-7625-0116 7-5/8” 7.800 7-5/8” 39# VAM FJL PIN

PS-7625-0126 7-5/8” 7.800 7-5/8” 33.7# VAM FJL PIN

PS-7625-0130 7-5/8” 7.800 7-5/8” 33.7# TENARIS WEDGE 513 PIN

PS-7625-0140 7-5/8” 7.800 7-5/8” 33.7# HUNTING SEAL LOCK FLUSH PIN

PS-7625-0163 7-5/8” 7.800 7-5/8” 39# VAM FJL PIN

PS-8625-02 8-5/8” 8.825 8-5/8” 40# TENARIS WEDGE 513 PIN

PS-8625-08 8-5/8” 8.825 8-5/8” 40# ATLAS BRADFORD ST-L PIN

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Offset Union Technical Specifications

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The UMS Flowell Offset Union is used to re-centre or adjust the centre of the tubing string components typically below offset hangers. The Offset Union is typically used below pod hangers with an eccentric tubing connection, where the height between the pod hanger and the ESP pump is required to be minimised.

The offset union has a specified required offset.The orientation of the offset is controlled by the UMS Flowell Piranha Lock connector which allows angular adjustment in 6-degree increments. This prevents the need for having timed threads to provide the required orientation. Once orientated to the required angular position, the clutch teeth of the Piranha Lock connector are locked in position to prevent rotation.

FEATURES & BENEFITS• Allows re-centering of adjustment of centre lines below

offset hangers• No requirement for timed threads• Used where height is required to be minimised,

compared to using a long pup joint for deflection

SPECIFICATIONS• 5,000psi MWP• Orientation in 6-degree increments• Available in low alloy or 13Cr material

• Choice of elastomers

Part Number Top Connection Bottom Connection Offset (in) Maximum OD (in)

XO-00312 3-1/2” 9.2# VAM TOP Box 3-1/2” 9.2# VAM TOP Pin 0.890 4.710

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Tubing AdjustableUnion


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Part Number Tubing size (in) Top connection Bottom connection Overall Length Closed (in)

Stroke (in) OD (in) Nominal ID (in)

AU-2375-09 2-3/8 2-3/8” 4.6# VAM TOP BOX 2-3/8” 4.6# VAM TOP PIN 53.67 12 3.531 1.957



AU13-0031 3-1/2 3-1/2” 9.2# VAM TOP BOX 3-1/2” 9.2# VAM TOP PIN 36.5 8 5.00 2.959

AU13-0072 3-1/2 3.500” 9.2# VAM TOP BOX 3.500” 9.2# VAM TOP PIN 73.25 24 5.00 2.959

AU13-0076 3-1/2 3.500” 9.2# JFE BEAR 13CR CLEAR RUN BOX

3.500” 9.2# JFE BEAR PIN 73.05 24 5.00 2.953

AU18-0001 3-1/2 X 4-1/2 3-1/2” 9.2# TENARIS BLUE DOPELESS BOX

4-1/2” 12.6# TENARIS BLUE DOPELESS PIN

86.17 24 5.00 2.906

AU18-0019 4 4” 10.9# TENARIS BLUE DOPELESS BOX

4” 10.9# TENARIS BLUE DOPELESS PIN

71.4 22.5 5.36 3.390


AU18-0003 4-1/2 4.500” 13.5# TENARIS BLUE BOX

4.500” 13.5# TENARIS BLUE PIN

71.2 22.5 5.86 3.867


AU13-0051 5-1/2 5-1/2” 17# VAM TOP PIN 5-1/2” 17# VAM TOP PIN 42.0 6.00 7.85 4.65

AU13-0067 5-1/2 5-1/2” 23# VAM TOP PIN 5-1/2” 23# VAM TOP PIN 47.72 7 7.85 4.65

AU13-0081 7 7” 32# VAM TOP BOX 7” 32# VAM TOP PIN 104.52 24 8.206 5.675

(TAU)

UMS Flowell Tubing Adjustable Union (TAU) is a quick and easy way to orientate and space out your completion. The TAU is typically used to assist with the space out of ESP power cables at the ESP packer or tubing hanger, and also to space out the short string in dual packers for dual completions.

Other applications include; orientation and adjustment between upper and lower y-tools in dual ESP completions, ESP motor lead extension (MLE) space out and ESP orientation inside ESP capsules or pods.

The TAU can be adjusted telescopically, rotated to both the left and right in 6 degree increments, then locked. A choice of different stroke lengths allows the customer to select the one that suits their application best.

A selection of metallurgy and elastomers allows the customer to select the materials that best suit their well environment.

FEATURES & BENEFITS• Available in 1.9” to 7” tubing sizes• Other sizes and threads available on request• Quick to adjust• Clutch design allows quick and easy orientation in 6°

increments• Locked to right and left-hand rotation• 6”, 12” & 24” standard telescopic length. Other stroke

lengths available

SPECIFICATIONS• Low alloy or 13Cr metallurgy• Viton, Aflas, or HNBR elastomers or non-elastomeric

stacks available for high temperature applications• 6500psi MWP limited by elastomers• Matched tubing tensile and compression ratings

30 31

Flow ManagementDiverter Valve - Standard


umsflowell.com

(FMDV-S)The Flow Management Diverter Valve (FMDV-S) can be utilised with any ESP application, including single ESPs, Y-Tools, encapsulated ESPs (pods) and dual ESP applications.

Its primary function is to act as a flow bypass device, with the added capabilities of preventing backflow through the ESP and reducing exposure of the ESP to well debris. The combination of these capabilities reduces wear and tear, increases reliability, and prolongs the life of the ESP unit.

When the FMDV is in bypass mode, the well flow (natural flow or flow from a secondary source) bypasses the non operating ESP, eliminating the ESPs exposure to large pressure drops while also preventing unnecessary wear.

When located above a running ESP, the FMDV protects the ESP from backflow. After the running ESP is stopped, the FMDV closes and backflow of the tubing contents is diverted to the annulus. This eliminates backspin on the ESP which can break the ESP shaft. In addition a flapper within the FMDV prevents any solids suspended in the tubing from settling inside the pump.

FEATURES & BENEFITS• Constant volume sealed spring chamber protects spring

from exposure to well debris.• Large operational flow range.• Minimal distance between ports and shuttle reduces

debris build up.• Soft spring & magnet balanced, to reduce chatter at

lower flow rates.• Magnetic ring provides a strong hold down force for

annular flow, preventing the valve shifting due to difference in pressure.

• Jetting holes clear debris upon ESP start up.

Part Number Tubing Size (in)

OD (in) Length (in)

Thread Connections Material Min Flow Rate (bbl/d)

Maximum Flow Rate (bbl/d)

Min Pump Pressure (psi)

Max Pump Pressure (psi)

FMDV-0106-01-4140 2-7/8 4.00 48.3 2-7/8” 6.5# EUE 80ksi Low Alloy Steel 200 8,000 60 5,000

FMDV-0106-01-13CR 2-7/8 4.00 48.3 2-7/8” 6.5# EUE 80ksi 13CR 200 8,000 60 5,000

FMDV-0106-02-4140 2-7/8 4.00 48.3 2-7/8” 6.4# VAM TOP Low Alloy Steel 200 8,000 60 5,000

FMDV-0106-02-13CR 2-7/8 4.00 48.3 2-7/8” 6.4# VAM TOP 80ksi 13CR 200 8,000 60 5,000

FMDV-0089-01-4140 3-1/2 5.25 50.00 3-1/2” 9.3# EUE Low Alloy Steel 300 15,000 80 5,000

FMDV-0089-01-13CR 3-1/2 5.25 50.00 3-1/2” 9.3# EUE 80ksi 13CR 300 15,000 80 5,000

FMDV-0089-02-4140 3-1/2 5.25 50.00 3-1/2” 9.2# VAM TOP Low Alloy steel 300 15,000 80 5,000


FMDV-0090-01-4140 4-1/2 6.00 50.30 4-1/2” 12.75# EUE Low Alloy steel 400 22,500 100 5,000

FMDV-0090-01-13CR 4-1/2 6.00 50.30 4-1/2” 12.75# EUE 80ksi 13CR 400 22,500 100 5,000

FMDV-0090-02-4140 4-1/2 6.00 50.30 4-1/2” 12.6# VAM TOP Low Alloy steel 400 22,500 100 5,000


Notes:

1. Other sizes, material and thread connections available upon request.2. OD is body diameter and doesn’t include MLE cable guard.3. Tensile, compression and torque rating matched to tubing end connection.

FEATURES & BENEFITS• Shifting & locking accessory tool available.• High quality medical grade materials minimise erosion of

key components.• UMS Flowell Piranha lock connections allow full

string torque to be applied through the FMDV in both directions.

• Protects the ESP from unnecessary wear and tear.• Minimises exposure of the ESP to harmful well debris.• Extends ESP operational lifetime.

32 33


umsflowell.com

Flow ManagementDiverter Valve - Hydraulic (FMDV-H)

The Flow Management Diverter Valve (FMDV-H) can be utilised with any ESP application, including single ESPs, Y-Tools, encapsulated ESP`s (pods) and dual ESP applications.

Its primary function is to act as a flow bypass device, with the added capabilities of preventing backflow through the ESP and reducing exposure of the ESP to well debris. The combination of these capabilities reduces wear and tear, increases reliability, and prolongs the life of the ESP unit. When the FMDV is in bypass mode, the well flow (natural flow or flow from a secondary source) bypasses the non operating ESP, eliminating the ESPs exposure to large pressure drops while also preventing unnecessary wear.

When located above a running ESP, the FMDV protects the ESP from backflow. After the running ESP is stopped, the FMDV closes and backflow of the tubing contents is diverted to the annulus. This eliminates backspin on the ESP, which can break the ESP shaft. In addition, a flapper within the FMDV prevents any solids suspended in the tubing from settling inside the pump. The hydraulic line allows pressure testing of the tubing, without the need to run a slickline plug. The hydraulic line can also be used as a contingency option to shut the annular ports, ensuring production is always available.

FEATURES & BENEFITS• Constant volume sealed spring chamber protects spring

from exposure to well debris.• Large operational flow range.• Minimal distance between ports and shuttle reduces

debris build up.• Soft spring & magnet balanced, to reduce chatter at

lower flow rates.• Magnetic ring provides a strong hold down force for

annular flow, preventing the valve shifting due to difference in pressure.

• Jetting holes clear debris upon ESP start up.• Shifting & locking accessory tool available.• High quality medical grade materials minimise erosion of

key components.

Part Number Tubing Size (in)

OD (in) Length (in)

Thread Connections Material Min Flow Rate (bbl/d)

Maximum Flow Rate (bbl/d)

Min Pump Pressure (psi)

Max Pump Pressure (psi)

FMDV-H-0010-01-4140 3-1/2 6.127 64.19 3-1/2” 9.3# EUE 80ksi Low Alloy Steel 300 15,000 80 5,000

FMDV-H-0010-01-13CR 3-1/2 6.127 64.19 3-1/2” 9.3# EUE 80ksi 13CR 300 15,000 80 5,000

FMDV-H-0010-02-4140 3-1/2 6.127 64.19 3-1/2” 9.2# VAM TOP 80ksi Low Alloy Steel 300 15,000 80 5,000

FMDV-H-0010-02-13CR 3-1/2 6.127 64.19 3-1/2” 9.2# VAM TOP 80ksi 13CR 300 15,000 80 5,000

Notes:

1. Other sizes, material and thread connections available upon request.2. OD is hydraulic body diameter which includes a cable slot for MLE and service lines.3. Tensile, compression and torque rating matched to tubing end connection.4. 10,000psi hydraulic line pressure for 5,000psi tubing test.

FEATURES & BENEFITS• UMS Flowell Piranha lock connections allow full

string torque to be applied through the FMDV in both directions.

• Protects the ESP from unnecessary wear and tear.• Minimises exposure of the ESP to harmful well debris.• Extends ESP operational lifetime.• Hydraulic line facilitates pressure testing of the tubing,

without the need to run a slickline plug.• Hydraulic line can be used to shut the annular ports,

ensuring production is always an option.

34 35

Pod Casing JointsUMS Flowell Pod Casing Joints are used to create the required length to shroud the ESP, to isolate the well fluids from the well casing.

The size of the pod casing is determined by the well casing drift, the ESP series and pressure requirements. Where space is limited, flush joint casing must be used.

FEATURES & BENEFITS• Coupled or flush joint connections• API 5CT Range 2 length as standard (25-34ft)• 5-1/2” to 10-3/4” pod casing sizes available• Various Thread connections available to meet customer

requirements• Box x Pin configuration

SPECIFICATIONS• Low alloy steel or 13Cr material options• API 5CT

Technical SpecificationsPart Number Thread connections Material Length Internal Drift (In) Notes

5500155FJLR213CR 5-1/2” 15.5# VAM FJL API 5CT L80 13CR RANGE 2 – 25-34FT 4.825 -

550017BTCR2L801 5-1/2” 17# API BUTTRESS API 5CT L80 TYPE 1 RANGE 2 – 25-34FT 4.767 -

700026BTCR2L801 7” 26# API BUTTRESS API 5CT L80 TYPE 1 RANGE 2 – 25-34FT 6.151 -

700029STLR2G13CR 7” 29# ATLAS BRADFORD ST-L API 5CT L80 13CR RANGE 2 – 25-34FT 6.059 Grooved For Casing Clamps

76252973SB3013CRAA 7-5/8” 29.7# TENARIS 3SB API 5CT L80 13CR 30FT 6.750 -

7625297FJL30L801 7-5/8” 29.7# VAM FJL API 5CT L80 TYPE 1 30FT 6.750 -

7625297FJL30GL801 7-5/8” 29.7# VAM FJL API 5CT L80 TYPE 1 30FT 6.750 Grooved For Casing Clamps

7625337VT3013CR 7-5/8” 33.7# VAM TOP API 5CT L80 13CR 30FT 6.640 -

862540STLR213CR 8-5/8” 40# ATLAS BRADFORD ST-L API 5CT L80 13CR RANGE 2 – 25-34FT 7.625 -

862540STLR2G13CR 8-5/8” 40# ATLAS BRADFORD ST-L API 5CT L80 13CR RANGE 2 – 25-34FT 7.625 Grooved For Casing Clamps

862540HSLFR2GL80 8-5/8” 40# HUNTING SEAL LOCK FLUSH API 5CT L80 13CR RANGE 2 – 25-34FT 7.625 Grooved For Casing Clamps

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36 37

Pod Bottom CrossoverAssemblyThe UMS Flowell Pod Bottom Crossover connects the pod casing to the tailpipe below the pod. A 10ft casing pup joint and a 6ft tubing pup joint are made up to the crossover to act as saver subs, allowing the assembly to be picked up from the pipe deck, ready to be made up to the completion string.

FEATURES & BENEFITS• Coupled or flush joint casing connections to suit the pod

casing• 5-1/2” to 10-3/4” pod casing sizes available• Thread connections to meet customer requirements• Box x Pin configuration


Part Number Pod Size OD (in) Top Connection Bottom Connection

PS-5500-0043 5-1/2” 5.930 5-1/2” 15.5# VAM TOP HC BOX 3-1/2” 15.5# VAM TOP PIN

XO-00250 5-1/2” 6.050 5-1/2” 17# API BUTTRESS BOX 3-1/2” 9.3# EUE PIN

XO-00315 7” 7.676 7” 26# API BUTTRESS BOX 3-1/2” 9.3# EUE PIN

PS-7000-17 7” 7.470 7” 29# JFE BEAR SC BOX 4-1/2” 12.6# JFE BEAR PIN

PS-7000-20 7” 7.644 7” 29# VAM TOP BOX 3-1/2” 9.3# EUE PIN

PS-7625-0041 7-5/8” 7.625 7-5/8” 33.7# ATLAS BRADFORD ST-L BOX 5-1/2” 17# TENARIS BLUE PIN

PS-7625-0061 7-5/8” 7.625 7-5/8” 33.7# TENARIS WEDGE 513 BOX 5-1/2” 23# TENARIS BLUE PIN

PS-7625-0077 7-5/8” 7.625 7-5/8” 29.7# VAM FJL BOX 3-1/2” 15.8# TENARIS PH6 PIN

PS-7625-0089 7-5/8” 7.625 7-5/8” 29.7# VAM FJL BOX 4-1/2” 12.6# VAM TOP PIN

PS-7625-0093 7-5/8” 7.625 7-5/8” 29.7# ATLAS BRADFORD ST-L BOX 4-1/2” 12.6# JFE BEAR PIN

PS-7625-0108 7-5/8” 8.213 7-5/8” 29.7# VAM TOP BOX 5-1/2” 17# VAM TOP PIN

PS-7625-0121 (INTEGRAL NIPPLE) 7-5/8” 7.625 7-5/8” 29.7# VAM FJL BOX 4-1/2” 12.6# VAM TOP PIN

PS-7625-0141 7-5/8” 7.625 7-5/8” 33.7# HUNTING SEAL LOCK FLUSH BOX 4-1/2” 12.6# JFE BEAR PIN

PS-7625-0141 7-5/8” 7.625 7-5/8” 33.7# ATLAS BRADFORD ST-L BOX 5-1/2” 17# VAM TOP PIN

PS-8625-03 8-5/8” 8.625 8-5/8” 40# TENARIS WEDGE 513 BOX 5-1/2” 23# TENARIS BLUE PIN

PS-8625-09 8-5/8” 8.625 8-5/8” 40# ATLAS BRADFORD ST-L BOX 5-1/2” 17# JFE BEAR PIN


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38 39

Pod TailpipeNipple AssemblyThe UMS Flowell Tailpipe Nipple Assembly is normally made up directly below the pod bottom crossover.

The nipple profile allows a standing valve to be temporarily set in the nipple, so that the pod casing can be pressure tested prior to installing the ESP inside the pod. The nipple has 6ft tubing pup joints made up to the nipple to act as saver subs, allowing the assembly to be picked up from the pipe deck, ready to be made up to the completion string.

FEATURES & BENEFITS• Nipple sizes to suit the tubing (normally the same nipple

size as the optional nipple on the pod hanger assembly for testing the production tubing)

• Thread connections to meet customer requirements• Box x Pin configuration


Part Number Top Connection Bottom Connection Nipple size (in)

PS-7625-0042 5-1/2” 17# TENARIS BLUE BOX 5-1/2” 17# TENARIS BLUE PIN 3.500


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40 41

Flush Joint Casing Clamp (Pod Casing Clamps)The UMS Flowell Flush Joint Casing Clamp is used where space is premium and flush joint casing is required. The clamps are low profile for fitting in tight spaces, and grip the cables or service lines against the body of the casing.

Internal teeth on the clamp provide a grip on the casing to prevent the clamp from slipping.

FEATURES & BENEFITS• For flush joint casing where space is limited• Internal teeth for gripping clamp to the casing• No stop collars required• Grips and protects cable and or service lines• Precision investment casting• Lightweight and robust• 5-1/2” to 10-3/4” sizes available

SPECIFICATIONS• Low alloy or 13Cr equivalent investment casting with

Inconel 718 fasteners• 14 ton load on clamp face before slippage

Part Number Min Well Casing Size Pod Size OD (in) ID (in) Lines

PCC-525-04 7" 26# 5-1/2" 6.120 5.250 (For Grooved Pod Casing) 11mm X 11mm (QTY: 1)

PCC-700-04 9-5/8" 53.5# 7" 8.200 6.940 (For Grooved Pod Casing) 13mm X 13mm (QTY: 1), #4 MLE (QTY: 1)

PCC-700-06 9-5/8" 53.5# 7" 8.200 6.940 (For Grooved Pod Casing) 13mm X 13mm (QTY: 1)

PCC-700-07 9-5/8" 53.5# 7" 8.200 6.940 (For Grooved Pod Casing) #4 MLE (QTY: 1)

PCC-700-12 9-5/8" 53.5# 7" 8.200 6.940 (For Grooved Pod Casing) 0.86" X 0.43" (QTY: 2), 1.248" X 0.486" MLE (QTY: 1)

PCC-7525-01 9-5/8" 53.5# 7-5/8" 8.375 7.525 (For Grooved Pod Casing) 13mm X 13mm (QTY: 2), 11mm X 11mm (QTY: 1), 1.342" X 0.572" MLE (QTY: 1)

PCC-7525-02 9-5/8" 53.5# 7-5/8" 8.375 7.525 (For Grooved Pod Casing) 13mm X 13mm (QTY: 2), 11mm X 11mm (QTY: 1)

PCC-7525-21 9-5/8" 53.5# 7-5/8" 8.375 7.525 (For Grooved Pod Casing) Ø11mm (QTY: 2)

PCC-7525-28 9-5/8" 53.5# 7-5/8" 8.375 7.525 (For Grooved Pod Casing) 13mm X 13mm (QTY: 2), 11mm X 11mm (QTY: 2), 1.342" X 0.572" MLE (QTY: 1)

PCC-7525-30 9-5/8" 53.5# 7-5/8" 8.375 7.525 (For Grooved Pod Casing) 13mm X 13mm (QTY: 2), 11mm X 11mm (QTY: 2)

PCC-7625-06 10-3/4" 40.5# 7-5/8" 9.100 7.625 Ø3/8" (QTY: 2), 1.655" X 0.635" MLE (QTY: 1)

PCC-7625-09 10-3/4" 40.5# 7-5/8" 9.100 7.625 Ø3/8" (QTY: 2)

PCC-7625-12 9-5/8" 53.5# 7-5/8" 8.375 7.625 Ø3/8" (QTY: 2)

PCC-7625-16 9-5/8" 47# 7-5/8" 8.480 7.625 14mm X 14mm (QTY: 1), 26mm X 11mm (QTY:1)

PCC-7625-25 10-3/4" 79.2# 7-5/8" 9.100 7.625 Ø1/4" (QTY: 1), Ø3/8" (QTY: 2), #1 MLE (QTY: 1)

PCC-7625-26 9-5/8" 47# 7-5/8" 8.480 7.625 22mm X 11mm (QTY: 2), 1.292" X 0.490" MLE (QTY: 1)

PCC-7625-28 9-5/8" 47# 7-5/8" 8.480 7.625 22mm X 11mm (QTY: 2)

PCC-7625-29 9-5/8" 47# 7-5/8" 8.480 7.625 44mm X 12mm (QTY: 1)

PCC-7625-38 9-5/8" 47# 7-5/8" 8.480 7.625 Ø1/4" (QTY: 5), Ø3/8" (QTY: 2)

PCC-7625-39C 10-3/4" 79.2# 7-5/8" 9.000 7.625 11mm X 11mm (QTY: 1), Ø3/8" (QTY: 1), #1 MLE (QTY: 1)

PCC-7625-40C 10-3/4" 79.2# 7-5/8" 9.000 7.625 11mm X 11mm (QTY: 1)

PCC-8625-14 10-3/4" 55.5# 8-5/8" 9.604 8.625 13mm X 13mm (QTY: 1)


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42 43

Pod WorktableThe UMS Flowell Pod Worktable is made up to the pod sleeve assembly.

The worktable provides a work surface to land the ESP lifting clamp while installing the ESP inside the pod.

The worktable provides a staggered height gap to allow the MLE and control line cables to pass into the pod, avoiding any risk of pinching them.

The worktable has an internal sleeve that protects the seal bore of the sleeve when running the ESP through the sleeve into the pod casing. An external sleeve protects the external threads on the pod sleeve. The worktable is a split design so that it can be removed from the pod.

FEATURES & BENEFITS• Landing area for ESP lift clamps• Staggered C-plate design to allow cable entry into the

pod• Internal pod sleeve seal bore protector• External thread protector for pod sleeve• Split design for easy removal from the pod sleeve• Hole cover to avoid dropped objects into pod

SPECIFICATIONS• Structural Steel• SWL = 15 Tonne

Technical SpecificationsPart Number Pod size WLL (Te)

WT-00116 5-1/2” 15

PS-7625-0020 7”/7-5/8” 15

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44 45

Pod SleeveHandling And Pressure Test ToolThe UMS Flowell Pod Sleeve Handling and Pod Pressure Test Tool is used for handling the pod sleeve assembly and also to pressure test the pod system prior to installing the ESP.

The handling tool is made up to the pod sleeve assembly on the pipe deck. The handling tool has a dummy coupling for picking up the assembly with elevators.

Once the pod sleeve assembly is made up to the pod casing, slickline equipment can be made up to the handling tool and a standing valve can be set in the tailpipe nipple assembly.

Once set in the nipple, the top connection of the handling tool can be made up to the rig Kelly hose to fill and pressure test the pod casing with the cementing unit.

FEATURES & BENEFITS

• Top box connection normally the same as the production tubing for make up to a drill pipe well control crossover

• Dummy coupling shoulder for elevators• Quick union for make up to pod sleeve

SPECIFICATIONS• Low alloy steel• 5000psi MWP

Part Number Pod size Top connection

PS-5500-0052 5-1/2” 3-1/2” 9.3# EUE BOX

PS-7625-0043 7”/7-5/8” 5-1/2” 17# VAM TOP BOX

TD12-525 7”/7-5/8” NC50 (4-1/2” IF) BOX

PS-8625-14 8-5/8” 5-1/2” 17# JFE BEAR BOX


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46 47

Lift Nubbin For Flush JointCasingThe UMS Flowell Lift Nubbin For Flush Joint Casing allows handling of flush joint casing and tubing. The Flush Joint Casing Clamp Nubbins have a pin thread to mate with the corresponding flush joint box thread on the casing or tubing.

A 4.75 ton swivel allows single joints to be lifted with the tugger line or crane without the need for single joint elevators. A shoulder on the lift nubbin acts as a dummy coupling and allows the string to be handled with side door or centre latch elevators.

If slip type elevators are used, the dummy coupling shoulder acts as a stop collar in the event that unplanned string slippage occurs.

FEATURES & BENEFITS• Lightweight• Available casing sizes from 5-1/2” upwards• Various thread options• Elevator shoulder for picking up string weight or used as

a stop shoulder when using slip type elevators

SPECIFICATIONS• Elevator shoulder rating dependent on thread size,

thread type, grade, and tubing/casing weight

Technical SpecificationsPart Number Thread Connection WLL (Te)

LN-7625-297-FJL 7-5/8” 29.7# VAM FJL PIN 50

LN-7625-337-FJL 7-5/8” 33.7# VAM FJL PIN 50

SLN-7625-337-TSH513 7-5/8” 33.7# TENARIS WEDGE 513 PIN 50

SLN-8625-01-STL 8-5/8” 40# ATLAS BRADFORD ST-L PIN 50

SLN862502TW513 8-5/8” 40# TENARIS WEDGE 513 PIN 50

umsflowell.com

48 49

Pod Well Control SubThe UMS Flowell Pod Well Control Sub is a means of containing well control when building the ESP inside the Pod. The Pod Well Control Sub is similar in design to the Pod Sleeve Handling and Pressure Test Tool, except it has a perforated pup joint with a universal head for making up to the ESP.

In the event of a well control situation, the Pod Well Control Sub is made up to the ESP section landed on the worktable. The Pod Well Control Sub along with ESP is lifted to remove the worktable and then lowered to make up to the Pod sleeve. The top connection of the Pod Well Control Sub is made up to the top drive or kelly hose and the BOP rams closed onto the Pod casing. Pumping through the top drive or kelly hose can then begin to control or kill the well.


umsflowell.com

FEATURES & BENEFITS• Fully torqued and load tested• Full material traceability• Robust construction• Allows well control during ESP build, without the need to

drop the ESP inside the Pod• Can be used for dual purpose Pod Sleeve Handling and

Pressure Test Tool and Pod Well Control Sub• Provided with drill pipe connection for make up to the rig

drilling system

SPECIFICATIONS• Low alloy steel • 10,000psi MWP

• 50 Tonne Working Load Limit (WLL)

Part Number Pod Size Top Connection Bottom connection WLL (Te)

TD12-528 7”/7-5/8” NC50 (4-1/2” IF) BOX REDA 540/562 UNIVERSAL FLANGE BASE 50

TD12-215 8-5/8” NC50 (4-1/2” IF) BOX REDA 540/562 UNIVERSAL FLANGE BASE 50

TD12-503 8-5/8” NOV XT-57 EXTREME TORQUE REDA 540/562 UNIVERSAL FLANGE BASE 50

50 51

Pod HangerStabbing GuideThe UMS Flowell Pod Hanger Stabbing Guide is a split funnel design which is fitted to the pod sleeve assembly, prior to landing the pod hanger.

The stabbing guide assists with alignment of the pod hanger into the pod sleeve seal bore, and helps prevent any damage to the pod hanger or pod sleeve.


umsflowell.com

FEATURES & BENEFITS• Robust lightweight construction• Secures to the outside profile of the Pod Sleeve• Greatly reduces the risk to damaging the pod hanger or

Pod sleeve during landing

• Funnelled design to guide the pod hanger into position

SPECIFICATIONS• Nylon body with stainless steel latch and hinge, with a

polyamide and aluminium handles

Part Number Pod Hanger Size

TD12-474 7” & 7-5/8”

TD12-496 8-5/8”

TD12-004 10-3/4”

52 53

UMS Flowell – Turriff, South Bogton, Forglen, Turriff, Aberdeenshire, Scotland, UK, AB53 4LA.Tel: +44 (0)1888 568771

UMS Flowell – East Kilbride, Suite 10, Arx house, James Watt Avenue,Scottish Enterprise Technology Park, East Kilbride, Scotland, UK, G75 0QDTel: +44 (0)1355 222611

Date post:	06-Feb-2022
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