Dual Zone ESP Completions - umsflowell.com

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Dual Zone ESP CompletionsCATALOGUE VERSION 1.0 JUN 2021

ContentsSPECIFICATIONSPage 05 Sizing InformationPage 08 UMS Flowell Tubing Thread PropertiesPage 11 Standard Metallic Material Options And CodesPage 12 Standard Seal Material Options And CodesPage 15 Completion Design Considerations

EQUIPMENT - UPPER SYSTEMPage 36 Y-Tool Assembly (Comingled Flow)Page 38 Flow Crossover Assembly (Independent production to surface)Page 40 Seal Assembly (Stinger)Page 42 Bypass TubingPage 44 Bypass Tubing ClampPage 46 Pump Support For Y-Tool Applications

HANDLING EQUIPMENTPage 48 Bypass Safety ClampPage 50 Bypass Swivel Lift NubbinPage 52 ESP Work Table

DUAL ZONE - SINGLE ESP - CONCENTRIC TUBING STRINGSPage 16 Upper Zone Natural Flow / Lower Zone ESP (Seal Bore Packer)Page 18 Upper Zone Injection / Lower Zone ESP (Seal Bore Packer)Page 20 Upper Zone Natural Flow / Lower Zone ESP (ESP Packer)Page 22 Upper Zone Injection / Lower Zone ESP (ESP packer)Page 24 Upper Zone ESP / Lower Zone Natural Flow (Seal Bore Packer Or Tubing Retrievable Packer)Page 26 Upper Zone ESP / Lower Zone Injection (Seal Bore Packer Or Tubing Retrievable Packer)

EQUIPMENT - LOWER SYSTEMPage 54 Pod System (Encapsulated ESP)Page 56 Pod Hanger AssemblyPage 58 Pod Hanger Seal Sleeve & Lockdown Ring AssemblyPage 60 Pod Casing JointsPage 62 Pod Bottom Crossover AssemblyPage 64 Pod Tailpipe Nipple AssemblyPage 66 Pod Casing Clamps (Flush Joint Casing)

HANDLING EQUIPMENTPage 68 Pod WorktablePage 70 Pod Sleeve Handling Tool & Pressure Test ToolPage 72 Lift Nubbin For Flush Joint CasingPage 74 Pod Well Control SubPage 76 Pod Hanger Stabbing Guide

DUAL ZONE - DUAL ESP - CONCENTRIC TUBING - INDEPENDENT PRODUCTION TO SURFACEPage 32 Upper Zone ESP / Lower Zone ESP (Seal Bore Packer)Page 34 Upper Zone ESP / Lower Zone ESP (ESP Packer)

DUAL ZONE - DUAL ESP COMINGLED SINGLE TUBINGPage 28 Upper Zone ESP / Lower Zone ESP (Seal Bore Packer)Page 30 Upper Zone ESP / Lower Zone ESP (ESP Packer)

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Tubing sizes dependent on well characteristics selected by the completion engineer.

Well Casing Size

9-5/8” 7”

Option A Outer Tubing Size 5-1/2” 3-1/2”

Inner Tubing Size 3-1/2” 2-7/8”

Option B Outer Tubing Size 4-1/2” -

Inner Tubing Size 2-7/8” -

Sizing Information

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

1. Production Tubing Sizes For Dual Zone Independent Production To Service.

OD Outer Production Tubing

OD Inner Production Tubing

4 5

Maximum ESP OD

Bypass Tubing Max OD

Casing Drift Diameter

Maximum OD Of ESP (in)

3.19 3.750 3.870 4.000 4.56 5.13 5.400 5.625

Casing size Maximum Bypass Tubing OD (in)

7” 23-26lb/ft 2.875 2.375 2.125 2.125 - - - -

7” 29-35lb/ft 2.375 2.125 2.125 - - - - -

9-5/8” 40-47lb/ft 5.000 4.500 4.500 4.250 3.500 2.875 2.875 2.875

9-5/8” 53.5lb/ft 5.000 4.500 4.500 4.250 3.500 2.875 2.875 2.750

2. Upper ESP Bypass Tubing Sizing

3. Lower ESP Pod Sizing

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

Bypass tubing must withstand and support installed loads, and loads due to tubing movement during operation. In some cases, heavy wall or high-grade tubing is required to meet the load requirements.

A tubing stress analysis is always recommended to select the correct strength of bypass tubing.

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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.

8 9

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.

10 11

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 ConsiderationsCompletion design considerations vary depending on the application. Decisions must be done on a case by case basis.

The objective of dual zone completions is to increase production of a well with two or more reservoir zones. Some guidelines are provided below.

Model each zone independently to see production benefits versus costs

Select candidate wells

Fit check valves above each ESP

and utilise standard X-mas tree

Use concentric tubing designs and unconventional X-mas tree with a lower

tubing hanger for outer tubing production through wing valve, and upper tubing

hanger for inner tubing production through swab valve

Review reservoir data

Check perforation intervals to determine if the zones can be isolated (enough space

between the zones to set a packer)

Is an ESP required for each zone?

Yes No

Can the flow from each zone be comingled from each pump discharge using a variable

speed drive (VSD)?

No

Yes

14 15

Lower ProductionZone (ESP)

Upper ProductionZone (Natural Flow)

Upper Zone Natural Flow / Lower Zone ESP (Seal Bore Packer)DUAL ZONE – SINGLE ESP – CONCENTRIC TUBING STRINGS

Multiple reservoirs can be produced independently in the same well bore. In cases where the upper zone can flow naturally and the lower zone requires an ESP, a dual zone completion can be used with two concentric production tubing strings.

When the distance between zones is restricted, a pod system with seal bore packer can be used.

This also allows zones to be isolated with an isolation valve to prevent communication between zones during a workover.

Advantages:

• Increased production by producing two zones independently with dissimilar productivity

• Only need to drill one well to maximise production from both zones

• Pod system eliminates ESP cable going past perforations

• Seal bore packer used when distance between zones is small

• Allows zone isolation with an isolation valve during workover to prevent zone communication

ESP Assembly (Lower Production Zone) Seal Bore PackerFMDVFlow Crossover Assembly

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Pod Casing Clamp

Tailpipe TubingSeal Bore PackerLower Pod Crossover Assembly

Pod Casing

1

2

3

4

5

ESP Gauge6

ESP Motor7

MLE Protector8

ESP Seal Protector

Discharge Pressure Sub

9

12

ESP Pump Intake10

FMDV14

Offset Union16

Stinger17

Flow Crossover18

Outer Tubing (ESP Production From Lower Zone)19

Inner Tubing (Natural Flow Production From Upper Zone)20

ESP Pump11

Discharge Head13

13

151516

Pod Hanger Assembly15

16 17

ProductionZone (ESP)

InjectionZone

Upper Zone Injection / Lower Zone ESP (Seal Bore Packer) DUAL ZONE – SINGLE ESP – CONCENTRIC TUBING STRINGS

Simultaneous production and injection can be achieved in a single well bore. Injection into the upper zone provides pressure support for the lower production zone to increase production.

Produced water from the lower zone can be recycled and injected back into the well. When the distance between zones is restricted, a pod system with seal bore packer can be used.


Advantages:

• Injection to upper zone to boost lower zone reservoir pressure to increase production in a single well bore

• Ability to recycle produced water from the produced zone and recycle into the upper injection zone




ESP Assembly (Lower Production Zone) Seal Bore PackerFMDVFlow Crossover Assembly

123567888

12

91011141517181920 4 4 4

Pod Casing Clamp


Pod Casing

1

2

3

4

5

ESP Gauge6

ESP Motor7

MLE Protector8

ESP Seal Protector


9

12

ESP Pump Intake10

FMDV14


Stinger17

Flow Crossover18


Inner Tubing (Injection Into Upper Zone)20

ESP Pump11

Discharge Head13

13

16

Offset Union16

18 19

Upper Zone Natural Flow / Lower Zone ESP (ESP Packer)DUAL ZONE – SINGLE ESP – CONCENTRIC TUBING STRINGS

ESP Assembly (Lower Zone Production)Flow Crossover Assembly ESP Packer

1

Lower ProductionZone (ESP)

Upper ProductionZone (Natural Flow)

2345633 7

8

101111131416 15

Multiple reservoirs can be produced independently in the same well bore.

In cases where the upper zone can flow naturally and the lower zone requires an ESP, a dual zone completion can be used with two concentric production tubing strings.

In this case an ESP packer is used to separate zones. Compared to the seal bore packer, this configuration has no means of zonal isolation during workover, and requires sufficient distance between zones for the ESP packer and ESP.

Advantages:



Disadvantages:

• No zone isolation during workovers

• ESP cable potentially needs protection past upper perforations

• Requires enough distance between zones for ESP packer and ESP

MLE Cable

ESP GaugeESP MotorMLE Protector

ESP Seal Protector

1

2

3

4

5

ESP Pump Intake6

ESP Pump7

Discharge Pressure Sub8

ESP Packer

Flow Crossover

10

14

Cross Coupling Clamp11


Inner Tubing (Upper Zone Natural Flow Production)16

Stinger13

9

Discharge Head9

Offset Union12

12

20 21

ESP Assembly (Lower Zone Production)Flow Crossover Assembly ESP Packer

1


Injection Zone

2345633 7

8

101111131416 15

9

12

Upper Zone Injection / Lower Zone ESP (ESP Packer)DUAL ZONE – SINGLE ESP – CONCENTRIC TUBING STRINGS

MLE Cable


ESP Seal Protector

1

2

3

4

5

ESP Pump Intake6

ESP Pump7


ESP Packer

Flow Crossover

10

14

Cross Coupling Clamp11


Inner Tubing (Upper Zone Natural Flow Production)16

Stinger (With Latch To Prevent Pump Out)13

Simultaneous production and injection can be achieved in a single well bore. Injection into the upper zone provides pressure support for the lower production zone to increase production.

Produced water from the lower zone can be recycled and injected back into the well. In this case an ESP packer is used to separate zones.

Compared to the seal bore packer, this configuration has no means of zonal isolation during workover, and requires sufficient distance between zones for the ESP packer and ESP.

Advantages:

• Injection to upper zone to boost lower zone reservoir pressure to increase production in a single well bore

• Ability to recycle produced water from the produced zone and recycle into the upper injection zone

Disadvantages:




Discharge Head9

Offset Union12

22 23

Lower ProductionZone (Natural Flow)

UpperProductionZone (ESP)

31314

Upper Zone ESP / Lower Zone Natural Flow(Seal Bore Packer Or Tubing Retrievable Packer)DUAL ZONE – SINGLE ESP – CONCENTRIC TUBING STRINGS

Multiple reservoirs can be produced independently in the same well bore.

In cases where the upper zone requires an ESP and the lower zone flows naturally, a dual zone completion can be used with two concentric production tubing strings.

A flow crossover with high strength bypass tubing is used with a pump support. Zone isolation is either with a seal bore packer or a retrievable tubing packer.

The seal bore packer allows zonal isolation during workover, where the tubing retrievable packer does not.

Advantages:



• Seal bore packer allows zone isolation with an isolation valve during workover to prevent zone communication where the tubing retrievable packer does not

Pump Support Block

Tailpipe TubingSeal Bore Packer Or Tubing Retrievable PackerSpear

ESP Gauge

1

2

3

4

5

Flush Joint Bypass Tubing6

ESP Motor7

Bypass Tubing Clamp8

MLE Cable


9

13

ESP Pump Intake11

Telescopic Swivel15

Discharge Head14

ESP Pump12

Seal Bore Packer Or TubingRetrievable Packer

ESP Assembly (Upper Zone Production)Flow Crossover Assembly

Pump Support Assembly

12456710 89118121516171819 8

ESP Seal Protector10

Stinger16

Flow Crossover17

Inner Tubing (Lower Zone Injection)18

Outer Tubing (ESP Production From Upper Zone)19

24 25

InjectionZone


313

Seal Bore Packer Or TubingRetrievable Packer

ESP Assembly (Upper Zone Production)Flow Crossover Assembly


12456710 89118121516171819 8

14

Upper Zone ESP / Lower Zone Injection (Seal Bore Packer Or Tubing Retrievable Packer)DUAL ZONE – SINGLE ESP – CONCENTRIC TUBING STRINGS

Simultaneous production and injection can be achieved in a single well bore. Injection into the lower zone provides pressure support for the upper production zone to increase production.

Produced water from the upper zone can be recycled and injected back into the well. Zone isolation is either with a seal bore packer or a retrievable tubing packer.

The seal bore packer allows zonal isolation during workover, where the tubing retrievable packer does not.

Advantages:

• Injection to lower zone to boost upper zone reservoir pressure to increase production in a single well bore

• Ability to recycle produced water from the produced zone and recycle into the lower injection zone


Pump Support Block

Tailpipe TubingSeal Bore Packer Or Tubing Retrievable PackerSpear

ESP Gauge

1

2

3

4

5


ESP Motor7


MLE Cable


9

13

ESP Pump Intake11

Telescopic Swivel15

Discharge Head14

ESP Pump12


Stinger16

Flow Crossover17

Inner Tubing (Lower Zone Injection)18


26 27

Upper Zone ESP / Lower Zone ESP(Seal Bore Packer)DUAL ZONE – DUAL ESP - COMINGLED SINGLE TUBING

Multiple reservoirs can be produced independently in the same well bore. In cases where the upper zone and the lower zone require an ESP, a dual zone completion can be used with a single production tubing string by comingling the discharge of each ESP.

When the distance between zones is restricted, a pod system with seal bore packer can be used.


Advantages:

• Injection to lower zone to boost upper zone reservoir pressure to increase production in a single well bore

• Ability to recycle produced water from the produced zone and recycle into the lower injection zone


ESP Assembly (Lower Zone Production)ESP Assembly (Upper Zone Production) Seal Bore PackerFlow Crossover / Y-Tool Assembly


12356

4 444

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13

151618

17

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21

2224 23

Pod Casing Clamp


Pod Casing

1

2

3

4

5

ESP Gauge6

ESP Motor7

MLE Protector8

MLE Cable

ESP Pump

9

12


FMDV15

Discharge Head14

ESP Pump Intake11


LowerProductionZone (ESP)

9

13


Spear17

Pump Support Block18



Pump Sub21

Telescopic Swivel22

Flow Crossover / Y-Tool23

Production Tubing (Comingled Production)24

1414


28 29

16

ESP Assembly (Upper Zone Production)

12467

Flow Crossover / Y-Tool Assembly

1517 141414 5

8

1212

ESP Assembly (Lower Zone Production)

467

ESP Packer

10

11

53 33

13 8


99

Upper Zone ESP / Lower Zone ESP(ESP Packer)DUAL ZONE – DUAL ESP - COMINGLED SINGLE TUBING

ESP Seal Protector


MLE Cable

1

2

3

4

5

ESP Pump Intake6

ESP Pump7


Gauge Swivel

ESP Packer

Cross Coupling ClampPump Support

Bypass Tubing Clamp

10

11

12

13

14

Stinger15


Production Tubing (Comingled Production)17





Advantages:



Disadvantages:




Discharge Head9

30 31

Upper Zone ESP / Lower Zone ESP(Seal Bore Packer)DUAL ZONE - DUAL ESP - CONCENTRIC TUBING - INDEPENDENT PRODUCTION TO SURFACE

Pod Casing Clamp


Pod Casing

1

2

3

4

5

ESP Gauge6

ESP Motor7

MLE Protector8

MLE Cable

ESP Pump

9

12


FMDV15

Discharge Head14

ESP Pump Intake11


Spear17

Pump Support Block18



Pump Sub21

Telescopic Swivel22


Inner Tubing (ESP Production From Lower Zone)25

ESP Assembly (Lower Zone Production)ESP Assembly (Upper Zone Production) Seal Bore PackerFlow Crossover / Y-Tool Assembly


12356

4 444

71011128 8 8

13

151618

17

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21

2225 24



9

13



Advantages:


• Allows fiscal measurement of production from each zone





Stinger23


2326

14


14

32 33

Advantages:


• Allows fiscal measurement of production from each zone


Disadvantages:




16

Upper Zone ESP / Lower Zone ESP(ESP Packer)DUAL ZONE - DUAL ESP - CONCENTRIC TUBING - INDEPENDENT PRODUCTION TO SURFACE

ESP Assembly (Upper Zone Production)

12467

Flow Crossover / Y-Tool Assembly

151718 141414

Multiple reservoirs can be produced independently in the same well bore. In cases where the upper zone and the lower zone require an ESP, a dual zone completion can be used with concentric tubing strings to allow fiscal measurement of production from each zone or reservoir.


5

8

ESP Seal Protector


MLE Cable

1

2

3

4

5

ESP Pump Intake6

ESP Pump7


Gauge Swivel

ESP Packer

Cross Coupling ClampPump Support

Bypass Tubing Clamp

10

11

12

13

14

Stinger15


Inner Tubing (ESP Production From Lower Zone)17


12

ESP Assembly (Lower Zone Production)

467

ESP Packer

10

11

53 33

13 8


12



9

Discharge Head9

9

34 35

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Y-Tool Sub Assembly(Comingled Flow)A Y-Tool Assembly provides the junction for comingling flow from upper and lower zones into the single production tubing.

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

• Optional top nipple used to set a plug, to test the production tubing or set a packer. Used with an isolation tool to straddle the Y-tool body for bullheading the well or isolating the upper ESP when running dual Y-tool ESP completions

• The Y-tool body used to create a junction between the upper zone and lower zone, to comingle the flow into the production tubing

• Bypass Nipple, for setting a plug, should one zone need isolated.

• Load bearing and sealing adjustable swivel with 15-inch stroke adjustment, for make up to the bypass tubing

• 10ft pump sub, for make up to the ESP pump discharge head

• Optional bypass tubing crossover, for reducing bypass tubing size.

The parts are torqued, pressure tested and drifted as an assembly, ready for make up to the ESP system on the well site.

For more information refer to our Y-Tool catalogue

FEATURES & BENEFITS• Fully torqued and tested• Full material traceability• Robust construction• Can be used for single and dual ESP logging bypass

Systems as well as for comingled dual zone production systems

SPECIFICATIONS• Low alloy steel or 13Cr material options to API 5CT• 5000psi MWP

36 37

Flow Crossover Assembly(Independent Production To Surface)

FEATURES & BENEFITS• Fully torqued and tested• Full material traceability• Robust construction• Can be used as junctions for dual zone independent or comingled flow systems


The Flow Crossover Assembly provides the junction for lower zone and upper zone concentric tubing strings. The top connection of the flow crossover is connected to the production tubing. The lower connection of the flow crossover block has an extended seal bore receptacle for landing a seal assembly (or stinger), which is connected to the inner production tubing.

This provides a sealed barrier between the outer and inner tubing strings. The offset leg of the flow crossover is connected to the Upper ESP in most cases, or connected to the lower system in cases where the upper zone is natural flow or an injection zone.

Part no Casing Size OD (in) Top Connection Top Nipple size (in) Seal Bore Size (in) Pump connection Bypass connection

FX-09625-0002 9-5/8” 8.25 5-1/2” 17#API BUTTRESS BOX

3.688 2.750 3-1/2” 9.3#EUE PIN

2-7/8" 8.6#ST-L PIN L80 TYPE 1

FX-07000-0007 7” 6.00 3-1/2” 9.3#EUE BOX

2.812 2.312 2-3/8” 4.7#EUE PIN

2-3/8” 4.6#F2J PIN

Technical Specifications

The UMS Flowell Flow Crossover assembly comprises of the following items:


• Optional top nipple used to set a plug, to test the production tubing or set a packer

• Flow crossover body to create the junction between the upper and lower zone systems

• Extended seal bore receptacle for receiving the inner tubing seal assembly (stinger)

• Load bearing and sealing adjustable swivel with 15-inch stroke adjustment, for make up to the bypass tubing

• 12ft pump sub for make up to the upper ESP pump discharge head, or the lower system for upper zones that are natural flow or injection zones.

• Optional bypass tubing crossover, for reducing bypass tubing size.

The parts are torqued, pressure tested and drifted as an assembly ready for make up to the ESP system on the well site.

umsflowell.com

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Seal Assembly(Stinger)The Seal Assembly (Stinger) is made up and run with the inner production tubing string and seals in the seal bore receptacle of the flow crossover assembly, to provide a barrier between the inner and outer production tubing strings.

The stinger has a series of bonded seals providing 36” of seal movement. The seal assembly can either have a top or bottom no-go, or where a high load pump out prevention is required for injection / production systems, a snap latch can be used to prevent the stinger from unseating.

The UMS Flowell stinger assembly comprises of:

• A crossover to make up to the inner production tubing• 10ft blast joint for erosion prevention at the outer tubing

entry point at the flow crossover, and to provide stiffness for enabling stinger seating into the seal bore receptacle

• Bonded seal assembly stinger with inner nipple profile, for testing the stinger seals and production tubing with a standing valve

FEATURES & BENEFITS• Fully torqued and tested• Full material traceability• Robust construction• Either Top No-Go, bottom No-Go or snap latch design• Inner nipple profile for testing stinger seals and inner

production tubing with a standing valve

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

• 5000psi MWP

Part No. Tubing Size No-Go size (in) Top Connection Seal Size (in) Inner Nipple Size (in)

SA-2750-0020 2-7/8” 2.802 2-7/8” 6.5# EUE BOX 2.750 1.812

SA-2312-0012 2-3/8” 2.340 2-3/8” 4.7# EUE BOX 2.312 1.500


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Part Number Box Thread Pin Thread Length (ft) Internal Drift (in)

287-STL-15 2-7/8” 8.6# ST-L 2-7/8” 8.6# ST-L 15 2.165”

287-VAMFJL-15 2-7/8” 8.6# VAM FJL 2-7/8” 8.6# VAM FSL 15 2.165”

PJ-2375-46-F2J-15 2-3/8” 4.6# F2J 2-3/8” 4.6# F2J 15 1.901”

Other Lengths Available

Technical SpecificationsBypass TubingUMS Flowell Bypass Tubing is positioned alongside the electrical submersible pump assembly, to provide unobstructed, fully protected passage, for coiled tubing or wireline toolstrings.

The Bypass Tubing has a smooth internal profile to remove the possibility of hang-up of the coiled tubing or wireline strings.

UMS Flowell F2J premium (metal to metal seal) flush joint thread is provided as standard, however other threads can be provided upon request.

FEATURES & BENEFITS• Box x Pin thread• Other threads available on request• 15ft standard length, other lengths available• No coupling- Flush outside diameter to maximize space


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Bypass Tubing Clamp

FEATURES & BENEFITS• Precision investment castings• Robust designs• Universal clamp for 9-5/8” casing• Grip features to prevent slippage, load tested to 0.86 ton• Universal cable clip designs for flat MLE and ¼” discharge

pressure line

SPECIFICATIONS• Low alloy steel or 13Cr material options

Technical SpecificationsBypass Clamp

Part Number Casing Size Clamp OD (in) ESP Size Bypass Tubing Size

TD12-096 7” 5.960 Universal 300/400 Series 2-1/8”

TD12-100 7” 5.960 Universal 300 Series 2-3/8”

BPC-0700-014C 7” 6.000 Novomet 319 Series 2-7/8”

BPC-09625-005 9-5/8” 8.350 500 Series 2-3/8”

BPC-09625-013 9-5/8” 8.350 Universal 500 Series 2-7/8”

BPC-09625-034 9-5/8” 8.350 400/500 Series fixed neck sizes - refer to drawing table 2-7/8”


BPC-09625-069 9-5/8” 8.350 Universal 500 Series - ABC Installation 2-7/8”

BPC-09625-051 9-5/8” 8.350 Universal 500 Series - Flatpack (Ecuador specific) 2-7/8”


BPC-09625-059 9-5/8” 8.250 Novomet 406 Series 4-1/4”


BPC-10750-0003 10-3/4” 9.53 Machined Neck for 500 Series 3-1/2”

BPC-10750-0008 10-3/4” 9.53 SLB 562 Protector (Trident MLE Pothead) 3-1/2”

The UMS Flowell Bypass Tubing Clamp is designed to provide full protection to the ESP MLE cable and auxiliary control/injection lines, whilst ensuring adequate flow area around the completion. The clamp also maintains the maximum stand-off between the ESP assembly and the casing, to give cooling to the electric motors.

The 9-5/8” bypass clamp has adjustable jaws to allow fitting onto 400 to 562 series ESP necks. The clamp has gripping features to secure the clamp to the bypass tubing. The standard clamp fits 2-7/8” bypass tubing. Fitting inserts to the clamp allows the clamp to be changed to 2-3/8” bypass tubing.

The 9-5/8” x 2-7/8” Bypass Clamp has been load tested to 0.86 ton before slippage occurred. The clamps have universal cable clips on either side to grip ¼” discharge pressure lines and the ESP MLE cable.

The 7” bypass clamp can be machined for 2-3/8” or 2-1/8” bypass tubing, and for 338 series to 400 series ESP neck sizes. This clamp also comes with a universal cable clip to grip ¼” discharge pressure lines and the ESP MLE cable.

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Part Number OD (in) ESP Gauge Swivel Pin Thread Bypass Box Thread Tailpipe Pin Thread

7PS-00014 5.80 2-3/8” 4.7# EUE 2-3/8” 4.6# F2J 3-1/2” 9.3# EUE

958PS-018 8.00 2-3/8” 4.7# EUE 2-7/8” 6.4# F2J 3-1/2” 9.3# EUE

958PS-035 8.00 2-3/8” 4.7# EUE 2-7/8” 8.6# ST-L 3-1/2” 9.3# EUE

Technical SpecificationsPump Support For Y-ToolApplicationsThe Pump Support Sub is an optional component of the bypass system. It is primarily used when running dual ESP’s or when tailpipe is to be run below the ESP and located into a PBR.

The purpose of the Pump Support Sub is to transfer any compressive loading to the ESP and tensile loading to the bypass tubing upon retrieval of the system.

FEATURES & BENEFITS• Allows compressive loads to be transferred onto the ESP

rather than the weaker y-tool bypass tubing• Allows tensile loads to be transferred through the bypass

tubing rather than the weaker ESP flange bolts• Available for 10-3/4”, 9-5/8”, 7-5/8” & 7” casing sizes• 2-3/8” EUE swivel for make up to the ESP motor base or

ESP gauge• Simple installation

SPECIFICATIONS• Available in low alloy or 13Cr metallurgy• Choice of threaded connections• Tensile strength dependent on the bypass tubing• Thread weights and grades to suit application• Supplied in a torqued and pressure tested sub assembly

with an 8ft bypass tubing pup joint and 6ft tailpipe pup joint as standard for handling

• Requires bypass tubing to be spaced out between the Y-tool and pump support, using standard bypass tubing lengths, and in addition, with spacer bypass tubing pup joints supplied in 1ft, 2ft, 3ft, 5ft and 8ft lengths. Fine adjustment is made with the telescopic swivel which has 15” stroke as standard.

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Part Number SWL Tubing Size Die Part Number

SC-0005 20 ton 2-7/8” SC-0006

SC-0009 20 ton 2-3/8” SC-0010

SC-0026-3500 10 Ton 3-1/2” SC-0024

SC-0026-4000 10 Ton 4” SC-0023

SC-0026-4500 20 ton 4-1/2” SC-0018


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Bypass SafetyClampThe UMS Flowell Bypass Safety Clamp provides a means of supporting the weight of the bypass tubing or the string weight during assembly of the system, when landed on the ESP work table (stove pipe).

The safety clamp has interchangeable tubing dies to suit the size of bypass tubing.

The safety clamp has a safe working load of 20 tonnes for use on systems with heavy tailpipe or for dual y-tool ESP applications.

FEATURES & BENEFITS• Lightweight• Lifting handle locations• Common body with interchangeable slip dies for 2-3/8”

and 2-7/8” tubing• 4 slip dies per assembly

SPECIFICATIONS• 20 Ton SWL• 2-1/8” to 2-7/8” tubing sizes

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Bypass Swivel Lift NubbinThe UMS Flowell Swivel Lift Nubbins allow handling of flush joint casing and tubing. The Swivel lift 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 in tubing and casing sizes from 2-1/8” upwards• Various thread options• Swivel hoist to allow make up of tubing / casing• Elevator shoulder for picking up string weight or used as

a stop shoulder when using slip type elevators

SPECIFICATIONS• 4.75 Ton SWL swivel hoist ring• Elevator shoulder rating dependent on thread size,

thread type, grade, and tubing/casing weight

Part Number SWL Pin Thread

SLN-2375-01-F2J 4 Ton / 20 Ton 2-3/8” 4.6# F2J

SLN-2875-01-F2J 4 Ton / 20 Ton 2-7/8" 6.4# F2J

SLN-2875-02-STL 4 Ton / 20 Ton 2-7/8” 8.6# ST-L


* 4 Ton when lifting with shackle / swivel20 Ton when using body shoulder with elevators

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ESP Worktable

The UMS Flowell ESP Worktable (or stove pipe) is a light weight worktable, used for supporting the weight of the ESP and bypass tubing when installing the system at the well site at a comfortable working height.

The weight of the installation is transferred onto the table by the ESP lifting clamp and/or bypass tubing safety clamp. The standard lightweight table comes fitted with a safety-gate feature to prevent swinging of assemblies. The table weighs 65kg and features foldable lifting handles for easy manoeuvrability.

The standard top plate has a 7 inch cut out for up to 675 series ESPs.

FEATURES & BENEFITS• Lightweight• Lifting handles• Safety gate feature• Optional adapter plate for rotary table if required

SPECIFICATIONS• 20 Ton SWL• 7” cut-out

(Stove Pipe) Part Number SWL Weight (kg) C-Plate Size (in)

WT-0002 20 Ton 65 7


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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

Pressure Discharge Sub9

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


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:


• 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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Pod Casing JointsUMS Flowell Pod Casing Joints are used to create the required length to shroud the ESP, so it isolates 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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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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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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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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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 SWL (Te)

WT-00116 5-1/2” 15

PS-7625-0020 7”/7-5/8” 15

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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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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 SWL (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

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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.

Technical SpecificationsPart Number Thread Connection SWL (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

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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)

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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.


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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”

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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

Documents

Dual Zone ESP Completions - umsflowell.com