MENAPS-11-18 Predicting Wellbore Dynamic-Shock Loads · PDF filePredicting Wellbore Dynamic-Shock Loads Prior to Perforating SPE 143787 Jack Burman/Exploitation Technologies, LLC/SPE;

Predicting Wellbore Dynamic-Shock Loads Prior to Perforating SPE 143787Loads Prior to Perforating SPE 143787

Jack Burman/Exploitation Technologies, LLC/SPE;

Martin Schoener-Scott, Cam Le, and David Suire/Halliburton/SPE

Agenda

� Software Overview

� Validation Example

2© 2011 HALLIBURTON. ALL RIGHTS RESERVED.

� Case Histories

� Comparing the Cases

� Conclusions

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Dynamic -Shock Modeling Software

� Simulation software that focuses on dynamic loading of tubulars, packers, casing and other completion equipment.


� Inception– 2003– SPE 90042

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Other SPE Papers

SPE 144059


OTC 21059MENAPS-11-18

Physics Based Model

Wellbore

Possible Surface Over or Under-Pressure� Tool burn

� Navier-Stokes equation– transient mixed-phase

compressible fluid flow in well

� Transient Bernoulli– choke flow for perfs

� Fracture mechanics

Tubing,Packers, etc.


Fluid motion in Well, Tubing

Energized Zone

WellboreFluids

Fluid Motion In/Out of Perfs/FracsEnergy

Source (PerfGun)

Basic Wellbore Geometry

� Fracture mechanics– frac initiation and propagation

� Wave equation– elastic solids in equipment

string

� Transient layered Darcy flow

– formation

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Dynamic Failure Modes

Packer- Axial Loads- Differential Failure

Tubing- Comp and Tension- Burst and Collapse- Bending


Guns- Comp and Tension- Burst and Collapse

Bridge Plug/Sump- Axial Loads- Differential Failure

Casing- Burst

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Dynamic Loads

Packer- Pressures- Solid loads

Tubing- Solid loads above andbelow packer

- Drag inside andoutside


Guns- Solid load- Pressures internal andexternal

- Drag inside andoutside

Bridge Plug/Sump- Pressures

Casing- Pressures

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Validation ExampleModel Matching – New Gun SystemModel Matching – New Gun System

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High Speed Gauge

� 1-11/16” OD x 50” (22 lbs)– Additional 17” with Shock

Mitigator

� 30,000 psi (peak), 30,000 psi (static)

� +/-50,000 G’s of Acceleration


� +/-50,000 G’s of Acceleration� 4,000,000 data points� 150°C� Sampling Rate (High,

Intermediate, and Slow Speeds)– 115,000 data points/second,

and down to one sample every 10 seconds

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5 ¾” 18spf HSD Mirage RDX

� What dynamic loads are to be expected during


� What dynamic loads are to be expected during gun detonation?

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Well 1


• Initial overlay with original geometry

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Well 1


• Overlay with update geometry

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Well 1


• Overlay with adjusted gun remnant and permeability

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Well 2


• Initial overlay

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Well 2


• Overlay with adjusted gun remnant and permeability from well 1

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Well 1

257 kips downward

Pre-Job Model Post-Job Model

206 kips downward


395 kips upward

273 kips upward

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Well 2Pre-Job Model Post-Job Model

174 kips downward138 kips downward


391 kips upward

273 kips upward

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Lessons Learn

� New gun system characteristic of retaining explosive energy in these conditions

� Loads were over predicted in initial models– Longer gun assembles can be run without much


– Longer gun assembles can be run without much concern

� To match FastGauge Data in late time adjustment to perm was require to match the actual reservoir response– Confirm by feedback from customer's production data

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Case HistoriesCase Histories

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Location – Gulf of Mexico, East Breaks (EB) and Garden Banks (GB).


Geographic distribution of 2008 discoveries by wate r depthhttp://www.gomr.boemre.gov/PDFs/2009/2009-016.pdf

EB GB

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Shrouded Firing Head

Time Delayed Firing HeadHigh Strength Shroud


6 ½” Gun System 14spf

Double Pin Connector

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GB Case 1: Stage 1 motion, packer load, tubing compression, and tension

Packer movementTubing movement

� 9 5/8 in. packer� 1 - 10 ft pup joint 3 ½ in. 12.95#/ft P-110 tbg� Below packer safety joint� 1 - 10 ft pup joint 3 ½ in. 12.95#/ft P-110 tbg� 3 ½ in. fill disc assembly� 1 - 30 ft joint 3 ½ in. 12.95#/ft P-110 tbg� Shrouded firing head assembly� Top shot 19750ft.� 43 ft loaded 6 ½ in 14 spf RDX Super Hole� Sump packer 10 ft below bottom shot� BHP 10000psi

Packer Movement


Tubing compressive loading – 345k

Packer loading - 319k

� BHP 10000psi� PBTD 246 ft below bottom shot

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Case 1: Stage 1 pressure at specific locations (nodes) in the wellbore

Bottom perforations

� 9 5/8 in. packer� 1 - 10 ft pup joint 3 ½ in. 12.95#/ft P-110 tbg� Below packer safety joint � 1 - 10 ft pup joint 3 ½ in. 12.95#/ft P-110 tbg� 3 ½ in. fill disc assembly� 1 - 30 ft joint 3 ½ in. 12.95#/ft P-110 tbg� Shrouded firing head assembly� 43 ft loaded 6 ½ in 14 spf RDX Super Hole� Sump packer 10 ft below bottom shot� PBTD 246 ft below bottom shot


Differential pressure at the packer – 1700psi

Top perforations

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Case 1: Stage 1 average pressure in perforated interval

Peak pressure in perforated interval – 15268psi

Initial wellbore pressure


Formation pressure

� 9 5/8 in. packer� 1 - 10 ft pup joint 3 ½ in. 12.95#/ft P-110 tbg� Below packer safety joint � 1 - 10 ft pup joint 3 ½ in. 12.95#/ft P-110 tbg� 3 ½ in. fill disc assembly� 1 - 30 ft joint 3 ½ in. 12.95#/ft P-110 tbg� Shrouded firing head assembly� 43 ft loaded 6 ½ in 14 spf RDX Super Hole� Sump packer 10 ft below bottom shot� PBTD 246 ft below bottom shot

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GB Case 2: Stage 3 Iteration 2


� 9 5/8 in. packer� 3 - 10 ft joint 3 ½ in. 12.95#/ft P-110 tubing� Below packer safety joint � 6 - 10 ft joint 3 ½ in. 12.95#/ft P-110 tubing� 3 ½ in. fill disc assembly� Shrouded firing head assembly� Top shot 21509ft� 60 ft loaded 6 ½ in. 14 spf RDX Super Hole � Frac pack packer 10 ft below bottom shot with packer plug installed

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EB Case 3: Iteration 1 initial proposed BHA

� 9 5/8 in. packer� 1 - 10 ft pup joint 3 ½ in.12.95#/ft P-110 tbg� 3 ½ in. fill disc assembly� 1 - 30 ft joint 3 ½ in. 12.95#/ft P-110 tbg� Shrouded firing head assembly� Top shot 7500ft MD� 30 ft loaded 6 ½ in. 14 spf RDX Super Hole� PBTD 84 ft below bottom shot


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Case 3: Iteration 2 with addition of BPSJ and tubing

� 9 5/8 in. packer� 1 - 30 ft joint 3 ½ in.12.95#/ft P-110 tbg� Below packer safety joint� 1 - 30 ft joint 3 ½ in. 12.95#/ft P-110 tbg� 3 ½ in. fill disc assembly� Shrouded firing head assembly� Top shot 9102ft� 30 ft loaded 6 ½ in. 14 spf RDX Super Hole� PBTD 84 ft below bottom shot


Compressive Yielding @ 8,990-8,991

Bending in Tubing @ 8,990-8,992

Case 3: Iteration 3 with additional 60 ft of tubing & all tubing joints where changed to 10 ft pup joints


� 9 5/8 in. packer� 6 - 10 ft pup joint 3 ½ in.12.95#/ft P-110 tbg� Below packer safety joint� 3 - 10 ft pup joint 3 ½ in. 12.95#/ft P-110 tbg� 3 ½ in. fill disc assembly� 3 - 10 ft pup joint 3 ½ in. 12.95#/ft P-110 tbg� Shrouded firing head assembly� 30 ft loaded 6 ½ in. 14 spf RDX Super Hole� PBTD 84 ft below bottom shot

Slide 28

AS1 This doesn't seem clear.Adrienne Silvan, 5/5/2011

Comparing Case 1 Stage 1 with Case 3 Iteration 2:Pressures at Selected Nodes

21,600 psi15,400 psi


3,200 psi differential at packer

1,700 psi differential at packer

Case 1 Stage 1 Case 3 Iteration 2MENAPS-11-18

Comparing Case 1 Stage 1 with Case 3 Iteration 2: Average Pressures in Perforated Interval

15,246 psi15,268 psi


Case 1 Stage 1 Case 3 Iteration 2

5,878 psi reservoir

9,994 psi reservoir

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Comparing Case 1 Stage 1 with Case 3 Iteration 2: Rat Hole


246 ft

84 ft

Case 1 Case 3

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Comparing Case 1 Stage 1 with Case 3 Iteration 2: Summary

� Higher peak pressures

� Higher packer differential


� Lower BHP

� Less rat hole volume

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Conclusions

� An experienced modeler can predict dynamic behavior during a perforating event.

� Dynamic behavior is not always intuitive.


� Dynamic behavior is not always intuitive.

� Eliminate potential problems before execution.

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Burning Questions


What Do You Think

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Documents

MENAPS-11-18 Predicting Wellbore Dynamic-Shock Loads · PDF filePredicting Wellbore Dynamic-Shock Loads Prior to Perforating SPE 143787 Jack Burman/Exploitation Technologies, LLC/SPE;