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Pozos Multilaterales
Ramon Perdomo
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Agenda
Pozos Multilaterales
• Definición / Historia
• Clasificación TAML de Pozos MLT
• Diseños Pozos Multilaterales
• Aplicaciones MLT
• Tipos de Tecnología MLT
• Productos de Completación MLT
• Estadísticas
• Fututo Multilateral
• Contacto con el Cliente
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Un pozo multilateral es aquel en el cual uno omas hoyos laterales (comúnmente llamadosbrazos laterales o ramales) son construidosdesde un pozo principal (comúnmente conocidocomo brazo principal o tronco).
Concepto
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Historia Antecedentes Multilaterales
Robert E. Lee -1934 Reynolds, et al - 1938
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Zublin - 1953 Alexander Grigoryan - 1953
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Clasificación TAML de Pozos MLT
Junta abierta sin soporte. Hoyo principal ylateral abierto o con liner ranurado sin conexiónmecánica en la junta
Nivel 1
Nivel 2
Hoyo principal revestido y cementado, hoyolateral abierto o con liner ranurado sinconexión mecánica en la junta
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Nivel 4
Nivel 3Hoyo principal revestido y cementado, hoyolateral revestido pero no cementado. El pozolateral esta unido mecánicamente al pozoprincipal pero no existe aislamiento hidráulico.
Hoyo principal y lateral revestido ycementado. La integridad hidráulicadepende de la calidad del cemento
Clasificación TAML de Pozos MLT
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Nivel 5
Nivel 6
La integridad en la junta es proporcionada por lacompletación. La junta puede ser cementada ono. Restricción en ID. Integridad por Cemento noes aceptable
La integridad en la junta esproporcionada por el revestimiento.Sin restricción de ID. Integridad por cemento no es aceptable.
Clasificación TAML de Pozos MLT
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La geometria de los pozos multilaterales permiten adecuar un diseño alas necesidades de drenage
DualDual -- Alas de Alas de GaviotaGaviota
EspinasEspinas dede PescadoPescado
TrilateralTrilateral -- Apilado Apilado DualDual -- Apilado Apilado
DualDual -- TenedorTenedorTrilateralTrilateral – – PataPata dede CuervoCuervo
DualDual -- Alas de Alas de GaviotaGaviota
EspinasEspinas dede PescadoPescado
TrilateralTrilateral -- Apilado Apilado DualDual -- Apilado Apilado
DualDual -- TenedorTenedorTrilateralTrilateral – – PataPata dede CuervoCuervo
Diseño de Pozos MLT - Faja del Orinoco
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Trilateral con Fishbones
Diseño de Pozos MLT - Faja del Orinoco
Dual Lateral
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APLICACIONES MULTILATERALES
Reducciones de Costo de Capital y delProyectoMejora en el Valor del Yacimiento
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Reducción de Costo de Capital
Hacer que el costo de un Pozo MLT seamenor que 2 pozos – Pozos de alcance extendidos
– Pozos ProfundosConsideraciones de Superficie – BOP’s – Equipos de Producción – Slots Disponibles
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Don’t drill it twice
Reducción de Costo de Capital
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050
100150200250300350400450500550600650700750800850900950
10001050110011501200125013001350140014501500155016001650170017501800185019001950200020502100215022002250230023502400245025002550260026502700275028002850
0 5 10 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 90 95 100 105 110 115 120 125 130 135 140 145 150 155 160 165 170
EST.
P R O F U N D I D A D E
( M )
DIAS
Whipstock
Seccion 8 1/2"
Seccion 6 1/8"
Seccion 8 1/2"
Seccion 6 1/8"
Perforando Ventana
Seccion 12 1/4"
Brazil Project
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Reduccion de costos de CapitalOptimizando el desarrollo del campo
Esto? O Esto?Ahorros de facilidades de superficieCostos de Preparacion de Locaciones
Impacto ambiental
BOP’s – Lineas de FlujoFacilidades de ProduccionSlots
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Open Hole Junc ture
Mainbo re Target
Lateral Target
Multilateral Hoyo AbiertoCompetent Formation
Reducción de Costo de Capital
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Reducción de Costo de Capital
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LateralJuncture
Mainbore Target
LateralTarget
Reducción de Costo de Capital
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Reducción de Costo de Capital
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Reducción de Costo de Proyecto
• Facilidades mas pequeñas/ menos plataformas / Mayorcantidad de objetivos dentro del yacimiento.
• Reducir Mantenimiento
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Reducción de Costo de Proyecto
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Mejora en el Valor del Yacimiento
Drenaje mas completo – Mitigar problemas de Heterogeneidad del Yacimiento – Eficiencia del Barrido
• Mejor patrón de drenaje – Mejora la producción de fluidos difíciles (Tight Gas / Fluidos
viscosos)• Exposición al Yacimiento• Conectar Fracturas
– Tiempo• Poder acceder a mas reservas mientras que las instalaciones
de la zona de producción sigue siendo económica• Mantener los Pozos sobre el limite económico por mas tiempo
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Aceleración de Tasas – Tasas mas altas de Producción
• Mas Brazos• Mas Yacimientos
– Producción Temprana.Yacimientos Secundarios - Maduros – Reservas Marginales hechas Económicas
Mejora en el Valor del Yacimiento
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Heterogeneidad del Yacimiento
LOW MODERATE HIGH
LOW
Wave-dominatedDelta
Tidal depositsMeander Belt
FluvialDominated
MODERATEEolian
Distal DeltaFront
Braided Stream,Tide Dominated
HIGHTurbidites Braid Delta
Fluvial
Dominated Delta
Lateral Heterogeneity
CompartmentalizedUnconnectedLaterally bypassed
Low recovery efficiency,
Design infill drilling
and recompletions
(1)
Source: modified from (1) The Three-dimensionalfacies architecture of terrigenous clasticsediments and its implication for hydrocarbondiscovery and recovery. Concepts inSedimentology and Paleontology. Miall,A;Tyler,N.
Chapter 1, p.4 t. 1-2 (1991)
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Heterogeneidad del Yacimiento
Conectar el yacimiento e incrementar el area deDrenaje desconectado por la estratigrafia del yacimiento
x
z
3D VIEW Y
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Producir zonas no conectadas debido a desconexiónestructural
Reservoir HeterogeneityFallas Estructurales
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Well Pad & Area de Drenaje
1600 meter 1600 meter
6 0 0 m
e t e r 1200 meter 1200 meter
Pad
600 m x 1600 m = 237 acres
3200 m x
1800 m =
1423 acres
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LM17 LM19Single
Horizontal
SingleLateral
Dual Lateral
w/Fish bonesTriple Lateral
w/Fishbones
Dual Lateralw/Fishbones
Sencillo
Multilateral Field Development
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Reducción de presión en el fondo del pozoPor si solo no es un factor determinante para un
proyecto de pozo MLT, pero es un beneficio
Adicional
Distribuye el ΔP sobre un área mas grande delyacimiento
Ha resultado decisiva para limitar la irrupción
del gas
Ha mejorado las tasas de producción en estas zonasReduce la conificacion del agua & producción
de arena
Mejora en el Valor del Yacimiento
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∆ P = X
Lower Drawdown Pressures
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∆ P = X/10
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∆ P = X/40
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Mayor exposición al Yacimiento (Crudos Pesados)
Problemas por longitud de secciónhorizontalProblemas por heterogeneidad delyacimiento y alta viscosidadProblemas caída Temprana deProducción
Se evita:
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LM19-1
600m 689m 1021m
A
B
D
E
C
F
G
#3ST
#1#3
#8
#7
Estrategia de desarrollo con pozos horizontales
363636
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A
B
D
E
C
F
G
#3ST
#1
#3
#8
#7
Estrategia de desarrollo con pozos multilaterales
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Mayor exposición al Yacimiento (Tight Gas)
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Lower Latch
Coupling
Liner Hanger 7.00” x 4.50” w/ PBR
Bridgeplug
BOW@ 12,225’
MD
Top of PBR @12,242.5’ MD
Seal Unit 4 ½” 12.6# Q-125 FJL B
HPH Packer 4 ½” 12.6# Q-125 VAM
TOP Box (bottom)
4-1/2” 12.6# Joint Q-125 VAM TOP B x FJL P
4 ½” 13.5# liner shoe @ 17,569’ MD
4-1/2” 12.6# Joint Q-125VAM TOP P x P
TJ,5.43” ID
Slip-on swell packer
Mayor exposición al Yacimiento (Tight Gas)
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Economía en la Mejora del Yacimiento
Valor Neto Presente (NPV) - – Incrementado – Aceleración de las tasas & Recuperación Final Flujo de Caja - – Tasas de prod ucc ión inc rementadas / Mas f lujo de caja
Elevación de Costos($/BOE) - – Mas b ajo s - Men o s Cap ex y m a s Pr o du c c ión
Retorno sobre activos fijos- – Increm entado & Recuperación Final
Reposición de Reservas – – Recuperación d e Reservas d e la actual idad ant ieconómica
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Los sistemas multilaterales SperryRite® estándivididos en tres principales categorías:
Sistemas de Ventanas PremiladasSistemas de Salidas MiladasSistemas de completación Multilateral
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Asset Manager
La tecnologia multilateral Halliburton provee una variedad desoluciones especializadas para maximizar el drenaje delyacimiento a traves de una arquitectura del pozo avanzada.
Cual es la diferencia con la competencia?
La caracteristicas de varios de nuestros productos que nuestroscompetidores ni tienen:Ventanas Pre-miladasLatch coupling technologySistemas de milados sobre el casingJuntas nivel 4 cementadasCompletaciones submarinas nivel 5
Halliburton es el lider del mercado en instalaciones multilaterales yespecializados en las mas complejas aplicaicones del nivel 4 y 5.
Halliburton es el lider Global en MLT
© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
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Asset Manager
Aplicaciones para nuevos pozos, el casing principal incorpora unaventana premilada y un latch coupling orientado.
El Latch Coupling es el principal componente del sistema
Manejo de cortes – No se requiere el milado de acero para lasalida lateral, Aluminio es facilmente circulado. Costos por viajesde limpieza son evitados.
Compatible con todos los sistemas de completacion multilateral
SperryRite®Niveles TAML desde el 2 hasta 5
Sistemas de Ventanas Multilaterales Pre-Miladas
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V t P il d
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DESCRIPCIONLa Junta Ventana es un Casing de 9 5/8 ” premilado. La abertura delcasing se encuentra protegida por un recubrimiento de aluminio. Por debajo de la ventana se encuentra de los latch coupling que es laparte donde se acoplaran el whipstock, Workover Whipstock y JST.Este coupling permite asentar y orientar todas las herramientas haciala abertura en el Casing.ESPECIFICACIONESLongitud Total (L1) 36.6 ’Tope Junta – Key de Orientación (L2) 5.85 ’Fondo de Junta – Datum line (L3) 3.40 ’Tope de Ventana – Datum Line (L4) 22.99 ’Fondo de Ventana – Datum Line (L5) 6.66 ’Conexión Fondo Buttress PinConexión Tope Buttress BoxMáximo OD (Chaqueta de Aluminio) 11.320 ”Máximo OD (Upper Coupling) 11.300 ”Mínimo ID (Key de Orientación) 8.354 ”Mínimo ID (Upper Coupling) 8.681 ”Grado L80Máxima Tensión 325,000 lbsPresión de Estallido (Chaqueta de Aluminio) 3600 psiPresión de Colapso (Chaqueta de Aluminio) 2500 psiMáximo DLS para correrlo en Hoyo (Grados por 30 metros) 15 gradosMax. DLS para asentarloen el Hoyo (Grados por 30 metros) 3 grados1) Pup Joint Superior
2) Upper Coupling3) Ventana de Aluminio4) Casing5) Latch Coupling6) Pup Joint Inferior
Ventana Premilada
h C li l C d l Si
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Latch Coupling: El Corazon del Sistema
Window
Latch Coupling
Aluminium Sleeve
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Asset Manager
Aplicaciones en pozos nuevos o reentradas – La ventana lateral esmilada usando un sistema guia.
La geometria es precisamente controlada y asemeja al cortepremilado.
Todos los sistemas multilaterales de Halliburton utilizan el latchcoupling SperryRite, para pozos ya perforados y revestidos, ellatch coupling es combinado con un packer acoplador.
MillRite® Level 2, 3 or 4 milled exit systemReFlexRite® level 5 milled isolated tie-back multilateral system
Sistemas de Ventana milada Multilateral
Conventional Milling
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Conventional Milling
• Poor and undefined windowgeometry
• Short casing exitwindows
• Roll-off (windows curve to the right)• Difficult re-entry access to laterals
due to ID restrictions
• “Sweet Spot” is only ½ to 1/3 ofactual window length
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The primary millingassembly “machines” thewindow while controlling thewindow geometry.
Emulates the pre-milledwindow geometry.
MillRite ® Milled Exit System
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MillRite ® Milled Exit System
The primary millingassembly “machines”the window whilecontrolling the windowgeometry
MillRite® Milled Exit System
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Asset Manager
• TAML Level 2, 3, 4 or 5• High-strength junction using a track-guided
milling system creates a consistent,geometrically controlled window
• Eliminates “roll -off” and dogleg severityproblems associated with conventionallymilled windows
• Gives a longer full gauge window than aconventionally milled window
• New or existing wells
MillRite® Milled Exit System
Secuencia Operacional
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MillRite® MillingMachine
Latch Coupling
• The MillRite® latches will be timed onsurface to the desired window orientation.
• Run and latch MillRite® in Latch Coupling.• Mill first pass window.• POOH MillRite® Milling Assembly
Secuencia Operacional
Second Pass Mill & Whipstock
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A whipstock is a downhole tool designed toassist with the milling assembly to make alateral borehole from the parent borehole.
Comprised normally of two parts, an upperdeflector member commonly referred to asthe whipface, and an anchoring system, eithermechanical or hydraulic.
Second Pass Mill & Whipstock
SperryRite® Whipstock
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SperryRite® Whipstock
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5°
Vertical
SperryRite® Shear mill
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SperryRite® Shear mill
DESCRIPCION
La Window Mill tiene ocho aletas principales con cuatro aletas en lanarizque tienen insertados 17 x 13 ” PDC.
En la Nariz se inserta el Shear Bolt que permite conectarlo al Face delWhipstockpara que sea corrido en el hoyo.
ESPECIFICACIONES
Longitud Total (L1) 2.144 ’
Altura Aletas
(L2) 0.1915 ’
(L3) 0.3192 ’
(L4) 0.3250 ’
OD Nariz (D1) 6.050 ”
Máximo OD (D2) 8.515 ”
Secuencia Operacional
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Latch Coupling
• The whipstock latches will be
timed on surface to the desired windoworientation.
• Run and latch drilling whipstock inLatch Coupling.
• Shear the bolt and release whipstock.
• Dress the window to full gauge with thesecond pass mill.
Whipstock
Secuencia Operacional
Secuencia Operacional
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Latch Coupling
• Second pass mill to open up first passwindow and mill 10’ of rat hole.
• POOH with milling assembly.
Secuencia Operacional
Secuencia Operacional
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Latch Coupling
• Drill upper lateral hole.
Secuencia Operacional
Secuencia Operacional
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Latch Coupling
• Correr Die Collar y pescar whipstock.
Die Collar
Secuencia Operacional
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Integridad Mecanica en la junta para esta junta es creadousando una junta de transition premilada el cual sale porla ventana hacia el lateral. Un gran ID para accesar alhoyo inferior y un completo acceso al liner lateral permiteincrementar la capacidad de produccion y reentrada a ellateral y hoyo principal.
MachRite
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2003
Primer Pozo MLT Nivel 3 - Sistema MachRiteInstalado por Halliburton a Nivel Mundial
Sistema MachRite con Ventana de Aluminio
LatchRite® System
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Asset Manager
• TAML Nivel 4
• Junta de alta resistencia usando un linercementado con transition joint.
• El unico sistema nivel 4 que proveeaislamiento hidraulico y control de arena en la
junta.• Manejo del desecho del milado.• Provee un full gauge en la zona de la junta.• Permite un completo acceso a lateral y hoyo
principal.
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Sistema LatchRite ™ + JST ™(Junction Support Tool)
Nivel 4
Secuencia Operacional
Secuencia Operacional de Dual Lateral MLT
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13 3/8”Perforar hoyo de 17 ½” y correr casing de 13 3/8”Ejecutar cementación
Secuencia Operacional de Dual Lateral MLT
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13 3/8”
Perforar sección de 12 ¼”Correr Casing de 9 5/8” con ventana premiladaOrientar Ventana con gyroRealizar cementación de casing 9 5/8”
9 5/8”LatchRite
Window
9 5/8”7”
9 5/8”9 5/8”
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Orientación de Casing 9 5/8 ”
Para la orientación de la Ventana se utiliza el Wireline Orienting Tool, el cual seacopla al Key interno de la ventana LatchRite TM
Key de Orientación
Sistema LatchRite® Nivel IV
Secuencia Operacional de Dual Lateral MLT
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Perforar sección de 8 ½” (Lateral A)
9 5/8”LatchRite
Window
13 3/8”
9 5/8”9 5/8”
Lateral A
Secuencia Operacional de Dual Lateral MLT
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Correr Liner de 7” (Lateral A)
13 3/8”
9 5/8”
9 5/8”LatchRite
Window
9 5/8”7”
Lateral A
Secuencia Operacional de Dual Lateral MLT
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13 3/8”
9 5/8”
9 5/8”LatchRiteWindow
9 5/8”7”
Lateral A
Correr whipstock de perforación y abrir ventana Lat. B
Secuencia Operacional de Dual Lateral MLT
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13 3/8”
9 5/8”
9 5/8”LatchRiteWindow
9 5/8”7”
Lateral A
Perforar sección de 8 ½” (Lateral B)
Lateral B
Secuencia Operacional de Dual Lateral MLT
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
13 3/8”
9 5/8”
9 5/8”LatchRiteWindow
9 5/8”7”
7”
Lateral A
Correr y cementar liner de 7” Lat. B
Lateral B
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Corrida de Transition Joint
La articulación permite un pivote para que el liner se coloque en ellateral sin problemas, además permite que la parte inferior delrunning tool haga tope con el whipstock para que de exista un controlexacto de la profundidad.
Sistema LatchRite® Nivel IV
Secuencia Operacional de Dual Lateral MLT
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
13 3/8”
9 5/8”
9 5/8”LatchRiteWindow
9 5/8”7”
7”
Lateral A
Lateral B
Correr BHA con mecha de 6 1/8” y cement cutter de 8 ½”
Secuencia Operacional de Dual Lateral MLT
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
13 3/8”
9 5/8”
9 5/8”LatchRiteWindow
9 5/8”7”
7”
Lateral A
Lateral B
Washover y pesca del Whipstock Lat. B
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Washover Pipe
Su diseño de como esta posicionados los cortadores permite cortar fácilmente elMetal, cemento y goma que exista entre el casing y el whipstock
Sistema LatchRite® Nivel IV
Secuencia Operacional de Dual Lateral MLT
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
13 3/8”
9 5/8”
9 5/8”LatchRiteWindow
9 5/8”7”
7”
Lateral A
Lateral B
Perforar Baffle collar Lateral A
Nota:El Baffle collar puede ser sustituido por un cuelloFlotador invertido Cementado.
Secuencia Operacional de Dual Lateral MLT
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
13 3/8”
9 5/8”
9 5/8”LatchRiteWindow
9 5/8”7”
7”
Corrida de JST (Junction Support Tool) Lat “B”Junta de protección adicional (7 1/8” ID)Plataforma para Deflector de reentrada
Lateral A
Lateral B
Secuencia Operacional de Dual Lateral MLT
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
13 3/8”
9 5/8”
9 5/8”LatchRiteWindow
9 5/8”7”
7”
“Diseño
Final Dual Lateral Nivel 4”
Lateral A
Lateral B
Evolucion Tecnológica
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Evolucion Tecnológica
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LATCH COLLET: High level Finite Element Analysis (FEA) software was used to develop a high strength colletcapable of being latched in the same as a traditional spring loaded latch, but with a very large ID. Designingfor latch loads in excess of 20,000 lbs. force created a multitude of stress related problems, but with properdesign and material selection a product was made to almost exactly imitate the operation of a standard latchassembly.
Evolucion Tecnológica
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JST Suppo rt Sleeve toPreserve Level 4 Jun ction
LVL 4 Junction
Evolucion Tecnológica
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FK20-5 JST Latch Collet:
-Excessive rotation while locating latch profile
-Hole not clean of sand and steel debris
-Surface of steel not hard enough
-Latch loads lower than expected
Evolucion Tecnológica
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1. Locate latch with minimal rotation. Low RPM and high torque.
2. Set down weight to confirm latched. Up to 35,000 lbs.
Hard surface will prevent erosiondue to sand and steel debris
Change bevel angle tosupport more weight
Side load can support torqueup to 10,000 ft-lbs.
Operational Changes:
© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
E t dí ti d I t l i d P MLT F j d l O i
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Nivel Figura
3
LTBS ™1
MachRite ™1
4LatchRite ™(@ Feb 2011)
234
5 MSCS™ - 19971
Estadísticas de Instalaciones de Pozos MLT - Faja del Orinoco
E t dí ti d I t l i d P MLT F j d l O i
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LTBS ™Ventana
Fibra Vidrio
MSCS ™(Multi String
CompletionSystem)
RMLS™Ventana
Fibra Vidrio
LatchRite ™Ventana
Aluminio
MachRite ™Ventana
Aluminio
LatchRite ™+
JST
Nivel 3 5 4 4 3 4
AñoInstalación
1996 1997 2000 2001 2003 2004
Numerode Viajes
6 Viajes Completacion5 Viajes
7 Viajes 5 Viajes 3 Viajes 6 Viajes
Instalaciones@ Feb/2011 1 1 91 16 1 127
Evolucio n Tecnológica Sistem as MLT Hall iburton en Venezuela
1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Estadísticas de Instalaciones de Pozos MLT - Faja del Orinoco
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Consideraciones Especiales del Pozo LatchRiteNivel IV
En la sección tangencial del hoyo de 12 ¼’’ los DLS no deben ser mayores de 3grados.La tasa de construcción (doglegs) debe ser menor a 10°/100 en la sección de 12 ¼’’por encima de la sección tangencial.La sección tangencial debe ser como aproximadamente de 200 pies en MD.La sección tangencial donde estará la junta deberá tener una inclinación entre los 5grados y 90 grados.La sección tangencial deberá estar en zona lutitica para proveer una mayor integridadde la Junta
Las siguientes consideraciones son requeridas para lograr los objetivos recomendadosde una junta de nivel 4 para un pozo MLT dual típico:
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Productos de Completacion MLT
IsoRite®
FloRite® FlexRite®
IsoRite® Isolated Multilateral Completion System
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
IsoRite® Isolated Multilateral Completion System
The IsoRite® system was developed to:
• Provide lateral re-entry in anySperryRite® multilateral junction that
has a Latch Coupling• Provide through-tubing re-entry with
wireline or coiled tubing
• Provide flow control and temporary
hydraulic isolation up to 10,000psi• Have the ability to perform
multilateral well intervention
IsoRite® CompletionSystem
Installation Schematic9 5/8” FloRite Level 5 Junction
FloRite® Multistring
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
3 1/2” Lateral Tubing3.688” Seal Stem
Install FloRite Vector Block
• M/UP & RIH with Vector Block assy as below
1. Shrouded Seal stinger for lateral OHGP Packer seal bore
2. 3 ½” tubing joints3. Mainbore seal stinger for DBD sting in
4. 3 ½” tubing joints
5. Vector Block assembly
6. 5 ½” tubing joints
7. G-10 Retrievable Torque Locked Packer w/ seal bore extension
8. Packer running tool
9. Running string to surface
• Long string deflects into lateral and shroud shears as seals enter OHGP Packerseal bore.
• Mainbore short string stings into DBD seal bore
• Set G-10 packer, and release running tool
• POOHLatch
Coupling
The following steps are not shown in schematic
Run Upper Completion• M/UP 7” upper completion as per program.
• RIH
• Land in G-10 packer seal bore
• Set completion packer Lateral String (red)
Mainbore String(green)
ShroudedStinger (lateral)
Lateral Seal stem(released from
shroud)
3 1/2” Lateral Tubing w/3.688” Seal Stem & 4.35”Lateral Sheath Assembly
3 1/2” MainTubing
3.688” Seal Stem
Mainbore Stinger
5” or 5 ½” Tubing(not shown)
9-5/8” G-10 Packer (not shown)
The FloRite® system was developed to:• Provide permanent hydraulic
isolation of the junction, up to10,000psi.
• Allow separate or commingledproduction from a dual completion.
• Provide flow control and isolation
• Have the ability to performmultilateral well intervention via CT orwireline.
• Provide lateral and mainbore flowcontrol.
Completion System
FloRite®
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
FloRite®
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Single String Seal Bore Packer
Vector Block Assembly
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
D-shaped section offlexible junction.
Mainbore stinger –enters seal stack in deflector
94
Sistemas Multilaterales Noruega
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
• 1996: 1 st Halliburton MLT job for Hydro on Oseberg C (4503)• 1997: 1 st MLT well on Troll Olje (4503)• 1999 – 2000: FlexRite® system developed for Troll
• 2001: 1 st FlexRite® installation.• Typical installation time: 6.2 days.
FlexRite
Junction
• Lower mainbore completed beforeworking on upper lateral.
• Lateral branch drilled from 9 5/8 ”
window to TD in single hole size &
completed with premium sandscreens.
9595
Norway Offshore Sub Sea Level 5 FlexRite ™ Penta-Lateral
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
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Estadisticas
Where has the technology been used?
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
gy
Over 715 installations globally:
Argentina Italy Qatar Australia Japan Russia
Brazil Kazakhstan Saudi Arabia
Canada Kuwait Trinidad
China Malaysia UAE
Colombia Mexico UKCongo Netherlands USA
Egypt New Zealand Venezuela
India Norway Yemen
Indonesia Oman
Where has the technology been used?
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Asset Manager
Ongoing Projects
Past Experience
234 Level 4(PDVSA)
100 Level 5(StatoilHydro)
18 Level 4
7 Level 5(Aramco)
9 Level 5(Apache)
40 Level 2/3(CS resources)
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Futuro Multilateral
What is next for this technology?
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
FlexRite System OHGP
Combining our proven FlexRite subsea Level 5system with the capability to install an Open HoleGravel Pack on the lateral completion.
Deepwater Solutions
Taking sealed junction technology to deeper andmore challenging environments.
MachRite XE*
MachRite Level 3 junction system combined withEasywell swelling packers to create the world’s firstswell-packer isolated junction.
FlexRite OHGP
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Dual Lateral level 4 Well Design
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
13 3/8 ” Casing
9 5/8”LatchRiteWindow
7” liner
7” liner
Lateral A
Lateral B
7” Stage Tool
7” Packer
Cement
7” Baffle Collar
7” Liner Hanger 9 5/8 ” Casing
Dual Lateral level 4 well modified for thermal production of heavy oil
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
13 3/8 ” Casing
9 5/8”LatchRiteWindow
9 5/8 ” Casing
Lateral A
Lateral B
HT Cement With Swelling Particles
7” Stage Tool
7” Packer
7” Travel Joint (ID = 6.366 in)
7” Baffle Collar
7” Expansion joint7” liner
7” liner
Dual Lateral level 4 well modified for thermal production of heavy oil
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Producer Well Injector Well
Reservoir temperature= 130 ̊ F
Temperature of producer well= 200 - 250 ˚F
150 m
150 m
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
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Contacto con el Cliente
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Design Process
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Asset Manager
Design Process• Define Objectives - What are we trying to do?
• Maximize Production• Maximize Recovery• Reduce Well Costs, alleviate slot constraints etc.• Evaluate Reservoir Flow Characteristics• Risk Mitigation
• Strategy – How will we accomplish this (concept)?• Maximize Reservoir Exposure• Multiple / Discrete Reservoirs• Flow Control / Monitoring
• Process – What do we need to implement?• Structure – What will we need to execute the process?
• Joint teams – Interactive Well Design• Resources – What equipment / people do we need?
Risk Mitigation
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Halliburton MLT has established a
Risk Register for each of the TAMLLevel junctions and completions weprovide.
There are at least as many risk factorsdocumented by Halliburton MLT that
the customer could think of, andprobably more.
Each risk is accompanied bymitigating actions or contingencymethods which either eliminates orsignificantly reduces operational risks.
Unable to installwhipstock in latchcoupling
Push and pull through latch to confirm depth prior tolatch-in, confirm latch-in with torque and weight.Perform clean-up run prior to whipstock installation if junk is suspected.Do not perform numerous latch in attempts if it issuspected that debris is residing in the latchcoupling. Perform clean up run if latch inparameters are erratic.
One instance where perforating debris in low side latchcoupling pockets prevented latching of the whipstockassembly into the latch coupling. Debris management andtaking necessary clean-up runs if debris is suspected mustbe followed.
To Asset Managers Reservoir Engineers: Halliburton
Positioning Strategy Statements
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Asset Manager
• To Asset Managers, Reservoir Engineers: Halliburtonmultilateral systems can increase your reservoirexposure, allowing long lateral screens to be passedthrough the high strength junction.
• To Drilling Managers, Supply Chain Managers /Procurement staff: We can provide the required sandcontrol with a hydraulically isolated TAML level 5 junction.Our experience and success rate is documented by ourOperational Excellence, available to our customers.
• To Drilling Managers, Drilling Engineers: Halliburtonmultilateral systems reduce overall field developmentcosts. The aluminum wrapped pre-milled window is fast,eliminates steel debris and reduces NPT.
What is so special about Sperry’s multilateral technology?
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Do you know what is really important when selecting amultilateral system?Casing window geometry.Installing pre-cut windows gives maximum debris control andfewer clean-out trips.
If we do have to cut a casing window, a track-guided millingsystem is deployed to guarantee the window geometry.The shape and length of the casing window is absolutely criticalwhen running advanced multilateral completions and attemptinglateral re-entry.
p p y gy
Elevator SpeechWhat is so special about Sperry’s multilateral technology?
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
The LatchRite system’s patent protected washoveroperation completes the junction in fewer trips, reducingwell construction costs.Worldwide experience in installing pre-milled windows -maximum debris control and fewer clean-out trips.
The LatchRite systemHigh strength TAML level 4 junction with hydraulicisolation for sand control and a documented 97% successrate. Provides full bore access to the mainbore and lateralswhich means higher production flow capability and access
for stimulation.
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Outline the objectives ... leverage tax advantages, long term
Administrative / Economic
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
What is the value and risked rate of return on investment, howsensitive is the project success to risk factors?
Do risks and interface issues warrant use of an integrated serviceprovider and are incentive schemes to align risk / reward in order?
How does a multilateral development scheme compare to the nextbest alternative?
How quickly can it be planned & implemented, what is the serviceproviders mobilization time? Who will prepare the different
procedures? Contingencies?Does service provider have operational / support capability forplanned operation (infrastructure)?
ultimate recovery & reservoir management, immediate maximumproduction, slot preservation and environmental factors.
Jun ct ion Select ion
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Histor ical ly formation h as been im permeable shale or c layston e.
Pressure requirement - What is lateral’s lowest target pressure
re la t ive to junc t ion form ation fracture s t rength? Mechanical and chemica l s tab il ity o f junct ion format ion - Whatare formation’s sensitivity to proposed well path, drilling,com plet ion , s t imula tion and prod uct ion f lu ids?
Problem zones - Close proximi ty to OWC, over-pressured orsu bs idence zones?
Good cement in m ainbore - Does cement bond log sh ow g oodbo nd at plann ed exi t poin t in parent casing?
Head cou nt – Is i t po ss ib le to u se a com bination of c ro ss- t raining and m ult i -tasking to reduc e the num ber of operatorsoffsho re, with the addi t ional us e of a real t ime centre?
Dril l ing Iss ues
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Where is planned K OP & target? - Well path tor tuo si ty, leng thand size of m ainbo re / lateral section , available weigh t to run
and land casing / l iner s t r ing ? How w i ll the k ickoff be in it ia ted? - Open ho le / cased hole ,m illed or p re-mi l led w indow ?
Does po re pressu re / f racture g radient c urv e analysis in dicate
an abn orm al wel l con trol issue con sidering selected exi t po int / c as ing p lan? Well con tro l p rog ram ?
Optim al separation betw een each leg o f the well?
Geos teer ing to s tay within the reservo ir?
Mud pro gram - Hole s tabi l i ty, penetrat ion rates , ho le cleanin g,sol ids c on trol , lubr ic i ty / torqu e drag?
Com plet ion Issu es What is the p urpo se of the w ell o i l , gas , injector, m ult ipurp ose?
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p p g j p p
What casing s izes / weights planned? (Mainb ore and la teral)
Typ e of co m pletion : Cemented l iner and p erf, sc reens , frac pac,acid, st im ulation , etc.?
Government regula tions o n separat ion of f low s t ream s f rom
different reservoirs? ... Co-min gled or s eparated pro du ction
required? What tubing s izes/w eigh ts planned?
What is planned l i fe of la teral - disp osable/sho rt la teral or
sign if icant investm ent to b e pro tected?
What bui ld rates above and be low junct ion m ust be passed bycom plet ion too ls & w hat is the minim um I.D. requirem ent forfuture intervent ion ?
Completion Issues (Cont…)
D th j t i dt b l df dj i i t /
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Does the junct ion need to be sealed from adjoining w ater / gas
or different press ure regim e?
What is jun ction DP requirem ent and accep tance cri teria?
What bot t lenecks exis t in p rodu ct ion sy s tem & are they
alleviated with ML w ell deliverabil i ty?
How m uch debr is i s generated in the junc t ion cons t ruc t ion
process and i s th is addressed in the sys tem des ign?
Is w ater / gas co ning / crest ing a co ncern?
Is sand pro duc t ion a con cern?
Maintenanc e Iss ues
Whatfuturest im ulat ion treatmentsmigh tbeplanned?
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What future s t im ulat ion t reatments migh t be planned?
Is w ater enc roachm ent a co nc ern with rela ted diagno st ic /
conform ance i ssues to be addressed? Is r e-perfor ation o f lateral plann ed?
Is log ging of la teral plann ed?
Is deepenin g / work ov er of lateral envisaged ?
What too l s izes wil l be run in la teral - thru tub ing, thru c asing?
Is w ell intervent ion planned thru tub ing, thru casing , witho ut
kil l ing well?
Ini t ial Enqu iry L evel
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
The Screening Document:
Outlines the most salientaspects
Focuses the customer’smind on these points
Gives us a clearer indicationof what is expected andrequired.
Factores para posicionarse en el mercado
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TECNOLOGIA
TIEMPO DEINSTALACION
EXPERIENCIA
COSTO DELSISTEMA
Factores para posicionarse en el mercado
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Guías de Calidad
Factores para posicionarse en el mercado
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Experiencia
50
55
60
65
70
75
80
8590
95
100
2004 2005 2006 2007 2008 2009 2010
81 85 8292
8580
100
% Whipstock Recovered 1 st Trip
Time Comparison Multilateral System Venezuela
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
0 50 100 150 200
SealRite Dual Lateral
MatchRite DualLateral
LatchRite AluminumWindow with JST
Dual Lateral
LatchRite CompositeWindow Dual Lateral
M u
l t i l a
t e r a
l S y s
t e m
Hrs
Run 9 5/8 w/the window(s) & orient w/gyro
Cement 9 5/8 Casing
P/U HRT, Retrieve Sleeve, POOH
P/U whipstock, RIH set whipstock, mill out window, POOH
P/U Retrieving Tool, RIH fish Whipstock, POOH
P/U Deflector, RIH set Deflector, POOH
Run 7" Liner and hang liner, POOH
Run 7'' Liner in lateral B, cement & POOH w/RT
P/U Cleaning BHA, drill cement to top of whipstock, POOHw/RT
P/U Cleaning BHA, drill cement & clean lateral, POOH
P/U Washover BHA, washover & retrieve whipstock, POOH
P/U Main bore cleaning BHA, clean mainbore, POOH
Install JST
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Preguntas