PESA 2012 Spring Oil 101 Teel

8/12/2019 PESA 2012 Spring Oil 101 Teel

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SchlumbergerP

ublic

Equipment, Systems and Processes

Mark E. Teel

Client-Relations Manager

SRC Schlumberger Rosharon Center


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2 Initials


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3 Initials

5/15/2012

The Life of Oil and Gas Wells and ReservoirsSeismic

ExplorationExploration

DrillingDevelopment

DrillingFormationEvaluation

WellTesting

Casing andCementing

Complete StimulateWorkoverInterventions

Monitor andManage

Plug andAbandon


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4 Initials

5/15/2012

Oil and Gas Drilling Rigs


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5 CAP

How deep is deep?

500 m

(1640 ft)301 m

(988 ft)


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6 Initials

5/15/2012


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7 Initials

5/15/2012


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8 Initials

5/15/2012


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9 Initials

5/15/2012


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10 CAP

Identifying Needs and Challenges

So, How deep

are we going?

Deeper than

ever!

Empire

State

Building


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11 Initials

5/15/2012


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12 CAP

How deep are we going below the seafloor?


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13 Initials5/15/2012


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14 CAP

How deep are we going below the seafloor?


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Wellbore Architecture

WellCompletions


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Multilateral Wells and Wellbore Junctions

StrengthSolids Exclusion

Hydraulic Pressure Isolation

Lateral accessDefine technique, coiled tubing, wireline, rig

Size and type of tools for intervention


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20, Completion Basics15-May-12

What is a well completion?

Equipment installed and procedures performed in oil or gas

wellbores to facilitate flowing fromproductionor pumping

intoinjectionsubsurface formations after drilling, running

steel casing and cementing the primary casing or liner in place.

Production tubing and other equipment components of a well

completion helptransport hydrocarbonsto surface in an

efficient cost-effective, controlled, measured, and safe manner.


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Well Completions Conveyance, or transport, into and out of

Data acquisition Flow control and flow management

Communication and data transmission

SAFETY !

Completion installations can be:

temporary for well testing or

permanent for long-term production

life of a well, field, or reservoir


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Oilwell PerforatingPerforate

Wireline conveyed

TCPTubing Conveyedperforating


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Explosive Shaped-Charges

TCP Tubing-Conveyed Perforating


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Shaped Charge Animation (to 30 microseconds)


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Shaped Charge Animation (to 140 microseconds)


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Cased, Cemented and Perforated

The most common type of well completion

Selective production, stimulation and zonal isolation

Pressure control and safety

Multiple individual zones completed in a single wellbore


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PERF Lab Testing CapabilitiesPV-93 Test (2008) PV-94 Test#001 (2009)


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Well Classifications Wellbore and reservoir interaction

Steel cased, cemented and perforated

Openhole, or barefoot

Standalone screens, gravel and frac packs

Vertical, high-angle, and horizontal

Flowing method Natural flow

Artificial lift

Number of completed zones Single

Multiple


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Completions tubulars and equipment-plumbing



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Well


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Wellbore Architecture

WellCompletions


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Packers ANCHOR production tubing inside cemented casing SEAL to isolate the tubing-casing annulus and act as a

pressure barrier between formation, or reservoir pressure,

and the upper wellbore annulus or between multiple zones

PROTECT upper steel casing from erosion, corrosion:

H2O, H

2S, CO

2

Available in different types:

Permanent

Retrievable

Single, dual or triple string, multi-ported, sealbore


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X-Series Retrievable Production Packers

XHP

XMP


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Openhole Sandface Completions

Advantages

Maximizes area open to flow

Decreases pressure drop, or pressure drawdown

Minimizes formation damage from cementing,

perforating and completion fluids and operations

Disadvantages

Lack of pressure containment and selective control

Possible borehole instability and risk of hole collapse


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Mechanical Screens and ICD Inflow Control Devices



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Swellable Openhole Packers


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WellC l


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Sand-Control Completions and Pumping

Completions

Z l


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Zones to be completed

When more than one zone will be

producing at the same time

When zones are prepared to produce

at different periods of time without

need of major intervention (workover)

May need: dual, triple strings, sliding

sleeves, permanent control valves

Remedial workovers difficult whenmore than one tubing is used

Sequential Production with a


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Packer and Single Tubing String

Zone 2: 1000 psi

Zone 1: 1500 psi



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Zone 2: 1000 psi

Zone 1: 1500 psi

Commingled Production with a


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Commingled Production with a


Zone 2: 1000 psi

Zone 1: 1500 psi

Packers and Sliding Sleeves or Valves


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Packers and Sliding Sleeves or Valves

and Single Tubing String

Zone 2: 1000 psi

Zone 1: 1500 psi

Sliding Slee es


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Sliding Sleeves

Provide communication tubing-annulus

Used to circulate wells

To produce selectively different zones

Reduced internal diameters


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Flow Management: Two Production Zones

Dual producing zones, formations or reservoirs

Drilling, well-construction and well-completions savings

l A l


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Flow Management: Accelerated Production

and Optimal Reserve Recovery

Intelligent Completions benefits and history


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0.7

0.6

0.5

0.4

0.3

0.2

0.1

100 200 300 400 500 600 700

Days

Intelligent Completions benefits and history

Cumulative Oil Production and Flow Strategy Comparison

Sequentia

l

Uncontrolled

Commingled

Controlled

Commingled

Flow Management


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Oseberg

B-38 is the 2nd well

drilled exclusively in

the Ness formation

Ness target contribution

70,000 B/D350,000 B/D

(field)

7 in. QUANTUM

isolation

packers

Completion string

Subsurface Safety

Valve

Flow control valve

1 per zone

9-5/8 in. QUANTUM

production packer

Flow Management

Permanent Downhole Flow-Control Valves

Phase 1 Prove the ValueSPE 71677 & 107117


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SchlumbergerConfidential

-2700

-2600

-2500

Depth

m TVD MSL

Middle Tarbert coal

UN 1

30/9-B-39 T3*

T3T4

-2700

-2600

4000 5000 6000

4000 5000 6000

@ 2701.5m TVD MSL

OWC UN1/LN35 GS

0 0 .2 0 .4 0 .6 0 .8 1 .0

Ki lometer

LN35

T1

T2UN2 coa l

Top LN35 coal

LN1 coal

DUNLIN GP.

LN 2

LN35

GAMMA MAIN

GAMMA SOUTH

Intra Heather sand,part ly cemented

T5

?

B -38 B , p lan

B38AT2, plan*

B -38 AT2, bore t*

Ran./Et ive Fm

B-38 A , bore t *

Oseberg Fm

OWC GM UN1

OWC GMLN35

Ness Fm.

SHETLAND GP.

Draupne Fm.

Heather Fm.

Tarbert Fm .

-2500

TD

B38AT2

TD

B38A

??

L e g e n d :

*the wells are projected onto the cross-section

TARGETS: mT V D MS L mT V D R K B mMD

T1 2610.0 2668.0 5616,5

T 2 2617.5 2675.5 5836,8

T 3 2663.8 2721.8 6180,0T 4 2670.4 2728.4 6559,7

T 5 2655.9 2713.9 6781,8

Vertical displacement from O FC

Zone 1Zone 1

Zone 3Zone 3

Zone 2Zone 2

Production was declining

Require to produce

untapped reserves

Not continuous

reservoirs

Required long reach and

highly deviated Required to control gas

coning and water

breakthrough.

Case study : Multiple zones selective wells - Norway (2000 2001)SPE 71677 & 107117

Phase 1 Prove the ValueSPE 71677 & 107117


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SchlumbergerConfidential

Long reach & highly deviated Monobore wells

9-5/8 Casing with 7 liner though reservoir

9-5/8 Production and 7 Isolation packers

TRFC-HN remotely operated flow control valves

Hydraulic control lines to surface

Intervention capability

Pressure & temperature monitoring

9 5/8 Casing

3 Flow Control

Valve3 Flow Control

Valves7 Liner

Production

packer

Case study : Multiple zones selective wells - Norway (2000 2001)SPE 71677 & 107117


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Expansion joints


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Expansion joints

Allow thermal expansion and

contraction of tubing string

between fixed points

Allows tubing disconnection and

reconnection of upper completion

with sealing

Composed of a assembly with

elastomer seal and wiper rings,

depending on downhole conditions


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Pump-Out Plugs Base component of production tubingstring, many times for hydraulically

set packers

Guide re-entry of intervention tools

into tubing once seat and ball are

expended

Allow for easy liner top entry in high-

angle wells


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Reentry Guide


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Reentry Guide

Component in the production tubing

Guide reentry of intervention tools

back into tubing

Allow for easy liner top entry in

high-angle wells


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Landing Profile Nipples and Locks


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Landing Profile Nipples and Locks

Allow landing and locking of multiple

accessories in the tubing string for:

Flow control

Plugging devices

Many different profiles

Basic types: No-go and selective


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Completion Accessories-Chemical Injection


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Completion Accessories Chemical Injection

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SchlumbergerPrivate

DCIN - Features

New generation of chemical injection mandrels

One piece body (no welds)

Limited leak paths Internal check system

Proven supplier of check valves

Checks can be tested to full working pressure installed in to themandrel

Optional profile


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Control-Line Clamps and Protectors


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Purpose

Protect control line

Support control line

Features

Location on tubing couplings

Lightly grip control line

Multiple line capability

Upset for Large O.D. assemblies.

Various types and sizes of lines.

Flow Control: FIV Formation Isolation Valve


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Bi-directional ball valve to provide a

Safety Barrier during the well completion

program

Rig time savings via remote actuation

Improve and enhance reliability and

operability

Next Generation FIV

n-Trigger

New MechanicalSection

New Ball Section

Contingency Opening

Tool

API Debris Testing

Actuation Module

Mechanical / Ball Module

n-Trigger

S-Trigger

MFIV-II


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Mechanical Ball

Shifting tool interface

Holds valve open/close

Barrier

- Rotates

open/close

Same mechanical and ball sections as FIVSame mechanical and ball sections as FIV--IIII

Same shifting tools as FIVSame shifting tools as FIV--IIII Extensions 3ft, 6ft or 9ft, same as for FIVExtensions 3ft, 6ft or 9ft, same as for FIV--IIII


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Flow Control


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Surface-Controlled Subsurface Safety ValvesPrimary purpose

Emergency well-control device

Prevent: (Piper Alpha)personnel, environmental,

equipment, and reserve losses

Secondary purpose Downhole flow control

allow for wellhead maintenance

serve as a secondary barrier

SafetyValveConstructionSafetyValveConstruction


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Hydraulic PistonHydraulic Piston Power SpringPower Spring FlapperFlapper

Power SourcePower Source[Opening Force][Opening Force]

Closure MechanismClosure MechanismPower SourcePower Source[Closing Force][Closing Force]

Surface Controlled Subsurface Safety Valve (SCSSV)Surface Controlled Subsurface Safety Valve (SCSSV)

StandardSpringStandardSpringTypeDesignTypeDesign

FlapperClosureFlapperClosure


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FlowtubeFlowtube

pp

PowerSpringPowerSpring

Hydraulic

PistonHydraulic

PistonPiston

BorePiston

Bore

Production

Production

TubingPressureTubingPressure

FlowTubeandFlapperClosureMechanismsFlowTubeandFlapperClosureMechanisms


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Intelligent CompletionsMonitor and

Manage


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Reservoir Monitoring Control.Real time production optimization

Reservoir EnergyPressure


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Water drive Gas drive Solution-gas drive

Artificial Lift Technologies


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77 Initials5/15/2012 Electrical submersible pumps

Gas lift valves

Natural Flow or Artificial Lift


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Natural flow: Enough reservoir

pressure to bring fluids to surface

Artificial lift: Add energy to the fluid

Electrically driven, mechanical

positive-displacement beam pumps

ESP electric submersible pumps

Gas lift (re-injecting produced gas)

Side-Pocket Mandrels


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SchlumbergerPublic


Annulus-tubing communication

device in an artificial-lift completion

A valve is located to allow gas toenter the tubing to lift the oil

More than one are installed in a well

INJECTION GAS

PRODUCED FLUID

PRESSURE (PSI)1000 20000

CONSTANT FLOW GAS LIFT WELL


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INJECTION GAS

DEPT

H(

FT

TVD)

1000

2000

3000

4000

5000

6000

7000

0

OPERATING GAS LIFT

VALVE

CASING PRESSURE WHEN

WELL IS BEING GAS LIFTED

FBHP

SIBHP

FLOWINGTUBINGPRES

SUREGRADIENT

Gas lift

valves


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Stimulate


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Stimulation, Pumping Services

Acidizing

Fracturing


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P&A Plug and AbandonAbandonment


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Four Life Stages of Reservoir Development


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Stage 2

Delineation

Determinethereservoirextent

Determinereservoirproperties

Determine

reservoirmodel

Furtherreduce risk

Stage 1

Exploration

Starting to reducethe risk

Choose the rightpoint

Locate potentialreservoir

Stage 3

Development

Achieving fullproduction

Refine reservoir model

Reservoir monitoring

Continue reducing therisk

Stage 4

Late Life

Water production

Depleted pressure

Intervention

Stimulation

Flow assistance


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Focus on Technology and the Reservoir Life Cycle


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Exploration Appraisal Development Production

Reservoir Optimization

Traditional Development

CashFlow

+

0_ Time

Documents

PESA 2012 Spring Oil 101 Teel