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WELL COMPLETION PLANNING
ContentsContents Page Page
Introduction .................................................. 1
Completion Planning Process ...................... 1
Reservoir Parameters .................................. 5
Produced Fluid Characteristics .................... 6
Wellbore Construction .................................. 7
Completion Assembly and Installation ......... 8
Initiating Production ..................................... 9
Stimulation ................................................... 10
Well Service and Maintenance .................... 11
Logistic, Location and Environment ............. 12
Client Stock, Convention or Preference ....... 12
Regulatory Requirements ............................ 12
Revenue and Cost ....................................... 13
Economic ..................................................... 13
Company Objectives .................................... 13
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This manual section is a confidential document which must not be copied in whole or in part or
discussed with anyone outside the Schlumberger organisation.
Although many wells (and fields) may be similar, the
success of each completion system should be closely
based on the individual requirements of each well. There-
fore, generic design or installation procedures should be
carefully reviewed and amended as required.
The flow chart shown in Fig. 1 (principal phases summa-
rized in Fig. 3) reflects the general sequence in which
completion design and installation factors are typically
studied. The "hook point" is provided as a reference point
to which specific procedures, detailed later in this manual,
will connect.
The economic impact of designing and installing non-
optimized completions can be significant. Consequently
the importance of completing a thorough design and
engineering process must be stressed. Delaying the com-
mencement of the wells payout period is one example of
how non-optimized completion design, or performance,
can effect the achievement of objectives. However, while
reducing installation cost and expediting start-up are
important objectives, further reaching objectives, such as
long-term profitability must not be ignored (Fig. 2). As is
illustrated, a more complex and costly completion may
provide a greater return over a longer period. In addition,
the consequences of inappropriate design can have a
significant effect, e.g., requiring premature installation of
velocity string or artificial lift.
Introduction
Planning a completion, from concept through to installa-
tion, is a complex process comprising several distinct
phases. Many factors must be considered, although in
most cases, a high proportion can be quickly resolved or
disregarded. Regardless of the complexity of the comple-
tion design, the basic requirements of any completion
must be kept in mind throughout this process, i.e., a
completion system must provide a means of oil or gas
production (or injection) which is safe, efficient and eco-
nomic.
Ultimately, it is the predicted technical efficiency of a
completion system, viewed alongside the company objec-
tives which will determine the configuration and compo-
nents to be used.
Completion Planning Process
This section outlines the principal factors which should be
considered when planning an oil or gas well completion.
In addition to the technical influences on completion
design and selection, economic and nontechnical issues
are also detailed. The relevance of these issues, in
common with technical details, is dependent on the cir-
cumstances pertaining to the specific well, completion or
field being studied.
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Component
Installation
Onsite
Preparation
Pre-installation Well Service Work
• Perform required treatments
• Drift run (minimum/essential)
Surface/Production Equipment
• Preparation and checking
Budgetary Analyses
• Actual vs. planned
Safety and Environmental Factors
• Precaution and contingency planning
Completion
Evaluation
Monitor Production Parameters
• Actual vs. Forecast
Evaluate Production Response
• Actual vs. Forecast
 
Final Budgetary Analyses
• Actual vs. Forecast
Establish the objectives
and design basis
Essential Basics
• Safe
• Efficient
• Economic
Logistic and Location
• Surface and field facilities
• Location and wellsite constraints
Corporate Policy
• Medium and long-term objectives
• Contractual requirements/obligations
Determine the optimum
well performance
Reservoir Parameters
• Boundaries
• Structure
• Production mechanism
• Dimensions
• Rock Properties
• Rock composition
Reservoir Fluid Characteristics
• Physical properties
• Chemical properties
Modelling and analyses
• NODAL analyses
• Perforation analyses
• Others
Budgetary Considerations
• Investment incentives
• Revenue(s)
• Taxation
Legislative and Regulatory
• Safety and environmental factors
Production Constraints
• Downstream capacity
• Flexibility of production
• Production profile
• Recoverability
Establish conceptual
completion designs
Wellbore Construction
• Drilling phase considerations
• Evaluation phase considerations
• Pre-completion stimulation
Workover Philosophy
• Routine well service requirements
• Workover activities
Material Selection
• Forces on completion components
• Wellbore environment constraints
Review Alternative Completions
• Compile list of alternatives/options
• Confirm preferred completion type
Budgetary Analyses
• Review outline completion costs
Starting 
"philosophy
statement"
Finishing
"philosophy
statement"
Cleanliness standards
• Completion components
• Completion fluids
Dimensional checks
• Components
• String
* Space-out
Equipment handling
• Complex components
• Thread make-up
Proceedures
• Assembly installation
• Pressure testing
• Space-out)
Budgetary Analyses
• Actual vs. planned
Safety and Environmental Factors
• Precaution and contingency planning
Rig time and well downtime
• Efficient completion
Fig. 1a. Phases of well completion planning and installation.
Flowchart Key
Technical requirements
considerations and issues
Non-technical and
commercial issues
Procure components
and services
Issue Bid Request or Enquiry
• Technical specifications
• Scope of work
Bid Evaluation
• Design proposal
• Hardware selection
• Technical support
• Associated services
• Innovative packaging (?)
Recommendation
• Technical merit
• Integrated services
Vendors Meeting
• Confirm specifications/selection
• Review/revise the scope of work
Quality Assurance/Control
• Inspection and verification
• Controls and checks
Issue Bid Request or Enquiry
• Contractual non-technical content
Bid Evaluation (Commercial)
• Price/cost
• Incentives/penalties
• Innovative packaging
Recommendation
• Administrative
Vendors Meeting
• Establish contacts/form work group
• Issue formal order
Quality Assurance/Control
• Non-technical controls and checks
Planning of associated
service activities
Existing Completion Tubulars
• Partial or complete removal
• Preparation for concentric completion
Select Treatments
• Determined by specific conditions
Prepare Procedures
• Determined by application/conditions
Budgetary Analyses
• Return on Investment
Offsite
Preparation
Quality Assurance & Control
• Component Inspection
• Conformance to specified standards
Prepare Installation Procedure(s)
• Assembly
• Installation
• Testing
• Contingency Plans
Offsite Assembly
• Check and test key components
Confirm Project Timing
• Lead times
• Operational windows
Quality Assurance & Control
• Delivery time compliance
• Quality documentation package/file
Review strategyfor
well and field life
Production Strategy (Well/Field)
• Well performance
• Field performance
• Completion requirements
Local (Management) or Field Policy
• Medium- to long-term objectives
• Contractual requirements
Implications of Multiple Well Project 
• Effect on cost
• Operational conflict
• Production conflict
Develop detailed
completion design
Specific Procedures
• Velocity string
• Gas lift installation
• ESP installation
Completion Configuration
• Wellbore tubulars 
• Wellbore and perforations
• Near wellbore matrix
• Hydraulic fracturing
Production Initiation
• Inducing flow
• Clean-up program
Completion Fluids
• Required density
• Chemical composition
• Additives
• Compatibility
• Disposal
Well Service and Workover
• Completion function(s)
• Light service units (wireline & CT)
• Heavy service (snubbing and w/o rig)
Surface Support Facilities
• Utilities
• Downstream facilities
Modelling and Analyses
• NODAL analyses
• Others
Perforating
• SPAN* analyses
• Charge and gun selection
Client Convention and Preference
• Existing stock
• Contractual obligations
• Corporate or local policies
• Familiarity and acceptance
Detailed Budget
• Capital cost
• Installation cost
• Operating cost
• Maintenance cost (routine)
• Major servicing cost (periodic)
Establish Project Time Scale
• Component availability
• Lead time(s)
• Operational windows
• Simultaneous operations (offshore)
 
HO
OK
PO
IN
T
FO
R SPECIFIC PROC EDURES
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ESTABLISH THE OBJECTIVES
AND DESIGN BASIS
DETERMINE THE OPTIMUM
WELL PERFORMANCE
ESTABLISH CONCEPTUAL
COMPLETION DESIGNS
REVIEW STRATEGY FOR LIFE
OF THE WELL AND FIELD
DEVELOP DETAILED
COMPLETION DESIGN
PROCUREMENT OF
COMPONENTS AND SERVICES
PLANNING OF ASSOCIATED
WELL SERVICE ACTIVITIES
OFFSITE PREPARATION
ONSITE PREPARATION
INSTALLATION
EVALUATION
Fig. 2. Consequences of a non-optimized completion system.
Fig. 3. Principal phases of well completion.
Drilling, DST, completion
logging and stimulation
Optimized
productionNon-optimized
production
 Time (Life of the well)
Ex
pe
nd
itu
re
/R
ev
en
ue
+$
-$
Enhanced
Recovery
Stimulation
Thru-tubing 
W/O
Profile
Modification
P & A
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Reservoir Boundaries
Structural traps
Staratographic traps
Unconformities
Permeability contrasts
Reservoir Structure
Continuity
Permeability barriers
Isotropy
RESERVOIR PARAMETERS
Production Mechanism
Water drive
Solution gas
Gas cap
Combination
Injection
Artificial
Physical Parameters
Size
Shape
Height
Pressure
Temperature
Rock Properties
Porosity
Permeability
Pore size distribution
Fluid saturation
Grain size and shape
Wettability
Rock Composition
Composition
Consolidation
Contamination
Clay content
Moveable fines
Cementaceous material
Scale forming materials
Fig. 4. Reservoir parameters.
Reservoir Parameters
The type of data outlined in this category are obtained by
formation and reservoir evaluation programs such as
coring, testing and logging. Typically, such data will be
integrated by reservoir engineers to compose a reservoir
model.
The reservoir structure, continuity and production drive
mechanism are fundamental to the production process of
any well. Frequently, assumptions are made of these
factors which later prove to be significant constraints on
the performance of the completion system selected.
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Physical Properties
Oil density
Gas gravity
Viscosity
Pour point
Gas-oil ratio
Water-oil ratio
Chemical Properties
Composition
Wax content
Asphaltenes
Corrosive agents
Toxic components
Scale
PRODUCED FLUID CHARACTERISTICS
Fig. 5. Produced fluid characteristics.
Physical characteristics of the reservoir are generally
more easily measured or assessed. Pressure and tem-
perature are the two parameters most frequently used in
describing reservoir and downhole conditions. The effects
of temperature and pressure on many other factors can be
significant. For example, corrosion rates, selection of
elastomer or seal materials and the properties of pro-
duced fluids are all effected by changing temperature and
pressure.
When investigating the reservoir rock characteristics, the
principal concern is assessing formation behavior and
reaction. This includes behavior and reaction to the drill-
ing, production or stimulation treatments which may be
required to fully exploit the potential of the reservoir.
The formation structure and stability should be closely
investigated to determine any requirement for stimulation
or sand control treatment as part of the completion pro-
cess.
The reservoir characteristics effecting completion con-
figuration or component selection are best summarized
by reviewing the reservoir structure, continuity, drive
mechanism and physical characteristics. These should
be reviewed alongside the physical and chemical proper-
ties of the formation (Fig. 4).
Produced Fluid Characteristics
Two conditions, relating to the chemical properties of the
produced fluid most effect the physical qualities of comple-
tion components and materials. These are chemical depo-
sition (scale, asphaltenes etc.) and chemical corrosion
(weight loss and material degradation). Both conditions
still account for significant losses in production and deg-
radation of equipment in many fields.
The ability of the reservoir fluid to flow through the comple-
tion tubulars and equipment, including the wellhead and
surface production facilities, must be assessed. For ex-
ample, as the temperature and pressure of the fluid
changes, the viscosity may rise or wax may be deposited.
Both conditions may place unacceptable back-pressure,
thereby dramatically reducing the efficiency of the comple-
tion system.
While the downhole conditions contributing to these fac-
tors may occur over the lifetime of the well, consideration
must be made at the time the completion components are
being selected. Cost effective completion designs gener-
ally utilize the minimum acceptable components of an
appropriate material. In many cases, reservoir and
downhole conditions will change during the period of
production. The resulting possibility of rendering the
completion design or material unsuitable should be con-
sidered during the selection process.
The production fluid characteristics effecting completion
configuration or component selection are best summa-
rized by reviewing the physical and chemical properties of
the fluid (Fig. 5).
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Wellbore Construction
Wellbore construction factors can be categorized in the
following phases.
• Drilling – The processes required to efficiently drill to,
and through the reservoir.
• Coring and testing – The acquisition of wellbore survey
and reservoir test data used to identify completion
design constraints.
• Pre-completion stimulation or treatment – Final prepa-
ration of the wellbore through the zone of interest for the
completion installation phase.
It is an obvious requirement that the drilling program must
be designed and completed within the scope and limits
determinedby the completion design criteria.
Most obvious are the dimensional requirements deter-
mined by the selected completion tubulars and compo-
nents. For example, if a multiple string completion is to be
selected, an adequate size of production casing (and
consequently hole size) must be installed. Similarly, the
wellbore deviation or profile can have a significant impact.
Drilling and associated operations, e.g., cementing, per-
formed in the pay zone must be completed with extra
vigilance. It is becoming increasingly accepted that the
prevention of formation damage is easier, and much more
cost effective, than the cure. Fluids used to drill, cement or
service the pay zone should be closely scrutinized and
selected to minimize the likelihood of formation damage.
Similarly, the acquisition of accurate data relating to the
pay zone is important. The basis of several major deci-
sions concerning the technical feasibility and economic
viability of possible completion systems will rest on the
data obtained at this time.
A pre-completion stimulation treatment is frequently con-
ducted. This is often part of the evaluation process in a
test-treat-test program in which the response of the reser-
voir formation to a stimulation treatment can be assessed.
The wellbore characteristics affecting completion con-
figuration or component selection are best summarized
by reviewing the drilling, evaluation and pre-completion
activities (Fig. 6).
Fig. 6. Wellbore construction
Drilling
Hole size
Depth
Deviation
Well path
Formation damage
Pre-completion
Casing schedules
Primary cementing
Pre-completion stimulation
WELLBORE CONSTRUCTION
Evaluation
Logging
Coring
Testing
Fluid sampling
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Completion Assembly and Installation
This stages marks the beginning of what is commonly
perceived as the “completion program”. It is the intent of
this manual to enlighten readers as to the true and
necessary extent of the “completion program”. As has
been demonstrated, considerable preparation, evalua-
tion and design work has been completed before the
completion tubulars and components are selected.
With all design data gathered and verified, the completion
component selection, assembly and installation process
commences. This phase carries obvious importance since
the overall efficiency of the completion system depends
on proper selection and installation of components.
A “visionary” approach is necessary since the influence of
all factors must be considered at this stage, i.e., factors
resulting from previous operations or events, plus an
allowance, or contingency, for factors which are likely or
liable to effect the completion system performance in the
future.
The correct assembly and installation of components in
the wellbore is as critical as the selection process by which
they are chosen.
This is typically a time at which many people and re-
sources are brought together to perform the operation.
Consequently, the demands brought by high, and mount-
ing daily charges imposes a sense of urgency which
requires the operation be completed without delay.
To ensure the operation proceeds as planned, it is essen-
tial that detailed procedures are prepared for each stage
of the completion assembly and installation. The com-
plexity and detail of the procedure is largely dependent on
the complexity of the completion.
In general, completion components are broadly catego-
rized as follows.
• Primary completion components
• Ancillary completion components
Primary completion components are considered essen-
tial for the completion to function safely as designed. Such
components include the wellhead, tubing string, safety
valves and packers. In special applications, e.g., artificial
lift, the components necessary to enable the completion
system to function as designed will normally be consid-
ered primary components.
Fig. 7. Completion assembly and installation.
Primary Components
Wellhead
Xmas tree
Tubing
Packer
Safety valve
Ancillary Components
Circulating devices
Nipples
Flow couplings
Injection mandrels
Tubing seal assembly
COMPLETION ASSEMBLY AND INSTALLATION
Completion Fluids
Completion fluid
Packer fluid
Perforating fluid
Kick-off fluid
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Ancillary completion components enable a higher level of
control or flexibility for the completion system. For ex-
ample, the installation of nipples and flow control devices
can allow improved control.
Several types of device, with varying degrees of impor-
tance, can be installed to permit greater flexibility of the
completion. While this is generally viewed as beneficial, a
complex completion will often be more vulnerable to
problems or failure, e.g., due to leakage.
The desire for flexibility in a completion system stems from
the changing conditions over the lifetime of a well, field or
reservoir. For example, as the reservoir pressure de-
pletes, gas injection via a side-pocket mandrel may be
necessary to maintain optimized production levels.
A significant fluid sales and service industry has evolved
around the provision of completion fluids. Completion
fluids often require special mixing and handling proce-
dures, since (i) the level quality control exercised on
density and cleanliness is high, and (ii) completion fluids
are often formulated with dangerous brines and inhibitors.
The ultimate selection of completion components and
fluids should generally be made to provide a balance
between flexibility and simplicity.
The completion component selection factors are best
summarized by reviewing the primary and ancillary com-
ponents, and installation procedures (Fig. 7).
Initiating Production
The three stages associated with this phase of the comple-
tion process include (Fig. 8 and 9).
• Kick-off
• Clean up
• Stimulation
The process of initiating flow and establishing communi-
cation between the reservoir and the wellbore is obviously
closely associated with perforating operations. If the well
is to be perforated overbalanced, then the flow initiation
and clean up program may be dealt with in separate
procedures. However, if the well is perforated in an
underbalanced condition, the flow initiation and clean up
procedures must commence immediately upon perfora-
tion.
The benefits of underbalanced perforating are well docu-
mented and the procedure is now conducted on a routine
basis. While the reservoir/wellbore pressure differential
may be sufficient to provide an underbalance at time of
perforation, the reservoir pressure may be insufficient to
cause the well to flow after the pressure has equalized.
Adequate reservoir pressure must exist to displace the
fluids from within the production tubing if the well is to flow
unaided. Should the reservoir pressure be insufficient to
achieve this, measures must be taken to lighten the fluid
Clean-up Program
Initial flowrate and
rate of increase
Evaluation program
Test–treat–test
PRODUCTION INITIATION
Inducing Flow
Gas lift
Nitrogen kick-off
Light-fluid circulation
Using completion components
or coiled tubing
Fig. 8. Production initiation.
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Near Wellbore and Reservoir Matrix
Matrix acidizing
Hydraulic fracturing
Non-acid treatments
STIMULATION
Wellbore and Perforations
Wellbore clean-up
Perforating acid
Perforationwash
Fig. 9. Stimulation
column - typically by gas lifting or circulating less dense
fluid. The preparations for these eventualities are part of
the completion design process.
The flowrates and pressures used to exercise control
during the clean up period are intended to maximize the
return of drilling or completion fluids and debris. This
controlled backflush of perforating debris or filtrate also
enables surface production facilities to reach stable con-
ditions gradually.
In some completion designs, an initial stimulation treat-
ment may be conducted at this stage. An acid wash or
soak placed over the perforations has proved effective in
some conditions. However, as underbalanced perforating
becomes more popular, the need and opportunity for this
type of treatment has diminished.
Stimulation
There are four general categories of stimulation treatment
which may be considered necessary during the process of
completing a well.
• Wellbore cleanup
• Perforation washing or opening
• Matrix treatment of the near wellbore area
• Hydraulic fracturing
Wellbore clean up will not normally be required with new
completions. However, in wells which are to be reperforated
or in which a new pay zone is to be opened, a well bore
clean up treatment may be appropriate. There are a range
of perforation treatments which may be associated with
new or recompletion operations.
Perforating acids and treatment fluids are designed to be
placed across the interval to be perforated before the guns
are fired. Used in overbalanced perforating applications,
the perforating acid or fluid reduces the damage resulting
from the perforating operation. Perforation washing is an
attempt to ensure that as many perforations as possible
are contributing to the flow from the reservoir. Rock
compaction, mud and cement filtrate and perforation
debris have been identified as types of damage which will
limit the flow capacity of a perforation, and therefore
completion efficiency.
If the objective of the treatment is to remove damage in or
around the perforation, simply soaking acid across the
interval is unlikely to be adequate. The treatment fluid
must penetrate and flow through the perforation to be
effective. In which case all the precautions associated
with a matrix treatment must be exercised to avoid caus-
ing further damage by inappropriate fluid selection.
Matrix treatment of the near wellbore area may be de-
signed to remove or by-pass the damage. Hydraulic
fracturing treatments provide a high conductivity channel
through any damaged area and extending into the reser-
voir.
Both matrix and hydraulic fracturing treatments require a
detailed design process which is documented in the
relevant Stimulation Manual.
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Well Service and Maintenance Requirements
The term “well servicing” is used (and misused) to de-
scribe a wide range of activities including :
• Routine monitoring
• Wellhead and flowline servicing
• Minor workovers (thru-tubing)
• Major workovers (tubing pulled)
• Emergency response and containment
Well service or maintenance preferences and require-
ments must be considered during the completion design
process. With more complex completion systems, the
availability and response of service and support systems
must also be considered (Fig.10).
Wellbore geometry and completion dimensions deter-
mine the limitations of conventional slickline, wireline,
coiled tubing or snubbing services in any application.
WELL SERVICE AND WORKOVER
Fig. 10. Well service and workover.
Completion System Function
Well testing and
routine monitoring
Emergency kill and containment
Heavy Workover Units
Drilling rig
Workover rig
Combined CT and
snubbing unit
Light Service Units
Slickline
Electric wireline
Coiled tubing
Snubbing
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Location
Access to well
Weather/climatic conditions
Environmental constraints
Proximity of neighboring interests
LOGISTIC AND LOCATION CRITERIA
Surface Facilities
Separator capacity
Export capability
Operational flexibility
Disposal facility
Logistic, Location and Environmental Constraints
Restraints imposed by logistic or location driven criteria
often compromise the basic “cost effective” requirement
of a completion system. Special safety and contingency
precautions or facilities are associated with certain loca-
tions, e.g., offshore and subsea.
A summary of the logistic, location and environmental
constraints affecting completion design and configuration
include well location, environmental conditions, weather
conditions and adjacent land use (Fig 11).
Client Stock, Convention or Preference
The completion configuration and design must ultimately
meet all requirements of the client. In many cases, these
requirements may not be directly related to the reservoir,
well or location (technical factors). An awareness of these
factors, and their interaction with other completion design
factors can help save time and effort in an expensive
design process.
The following factors are common criteria which must be
considered.
• Existing material stocks or contractual obligation
• Compatibility with existing downhole or wellhead compo-
nents
Fig. 11 Logistic and location criteria
• Client familiarity and acceptance
• Reliability and consequences of failure
Regulatory Requirements
There are several regulatory and safety requirements
applicable to well completion operations. These must
generally be fully satisfied during both the design and
execution phases of the completion process.
• Provision for well-pressure and fluid barriers
• Safety and operational standards
• Specifications, guidelines and recommendations
• Disposal requirements
• Emergency and contingency provisions
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Revenue and Costs
When completing an economic viability study, or compari-
son, the costs associated with each of the following
categories should normally be investigated.
• Production revenue
• Capital cost (including completion component and instal-
lation cost)
• Operating cost (including utilities and routine mainte-
nance or servicing cost, also workover, replacement or
removal cost.
The specific conditions, determined by the completion
being studied, can be applied to enable a complete and
representative cost analysis. In most cases, the order of
importance is as shown, with the revenue stream being
most critical.
Installation costs are significant if special completion
requirements impact the overall drilling or completion
time. The actual cost of completion components is often
relatively insignificant when viewed alongside the value of
incremental production from improved potential or in-
creased uptime.
Economic
The economic factors shown below are beyond the scope
of technical preparation for well completion design. How-
ever, they undoubtedly influence the industry. Conse-
quently a rudimentary understanding of the factors, and
their interaction with factors previously discussed is ben-
eficial.
• Market forces (including seasonal fluctuations and swing
production)
• Taxation (including tax liability or breaks)
• Investment availability
Company Objectives
A measure of success can only be effectively made if there
are clearly stated objectives. Such objectives may be
macroscopic, but nonetheless willinfluence the specific
objectives as applied to an individual well or completion.
In addition, the wider company objectives may allow
clarification of other selection factors, e.g., where two or
more options offer similar or equal benefit, and no clear
selection can be made on a technical basis.
• Desired payback period
• Cash flow
• Recoverable reserves
	Introduction to Completion
	Well Completion Planning
	Copletion Design and Engineering
	Types of Completion
	Completion Components
	Coiled Tubing Completion Spoolable Installation Sequence
	Terminology and Formlae