Upload
a-a-ichsan-cr
View
245
Download
3
Embed Size (px)
Citation preview
8/10/2019 artificial lift dude
1/145
Production Engineering
Objectives
8/10/2019 artificial lift dude
2/145
Production Engineering Objectives
1. Design and set the parameters for operationof a well or a system of wells in a safe andoptimized way during the whole well life.
associated with the maximization of the profit orthe production, subject to some constraints.
Maximization o f the ult im ate pro f i t from an oi l
f ie ld is achieved by designing a safe cost
ef fect ive system that balances rate of
produ ct ion against costs of prod uct ion
8/10/2019 artificial lift dude
3/145
Production Engineering
Objectives
New
Production
Wells
Maximize
ProfitOptimization
Design
8/10/2019 artificial lift dude
4/145
Production Engineering Objectives
2. Follow up the performance of wells that arealready in production in order to determine if
the system is behaving as expected. Make the appropriate recommendations in order
to safely bring the system to a new optimizedstate.
8/10/2019 artificial lift dude
5/145
Production
Wells
Performance
Deviations
Problem Detection and
Corrective Actions
Production Engineering
Objectives
Maximize
Profit
Monitor Performance
Analyze
Design
Optimization
8/10/2019 artificial lift dude
6/145
Production Engineering
ObjectivesIn order to accompl ish those
object ives the product ion engineer
mus t ful ly understand the nature of anoi l wel l and must master the
interact ion between al l other sub-
discipl ines
He must also ful ly understand thepo tential and l im itat ions o f art if ic ial l i f t
techniques
8/10/2019 artificial lift dude
7/145
The Producer Oil Well
8/10/2019 artificial lift dude
8/145
Oil Well
1. A production oil well is drilled to provide a
connection between the reservoir and the surface
facilities.
2. Its main purpose is to allow the fluids stored in the
reservoir to be produced from this original location
up to a point at the surface where they can be
separated, treated, processed, transported and
finally sold.
8/10/2019 artificial lift dude
9/145
3. This concept of oil well includes not only the so
called drilled well but also all other components that
are important for production, such as the reservoir,
perforations, flow lines, artificial lift equipment,
boosting equipment, chokes and any other
equipment that might interact with the fluids when
flowing from the reservoir up to the final separator.
Oil Well
8/10/2019 artificial lift dude
10/145
Oil Well Examples
8/10/2019 artificial lift dude
11/145
Fluid Production
Path of produced fluids
Reservoir
Perforations, gravel pack, etc.
Downhole equipment, casing, tubing.
Downhole artificial lift equipment
Mixed with lift gas or lift fluid
Wellhead, production chokes
Flow lines Mixed with production from other wells (manifolds)
Separator
Tank or Compressor
8/10/2019 artificial lift dude
12/145
Path of produced fluids
8/10/2019 artificial lift dude
13/145
Flow in Production System
Porous Media
Perforations
Production String
Downhole Equipment
Restrictions
Surface Flowline
Surface Equipment
RestrictionsProduction
Separator
Multiphase Pumpin System
Artificial Lifted Well
Long Production Flowlines
Compressed
Fluids in the
Reservoir
8/10/2019 artificial lift dude
14/145
Fluid Production
In each flow segment, the fluids interactwith the production components
Pressure and temperature changes.
Mixing with other fluids
Fluid properties constantly changing
8/10/2019 artificial lift dude
15/145
The Driving Force forProduction
8/10/2019 artificial lift dude
16/145
Driving Force
The driving force that moves fluids along the
reservoir and production system is the energy
stored in the form of compressed fluids in the
reservoir.
As the fluids move along the system components,pressure drop occurs. The pressure in the
direction of flow continuously decreases from thereservoir pressure to the final downstreampressure value at the separator.
8/10/2019 artificial lift dude
17/145
Driving Force
8/10/2019 artificial lift dude
18/145
Reservoir
Pressure
Individual
Components
Pressure,
Temperature and
Composition
Changes
Separation
Pressure( )cP q
rP
sP
Driving Force
8/10/2019 artificial lift dude
19/145
Natural Equilibrium Flowrate
8/10/2019 artificial lift dude
20/145
Natural Equilibrium Flowrate
The natural force that moves fluids in the system isthe reservoir pressure.
The reservoir pressure needs to overcome the
pressure drop in each of the components of thesystem and allow fluids to enter the separator.
Pressure drop in each production component is afunction of flowrate.
The flowrate value at which a specific well flows
using only the energy stored in the compressedreservoir fluids is called the natura l equi l ibr iumflowrate.
8/10/2019 artificial lift dude
21/145
Equilibrium Flowrate
The flowrate value at which a specific well
flows using only the energy stored in the
compressed reservoir fluids is called
natural equi librium f low rate.
( )r s cP P P q =
8/10/2019 artificial lift dude
22/145
Changes in Productionwith Time
8/10/2019 artificial lift dude
23/145
Production changes with
time As the reservoir is produced its pressure,
(driving force for producing fluids) naturally
declines. Appearance of a gas phase inside the porous
media also reduces the productivity of theliquid oil phase.
There are also changes in producingconditions such as Water-Oil Ratio, Gas-OilRatio, deposition of wax or scale, etc.
8/10/2019 artificial lift dude
24/145
Changes in Production
There is a reduction on the ability of the
reservoir to deliver fluids after the perforations
at a sufficient pressure to overcome the
pressure losses through the the production
system.
Therefore, the well seeks a new equilibrium
point of lower flowrate with lower pressurelosses in the reservoir and in the system.
8/10/2019 artificial lift dude
25/145
Changes inProduction
0
50 0
1000
1500
2000
2500
0 0.2 0.4 0.6 0.8 1 1.2 1.4 1.6
Cumulative Production (10^6 barrels)
EquilibriumF
lowrate
(bpd)
eq
0
50 0
1000
1500
2000
2500
0 200 400 600 800 1000
Time (days)
Equilibriu
mF
lowrate(bpd)
eq
8/10/2019 artificial lift dude
26/145
Changes in Production
The natural equilibrium flowrate declines
with time
There are situations however, when such
an equilibrium point does not exist any
longer and the well cannot produce
naturally any more and ceases to be anaturally flowing well and dies.
8/10/2019 artificial lift dude
27/145
Changes in Production
We need then to know:
What is the minimum equilibrium flowrate ?
Does the well let you know it will die ?
Can we forecast how long a well will produceunder natural flow conditions ?
Can we detect when a well is approaching the end
of the natural flow conditions life ?
After answering those questions we still haveone left:
Can we improve the ability of a well to produce
fluids ?
8/10/2019 artificial lift dude
28/145
Corrective Measures to
Increase Natural EquilibriumFlowrate
8/10/2019 artificial lift dude
29/145
Corrective Measures
In order to modify the natural equilibrium flowratedecrease that would occur with time we can usuallyact in three ways:
1. The first option is modify the production system toreduce the pressure drops by changing thephysical configuration of the system after theperforations:
Open Chokes
Tubing size Flowline size
Production Layout
8/10/2019 artificial lift dude
30/145
Corrective Measures
2. The second option is by increasing the ability of the reservoirto deliver fluids at higher pressures at the perforations
Water and gas injection in the reservoir
Stimulation techniques
Perforation Density
In both cases the well is s t i l l ca lled a natura l ly f lowin g
wel l s ince the equi l ib r ium f low rate w i l l be determ ined by
the abi l i ty of the reservo i r p ressure to ov ercome the
pressure drops in the system
8/10/2019 artificial lift dude
31/145
Corrective Measures
3. The third option is to install specific devices that willhelp the reservoir pressure to overcome thepressure drops in the system after the perforations.
This can be accomplished in two ways:
a. by a systematic injection of lift fluids that willreduce the gravitational pressure drop in thesystem (gas lift)
b. by using a pump to provide the additionalpressure increment to overcome part of thepressure losses in the system.
8/10/2019 artificial lift dude
32/145
Corrective Measures
In th is last case we have no more a
natura l ly f lowing wel l s ince now the
equi l ib r ium f lowrate wi l l be determ inedby the abi l i ty o f the reservoir p ressure to
overcome the pressure drops in the
system after the perforat ions with the
help o f an ex ternal sou rce o fhorsepower .
8/10/2019 artificial lift dude
33/145
Artificial Lift
8/10/2019 artificial lift dude
34/145
Artificial Lift
In the beginning of the oil industry it wasrecognized that the pressure of fluids insidethe porous media provided the necessaryenergy to lift the fluids to the surface.
Techniques that use an external source ofhorsepower to help the reservoir inovercoming the pressures losses in the
production system after the perforationsreceive the generic name of Ar t i f ic ial Li f t.
8/10/2019 artificial lift dude
35/145
Artificial Lift
Artificial lift is the area of petroleum engineering
that studies methods used to promote an
increase in the production rate of flowing wells
or to put wells back into production by using an
external horsepower source to help the reservoir
pressure to overcome the pressure drops in the
system downstream of the perforations.
8/10/2019 artificial lift dude
36/145
Artificial Lift Methods
8/10/2019 artificial lift dude
37/145
Artificial Lift Methods There are several artificial lift methods. The
most important ones are: Beam Pumping
Continuous Gas Lift
Electrical Submersible Pump
Progressive Cavity Pump Hydraulic Jet Pump
Intermittent Gas Lift
Hydraulic Pump
Plunger Lift Auto Gas Lift
Other Traditional Methods
Boosting Methods
Etc
8/10/2019 artificial lift dude
38/145
Artificial Lift Methods
The definition of Artificial Lift Methods requires theexistence of a external horsepower source. Twocomments must be made regarding plunger lift and autogas lift.
Plunger Lift can be operated in 2 modes
Injecting supplemental gas. In this case it fits exactly the definitionof Artificial Lift Method
Without gas injection. In this case, there is no externalhorsepower source and plunger lift is considered an enhancednatural flow
Auto Gas Lift In auto gas lift the injected lift gas comes from a different
production zone. There is no surface horspeower source. Theexternal horsepower source is the lift gas zone. This can beconsidered as a natural flow of two zones being producedsimultaneously.
8/10/2019 artificial lift dude
39/145
Artificial Lift - Uses
In Oil Wells
Boost production
Put wells back into production
Stabilize production
In gas wells or CBM wells
To remove condensate or water from wells
8/10/2019 artificial lift dude
40/145
Pump
Sucker Rods
Tubing
Suffing Box
Polished Rod
Prime Mover
Pumping Unit Beam Pump
8/10/2019 artificial lift dude
41/145
Pump
Sucker
Rods
Tubing
Suffing Box
Polished Rod
Prime
Mover
Pumping
Unit
Beam Pump Familiar to engineers andoperators
Simple design Low capital investment for
low production at shallowto medium depths.
High investment for high
flowrates in deep wells. Allow very low fluid levels
(low bottom hole flowingpressure).
Adaptable to scale and
corrosion problems Limitation with casing size.
Adaptable to automation.
Not suitable for crookedholes
8/10/2019 artificial lift dude
42/145
Unloading Valve
Gas Lift Mandrel
Tubing
Operating Valve
Packer
Christmas Tree
Injection Choke
Continuous Gas Lift
8/10/2019 artificial lift dude
43/145
Unloading Valve
Gas LiftMandrel
Tubing
Operating Valve
Packer
ChristmasTree
Injection
Choke
Continuous Gas Lift Low investment for deepwells.
Most efficient for high GLR. Low operating costs for
sand production.
Flexible.
Adaptable to crooked holes.
Capable of producing veryhigh flowrates
Requires a source of highpressure gas.
Can not achieve very lowbotton hole flowingpressures.
Casing and lines mustwithstand gas pressure
8/10/2019 artificial lift dude
44/145
Primary Transformer
Switchboard
Wellhead andelectricmandrel
Tubing
Round Cable
Packer
Pump
Separator
Protector
Flat Cable
Motor
ElectricalSubmersiblePump
8/10/2019 artificial lift dude
45/145
PrimaryTransformer
Switchboard
Wellhead
and
electricmandrel
Tubing
Round Cable
Packer
Pump
Separator
Protector
Flat Cable
Motor
ESP Can produce very highflowrates from shallow to
medium depths. Low investment costs forshallow depths.
Adaptable to automation.
Casing size is not critical for
high flowrates. Electrical cable design is the
weakest link.
Needs a VSD to be flexible.
Requires a stable source of
electricity. Big problems with scale.
Requires workover toremove unit.
8/10/2019 artificial lift dude
46/145
Transformer
Polished Rod
Electric Motor
Christmas Tree
Control
Panel
Tubing
Rods
Downhole PCP
Gas Anchor
Anchor
Progressing Cavity Pump
8/10/2019 artificial lift dude
47/145
8/10/2019 artificial lift dude
48/145
Christimas Tree
Tubing
Unloading Valve
Valve Mandrel
Operating Valve
Packer
Check Valve
Intermitor
Pressure Gas
Open
Closed
Intermittent Gas Lift
8/10/2019 artificial lift dude
49/145
8/10/2019 artificial lift dude
50/145
Artificial Lift - Management
The management of artificial lift is a continuousprocess divided in 5 steps:
1. Selection of Artificial Lift Method
2. Evaluation of production conditions to define wellequipment, production levels, failure-control andmonitoring strategy to protect well equipment.
3. Monitoring of production data
4. Monitoring of equipment performance5. Evaluation of production equipment failure
8/10/2019 artificial lift dude
51/145
Artificial Lift - Management
Design and Selection
1 Artificial Lift Method
Selection
2 Artificial Lift Equipment
Operational Conditions
Failure Control
Monitoring Strategy
3 Monitoring Production Data
4 Monitoring Equipment Performance
5 Evaluation of Equipment Failure
Monitoring and Evaluation
8/10/2019 artificial lift dude
52/145
1 - Artificial Lift Management
The monitoring and evaluation phase mayresult in a new design and selection phase.
Change artificial lift method Example continuous gas lift intermittent gas lift
Change artificial lift method equipment type. Example install a downhole separator
Change equipment protection
Example corrosion or scale inhibitor
Change operational conditions Example change flow rates
8/10/2019 artificial lift dude
53/145
1 - Artificial Lift Method
As we will see there are severalartificial lift methods.
Each method has its own
characteristics. The best method is a balance of the
method capabilities, restrictions,production flowrates, investment and
operational costs with the objective ofmaximizing profit or maximizing theexpected profit.
8/10/2019 artificial lift dude
54/145
1- Artificial Lift Method
The number of the viable options and therelative advantages or disadvantages ofmethods for a specific application dependsstrongly on two factors:
Well Type
Onshore Offshore
Dry completion
Satellite well
Extremely Harsh Conditions (Artic, desert, etc)
Existing Infrastructure Remote well
New well in a new field
New well in a existing field
Existing well in a existing field
8/10/2019 artificial lift dude
55/145
8/10/2019 artificial lift dude
56/145
1- Artificial Lift Method
Production conditions and constraints changein time.
The best artificial lift method is a function ofprevailing production conditions.
The best artificial lift method usually:
Is not the one that maximizes profit today
Is not the one that maximizes profit in a futurecondition.
The best artificial lift method is the one thatmaximizes ultimate profit.
8/10/2019 artificial lift dude
57/145
1- Artificial Lift Method
Usually maximization of ultimate profit isobtained by using different artificial liftmethods at different times during the life of awell.
The lift-changing capability advantages andcosts must be properly considered.
We must also know when those changesshould take place.
Example of Artificial Lift Changes
Continuous gas lift Intermittent gas lift Beam pumping Electrical Submersible Pump
Continuous gas lift Electrical Submersible Pump
Etc...
8/10/2019 artificial lift dude
58/145
1- Artificial Lift Method
In very few cases, a combination ofartificial lift methods may be the bestchoice.
Proper evaluation of the benefits andalso of the complexity of the systemmust be done.
Example of Artificial Lift Combinations
Gas lift and Electrical Submersible Pump Jet Pump and Electrical Submersible Pump
Etc...
8/10/2019 artificial lift dude
59/145
1- Artificial Lift Method
The proper selection of artificial lift system depends onseveral other disciplines such as drilling, completion,reservoir management, production layout, automation,etc....
Artificial lift should be considered since the beginningof the field development plan when reservoir, drilling,completion and production decisions are being made.
All known constraints, production conditions andfuture changes must be properly addressed.
This process requires good communication andinteraction between all correlated disciplines.
8/10/2019 artificial lift dude
60/145
8/10/2019 artificial lift dude
61/145
2- Method Design and Operating Settings
Several Production Characteristics affects thisphase.
Bottomhole Temperature
Solids Production
Gas Production Corrosive fluids
Scale Problems
Stability
Changes in production conditions with time
Casing condition Etc...
8/10/2019 artificial lift dude
62/145
Why So Many Options ?
8/10/2019 artificial lift dude
63/145
Artificial Lift Methods
There are several artificial lift methods. Themost important ones are: Beam Pumping
Continuous Gas Lift
Electrical Submersible Pump Progressive Cavity Pump
Hydraulic Jet Pump
Intermittent Gas Lift
Hydraulic Pump
Plunger Lift Auto Gas Lift
Other Traditional Methods
Boosting Methods
8/10/2019 artificial lift dude
64/145
Artificial Lift Methods
Selection
8/10/2019 artificial lift dude
65/145
8/10/2019 artificial lift dude
66/145
Factors Affecting the Selection of
Artificial Lift Methods
8/10/2019 artificial lift dude
67/145
Artificial Lift Methods Factors to be considered:
Flowrates (reservoir pressure and productivity index) GLR and WC behavior
API and viscosity
Depth of well and temperature
Condition of casing
Type of well (vertical or directional) Sand production, wax, emulsion corrosion and scale
conditions
Type and quality of energy available
Environment and environmental issues
Personnel training and experience
Capital investment and operational costs
Reliability
Data quality and uncertainty
Existing Infrastructure
Etc....
8/10/2019 artificial lift dude
68/145
Artificial Lift MethodsExample of Attribute Table
FairFairExcellentLow Flowrates
ExcellentFairFairFlexibility
ExcellentFairFairDepth
GoodExcellentPoorHigh FlowratesExcellentPoorPoorHigh GOR
PoorGoodPoorWax
ExcellentFairFairSand
Gas L i f tESPRod PumpParameter
What is good, fair, poor and excellent ?
Do we have the same scale to compare methods?
Do we use the same scales ?
8/10/2019 artificial lift dude
69/145
Artificial Lift Methods Attribute Tables
The information on those tables should be used as a
guideline in selecting a method for a specific application. It is very hard to find an average attribute value for a
certain application
Most of the times the following factors override theinformation on the tables.
Location Onshore
Offshore
Artic
Etc..
Existing Infrastructure Remote well
New well in a new field
New well in a existing field
Existing well
8/10/2019 artificial lift dude
70/145
Artificial Lift Methods Attribute Tables
The method selection sometimesbecomes a personal decision. Operators,
service companies, product manufacturermay have some preferences not usuallyjustified by a technical analysis.
8/10/2019 artificial lift dude
71/145
Artificial Lift Methods Attribute Tables
Several attribute tables are available in theliterature. Brown, Clegg-Bucaram-Hein, Neely, etc...
They were developed as a aid in comparingeach artificial lift method for each production
characteristic. They contain a dynamic information and
should be updated to reflect newdevelopments or limitations of the technology
The attributes can be classified into 3 types:1. Design Considerations and Overall Comparisons
2. Normal Operating Conditions
3. Artificial Lift Considerations
8/10/2019 artificial lift dude
72/145
Artificial Lift Methods AttributeTables
Clegg, J.D., Bucaram, S. M., Hein, N. W. Jr. New Recommendations andComparisons for Selecting Artificial Lift Methods, SPE 24834 - 1992.
8/10/2019 artificial lift dude
73/145
Table I Artificial Lift Design Considerations and Overall Comparisons
Good for low
volume wells. Canadjust injection
time andfrequency.
Good: must adjustinjection time andcycles frequently.
Excellent: gas
injection rate variedto changes rates.
Tubing needs to besized correctly.
Good to excellent:power fluid rate
and pressure
adjusts theproduction rate and
lift capacity.Selection of throatand nozzle sizesextend range of
volume andcapacity.
Good/excellent:Can vary powerfluid rate and
speed of downholepump. Numerouspump sizes and
pump/engine ratiosadapt to productionand depth needs.
Poor: pumpsusually run at a
fixed speed.
Requires carefulsizing. VSD
provides moreflexibility but addedcosts. Time cyclingnormally avoided.
Must size pumpproperly.
Fair: can alter
speed. Hydraulicunit provides
additional flexibilitybut at added cost.
Excellent: can afterstroke speed andlength , plunger
size, and run time
to controlproduction rate.
Flexibility
Excellent forflowing wells. No
input energyrequired because ituses the energy of
the well. Goodeven when small
supplementary gas
is added.
Poor: normallyrequires a highinjection gas
volume/barrel fluid.Typical lift
efficiency is 5% to10%; improvedwith plungers.
Fair: increase forwells that require
small injectionGLRs. Low for
wells requiring highGLRs. Typical
efficiencies of 20%but range from 5%
to 30%.
Fair to poor.Maximum
efficiency only
30%. Heavilyinfluenced by
power fluid plusproduction
gradient. Typicaloperating
efficiencies of 10%to 20%.
Fair to good: not asgood as rod
pumping owing toGLR, friction, and
pump wear.Efficiencies range
from 30% to 40%with GLR>100;
may be higher withlower GLR.
Good for high ratewells but
decreasessignificantly for
8/10/2019 artificial lift dude
74/145
Table I Artificial Lift Design Considerations and Overall Comparisons
Fair. Some trade invalue. Poor open
market value.
Fair: some trade invalue. Poor open
market value
Fair: some marketfor good used
compressors andsome trade in
value for mandrelsand valves.
Good: easily
moved. Sometrade in value. Fairmarket for triplex
pumps.
Fair market fortriplex pumps;good value for
wellsite system that
can be movedeasily.
Fair: some trade invalue. Poor openmarket values.
Fair/poor: easilymoved and somecurrent market for
used equipment.
Excellent: easilymoved and goodmarket for used
equipment
Salvage Value
Good if wellproduction is
stable.
Excellent if there isan adequate
supply of gas andan adequate lowpressure storage
volume for injection
gas. System mustbe designed for theunsteady gas flow
rates.
Excellent if
compressionsystem properly
designed andmaintained.
Good with properthroat and nozzle
sizing for theoperating
conditions. Mustavoid operating incavitation range of
jet throat; related topump intake
pressure. Moreproblems if
pressures > 4000psig.
Good with acorrectly designed
and operatedsystem. Problems
of changing wellconditions reducedownhole pump
reliability. Frequent
downtime resultsfrom operational
problems.
Varies: excellentfor ideal lift cases;poor for problems
areas. Verysensitive tooperating
temperatures and
electricalmalfunctions.
Good: normally
over pumping andlack of experience
decreases runtime.
Excellent: run timeefficiency >95% if
good operating
practices arefollowed and ifcorrosion, wax,asphaltenes,
solids, deviations,etc. are controlled.
Reliability
Usually very low.Same as
continuous flow
gas lift.
Well costs low.Compression costs
vary depending onfuel and
compressormaintenance. Key
is to inject asdeeply as possiblewith optimum GLR
Higher power cost
owing to
horsepowerrequirement. Low
pump maintenancecost typical withproperly sized
throat and nozzle.
Often higher than
rod pumps even forfree systems. Shortrun life increases
total operatingcosts.
Varies: if
horsepower is high,
energy costs arehigh. High pullingcosts result from
short run life. Oftenrepair costs are
high.
Potentially low, butshort run life onstator frequently
reported.
Very low for
shallow to mediumdepth (
8/10/2019 artificial lift dude
75/145
Table I Artificial Lift Design Considerations and Overall Comparisons
Essentially a lowliquid rate, highGLR lift method.Can be used forextending flow lifeor improving
efficiency. Ample
gas volume and/orpressure neededfor successfuloperation. Used on
8/10/2019 artificial lift dude
76/145
8/10/2019 artificial lift dude
77/145
Time Cycle isnecessary for
efficient operation.Pump Off is not
applicable.
Poor: cycle mustbe periodicallyadjusted. Labor
intensive.
Not applicable.
Poor: does notappear applicableowing to intake
pressure
requirement higherthan pump-off
Poor: possible butnot normally used.Usually controlled
only by
displacementchecks, pump-off
control notdeveloped
Poor: soft start andimproved
seals/protectors
recommended.
Poor: avoidshutdown in highviscosity/sand
producers.
Excellent if wellcan be pumped off.
Time cycle andPump-off Controller
Application
Well testing simplewith few problems
Poor: well testing
complicated byinjection gasvolume/rate.
Measurement ofboth input andoutflow gas a
problem.Intermittent cancause operating
problems with
separators.
Fair: well testingcomplicated by
injection gasvolume/rate.
Formation GLRobtained by
subtracting totalproduced gas frominjected gas. Gas
measurement
errors common
Same as hydraulic
reciprocatingpumps. Three
stage productiontest can be
conducted byadjusting
production steprates, pressured
recorder in place tomonitor intake
pressure
Fair: well testingwith standard
individual well unitspresents few
problems. Welltesting with a
central systemmore complex:
requires accuratepower fluid
measurements
Good: simple withfew problems. Highwater cut and high
rate wells mayrequire a free-
water knock-out.
Good: well testingsimple with few
problems.
Good: well testingis simple few
problems usingstandard available
equipment and
procedures.
Testing
Table II Normal Operating Considerations
Good: depends ongood well tests and
well pressure chart
Fair: complicatedby standing valve
and fallback.
Good/excellent:can be analyzed
easily. Bottomholepressure andproduction logsurveys easily
obtained.Optimization andcomputer controlbeing attempted
Same as hydraulicreciprocating
pumps.
Good/fair:downhole pump
performance can
be analyzed fromsurface power-fluid
and pressure,
speed, andproducing rate.
Bottomhole
pressure obtainedwith free pumps
Fair: electricalchecks but specialequipment needed
otherwise
Fair: analysisbased on
production andfluid levels only.
Dynamometersand pump-off cardsnot possible to use.
Excellent: can beeasily analyzed
based on well test,fluid levels, etc.
Analysis improved
by use ofdynamometers and
computers.
Surveillance
None normallyrequired.
Same ascontinuous gas lift.
Good: engines,turbines, or motors
can be used for
compression.
Same as hydraulicreciprocating
pumps.
Excellent: prime
mover can beelectric motor, gas,
or diesel firedengines or motors.
Fair: requires a
good power sourcewithout spikes or
interruptions.Higher voltagescan reduce I2R
losses.
Good: bothengines or motors
can be used.
Good: bothengines or motorscan be used easily
(motors more
applicable andflexible).
Prime MoverFlexibility
Plunger LiftIntermittent Gas
LiftContinuous Gas
LiftHydraulic Jet
Systems
HydraulicReciprocating
Pumping
ElectricalSubmersible
Pumping
Progressing CavityPumping
Sucker RodPumping
Attribut e
8/10/2019 artificial lift dude
78/145
Excellent.Same as
continuous flow
Excellent:produced gas
reduces need forinjection gas
Similar to hydraulicreciprocating
pump. Free gasreduces efficiencybut helps lift. Vent
free gas if possible.Use a gas anchor
Good/fair:concentric fixedpump or parallelfree permits gas
venting withsuitable downhole
gas separatorbelow pump intake.Casing free pump
limited to low GOR.
Poor for free gas(i.e. > 5%) throughpump. Rotary gasseparators helpful
if solids not
produced.
Poor if must pumpany free gas.
Good if can ventand use natural
gas anchor withproperly designedpump. Poor if must
pump >50% freegas.
Gas handling ability
No knowninstallations.
Same ascontinuous flow
Fair: dual gas liftcommon but goodoperating of dual
gas lift complicated
and inefficientresulting in
reduced rates.Parallel 2x2 in.nominal tubing
inside 7 in. casingand 3x3 in. tubinginside 9 5/8 in.casing feasible
Same as hydraulicreciprocating pump
except canpossibly handle
higher GLR but atreduced efficiency
Fair: three stringnonvented
applications havebeen made with
complete isolationof production and
power fluid fromeach zone. Limited
to low GLR andmoderate rates.
No knowninstallations. Larger
casing would beneeded. Possible
run and pullproblems.
No knowninstallations.
Fair: parallel 2 x 2in. low rate duals
feasible inside 7 in.casing. Duals
inside 5.5 in.casing currently notin favor. Gas is a
problem from lower
zone. Increasedmechanical
problems
Duals application
Table III Artificial Lift Considerations
Excellent.Same as
continuous flow
Excellent: fewwireline problemsup to 70 degree
deviation forwireline retrievable
valves
Excellent: short jet
pump can passthrough doglegs upto 24 degree/100ft. in 2 in. nominal
tubing. Sameconditions as
hydraulicreciprocating
pump.
Excellent. If tubing
can be run in thewell, pump
normally will passthrough the tubing.
Free pumpretrieved without
pulling the tubing.Feasible operationin horizontal wells.
Good: fewproblems. Limited
experience in
horizontal wells.Require long radiuswellbore bends to
get through.
Poor to fair:
increased load and
wear problems.Currently, very fewknown installations.
Fair: increased
load and wearproblems. Highangle deviated
holes (>70degrees) and
horizontal wells are
being produced.Some success in
pumping 15degrees/100 ft.
using rod guides.
Crooked/deviatedholes
Fair: normalproduction cycle
must be interruptedto batch treat to
well.
Same as
continuous flow
Good: inhibitor in
the injection gasand/or batch
inhibiting downtubing feasible.Steps must betaken to avoid
corrosion ininjection gas lines.
Good/excellent:inhibitor with power
fluid mixes withproduced fluid at
entry of jet pumpthroat. Batch treat
down annulusfeasible.
Good/excellent:
batch orcontinuous treating
inhibitor can becirculated withpower fluid for
effective control.
Fair: batch treatinginhibitor only to
intake unlessshroud is used.
Good: batchtreating inhibitor
down annulusfeasible
Good to excellent:
batch treatinginhibitor downannulus used
frequently for bothcorrosion and scale
control.
Corrosion/scale
handling ability
Plunger LiftIntermittent Gas
LiftContinuous Gas
LiftHydraulic Jet
Systems
HydraulicReciprocating
Pumping
ElectricalSubmersible
Pumping
Progressing CavityPumping
Sucker RodPumping
Attribut e
8/10/2019 artificial lift dude
79/145
Sand can stickplunger; however,
plunger wipestubing clean
Fair: standing valve
may causeproblems.
Excellent: limit isinflow and surfaceproblems. Typicallimit is 0.1 % sand
for inflow andoutflow problems.
Fair/good: jet
pumps areoperating with 3%sand in produced
fluid. Power fluid to
jet pump cantolerate 200 ppm of25 micron particlesize. Fresh watertreatment for saltbuildup possible
Poor: requires
8/10/2019 artificial lift dude
80/145
Excellent: for lowflow rates of 1 to 2B/D with high GLR.
Good: limited by
efficiency andeconomic limit.Typically to 4
bbl/cycle with up to48 cycles/day
Fair: limited byheading and
slippage. Avoidunstable flow
range. Typicallylower limit is 200
B/D for 2 in. tubingwithout heading;
400 B/D for 2.5 in.and 700 B/D for 3
in tubing.
Fair: >200 B/Dfrom 4000 ft
Fair: not as goodas rod pumping.Typically 100 to
300 B/D from 4000to 10000 ft. >75
B/D from 12000 ftpossible
Generally poor:lower efficiencies
and high operatingcosts for
8/10/2019 artificial lift dude
81/145
Artificial Lift Methods Attribute Tables
After selection of potential choices, acareful, realistic and detailed design of thesystem must be made.
This phase is extremely important, since apoor or neglected design may ruin theadvantages of a certain option resulting ina very bad performance for a otherwise
excellent choice.
8/10/2019 artificial lift dude
82/145
Artificial Lift Methods Attribute Tables
After designing the appropriate candidates, afinal realistic economic analysis will indicate thebestchoice.
Maximization of ultimate profit is the goal.
The economic analysis requires Investment costs and Salvage values
Operational costs Artificial Lift system performance
Production Forecast
Failure rate estimate under the expected operating conditions
Oil, gas and energy prices and method flexibility
Etc...
O O
8/10/2019 artificial lift dude
83/145
Our Objective
Our objective Is not to maximize production
Is not to minimize operational costs
Is not to minimize investment costs
Is not to minimize downtime
Our objective Is to maximize profit through an intelligent
management of operational and investment costs. Awell designed system will balance costs, productionand reliability under the various physical, economical
environmental, human and technical constraints. We are in the business of producing profit
through oil, gas and water production.
I C
8/10/2019 artificial lift dude
84/145
Investment Costs
The investment costs for a artificial liftmethod for a certain application arefunction of:
Flowrate
Lifting depth
Setting depth
8/10/2019 artificial lift dude
85/145
8/10/2019 artificial lift dude
86/145
Investment Costs AN EXAMPLE
The following tables and graphs are based on: Johnson, L. D.: Here are Guidelines for Picking an Artificial Lift
Method - The Oil and Gas Journal, August 26, 1968.
In estment Costs
8/10/2019 artificial lift dude
87/145
Investment Costs
Lift Depth (ft)
Rod Pumping Investment Costs (US$)
Flowrate(bpd)
26180176901100
23220165901000
2062016190900
287102040015700800
252902021012950700
31150229901838011840600
3285025990191601587010720500
2848026570222101737013630986540025480220501876014410119358635300
21640197701600012845101157455200
1993016520135951123586756345100
700060005000400030002000
I t t C t
8/10/2019 artificial lift dude
88/145
Investment Costs
Lift Depth (ft)
Hydraulic Pumping Investment Costs (US$)
Flowrate(bpd)
3783035610331903077028350259351100
3513033210308902857026250239301000
347903247030150278302551023190900
292102729025370234502153019610800
269802506023140212201930017380700
239202230020680190601744015820600
239202230020680190601744015820500
229302131019690180701645014830400217502013018510168901527013650300
211601954017920163601475013140200
203401872017100154801386012240100
700060005000400030002000
8/10/2019 artificial lift dude
89/145
Investment Costs
Lift Depth (ft)
Electrical Submersible Pumping Investment Costs (US$)
Flowrate(bpd)
2647026470264702647026470264701200
2274022740227402274022740227401000
189001890018900189001890018900800
156501565015650156501565015650600121701217012170121701217012170400
700060005000400030002000
8/10/2019 artificial lift dude
90/145
Beam Pumping
0
5000
10000
15000
20000
25000
30000
35000
0 200 400 600 800 1000 1200
Flowrate (bpd)
InvestmentCost(US$)
Lift Depth (ft) 7000 6000 5000
4000
3000
2000
8/10/2019 artificial lift dude
91/145
Hydraulic Pumping
0
5000
10000
15000
20000
25000
30000
35000
40000
0 200 400 600 800 1000 1200
Flowrate (bpd)
InvestmentCo
st(US$)
Lift Depth (ft)
7000
5000
3000
2000
8/10/2019 artificial lift dude
92/145
Regions of Minimum Investment
8/10/2019 artificial lift dude
93/145
Lift Depth = 5000 ft
0
5000
10000
15000
20000
25000
30000
35000
40000
0 200 400 600 800 1000 1200
Flowrate (bpd)
InvestmentCos
t(US$)
Artificial Lift Method
Beam Pumping
Hydraulic Pumping
Electrical Submersible Pump
Regions of Minimum Investment
Regions of Minimum Investment
8/10/2019 artificial lift dude
94/145
Beam - Hydraulic - Electrical Submersible
Pumping
0
5000
10000
15000
20000
25000
30000
35000
40000
0 200 400 600 800 1000 1200
Flowrate (bpd)
InvestmentCost
(US$)
Lift Depth (ft)
7000
6000
5000
4000
3000
2000
Regions of Minimum Investment
Minimum Investment Regions
8/10/2019 artificial lift dude
95/145
2000
3000
4000
5000
6000
7000
0 200 400 600 800 1000 1200
Flowrate (bpd)
Lift
Depth(ft)
Beam Pumping
Hydraulic Pumping
Electrical Submersible Pumping
Not necessarily Application Window
Operational Costs
8/10/2019 artificial lift dude
96/145
Operational Costs
The operational costs should also be considered
when selecting an artificial lift method. Usually the operational cost should not be the only
criteria for selecting a artificial lift method. Theoperational cost should be an imput to the economicalanalysis to be performed.
Operational cost is consituted by three terms: Fixed Costs
Costs that do not depend on the production but occur on aregular basis
Variable Costs Costs that are directly related with the production levels and
occur on a regular basis Workover Costs
Costs that are related with failure of the system or componentsof the system and occur at certain points in time.
O C
8/10/2019 artificial lift dude
97/145
Operational Costs
C = Daily Operational Cost
Cfixed = Fixed Operational Cost
Cv(q) = Variable Operational Cost
Cworkover = Workover Cost
workovervfixed CqCCC ++= )(
V i bl O ti l C t
8/10/2019 artificial lift dude
98/145
Variable Operational Costs
The variable operational costs consist of the costs to lift, treat,produce, discard, export all the produced fluids.
We can break it down into each specific fluid variableoperational cost.
Another component of the operational cost consist of the cost of
energy used to help producing the fluids from the bottom of thewell to the surface (lift cost).
HPCqCqCqCC hpggwwoov +++=
V i bl O ti l C t
8/10/2019 artificial lift dude
99/145
Variable Operational Costs
Each individual fluid production is associated withthe oil production. The energy consumption is alsoassociated with the oil production
)()()( ohpoopgoopwoov qHPCqqGORCqqWORCqCC +++=
WORp = Production Water Oil Ratio
GORp = Production Gas Oil Ratio
V i bl O ti l C t
8/10/2019 artificial lift dude
100/145
Variable Operational Costs
)()()( ohpoopgopwov qHPCqqGORCqWORCCC +++=
The right hand side can be lumped into a equivalent
production operational cost
)()( ohpooe
ov qHPCqqCC +=
)()( opgopwoe
o qGORCqWORCCC ++=
8/10/2019 artificial lift dude
101/145
8/10/2019 artificial lift dude
102/145
Optimum Production Flowrate
8/10/2019 artificial lift dude
103/145
Optimum Production Flowrate
The total operational cost then can be written as:
)()( ohpooe
oworkoverfixed qHPCqqCCCC +++=
CSP =
During normal production, the daily profit from thewell can be written as:
)()()( ohpooe
oworkoverfixedoo
e
o qHPCqqCCCqqSP =
Optimum Production Flowrate
8/10/2019 artificial lift dude
104/145
Optimum Production Flowrate
( ) )()()( ohpworkoverfixedooe
oo
e
o qHPCCCqqCqSP =
Simplifying the notation:
)()( ohpworkoverfixedooe
o qHPCCCqqPP =
)()()( oeooeooeo qCqSqP =
Optimum Production Flowrate
8/10/2019 artificial lift dude
105/145
Optimum Production Flowrate
0)(
)()(
=+=
o
ohpo
e
oo
o
o
e
o
o
dq
qdHPCqPq
dq
qdP
dq
dP
The maximum daily profit will occur when:
0=
odq
dP
Optimum Production Flowrate
8/10/2019 artificial lift dude
106/145
Optimum Production Flowrate
hp
e
o
o
e
oo
o C
Pdq
dPq
dq
dHP+
=
The opt imum produ ct ion flowrateis the solutionto the following equation:
The relationship between the HP and the wellequilibrium flowrate qo is extremly important to
determine the optimum profit flowrate. Therelationship between the equilibrium flowrate andthe horsepower consumption is called Ar t i f ic ia l Li f tMethod Performance Curve.
Artificial Lift Performance Curve
8/10/2019 artificial lift dude
107/145
Artificial Lift Performance Curve TheArtificial Lift Method Performance Curve can be
obtained through a nodal analysis of the system.
0
200
400
600
800
1000
1200
1400
1600
0 200 400 600 800 1000
Horsepower
EquilibriumF
lowra
te-
nf
e
qMaximum Profit
hp
o
e
o
o
oeoo
o
o
C
qPdq
qdPq
dq
qdHP)()(
)(+
=
Artificial Lift Performance
8/10/2019 artificial lift dude
108/145
Artificial Lift Performance
A artificial lift system should be designed to operate at the
optimum profit flowrate. The optimum profit flowrate is function of:
Artificial Lift Method Characteristics and specific design
Reservoir Inflow Performance and Production Characteristics
Fluids sale prices, operational costs and energy costs
When determining the method performance curve, allrestricitions must be considered in order to obtain a realisticcurve describing the application envelope of the method. Asa result the performance curve may not be complete asshown in the last picture The performance curve may be limited by factors such as:
Minimum flowrate to achieve stable production conditions.
Maximum or minimum conditions for operation of the system orcomponents of the system.
Equipments installed
Artificial Lift Performance Curve
8/10/2019 artificial lift dude
109/145
Artificial Lift Performance Curve
0
200
400
600
800
1000
0 100 200 300 400 500
Horsepower (HP)
OilFlowrate
(bpd)
Design Point
Maximum Motor HP
Minimum Stable Flowrate
Gas Fraction = 15%
VSD Operating Envelope
Artificial Lift Performance
8/10/2019 artificial lift dude
110/145
Artificial Lift Performance
Another important characteristics that helps to select anartificial lift method is the method flexibility around thedesign flowrate on the method performance curve. Thiswill help to evaluate the effects of:
Changes in the method performance due to changes in the
economical parameters Changes in the method performance due to uncertainties in the
design data
Changes in the method performance due to changes inproduction conditions with time.
Artificial Lift Performance
8/10/2019 artificial lift dude
111/145
The flexibility of the method is a function of the
equipment installed to provide flowrate control. The typeof control equipment installed may also change themethod performance curve.
Flowrate control can be obtained by: Changing surface equipment operating parameters
Choke Size
VSD Frequency
Gas Injection Pressure
Stroke length and SPM
Etc
Changing sub-surface equipment.
Oriffice of Gas Lift Valve Etc
Sometimes extension of a method flexibility is onlyaccomplished by a complete redesign of the system anda complete workover job.
Artificial Lift Performance Curve
8/10/2019 artificial lift dude
112/145
Artificial Lift Performance Curve
0
200
400
600
800
1000
0 100 200 300 400 500
Horsepower (HP)
OilFlowrate
(bpd)
Design Point
Minimum Stable Flowrate
Gas Fraction = 15%
Choke Control Operating Envelope
Pump Minimum Operating Flowrate without a VSD
Artificial Lift Performance Curve
8/10/2019 artificial lift dude
113/145
Artificial Lift Performance Curve
0
200
400
600
800
1000
0 100 200 300 400 500
Horsepower (HP)
OilFlowrate
(bpd
Design Point
Maximum Motor HP or Pump Range
Minimum Stable or Pump Range Flowrate
N por
Pr
Artificial Lift Performance
8/10/2019 artificial lift dude
114/145
Artificial Lift Performance
The performance curves behavior withcumulative production is an extremly powerfulanalysis tool. We can predict: Method performance during a certain depletion period
Method performance taking into consideration all
conditions and limitations imposed or intrinsic to thesystem or method.
Method flexibility in following the best economicproduction flowrate during the depletion period.
Method flexibility and its impact on the economics
during the production period.
Artificial Lift Performance
8/10/2019 artificial lift dude
115/145
The performance curve enables the determination of thebest (maximum daily profit) production strategy(equilibrium flowrate and horsepower) to be used as afunction of depletion for a certain design reflecting actualproduction conditions and limitations.
Depending on the method flexibility and the performancecurve limitations, the optimum prodcution strategy mayconincide or not with the optimum production flowrate.
Artificial Lift Performance
Artificial Lift Performance
8/10/2019 artificial lift dude
116/145
The relationship between the equilibriumflowrate and cumulative production isfundamental for an accurate production forecastof the system.
Artificial Lift Performance
dt
Nq
dN
pe
p=
)(
Artificial Lift Performance
8/10/2019 artificial lift dude
117/145
Solution of this ODE will enable us to determine:
dtetqetdNdNt
k
it
k
i
p
pv
p
nn
== )()(
)(tNp )(tqe
We can then estimate the cumulative production present
value from:
If a forecast for oil sale and production costs is known we can also calculate theeconomic present value for the system
Artificial Lift Performance
8/10/2019 artificial lift dude
118/145
The procedure outlined enables the determination of theoptimum operating parameters for a certain artificial lift
method design. For a certain design, the procedure will yield the
production strategy that will maximize daily profit underthe system conditions and restrictions.
The procedure will optimize the present value for
operating the well under a certain design. The procedure will not globally optimize present value due
to: Method flexibility and performance curves limitations due not allow
a certain design to produce at the best economical flowrate
possible. Optimum economical flowrate is outside the productionenvelope for that design.
For different depletion stages different designs will yield differentperformance curves.
The system will eventually fail and a well intervention will berequired to put the system back into a safe operating condition
Artificial Lift Performance
8/10/2019 artificial lift dude
119/145
0
200
400
600
800
1000
0 100 200 300 400 500
Horsepower (HP)
OilFlowrate
(bpd)
Optimum Economical Flowrate
Production Strategy
Production Envelope
System Failure
8/10/2019 artificial lift dude
120/145
Artificial Lift Performance
8/10/2019 artificial lift dude
121/145
Each artificial lift method or artificial lift
method application scenario will have: Different expected lifes
Different duration and costs associated with a
complete workover job. Different costs and options associated with a
simpler intervention to improve efficiency.
Different waiting line times.
Different changes in performance withdepletion
Artificial Lift Performance - Example
8/10/2019 artificial lift dude
122/145
0
5000000
10000000
15000000
20000000
25000000
30000000
35000000
40000000
45000000
50000000
0 500 1000 1500 2000 2500 3000 3500 4000
Time (days)
NominalProfit
(US$)
MTBF 720 Days
Workover Time 30 Days
Waiting Time 120 Days
Design Efficiency
No Failure 100% Performance Efficiency Design
Failure
Waiting Time
Workover
8/10/2019 artificial lift dude
123/145
All those effects are important to determinefor each scenario:
Total life span Number of design changes during life span
Best design strategy for each period
Artificial Lift Performance
8/10/2019 artificial lift dude
124/145
Optimum Flowrate and Artificial Lift Performance Curve
8/10/2019 artificial lift dude
125/145
The Artificial Lift Method Performance Curve can be
obtained through a nodal analysis of the system.
0
200
400
600
800
1000
1200
1400
1600
0 200 400 600 800 1000
Horsepower
EquilibriumF
lowrate-
nf
eqMaximum Profit
hp
o
e
o
o
o
e
oo
o
o
C
qPdq
qdPq
dq
qdHP)()(
)(+
=
8/10/2019 artificial lift dude
126/145
Optimum Flowrate and Artificial Lift
8/10/2019 artificial lift dude
127/145
pPerformance Curve
The Performance curve can be used to:
Determine the best operating conditionwhen the system and the reservoir
performance and production characteristicsare known. This is usually the approach tooptimize production conditions.
Design a artificial lift method to be installed
in a well when the reservoir performanceand production characteristics are known.
Optimum Flowrate and Artificial Lift Performance Curve
8/10/2019 artificial lift dude
128/145
The Performance curve also illustrates animportant problem.
Production forecast should be conducted toreflect the future reservoir behavior as well asthe future operating conditions of the
production and artificial lift system. This problem can only be solved in an
integrated way, since production operatingconditions will depend on future reservoir
behavior and reservoir behavior will dependon production history which is of coursecontrolled by production operating conditions.
Optimum Flowrate and Artificial Lift Performance Curve
8/10/2019 artificial lift dude
129/145
Usually this problem is solved by a Nodal Analysis
The Nodal Analysis is conducted using OPR curvesthat reflect the production system and artificial liftbehavior and a reservoir simulator to reflect thereservoir performance and production characteristics.
As we have seen, there are several equilibriumconditions between the OPRs and the reservoirbehavior that are reflected by the artificial liftperformance curve for a certain level of reservoirdepletion.
The correct equilibrium point should reflect the actual
conditions to be used during the operation of the well. The well should be operated as close as possible to
the optimum economical flowrate.
Optimum Flowrate and Artificial Lift Performance Curve
8/10/2019 artificial lift dude
130/145
This provides a criteria for the reservoirsimulator to select the best operating flowratefrom all the possible values from the OPRs.
The optimum production flowrate is given by:
hp
e
o
o
e
oo
o C
Pdq
dPq
dq
dHP+
=
Optimum Flowrate and Artificial Lift Performance Curve
8/10/2019 artificial lift dude
131/145
When the IPR is not known, the left hand sidecan be written as:
o
wf
wfoo dq
dP
P
HP
q
HP
dq
dHP
+
=
The optimum production flowrate is given thenby:
hp
eo
o
e
oo
o
wf
wfo C
PdqdPq
dq
dP
P
HP
q
HP+
=
+
Optimum Flowrate and Artificial Lift Performance Curve
8/10/2019 artificial lift dude
132/145
The criteria for the optimum flowrate is:
hp
e
o
o
e
oo
o
wf
wfo C
Pdq
dPq
dq
dP
P
HP
q
HP+
=
+
Production SystemBehavior
ReservoirBehavior
Economics andProduction Conditions
Managing Production
8/10/2019 artificial lift dude
133/145
a ag g oduct o
Managing the production characteristicsof each individual well can also havedramatic effects on the economicresults.
Example 347 Wells
qo 10 - 20 bpd
qw 0 - 176 bpd
Managing Production
8/10/2019 artificial lift dude
134/145
g g
0
5000
10000
15000
20000
25000
30000
0 5000 10000 15000 20000 25000 30000
Water Production (bpd)
OilProduct
ion(bpd)
Managing Production
8/10/2019 artificial lift dude
135/145
g g
If we can really isolate and identify thefixed, variable and energy cost we canoptimize a pool of wells responding tochanges in the oil price.
HPCqCqCqSCP hpwwoooof =+
So = 15 US$/stb
Co = 4.9 US$/stb
Cw = 4.9 US$/stb
Chp = 1 US$/(HP day)
HP= 0.1 HP/stb (water or oil)
8/10/2019 artificial lift dude
136/145
Managing Production
8/10/2019 artificial lift dude
137/145
g g
So = 11 US$/stb
Co = 4.9 US$/stb
Cw = 4.9 US$/stb
Chp = 1 US$/(HP day)
HP= 0.1 HP/stb (water or oil)
Managing Production
8/10/2019 artificial lift dude
138/145
g g
0
10000
20000
30000
40000
50000
60000
70000
80000
0 5000 10000 15000 20000 25000 30000
Oil Production (bpd)
Profit+Fixed
Cost(US$/d
Managing Production
8/10/2019 artificial lift dude
139/145
g g
0
20000
40000
60000
80000
100000
120000
140000
160000
0 5000 10000 15000 20000 25000 30000
Oil Production (bpd)
Profit+FixedCost(US$/d)
15 US$/stb
11 US$/stb
Interesting Data
8/10/2019 artificial lift dude
140/145
g
1,027Cubic Feet of Natural Gas
61,066HP day
3,412KWh of Electricity
5,800,000Barrel of Crude
21,400,000Ton of coal (907.2 kg)
Energy Content orEquivalence (BTU)
Energy Source
1 barrel*psi = 1.0389 BTU
Energy Content Equivalence
8/10/2019 artificial lift dude
141/145
gy q
1,027
3,412
61,066
5,800,000
21,400,000
BTU
Cubic Feet ofNatural Gas
KWh ofElectricity
HP day
Barrel ofCrude
Ton of coal(907.2 kg)
Cubic Feet ofNatural Gas
KWh ofElectricity
HP dayBarrel ofCrude
Ton of coal(907.2 kg)
1
3.31
60181
56471700951
2083762723503.71
1 barrel*psi = 1.0389 BTU
1 bpd*psi is equivalent to 1.79 10-7 barrels of oil / day
References
8/10/2019 artificial lift dude
142/145
1. Brown, K. E.: Overview of Artificial Lift Systems, SPE 9979, 1982.
2. Brown, K. E.: The Technology of Artificial Lift Methods, Vol. II-B, Chapter
9, Pennwell Books, Tulsa, OK, 1979.
3. Bucaram, S. M. & Patterson, J. C. Managing Artificial Lift, JPT April 1994,
SPE 26212.
4. Bucaram, S. M., Sullivan, J. H. A Data Gathering and Processing System toOptimize Production Operations, Journal of Petroleum Technology,
February 1972.
5. Bucaram, S. M., Yeary, B. J. A Data Gathering and Processing System to
Optimize Production Operations: A 14-Year Overview, Journal of Petroleum
Technology, April 1987.
6. Clegg, J.D., Bucaram, S. M., Hein, N. W. Jr. New Recommendations and
Comparisons for Selecting Artificial Lift Methods, SPE 24834 - 1992.
References
8/10/2019 artificial lift dude
143/145
7. Clegg, J.D., Bucaram, S. M., Hein, N. W. Jr. Recommendations and
Comparisons for Selecting Artificial Lift Methods, JPT December 1993.
8. Clegg, J. D., High Rate Artificial Lift, SPE 17638, Journal of Petroleum
Technology, March 1988.
9. Corteville, J., Hoffmann, F., Valentin, E. Activation des Puits: Critres de
Slection des Procds. Revue de Linstitut Franais du Ptrole, Vol. 41,
NO. 6, November 1986.
10. Duke, S.: Artificial Lift Which Method Best Fits your Needs ?,
Southwestern Petroleum Short Course 1981.
11. Fleshman, R., Lekic, H. O., Artificial Lift for High Volume Production
1999.
12. Jacobs, E. G. Artificial Lift in the Montrose Field, North Sea, SPE 15869
1986.
13. Johnson, L. D. Here are Guidelines for Picking an Artificial Lift Method,
The Oil and Gas Journal, August 1968.
References
8/10/2019 artificial lift dude
144/145
14. Kahali, K., Rai, R., Mukerjie, R. K. Artificial Lift Methods for Marginal
Fields, SPE 21696 1991.
15. Lea, J. F., Winkler, H. W. New and Expected Developments in Artificial Lift,
SPE 27990 1994.
16. Lea, J. F., Adisoemarta, P. S., Nickens, H. V. Artificial Lift for Horizontal
Wells, ETCE/OMAE 2000 Joint Conference Energy for the New
Millenium, February 14-17, 2000 New Orleans, LA.
17. Lea, J. F., Cox, J. C., Adisoemarta, P. S. Artificial Lift for Slim Holes, SPE
63042 2000.
18. Naguib, M. A., Shaheen, S. E., Bayoumi, E., Eman, N. A. Review of
Artificial Lift in Egypt, SPE 64508 2000.
19. Naguib, M. A., Bayoumi, A., Battrawy, A. Guideline of Artificial Lift Selection
for Mature Field, SPE 64428 2000.
20. Neely, A. B.:A. B. Neely Discusses Artificial Lift Techniques, Uses and
Developments. Journal of Petroleum Technology September 1980.
References
8/10/2019 artificial lift dude
145/145
21. Neely, A. B., Gbison, F., Clegg, J., Capps, B., Wilson, P. Selection of
Artificial Lift Method, SPE 10337 1981.
22. Renfu, W., Xlankan, C. Artificial Lift Techniques in China, SPE 14866
1986.
23. Saputelli, L. Combined Artificial Lift System An Innovative Approach,
SPE 39041 1997.
24. Stair, C. D., Artificial Lift Design for the Deepwater Gulf of Mexico, SPE
48933 1998.
25. Valentin, E. P., Hoffmann, F. C. OPUS: An Expert Advisor for Artificial Lift,
SPE 18184 1988.
26. William B., Gargord, D. W.: High Capacity Artificial Lift Alternatives in the
Offshore Environment. European Offshore Petroleum Conference and
Exhibition 1978 SPE 8070.