Transcript No Slide Title

Cardinal Surveys Company
Eliminate The Guesswork!
Bringing conformance within reach
with proven technology.
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Cardinal Surveys Company
Choose your treatment success rate:
0 - 5%
Based on assumptions.
5 - 90%
Based on partial data.
+90%
Based on defined problems with solutions
proven on previous applications.
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Assumptions
We know, it has to be this!
It’s the only thing that
could cause that…
The model shows…
Probable Result:
Damage productive zones.
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Partial Data
Water Analysis - you know the zone, what’s the flow path?
Production History / Correlation - Flow path, parts is parts?
Bond Logs - Good until the first stimulation.
Injector Response - flow path, vertical fractures, offset wells...
Pump In Tracers without Production Logs - Path of least
resistance, usually the good productive zone.
OR
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Call Wylie’s Psychic Logging Service
Don’t take the blame, we will!
Cheap Rates
REAL CHEAP
Impress Your Boss
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Step Rate Test
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Determine fracture point
Reservoir protection
Regulatory compliance
Can’t be estimated or based on assumptions
May be most vital of all diagnostics
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Step Rate Test
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Uniform Steps (Rates and Times)
Down-hole, real-time pressure measurement
Accurate flow rate measurment
Recording and filtering of data
Prepare well (shut in, water source)
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Define The Problem
(Locate Production)
TRAC-III to determine conformance problem.
A.
Annulus Logging with 7/8” O.D. Tools.
B.
Flowing Wells
C.
“Y” Tool & Submersible Pump (7/8” Tools).
D.
Memory PLT (Horizontal Applications).
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Annulus TRAC-III Production Logging With 7/8” O.D. Tools
Tracer Velocities
Temperature Logs
Collar Locator
Gamma Ray
Capacitance
Pressure
Caliper
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Annulus Logging Candidates
4.5” Casing & 2.375” Tubing
5.5” Casing & 2.875” Tubing
Or any combination of larger casing and
smaller tubing.
No liners or other restrictions in the annulus.
ROT: 100 BPD of produced fluids.
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Trac III Production Logs
• Dynamic, producing (e.g., actual or "real-time")
conditions.
• Temperature log.
• Capacitance log.
• Radioactive tracer log.
• All logs can be run simultaneously during one trip
in the well.
• 5 1/2 inch casing and 2 7/8 inch tubing.
• 4 1/2 inch casing and 2 3/8 inch tubing.
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Trac III Production Logs
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Positive monitoring of reservoir performance .
Detailed, zone-by-zone, information.
Changes in the down-hole conditions detected.
Reevaluate marginal production wells.
Rework watered-out or gassed-out wells.
Recompletion of unproductive offset wells.
Essential guidance for remedial-workover designs.
Cost-effective well recompletions.
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Trac III Production Logs
• Improved completion techniques for future wells.
• Immediate verification of perforation efficiency .
• Positive identification of the actual production
intervals.
• Confirmation of open hole log analysis and
assumptions used in the initial completion.
• Pinpoint mechanical problems.
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Trac III Production Logs
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Document baseline production profile for future reference.
Optimize pump placement.
Discover unwanted water sources for remedial procedures.
Correlate production results with injection profiles for
sweep efficiency of floods.
 Confirm engineering and geological assumptions and
analysis.
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Trac III Production Logs
 Verify stimulation job effectiveness and techniques.
 Plan accurate placement of mechanical isolation tools
(bridge plugs and packers.)
 Locate thief zones and undesirable cross-flows.
 Real-time snap shot of production well.
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7/8” O.D. Tool Lengths
Rope Socket (15" - 5/8" fishing neck)
Capacitance Tool (40")
Caliper (69")
Collar Locator (28.5")
Scintillation Gamma Ray Detector (60")
Microprocessor Controlled Ejector (75.5")
Temperature Tool (37")
Memory Pressure Gauge (14”)
Total Tool Length with crossovers = 30’
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Annulus TRAC-III Preparation
•Pull Tubing
•Remove Anchor
•Set Pump 100’ above Perfs
•Dual Completion Flange
•Small Pumping Tee
•Slimline Stuffing Box
•Remove Bridal Guard
•Vertical Clearance Above
Annulus Opening
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Dual Completion Flange
Top View
Side View
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Hand Packoffs
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Dual Head
Configured
&
Pump Is Engaged
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4.5” Casing & 2.375” Tubing
Note that there is not enough room to
install a valve on the annulus opening.
These flanges are specifically
designed for logging in 4.5” casing.
A dual completion flange, if there is
such, would not allow enough room
in the annulus for tool entry.
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TRAC-III Below Submersible Pump
Y-Tool Assembly
•Well must have 7” casing to accommodate Y-tool.
•Shut-in well & allow fluid to fall below pump
•Fish out plug
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Y-Tool Accessories For Logging
Running
Plug
Baby Red
Prevents
fluids from
being
circulated
by pump.
Used to
retrieve plug
from Y-tool.
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TRAC-III Below Submersible Pump
Y-Tool Assembly
•Install running plug on wireline
•Lower TRAC-III Tools & Running Plug to “Y”
•Lower TRAC-III Tools below pump
•Engage pump to seat running plug
•Run logs when well is stable
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Memory PLT
•Horizontal wells are the primary application in the Permian Basin.
•No real time feedback allowing procedure modification to
maximize information.
•Most wellbore events in producers are not continuous. Your
economics must reflect the possibility of multiple runs to
accomplish some test objectives.
•Most companies that have access to memory tools do not consider
production logging a core business.
•Great weapon, for the right battle!
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Production Logging Tidbits
There are no silver bullets in the
production logging industry.
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Production Logging Tidbits
Production logging for conformance
objectives is an investigative process.
It requires the knowledge, experience,
and authority to change the logging
procedure as needed to define anomalies
as they are encountered during the log.
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Production Logging Tidbits
Avoid the intentional design of tests that
rely completely on nuclear based data
acquisition. Their maximum radius of
investigation is approximately 24 inches
from the sensor.
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Production Logging Tidbits
In production logging, temperature logs are the center of
your universe.
They are always correct, although sometimes hard to
interpret by themselves.
Use data acquired from others sensors to help you interpret
the temperature logs.
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!We Want You On Location!
• Production logging is
an investigative
process
• Your knowledge of the
lease can make the
difference between a
good survey and a
great survey
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Correlation Logs
Logs used to align logging depths to
previously run open hole and cased hole
logs.
Avoid the LAST LOG SYNDROME. It
is generally acceptable for most production
logs to be within 2 to 3 feet of measured
depth. However, if you are on the 4th or
5th generation of logs, you may be
correlating 10’ to 15’ off depth. Always try
to use the original open hole logs or the
logs used to perforate the well.
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Temperature Logs
Producing temperature logs tend to
reflect in wellbore and near wellbore
events.
Shut-in temperature logs indicate events
outside the wellbore.
You must know the status of the interior
of the wellbore before you can interpret
shut-in temperatures.
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Capacitance
•Fluid Identification
•Calibrate between water and gas.
•Capacitance VS. Density Tool
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Tracer Velocities
Modified Velocity Profile Measurement
Production fluctuations do not affect
the calculations as severely as
stationary velocity shots.
Same velocity method is used in
flowing wells.
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Tracer
Velocities
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Caliper
•Measures internal diameter of wellbore.
•Gives general picture of conditions.
•Improves velocity calculations and profile.
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Merged
Log
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Example #1
•Rod pump well in S.E. New Mexico
•Was producing 30 oil, 60 water, and 0 gas.
•New perfs (upper set) added.
•Current production: 200 water, 0 oil, and 0 gas.
•Pump & tubing anchor set at mid perf.
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Example #1 – Customer Designed
Procedure
•Set PKR above top perf for PIT and pressure test.
•Well casing held 500 psi above PKR.
•Logs indicate water and porosity in upper set.
•Customer is certain water source is in new zone.
•Run PIT for cement squeeze design.
•Economics will only allow one attempt at fixing the problem.
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Example #1 - Cardinal Recommendation
•POOH & remove PKR.
•Set EOT 100’ - 200’ above top perf.
•Configure surface equipment for an Annulus TRAC-III.
•Determine water source and flow path to wellbore.
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Example #1 - Cardinal Results
Leak in CSG 400’ above top perf producing +300 bpd
water. Leak is at a collar and will give up water, but not
take water.
Pump removing +/- 200 bpd water to surface.
The new zone dead. It is not giving up or taking fluid.
Productive zone is taking 100 bpd water, crossflow
from leaking casing.
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? What If ?
Which zone do you believe would have been
squeezed had we followed the original request?
What if water was channeling up from below and
into the bottom set of perfs?
What if water was being produced from the new
zone? What would be the likely series of events?
End Result: LOST WELL
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Design The Solution
(Locate Loss Profile)
Pump-In Tracer or Injection Profile.
A.
Stationary Velocity Profile.
B.
Intensity Profile
C.
Channel Checks
D.
Crossflow Checks
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Injection Profiles - Why?
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Determine where fluids are going.
Check mechanical integrity of well bore.
Verify conformance to formation porosity.
Locate channels.
Check perforations.
Check fill.
Find scale and build-up.
Discover holes or unreported perforations.
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Injection Profiles - Objectives:
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SAFELY
Accurate and Quantative
Detect Mechanical Problems
Detect Channels
Minimize Risk to Well
Perform economically without sacrificing quality.
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Injection Profile Log - Components
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Radioactive Tracers
Spinner Logs
Temperature Logs
Caliper Logs
Collar Logs
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Injection Profile Log - Logs
• Injecting Temperature Log
• Two Radioactive Tracer Logs
– The Intensity Profile
– Series of Stationary Velocity Measurements
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Channel Checks
Packer Check
Shut-In Temperature Logs
Cross-Flow Checks
Caliper Log
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Injection Profiles - Preparation: Operator
• Review well records.
• Prepare a wellbore diagram:
– Current condition of the well.
– Significant past factors and changes.
– Well bore equipment (depths, i.d.):
• Casing, liners, tubing, packer(s), plugs, casing
shoe(s).
• Downhole control valves (mandrels).
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Injection Profiles - Preparation: Operator
• Well configuration:
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Perforations.
Open hole intervals.
Plugged or squeezed zones
Known thief zones, channels, and other known areas of
possible fluid loss should be indicated.
• Well head:
– Height.
– Connection required.
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Injection Profiles - Preparation: Operator
• Unusual conditions:
– Remote injection control valves.
– High pressures (above 2000 PSI).
– Safety hazards (hydrogen sulfide).
– Restrictions or modifications to normal
procedures.
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Injection Profiles - Preparation: Operator
• Lease and well data:
– Maps with locations, roads, and plants.
– Tabulation of injection rates and pressures.
– Depth correlation logs (primary log, gamma ray,
collar log).
– Previous profile(s).
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Injection Profiles - Preparation: Operator
• Preparation of the well for survey:
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Tubing or tail pipe 50' above the top perforation or shoe.
Full opening valve.
Stable rate 48 hours.
Slick line sinker bar run and T.D. check.
Rate meter and pressure gauge.
– Install crown valve
– Test valves and tree.
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Injection Profiles - Preparation: Operator
• Information needed at the well site:
– Maps with locations, roads, and plants.
– Tabulation of injection rates and pressures.
– Depth correlation logs (primary log, gamma ray, collar
log).
– Well diagrams.
– Previous profile(s).
– MSDS as required.
– Well history and recent workovers.
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Logging Tools
•Scintillation Detector
•16” to 24” radius of investigation
•Geiger Detector is 80% less
•O-ring sealed Ejector Port
•Temperature Tool
•0.1 degrees F resolution
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Injection Profiles - Procedures:
Logging Procedure
• Logging procedure:
– Injecting temperature survey.
– Gamma-ray and collar log.
• Correlate to log provided.
– Gamma-ray base log.
• (Reduced sensitivity)
– Caliper survey.
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Injection Profiles - Procedures:
Logging Procedure
• Logging procedure:
– Intensity profile.
• (One “Slug” of radioactive material.)
– Velocity profile.
• (Multiple stationary readings.)
– Downward channel check, if applicable.
– No Flow check, if applicable.
– Upward channel check (shoe or top perf.)
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Injection Profiles - Procedures:
Logging Procedure
• Logging procedure:
– Packer check.
– Tubing drop shots.
• (Verifies meter rate.)
– Check injection rate and record.
– Shut-in temperature surveys as required.
– Crossflow checks.
• (Necessary to interpret Shut-in Temps.)
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Velocity Profile
• Pi x r2 x h = Volume of a cylinder
• Pro’s:
– High resolution of data points
– Limited by the spacing from ejector to detector
• Con’s:
– Minor plant fluctuations effect calculated rates
– I.D. changes have a drastic effect on the
calculated rates
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Calculations and Interpretations:
Volumetric Flow Rates
• Volume = PI x Dia^2 / 4 * L
• Volumetric Flow = Vol / Time
Diameter
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Calculations and Interpretations:
Application of Volumetric Rates
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Tracer Elapsed Time Runs
Stationary Velocities
Spinner Flow Meters
Tubing Drop Shots
Crossflow Checks
Production Log Velocities
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Data Acquisition
A slug of radioactive I-131 is
released from the ejector and
the travel time is recorded till
arrival at the detector.
The volume of the cylinder
and the time of travel is used
to calculate a Barrel Per Day
rate.
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Velocity Shot Example
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Velocity Profile
• Most popular survey method
• Seldom the best
• 5.5” Casing Examples:
– 0.25” build up results in a 10.69% error
– 1.0” build up results in a 39.41% error
• You must have a caliper log for an accurate
stationary velocity survey.
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Calculations and Interpretations:
Caliper Log - Required!
In standard 5 1/2” Casing:
• A 1/4” buildup = 11% Error!
• A 1” buildup = 39% Error!
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Injection Profiles
Example Calculations
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I.D. = 4.96”
Reaction Time = 26.5 sec.
Tool Spacing = 5 ft.
Calculated velocity = 0.189 ft/sec
Calculated volumetric flow = 0.0252 cu.ft./sec
Flow = 388 BPD
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Intensity Profile
• Pro’s:
– Not adversely affected by hole size changes
– Not affected by plant fluctuations
– Gives visual representation of flow patterns
• Con’s:
– Less resolution of data points
– Limited by velocity of fluid and wireline speeds
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Data Acquisition
One large slug of I-131 is ejected
above the zone of interest. Multiple
gamma ray passes are made up
through the slug as it travels down
hole.
Losses of radioactive material from
the slug represent the amount of
injection lost in those same areas.
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Intensity Profiles
• Resolution of 20’ to 50’ between data points
– Velocity of injected fluid
– Mechanical limitations of wireline speed
• Resolution enhanced by Velocity Profile
• Usually the best profile method
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Calculations and Interpretations:
Intensity Profile
• Tool configuration - one scintillation
detector located below the ejector.
• Readings are made versus depth.
• Radioactive material is ejected ("slug")
above the perforated or open hole interval.
• Tools lowered approx. 20 ft. below slug,
and logged through slug ("drag run").
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Calculations and Interpretations:
Intensity Profile
• Repeat and catch slug at frequency adequate
to determine fluid loss.
• Slug logged at the constant speed.
• Repeat until slug stops moving or is lost to
formation.
• Loss calculations from area under curve
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Calculations and Interpretations:
Intensity Profile
• Quantified loss profile
• Bottom of injection movement (or loss
below L.T.D.)
• Possible channeling outside casing
• Possible holes in pipe or other mechanical
problems.
• Independent of wellbore diameter changes.
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Intensity
Profile
(“Drag Run”)
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•Temperature Logs can not distinguish
between events occurring inside, or
outside the wellbore
•Injection Temperatures show the bottoms
of fluid losses and major velocity changes
•Shut-in Temperatures indicate the tops of
events and give a relative magnitude of
fluid storage
•Injecting and Shut-in logs merging
indicate the absolute bottom of fluid
movement
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Injection
Temperature
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Cross Flow Checks
Slugs of I-131 are ejected above,
between, and below the zones.
Multiple runs are pulled though all
the slugs to determine if the is fluid
is migrating between zones in the
wellbore.
You must know the state of the well
to interpret shut-in temperatures.
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Caliper Log
Log Interpretation
Intensity Profile
Velocity Profile
Temperature Logs
No Flow Shot
Channel Check
Crossflow Check
http://www.cardinalsurveys.com
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Mult-Rate Injectivity Test
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Variable conditions / pressures
Entries (losses) variable
Accurate placement of chosen solution
Determine treatment issues / problems
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Example #2
Mechanical Isolation
Customer has flowing gas well in West Texas
Well has been acidized and fraced
Current Production Rate: 10 oil, 600 water, & 6MMcf gas
Test Objective: Reduce water without losing gas production
Production Log Indicates:
Water entry at bottom perfs with channel from below
and a minor oil entry
Additional oil entry at mid-perfs.
Major gas entry at top perfs.
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Example #2 - Recommendation
Isolate bottom perfs for mult-rate injection profile test.
Set PKR just below mid-perfs to allow maximum room to
monitor any injected fluids channeling up hole toward gas
zone.
Establish an envelope of rates and pressures that will keep
treatment chemicals in desired intervals.
Rates established in the envelope will allow calculations for
the selection of treatment chemicals, catalyst, and other
factors needed to place and set a successful treatment.
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A
B
C
D
Results
A. .25 bpm
B. .50 bpm
C. .75 bpm
Potential Problem
D. 1.0 bpm
Unacceptable
Rate must remain
below .5 bpm to keep
treatment in target
zone.
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? What If ?
•We need more rate. Timing factors on the catalyst for
most successful treatment in these situations requires a
shorter pump time.
•There is no envelope of rates and pressures to keep the
treatment in the desired interval. All rates and pressures
reach the good zone.
•WE NEED MORE OPTIONS
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Mechanical-Hydro Isolation
Same well and mechanical configuration
Inject water down tubing and tubing annulus
simultaneously
Vary rates and pressures to establish an acceptable
envelope
Special Consideration:
How much, if any, water can be injected into
primary pay without causing irreversible
damage?
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Hydro Isolation - Interface Logging
Forgotten Technology
•One of the first injection profiles ever conceived
•Still the most accurate injection profile known
•Developed for shot hole wells
•Resolution is limited only by pumping and metering equipment
at the surface
•More expensive than standard profile services due to time
•Technically the best logging application for pre-treatment, real
time monitoring during treatment, and real time monitoring the
curing period of conformance treatments.
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Well Configuration
Run blank tubing to just above PBTD
Rig up pump trucks to casing and tubing
Rig up Cardinal Tagmaster to inject I-131 into
casing line
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Interface
Logging
•Various Rates
•Real Time
Feedback
•Position & Stabilize
•Adjust Treatment
•Pre-job
•During Job
•Post Job
Containment
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Conclusions
Production logging can be used to screen wells for
conformance treatments by identifying wells with potential
for success or ultimate failure.
Production logging gives accurate data that can be used to
formulate, monitor, and keep conformance treatments in
the intended interval.
Conformance treatments can be greatly enhanced with the
use of proper production logging techniques and equipment
DON’T GUESS…… KNOW!
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Example Logs
• Coal Seam Annular Log
• Flowing Production Log
• Spectral Gamma Ray / Multi Iso Tracer
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