Cardinal Surveys Company

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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! Its 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, whats 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 Wylies Psychic Logging Service
Dont take the blame, we will!
Cheap Rates
REAL CHEAP
Impress Your Boss
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Step Rate Test

• Determine fracture point
• Reservoir protection
• Regulatory compliance
• Cant be estimated or based on assumptions
• May be most vital of all diagnostics

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Step Rate Test

• 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

• 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

• 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
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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
Baby Red
Running Plug
Used to retrieve plug from Y-tool.
Prevents fluids from being circulated by pump.
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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. Stationar
y Velocity Profile. B. Intensity
Profile C. Channel Checks D. Crossflow Checks
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Injection Profiles - Why?

• 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

• 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

• 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
• 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
• 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
• 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
• Pros
• High resolution of data points
• Limited by the spacing from ejector to detector
• Cons
• Minor plant fluctuations effect calculated rates
• I.D. changes have a drastic effect on the
  calculated rates

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Calculations and InterpretationsVolumetric Flow
Rates

• Volume PI x Dia2 / 4 L
• Volumetric Flow Vol / Time

Diameter
Length
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Calculations and InterpretationsApplication of
Volumetric Rates

• 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 InterpretationsCaliper Log -
Required!

• In standard 5 1/2 Casing
• A 1/4 buildup 11 Error!
• A 1 buildup 39 Error!

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Injection ProfilesExample Calculations

• 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

• Pros
• Not adversely affected by hole size changes
• Not affected by plant fluctuations
• Gives visual representation of flow patterns
• Cons
• 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 InterpretationsIntensity
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 InterpretationsIntensity
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 InterpretationsIntensity
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
Channel Check
No Flow Shot
Crossflow Check
http//www.cardinalsurveys.com
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Mult-Rate Injectivity Test

• 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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Results
A
B
C
D
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 DONT GUESS
KNOW!
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Example Logs

• Coal Seam Annular Log
• Flowing Production Log
• Spectral Gamma Ray / Multi Iso Tracer