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Presentacion REGISTROS PLT DE LA lOGGING SCHOOL.ppt
- 1. 1 Production Logging School ProductionLogging School
- 2. 2 Production Logging CourseTopics Production Logging Course Topics Applications Multi-phase Flow Profiling Well Diagnostics Terminology Measurement Principles Logging procedures -- Job design Qualitative Analysis techniques Quantitative Analysis
- 3. 3 Sub Topics Sub Topics Well Completions, Workovers and Stimulation Production Logging in Horizontal wellbores New Technologies Reservoir Characterization and Simulation
- 4. 4 General Applications andBenefits General Applications and Benefits Improve well and field production Verify or update reservoir model Evaluate effectiveness of drilling and completion processes Monitor EOR project Identify and locate production problems
- 6. 6 Wellbore Low Permeability Low Permeability HighPermeability Intermediate Permeability Water break through -- Fingering Water break through -- Fingering
- 7.
- 8. 8 Bad Cement Job OilZone Casing Leak Wellbore High-Pressure Gas Zone Channeling or Casing Leak Channeling or Casing Leak
- 9. 9 Reservoir Monitoring Reservoir Monitoring Production Profiling Oil, Water and Gas production rates at each entry Identify actual formation intervals producing desired products. Identify formation intervals that are under performing Identify formation intervals producing unwanted products Locate thief zones
- 10. 10 Reservoir Monitoring Reservoir Monitoring Pressure Transient Analysis Determine Reservoir permeability pressure skin damage Identify Reservoir Boundaries
- 11. 11 Reservoir Monitoring Reservoir Monitoring Formation Evaluation Determine Oil, Gas and Water Saturation's Identify and monitor Gas/Oil, Gas/Water and Oil/Water contacts
- 12. 12 Reservoir Monitoring Reservoir Monitoring Diagnostics Unusual change in production Channeling Tubing, Packer, Plug, etc. leaks Casing and cement squeeze failures
- 13. 13 Terminology Terminology Holdup Cut Slip Velocity
- 14. 14 Holdup Holdup The Gas,Oil or Water fraction occupying the borehole The Gas, Oil or Water fraction occupying the borehole Y Y Y Y Gas Water Gas Water 1 0 02 08 . . Y Y Y Y Gas Water Gas Water 1 0 0 1
- 15. 15 Cut Cut Fraction ofTotal production: Water cut = BWPD/Total BPD Fraction of Total production: Water cut = BWPD/Total BPD Y Y Y Y Gas Water Gas Water 1 0 02 08 . . Y Y Y Y Gas Water Gas Water 1 0 0 1 Gas Cut = 1 Water Cut = 0 Water Cut = 0
- 16. 16 Slip Velocity Slip Velocity Lowdensity gas rises quickly through a water column. The difference between the water velocity and the gas velocity equals the slip velocity. Slip Velocity Velocity Velocity Gas Gas Water The equation is the same for Slip VelocityOIL
- 17. 17 Production Logging Instruments ProductionLogging Instruments Velocity Measuring Instruments Fluid Identification Instruments Auxiliary Instruments Reservoir Evaluation Instruments
- 18. Monocable Telemetry/CCL/ Power Supply Gamma Ray X-YCaliper Roller Centralizer PRISM Fluid Salinity Water Holdup Indicator (Fluid Capacitance) Differential Pressure Fluid Density Radiation Fluid Density Roller Central. Temperature Basket Flowmeter Temp.-Press. Combination Hewlett-Packard Pressure Continuous Spinner Flowmeter Folding Impeller Flowmeter Typical Production Logging Tool String Computerized Logging Unit
- 19. 19 Velocity Measuring Instruments VelocityMeasuring Instruments Continuous Spinner Flowmeter Folding Impeller Flowmeter Basket Flowmeter
- 20. 20 Applications Applications Provide velocityprofile for quantifying volumetric flow. Detect low pressure thief zones (Best when well is shut in) Detect Packer, Plug, etc. leaks Detect Casing and Squeeze Cement failures Monitor changes in profile with timelapse surveys Quantitative measurement of flow rate where it is unknown or uncertain Compensate for wellbore storage effects during early time pressure buildup / drawdown surveys
- 21. 21 Advantages -- BasketFlowmeter Advantages -- Basket Flowmeter The Basket measures low flow rates in large diameter pipes. The Basket diverts and mixes flow to get a better mixture velocity response. Will measure positive RPS where the CSFM & FIFM will measure negative RPS from fallback. Still will respond negatively to fallback in some circumstances. Mixing of fluid helps the Fluid Identification measurements in Segregated flow.
- 22. 22 Basket Flowmeter --Logging Proc’s Basket Flowmeter -- Logging Proc’s Stationary measurements are made above and below fluid entries. Stationary measurements have a threshold of 50 to 100 BPD fluid production. A continuous up run with an open Basket Flowmeter provides a lower threshold and more discretely identifies the depth of fluid entries.
- 23. 23 Limitations -- BasketFlowmeter Limitations -- Basket Flowmeter When flowrates exceed 3000 barrels of liquid per day an alternative Flowmeter device should be considered. Rates of up to 3500 to 4000 BPD have been logged in 9-5/8” casing. 16,000 plus BGPD, 79 BWPD in 7 inch casing. 80 RPS basket response (Upper limit approx. 200 RPS) Typical restriction limitation is 1.81 inch S.N. Have logged through 1.79 inch S.N. by removing every other Basket petal.
- 24. 24 Measurement Principles Measurement Principles The spinner instruments incorporate an impeller that is rotated by a moving liquid or gas. The speed of the impeller rotation is recorded in revolutions per second (RPS)
- 25. 25 Qualitative Interpretation Qualitative Interpretation Plug leak Casing, Tubing leaks Fluid Interface (Identified with up and down run)
- 26. 26 Quantitative Interpretation Quantitative Interpretation QVelocity ID BPD ft inches Cross Section Area /min . 14 2 V V CF Average Measured Model 1 Model 2 Model 3 Folding Impeller Flowmeter Continuous Spinner Flowmeter Basket Flowmeter
- 27. 27 Velocity Profile Velocity Profile V= O at Pipe Wall Vf V V Vf Laminar Flow Turbulent Flow
- 28. N Vd V RE = fluiddensity, g / cc average fluid velocity, cm / sec d = pipe ID, cm = fluid viscosity, poise CF of 0.83 is commonly used in high rate production.
- 29. 29 Method 1 Method 1 %TotalFlow RPS RPS RPS RPS RPS RPS at flow RPS RPS at flow RPS RPS Measured Meas Meas 0 100 0 0 100 100 0% 100%
- 31. 31 Method 2 Method 2 RPS CableVelocity (Threshold Velocity) Calibrating The Spinner RPS vs. Cable Speed 2v t
- 32. 32 Typical CSFM ResponseCurve Typical CSFM Response Curve V CSF Response, RPS VT
- 33. 33 Method 2 Method 2 P o s i t i v e R o t a t i o n L i n e Maximum FluidVelocity, Vf With Flow RPSo Negative Rotation Line 2 X VT VT S t a t i o n R e s p o n s e C u r v e Against Flow Cable Velocity, ft/min Station R PS-C able Velocity C urve
- 34. 34 Method 2 Method 2 30 20 10 - 120 -80 4 0 8 0 1 2 0 1 6 0 2 0 0 2 4 0 2 8 0 3 2 0 3 6 0 WithFlow Against Flow Cable Velocity, ft/min RPS Station 1 Station 3 Station 2
- 35. 35 Method 3 Method 3 V RPS m VCable Velocity V Maximum fluid velocity ft m Slope of response curve RPS ft V Threshold velocity ft f Meas Threshold Meas f Threshold , / min , / / min , / min
- 36. 36 Fluid Identification Instruments FluidIdentification Instruments Radioactive Fluid Density Fluid Capacitance (Water Holdup Indicator) Differential Pressure Fluid Density Non-Focused Density (Photon)
- 37. 37 Applications Applications Provide densityprofile in multi-phase production well with FDN and DPFD Compute two phase holdup fractions in Gas/Water and Oil/Water production wells with FDN,FCAP or DPFD Compute three phase holdup fractions using (FDN or DPFD) with FCAP data Locate hydrocarbon entry points. Locate water entry points Locate borehole fluid contacts Locate product levels in storage wells Locate tubing and casing leaks when the leaks affect wellbore holdup Check the operation of gas lift valves
- 38. 38 Advantages Advantages The FDNMeasures mixture density in horizontal conditions The DPFD does not work in highly deviated wellbores The FCAP and DPFD are un-affected by background radiation. The FCAP measures water holdup in two or three-phase flow.
- 39. 39 Measurement Principles --FDN Measurement Principles -- FDN The Fluid Density instrument incorporates a collimated Gamma Ray source and Gamma Ray Detector separated by a window in the instrument that is open to the wellbore fluids. The Gamma Rays must travel through the wellbore fluids. The number of Gamma Rays detected, counts per second (CPS), are inversely related to the Density of the wellbore Fluids. The relationship is accurately established by calibrating in air and water.
- 40. 40 Fluid Density Fluid Density Detector GammaRays Source Sample of Wellbore Fluid Water = +/- 1.0 g/cc Oil = +/- 0.8 g/cc Gas = +/- 0.2 g/cc
- 43. 43 Measurement Principles --FCAP Measurement Principles -- FCAP The Fluid Capacitance functions as a variable capacitor. It is constructed with two surfaces acting as the plates of the capacitor with the wellbore fluid between these surfaces. The capacitance is related to the dielectric constant of the fluid between its’ plates. The capacitance influences the output frequency of a pulse generator. Therefore the measured pulse frequency is related to the dielectric constant of the fluids.
- 44. 44 Fluid Capacitance Fluid Capacitance Sensor Sampleof Wellbore Fluid Water = +/- 2000 Hz Oil = +/- 4000 Hz Dielectric Constants Water = 78, Oil = 4, Gas = 1 Tool Frequency Response Water: 2000 -- 3000 Hz Hydrocarbon: 3500 -- 4500 Hz Span approximation: 2000 Hz
- 45. 45 Measurement Principles --DPFD Measurement Principles -- DPFD The Differential Pressure Fluid Density measures the wellbore pressure at two points a fixed distance apart. The difference in the measured pressures is a function of the wellbore fluid density and the True Vertical Distance between the sensors.
- 46. 46 Differential Pressure FluidDensity Differential Pressure Fluid Density Sensor Port Differential Pressure Transducer Sensor Port Average Density of Sample of Wellbore Fluid
- 47. 47 Measurement Principles --NFD Measurement Principles -- NFD The Non-Focused Density is similar to the Fluid Density. It utilizes a Gamma Ray source that radiates outside the body of the instrument. The measured countrate is influence by surrounding borehole fluid density, hardware and possibly formation. The interpretation must consider hardware and formation effects.
- 48. 48 Quantitative Interpretation --FDN Quantitative Interpretation -- FDN Y Y Y Y Heavy Phase Holdup Y Light Phase Holdup Heavy Phase D Light Phase D H L H Mixture L H L H L H L 1 ( ) ( ) ensity ensity
- 49. 49 Quantitative Interpretation --FCAP Quantitative Interpretation -- FCAP Dielectric Constants Response Water Oil Gas F F F F Mixture Hydrocarbon Water Hydrocarbon 78 4 1 100 , , % ( ) ( ) Use Fluid Capacitance chart to determine Water Holdup
- 50. 50 FCAP response chart FCAPresponse chart 0 20 40 60 80 100 Water Holdup (%) Instrum ent Response (% ) 6.5 in. Test Section 0 20 40 60 80 100
- 51. 51 FCAP Response Chart-- Proflo FCAP Response Chart -- Proflo 0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1 0 0.068 0.1372 0.236 0.3064 0.3864 0.468 0.581 0.725 0.926 1 Water Holdup Instrument Response
- 52. 52 Three-phase Holdup -FCAP&FDEN Three-phase Holdup -FCAP& FDEN 1) Determine Y From Fluid Capacitance 2) from Eq.1 & 2 3) H Eq. 1. . Y Y Y Y Y Y Y Y Y Y Y H L I Mixture H H L L I I I Mixture L H L H I L L I H Eq 1 1 2
- 53. 53 Auxiliary Instruments Auxiliary Instruments Temperature Tracer / Flo-Log Hydrolog Sonan -- Noise Log
- 54. 54 Temperature Applications Temperature Applications Locate Gas and Liquid entry points Detect channels Locate leaks -- Plug, tubing, etc Detect casing and squeeze cement failures Injection profile Evaluate Injection operations -- Acid, Fracture, etc. Locate cement top by detecting heat of hydration from curing cement Locate lost circulation and downhole blowout zones
- 55. 55 Measurement Principles Measurement Principles The Temperature instrument uses a Platinum Resistance Temperature Detector (RTD). The RTD resistance changes with changing wellbore temperature.
- 56. 56 Qualitative Interpretation Qualitative Interpretation Geothermal Gradient Typical gradients are between: 0.5 deg.F/100ft. and 2 deg.F/100ft. This is dictated by the thermal conductivity of the formations and the proximity to geothermal energy.
- 57. 57 Interpretation Process Interpretation Process InvestigationPhilosophy Document all facts and observations Start at bottom of the log Locate first point of fluid movement Identify all active intervals (Entries, anomalies, etc.) Temperature log 1st. Then confirm and add zones interpreting Additional curves one at a time. Production or thief zone Water, Oil or Gas Identify no flow zones Develop flow model that does not violate any of the know facts or observations
- 58. What type ofproduction is associated with this Temperature profile? Geothermal Gradient
- 59. What type ofproduction is indicated by this production temperature curve. Bottom Zone? Liquid / Gas Top Zone? Liquid / Gas Geothermal Gradient
- 60. 60 Liquid Production TemperatureProfile Different Lengths of Production Times
- 61. 61 Liquid Production TemperatureProfile Different Flow Rates 200 BPD 400 BPD 800 BPD Geothermal
- 62. 62 Liquid Producer: ExampleTemperature Log
- 63. Both wells producefrom the same platform and same reservoir. One produces 11 MMcf/day and the other produces 1.1 MMcf/day. Select which well produces each rate and explain what might cause these differences. Geothermal Gradient Geothermal Gradient
- 64. Draw a flowingTemperature curve that best represents this liquid production condition. What would gas production look like? Geothermal Gradient
- 65. Draw a flowingTemperature curve that best represents this channel condition. Assume water production only. What would gas production through the channel look like?
- 66. Draw a flowingTemperature curve that best represents this channel condition Assume water production only
- 67. Draw a Temperaturecurve that best represents this injection condition. Assume water injection only. Geothermal Gradient
- 68. Draw a seriesof shut-in Temperature curves that best represents this injection condition. Assume water injection. Geothermal Gradient Injection Gradient
- 69. FDEN What is eachzone producing? Assume only OIL or GAS. 0.0 gm/cc 1.0 gm/cc
- 70. FDEN TEMP What is eachzone producing? Assume only OIL or GAS. 0.0 gm/cc 1.0 gm/cc
- 71.
- 72. 72 Sonan Applications Sonan Applications Locate small leaks where other services cannot. Detect flow behind or inside casing Detect channels Locate leaks -- Plug, tubing, etc Detect casing and squeeze cement failures Locate lost circulation and downhole blowout zones
- 73. 73 Measurement Principles Measurement Principles The Sonan instrument uses a sensitive ceramic microphone to monitor sounds generated by moving fluid or gas.
- 74. 74 Qualitative Interpretation Qualitative Interpretation There are two primary things that affect the measured sound energy. Pressure drop dictates the source sound level Attenuation decrease the source sound level as the sound travels through surrounding medium to the microphone. Sound attenuates more in gas than in liquid. High acoustic impedance contrasts reflect the sound signals reducing the transmission of the sound energy.
- 78. 79 Tracer Flo-Log Applications TracerFlo-Log Applications Injection and Production Profiles Detect channels Locate leaks -- Plug, tubing, etc Detect casing and squeeze cement failures Locate lost circulation zones
- 79. 80 Measurement Principles Measurement Principles The Tracer instrument uses one or two gamma ray detectors. It has an internal reservoir that is filled with a radioactive Oil, Water or Gas soluble fluid. A motor is used to displace small amounts of radioactive liquid into the wellbore fluid. This is monitored by the gamma ray detectors in two different ways. The RA material can be monitored with multiple logging passes. The velocity of the RA material is measured with stationary recording of the travel time between detectors.
- 81.
- 83. 84 Hydrolog Applications Hydrolog Applications Detect flow behind or inside casing Detect channels Locate leaks -- Plug, tubing, etc Detect casing and squeeze cement failures Provide water velocity profile Can be used in production or injection wells
- 84. 85 Measurement Principles Measurement Principles The Hydrolog instrument incorporates a linear accelerator for producing 14 MeV neutrons. The interaction of the neutrons with oxygen in the water produces a radioactive isotope with a half-life of 7.13 seconds. This radioactive tracer produces gamma rays with energies of 6.13 MeV and 7.12 MeV that are detectable by two gamma ray detectors positioned above the neutron source. Movement of the radioactive water past the gamma ray detectors causes an increase in the measured gamma ray countrates. From the increase in countrate at each detector the water velocity can be determined.
- 85. Detectors Casing & Cement Measurements -Inelastic Gamma Rays - Capture Gamma Rays - Activation Gamma Rays LS S SS Pulsed Neutron Source (14 MeV) Frequency = 1 KHz Pulsed Neutron Logging PDK-100 Hydrolog, Annular Flow Log, Carbon/Oxygen, PNHI
- 86. How do youknow if this is a channel or a plug leak? What instruments would identify a channel or plug leak from a water zone 20 ft. below the production perforations? FLOWING TEMPERATURE GEOTHERMAL GRADIENT SONAN 200 Hz Hydrolog
- 87. 92 Mathematical Models affecting OxygenActivation Measurements: Velocity equation for continuously pulsed Oxygen Activation Instruments. V D D C C V abs inst 2 1 1 2 ln Vabs = Absolute Fluid Velocity (ft/min) = Decay Constant (1/min) D1 = source to Detector 1 spacing (ft) D2 = source to Detector 2 spacing (ft) C1 = Countrate for Detector 1 (cps) (above background) C2 = Countrate for Detector 2 (cps) (above background) Vinst = Instrument Velocity
- 88. 93 Prism Applications Prism Applications Evaluate Hydraulic Fracturing Treatments Evaluate chemical stimulation's Evaluate cement squeeze operations Evaluate gravel pack operations Evaluate effectiveness of diverting agents. Monitor any single or multiple stage injection operation.
- 89. 94 Measurement Principles Measurement Principles The Prism instrument uses a gamma ray scintillation detector to measure the energy of surrounding gamma rays. A pulse height analyzer produces a spectrum of the gamma rays. The spectrum is used to identify the source isotopes and concentrations.
- 90. Au196 Sb 124 Hydra ulic Frac ture Antimony-Ta gged Proppa nt G old-Ta gged Fluid (Pa d) Ir192 Sc 46 Iridium -Ta gged Proppa nt Sc a ndium-Ta gged Fluid (Pa d) Hydra ulic Fra c ture 0795DPRISM4
- 91. 96 Quantitative Interpretation Quantitative Interpretation QVelocity ID BPD ft inches Cross Section Area /min . 14 2 V V CF Average Measured Model 1 Model 2 Model 3 Folding Impeller Flowmeter Continuous Spinner Flowmeter Basket Flowmeter
- 92. 97 Aw Ag Ao Vw Vo Vg Flow Rate (Q)= Velocity x Area Flow Rate (Q) = Velocity x Area Area Area Y Area Area Y Area Area Y gas gas oil oil water water Q Velocity Area Q Velocity Area Q Velocity Area gas gas gas oil oil oil water water water Slip Velocity Models Holdup Models Voil Vwater Vgas Yoil Ywater Ygas Mixture Velocity Basket Flowmeter Continuous Spinner Fullbore Spinner Fluid Density Fluid Capacitance Differential Pressure FDN
- 93. 98 Slip Velocity Charts SlipVelocity Charts * * * * * * * * * x x x x x x x x 0 20 40 60 80 100 0 20 40 60 80 100 Water Holdup (%) Oil/water flow test 0 Degree 30 Degree Slip Velocity (ft/min) * * * * * * x x x x x x x x Gas/water flow test 0 degree 30 degree 0 20 40 60 80 100 Water Holdup (%) 0 50 100 150 200 Slip Velocity (ft/min) 0 0.10 0.20 0.30 0.40 0.50 0 10 20 30 40 Water Holdup Y = 1.00 H 0.95 0.80 0.90 0.70 0.60 0.40 0.50 0.30 (H - L) gm/cc Slip Velocity, ft/min 0.2 0.4 0.6 0.8 1.0 20 40 60 80 100 FPM YW Air (Light Phase Density = 0.001) Methane (D.H. Den. = 0.05 -- 0.15) Oil (Light Phase D ensity = 0.80) Density = 0.9 S lip Ve lo city 15 30 45 60 75 90 0 1 2 3 Correction for Deviation Multiplicative for Vs Deviation from Vertical
- 94. 99 Q Q(BPD) (BPD) = V =V(ft/min) (ft/min) x 1.4 x I.D. x 1.4 x I.D.2 2 (inches) (inches) Q Velocity Area Y Area I D Velocity Velocity V Velocity Velocity Y V gas gas gas gas water sg water Mixture gas sg 14 2 . . . Yg = 0.2 Yw = 0.8 Yg = 1 Yw = 0
- 95. 100 Q Q(BPD) (BPD) = V =V(ft/min) (ft/min) x 1.4 x I.D. x 1.4 x I.D.2 2 (inches) (inches) Q Velocity Area Y Area I D Velocity Velocity V Velocity Velocity Y V gas gas gas gas water sg water Mixture gas sg 14 2 . . . Yg = 0.2 Vsg = 100 Vmixt = 20 Yg = 1 Vsg = 0 Vmixt = 20 Qwater BPD 20 0 2 100 14 4982 08 0 2 . . . . Qgas BPD 20 14 4982 695 2 . . Qgas BPD 0 100 14 4982 0 2 695 2 . . .
- 96.
- 97. 102 Proflo Proflo Multiphase flowanalysis program Quantitative analysis of Production Logging data Flow rate profile across production interval
- 98. 103 Required Log Data RequiredLog Data Velocity Continuous Spinner Flowmeter Basket Flowmeter Folding Impeller Flowmeter Fluid Identification (Holdup) Fluid Density Fluid Capacitance Differential Pressure Fluid Density Bottom Hole Temperature and Pressure Measured Estimated
- 99. 104 Required Fluid Parameters RequiredFluid Parameters Oil -- Rate and API gravity Gas -- Rate and Specific gravity Water -- Rate and Density (PPM NaCl, gm/cc) Separator Temperature and Pressure If available from PVT analysis Bo, Bg, Bw, Pb, Rs
- 100. Bg, Bo, Bw,Pb, Rs
- 101. Instrument response 100% flowand 100% water PROFLO Process Down hole flow rates 100% flow Down Hole Calibration
- 102. Basket Flowmeter Continuous Spinner orFullbore Spinner Slip Velocity Model Fluid Density & or Fluid Capacitance Holdup Profile Velocity Profile Vmixture Vso, Vsg Yg, Yw, Yo
- 103. V V VY V Y V V V V V V w mixt sg g so o o w so g w sg Q V Y K Q V Y K Q V Y K w w w o o o g g g K ID 14 2 .
- 104. GAS GRAVITY =0.65 CONDENSATE RATE, STB/MMSCF = 717.00 OIL GRAVITY, DEG API = 29.9 WELLHEAD PRESSURE, PSIG = 5050.0 WELL CONFIGURATION DEPTH, FT TUBING I.D., IN. ANGLE (VERT), DEG XXXXXX. 2.441 0.00 XXXXXX. 2.441 32.00 XXXXXX. 2.441 28.00 PIPE ABS. ROUGHNESS, IN. = 0.00094 BOTTOM-HOLE TEMPERATURE, DEG F = 184. PRESSURE DROP CORRELATION: HAGEDORN AND BROWN FLOW RATE PWH NODE PRESSURE WELLHEAD TEMP MSCFD PSIG PWF, PSIG DEG F 2120. 5050. 8407. 103. Nodal Analysis Estimation of Bottom Hole Pressure
- 105. 110 OIL WATER GAS SurfaceFlowrate 1520.0 B/D 1.0 B/D 2120.0 MCF/D Downhole Flowrate 2501.7 B/D 1.0 B/D 0.0 MCF/D Surface Density 29.90 API 1.100 GM/CC 0.650 air=1 Downhole Density 0.65 GM/CC 1.098 GM/CC 0.368 GM/CC Downhole FVF 1.6458 RB/STB 1.0023 RB/STB 0.0022 SCF/STB Reservoir Pres. 8407.00 Psia Bubble Point Pres. 6637.20 Psia Reservoir Temp. 184.00 F Solution GOR 1394.74 SCF/STB Surface GOR 1394.74 CF/STB Solution GWR 0.00 SCF/STB Z Factor 1.0000 Correlation Methods: Volume Factor Correlation: Glaso Viscosity Correlation: Beggs & Robinson PVT Summary PVT Summary
- 106. Customer: Operator, SouthTexas Increased production and identified new reserves Gas and Water Original Completion Zone B Gas and Water ? ? Recompletion Zone B Zone A ? Gas and Water Fault Interpretation after logging Zone B Zone A Gas Squeeze cement job Gas Drill out plug Production Zone A Zone B Fault
- 108. FINELY DISPERSED BUBBLE U (m /sec) L S 0.0 0.1 1.0 10 0.11.0 10 100 U (m/sec) G S Bubble Flow Slug Flow Churn Flow Annular Flow
- 109. 114 Water Fallback Water Fallback LightPhase (Oil) Heavy Phase (Water) 0% Water Cut on Surface 50% Water Holdup
- 110. Openhole Completion ina Horizontal Well With Drilling Practices That Restrict Production Recovery Possible Gas - Entry Point Gas - Oil Contact Productive Zone Oil - Water Contact Water - Entry Point Water - Entry Point Water Trap Gas Lock Oil Flow Water
- 111. Radius of Curvature 20- 100 ft 300 - 500 ft 600 ft Short Medium Long
- 112. Data Control Unit MastUnit Traveling Block 1 1/2-in. Coiled-Tubing Injector Head 1 1/2-in. Coiled Tubing BOP's Coiled Tubing Cable Head CCL Temp. Standoff Standoff Switching Sub Gamma Ray Flowmeter Schematic of Well-Site Equipment and Downhole Tool Assembly of a Coiled-Tubing Operation
- 113. Segregated Flow, LowWater Cut Oil Pipe Water Non-Diverting Logging Instrument
- 114. Centralizers Folding Impeller Spinner BasketDiverter Perforations Cased/Cemented Completion
- 115.
- 116. Total flow rategreater than Zone 1 Slotted Liner Flow rate inside liner decreases Zone 3 Zone 2 Zone 1 Use of External Casing Packers with Slotted Liners to Help Quantify Lateral Production Performance
- 117. Centralizers Spinner Basket Diverter FoldingImpeller Openhole Completion
Editor's Notes
- #14 Holdup is most commonly denoted by: Y or
- #31 Vary logging speed as much as possible to obtain the best linear regression.
- #34 Slopes can change at different intervals due to changes in the fluid. Typical Slope should be 3 RPS/100 ft/min or greater.
- #37 Water is always present even when no water production is documented.
- #40 Countrates in air and water are used to calibrateto grams/cc using an exponential fit.
- #63 Initial fluid temperature and Delta P dictate the flowing temperature. (cooling or warming) Mass flowrate dictates what happens above (production) or below (downflow/injection) the fluid source or presssure drop.
- #72 Can locate very small leaks that are unmeasureable by any other devices.
- #73 Stationary recordings are made at different times. If the well is not stable some anomalies may be misinterpreted. In order to prove an anomaly is depth related and not time related at least one repeat is necessary of the stations surrounding this anomaly.
- #75 Noise changes may be due to changes in the transmission medium and not noise sources.
- #76 Single phase flow is dominated by high frequencies.
- #77 Two phase flow is represneted by high low frequency repsonse. Take note of the logarithmic scale
- #78 Attenuation of the analog signal varies with frequency and line type and length.
- #98 Slip Velocity charts have been impirically derrived under several different conditions. Because of the inconsistencies in charts and downhole conditions affective use of these charts is limitted.