The quantified accuracy of the InSitu Family measurements expands the application of DFA from a single well to multiple-well analysis, defining reservoir architecture across the entire field. Fluid Profiling quantification of the variation of fluid properties is at higher resolution than conventional sampling and analysis and identifies and differenti- ates compositional grading, fluid contacts, and reservoir compartments.
Calibration
Two calibrations are required for the InSitu Fluid Analyzer system. The master calibration establishes the optical density baseline for the spectrometer under dry, empty flowline conditions. Before this
dry master calibration is conducted, the tool flowline is cleaned and the optical windows are disassembled and physically cleaned. The master calibration also calibrates the fluorescence detector under dry conditions and with the standard fluorescence fluid (Rhodamine 6G water solution) and checks the functionality of the spectrometers and fluorescence detector with defined fluids (J26 and water).
The master calibration is performed every 3 months, every three jobs, or if the tool was exposed to temperatures above 300 degF [150 degC], whichever occurs first.
Temperature compensation calibration is required for the spectrometers to compensate for drift of the baseline (i.e., optical density [OD] = 0 level established by the master calibration) at elevated temperatures. Temperature compensation calibration is performed every 6 months, every six jobs, or if the tool was exposed to temperatures above 300 degF, whichever occurs first.
Specifications
Measurement Specifications
Accuracy† (to 1 sigma, Fig. 1)
C1, wt% C2, wt% C3–5, wt% C6+, wt% CO2, wt% GOR, scf/stb GOR, %
Medium to heavy oil 1.7 1.1 4.5 4.4 2.5 185 16
Volatile oil 2.7 2.6 6.7 4.5 2.8 726 19
Condensate gas 2.9 3.7 4.1 6.8 3.1 – –
Dry gas 5.3 1.4 2.1 3.5 4.3 – –
pH Resistivity Density Pressure Temperature
Range of measurement 3 to 9 0.01 to 20 ohm.m 0.05 to 1.2 g/cm3 Max.: 25,000 psi Max: 350 degF [175 degC] Accuracy ±0.1 pH unit ±0.01 ohm.m ±0.012 g/cm3 ±10–4 full scale
Max.: ±2.5 10–4 full scale ±10–4 full scale Max.: ±2.5 10–4 full scale Resolution C1, wt% C2, wt% C3–5, wt% C6+, wt% CO2, wt% GOR, scf/stb GOR, % Oil 0.4 0.4 1.0 0.6 0.3 47 1 Gas 0.5 0.4 0.6 0.6 0.4 – 5
† Accuracy listed is for typical fluid in each fluid group; actual measurement accuracy may differ.
3 2 1 1 2 3
68.27% 95.45% 95.73%
Log Quality Control Reference Manual InSitu Fluid Analyzer Real-Time Quantitative Reservoir Fluid Measurements 160
Tool quality control
Standard curves
Standard curves for the InSitu Fluid Analyzer system are listed in Table 1. Table 1. InSitu Fluid Analyzer Standard Curves
Output Mnemonic Output Name
CHCR_IFA(0) InSitu Fluid Analyzer cumulative hydrocarbon composition ratio, methane CHCR_IFA(1) InSitu Fluid Analyzer cumulative hydrocarbon composition ratio, ethane CHCR_IFA(2) InSitu Fluid Analyzer cumulative hydrocarbon composition ratio, C3-C4-C5 CHCR_IFA(3) InSitu Fluid Analyzer cumulative hydrocarbon composition ratio, C6+ CHCR_IFA(4) InSitu Fluid Analyzer cumulative hydrocarbon composition ratio, CO2 CO2QI_IFA1 InSitu Fluid Analyzer CO2 ratio quality indicator
FFRES_IFA1 InSitu Fluid Analyzer flowline fluid resistivity FL0_IFA1 InSitu Fluid Analyzer fluorescence channel 0 FL0IMG_IFA1 InSitu Fluid Analyzer fluorescence channel 0 image FL1_IFA1 InSitu Fluid Analyzer fluorescence channel 1 FL1IMG_IFA1 InSitu Fluid Analyzer fluorescence channel 1 image FLR_IFA1 InSitu Fluid Analyzer fluorescence reflection FRAT_IFA1 InSitu Fluid Analyzer fluorescence ratio FSODIMG_IFA1 Filter spectrometer OD image GASFLG_IFA1 InSitu Fluid Analyzer gas flag GOR_IFA1 InSitu Fluid Analyzer gas/oil ratio
GORQ1_IFA1 InSitu Fluid Analyzer gas/oil ratio quality indicator GSODIMG_IFA1 Grating spectrometer OD image
HAFF_IFA1 InSitu Fluid Analyzer highly absorbing fluid flag
HCQI_IFA1 InSitu Fluid Analyzer hydrocarbon composition quality indicator LEGS_IFA1 InSitu Fluid Analyzer live-fluid analyzer equivalent green shade OPTCWF_IFA1 InSitu Fluid Analyzer coated window flag
PHDI_IFA1 pH from dye indicator
RCTEMP_IFA1 InSitu Fluid Analyzer resistivity cell temperature RODDQUAL_IFA1 Density-viscosity (DV) rod density quality flag RODRHO_IFA1 DV rod fluid density
RODVIS_IFA1 DV rod fluid viscosity RODVQUAL_IFA1 DV rod viscosity quality flag
SOIPRES_IFA1 InSitu Fluid Analyzer pressure and temperature (SOI) gauge pressure SOIPRESS_IFA1 InSitu Fluid Analyzer SOI gauge pressure
SOITEMP_IFA1 InSitu Fluid Analyzer SOI gauge temperature WATF_IFA1 InSitu Fluid Analyzer water fraction Mechanical Specifications
Temperature rating 350 degF [175 degC] Pressure rating 25,000 psi [172 MPa]
Borehole size—min. 6 in (5.75 in possible depending on hole conditions) Borehole size—max. No limit
Outside diameter 5 in [12.72 cm]
Log Quality Control Reference Manual InSitu Fluid Analyzer Real-Time Quantitative Reservoir Fluid Measurements 161
Operation
The InSitu Fluid Analyzer tool is placed below the power cartridge and can be run below or above the Pumpout Module. If pH measurement is required, the InSitu Fluid Analyzer tool is placed on the high-pressure end of the Pumpout Module.
Formats
The typical format in Fig. 2 includes QC outputs. More options are available if pH measurement is required. It is also possible to change the default formats with the dedicated InSituPro* software according to local needs.
• Track 1
– The Pumpout Module speed (POUDMS) and cumulative volume pumped (POUDRV) are shown with the InSitu Fluid Analyzer RODVIS_IFA1, RODRHO-IFA1, RCTEMP_IFA1, and FFRES_IFA1 curves. Density and viscosity QC flags are also included.
• Track 2
– The elapsed time (ETIM) is shown with the Pumpout solenoid status (POUDS3) and status indicators for the sample chamber valves (MUP1, MLP1, VP2, and VP1).
• Track 3
– Fluorescence images FL1IMG_IFA1 and FL0IMG_IFA1 from both channels are shown with the gas detector output GASFLG_IFA1.
• Track 4
– The flags are for the presence of oil, water, and highly absorb- ing fluid. Overlap of the oil and water tracks is also indicated in this track.
• Track 5
– GOR_IFA1 and the CO2 ratio (CO2R_IFA1) along with its high
and low values (HLCO2R_IFA1 and LLCO2R_IFA1, respectively) are used for QC and may not be shown in some log formats. • Track 6
– QC flags in this track are OPTCWF_IFA1, HCQI_IFA1, GORQI_IFA1, and CO2QI_IFA1.
• Track 7
Figure 2. InSitu Fluid Analyzer quality control format.
Log Quality Control Reference Manual InSitu Fluid Analyzer Real-Time Quantitative Reservoir Fluid Measurements 162 0.5000
1.5000 2.5000
1.5000
(−−−−)
IFA1 CO2 Ratio (CO2R_IFA1) (−−−−) 0 0.5 IFA1) (OHMM) 0 1 0 (GOR_IFA1)(F3/B) 5000
MRPOUD Motor Speed (POUDMS) (RPM) 0 5000 Status (POUDS3) (−−−−) 5 0 Elapsed Time (ETIM) (S) nce 0 Image (FL0IMG_ IFA1) 0 1 IFA1 CO2 Quality Indicator (CO2QI_ IFA1) (−−−−) IFA1 Gas Flag (GASFLG _IFA1) (−−−−) IFA1 GOR Quality Indicator (GORQI_ IFA1) (−−−−) IFA1 C1 Fraction IFA1 C2 Fraction 1278 XX87 XX96 XX05 XX14 XX23 XX32 XX41 XX50 XX59 XX68 XX77 XX86 XX95 XX04 XX13 XX22 XX31 XX40 XX49 XX58 XX67 XX76 XX85 0.5000 1.5000 2.5000 0.5000 1.5000 2.5000 0.5000 1.5000 2.5000 0.0000 0.8500 0.9500 0.0000 0.8500 0.9500 (−−)
IFA1 Flowline Fluid Resistivity (FFRES_ IFA1)
(OHMM)
0 1
IFA1 Gas Oil Ratio (GOR_IFA1)
(F3/B)
0 5000
IFA1 High Limit of CO2 Ratio (HLCO2R_IFA1)
(−−−−)
0 0.5
IFA1 Low Limit of CO2 Ratio (LLCO2R_IFA1)
(−−−−)
0 0.5
MRPOUD Hydraulic Pump Output Volume (POUDPV) (C3) 0 1000 MRPOUD Solenoid 3 Status (POUDS3) MRSC 1 Valve Position (VP1) (−−−−) −5 250 MRSC 2 Valve Position (VP2) (−−−−) −5 250 MRMS 1 Lower Valve Position (MLP1) (−−−−) 5 260 MRMS 1 Upper Valve Position (MUP1) (−−−−) 5 260
IFA1 Resistivity Cell Temperature (RCTEMP_IFA1)
(DEGF)
X50 X50
IFA1 DV−Rod Fluid Density (RODRHO_ IFA1)
(G/C3)
0.5 1.5
IFA1 DV−Rod Fluid Viscosity (RODVIS_ IFA1) (CP) 0 10 IFA1 IFA1 1 Image (FL1IMG_ IFA1) 0 0.3 IFA1 GOR Quality IFA1 Quality Indicator (HCQI_ IFA1) (−−−−) IFA1 Coated Window (OPTCWF _IFA1) (−−−−) IFA1 DV−Rod Density Quality (RODDQUAL_IFA1) (−−−−) IFA1 DV−Rod Viscosity Quality (RODVQUAL_IFA1) (−−−−) IFA1 C2 Fraction IFA1 C3 − C5 Fraction IFA1 C6+ Fraction IFA1 CO2 Fraction
Water
*** Quality Indicator Tracks for Hydrocarbon Composition Analysis ***
Computation Confidence Level: high = green, medium = yellow, low = red, no confidence = white | GOR | CO2 |OPTCWF| HCQI |
0.0000 0.8500 0.9500 0.0000 0.8500 0.9500
PIP SUMMARY Time Mark Every 60 S
Fluorescence Fluorescence Channel Channel Amplitude Min Max Amplitude Min Max Indicator Hydrocarbon Highly Absorbing Fluid Water− Overlap
Response in known conditions
• In mud and possibly in emulsions, HAFF_IFA1 is on and all the optical channels become saturated. There are no outputs for com- position, GOR, and the QC flags.
• In water, the water fraction track indicates blue shading. The
CO2, GOR, and composition QC flags can indicate a lower quality
depending on the amount of water present if oil is also observed.
Above a certain water threshold, composition, CO2, and GOR are
not computed.
• In oil, green shading is shown. The spectrometer tracks display coloration and composition and GOR is also computed. The fluores- cence channels display a higher value when oil is flowing in front of the sensor.
• In oil, the filter array spectrometer color optical densities define the exponential decrease with wavelength, making possible asphaltene gradient analysis based on fluid color.
• In gas, fluorescence reflection is dominant and gas composition is computed. Fluorescence is negligible.
• If oil-water emulsions are pumped, optical densities are high. With HAFF_IFA1 on, however, fluorescence still responds to the hydrocarbon presence.
• If the phase separation envelope is crossed downhole, gas flags are displayed if oil is pumped or fluorescence increases if retrograde gas is pumped, indicating that liquid dew is forming.
• OPTCWF_IFA1 alerts interpreters if an InSitu Fluid Analyzer window has stagnant liquids affecting the results while pumping. Corrective action then can be taken to clean the windows downhole during the survey.
• The flowline pressure gauge helps define sampling pressure, and flowline resistivity is instrumental while sampling with dual packers.
Log Quality Control Reference Manual MDT Dual-Packer Module 164
Overview
The Dual-Packer Module (MRPA) of the MDT* modular formation dynamics tester consists of two inflatable packer elements that seal against the borehole wall to isolate an interval of the borehole. The Pumpout Module (MRPO) is required to inflate the packers with wellbore fluid. The length of the test interval (i.e., the distance between the packers) is 3.2 ft [0.98 m] and can be extended by 2, 5, or 8 ft [0.61, 1.52, or 2.44 m]. For the 3.2-ft interval, the area of the isolated interval of the borehole is about 3,000 times larger than the area of the borehole wall isolated by an MDT probe. For fluid sampling, the large area results in flowing pressure that is only slightly below the reservoir pressure, which avoids phase separation even for pressure-sensitive fluids such as gas condensates or volatile oils. In low-permeability formations, high drawdown usually occurs with the probe, whereas the fluid can be withdrawn from the formation using the MRPA with minimum pressure drop through the larger flowing area. In finely lami- nated formations, the MRPA can be used to straddle permeable streaks that would be difficult to locate with a probe. In fractured formations, the MRPA can usually seal the interval whereas a probe could not. For pressure transient testing, following a large-volume flow from the formation, the resulting pressure buildup has a radius of investigation of 50 to 80 ft [15 to 24 m]. Similar to a small-scale drillstem test (DST), this type of testing offers advantages over conventional DST tests. It is environmentally friendly because no fluids flow to the surface, and it is cost effective because many zones can be tested in a short time. The MRPA can be used to create a micro-hydraulic fracture (i.e., stress testing) that can be pressure tested to determine the minimum in situ stress magnitude. The fracture is created by pumping wellbore fluid