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INTEGRATED PETROPHYSICAL EVALUATION OF TURBIDITIC SANDS IN NIGER
DELTA BASIN
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INTEGRATED PETROPHYSICAL EVALUATION OF TURBIDITIC SANDS IN NIGER
DELTA BASIN
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ABSTRACT
Large quantities of petroleum resources in the Niger Delta province are confined to
unconsolidated turbiditic and silici-clastic rocks. These rocks are usually associated with high
volumes of shale. The high volumes of shale create discontinuities within the reservoir units
causing division of the reservoir into several flow units. The complex nature of these reservoir
units coupled with the incidence of many thin beds within them makes it difficult to conduct
credible petrophysical evaluation using conventional log and core data. These types of data are
however the most common data available for most wells in the Niger Delta region. In this
research, an integrated approach is adopted in petrophysical evaluation of the reservoir sands
using conventional log and core data. The stock tank oil originally in place is estimated using
three different methods. These include;
I. Deterministic approach without consideration to the internal divisions (flow units) within
the reservoir.
II. Deterministic approach with consideration to internal divisions (flow units) within the
reservoir and
III. Probabilistic approach with sensitivity analysis for three different cases of net pay
thickness.
The outcome of the research showed that, when a deterministic evaluation is done without
considering internal divisions, the value for STOOIP is greater than that which considers internal
divisions of the reservoir. The range of STOOIP’s observed for the probabilistic approach is
relatively wide and therefore lends credence to the unpredictable nature of turbiditic sands. Many
internal divisions within a relatively thin thickness of sand also highlights the internal
discontinuities within the reservoir units. The research also highlighted that, sensitivity of
STOOIP to particular input parameters is reservoir dependent.
In conclusion, the integrated approach for petrophysical evaluation of turbiditic formations
enables better and thorough understanding of the reservoir units. Decisions can therefore be
based on the outcomes from this method going forward.
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ACKNOWLEDGEMENTS
I acknowledge the love of God from the day I was born to today. I appreciation my family for all
the support they have given me. To my mother, Mrs. Helen Awejori Agaasah and my siblings,
Rose, Richard and Raymond, I say, I am forever grateful for your love and support.
I am grateful to my supervisor, Prof. Djebbar Tiab. I thank you for your time and efforts
especially at the beginning of the research. You strengthened me at the beginning and that is
what has gotten me this far. I thank in a special way my second supervisor, Dr. Alpheus
Igbokoyi. You were always there for me. My appreciation also goes to all faculty of AUST
especially the heads of department: Prof. Godwin Chukwu, Prof. Wumi Iledare and Dr.
Abdulkadir Muktar.
My sincerest gratitude also goes to my mentor, Mr. Onuh Haruna (Boss). I am full of
appreciation for all the effort you put to get me data and prepare me for this research. I could not
have done it without you. I can never forget how you sacrificed your time to teach Prosper and I
continuously throughout the day and night when we came to your office at Lagos. Thank you
and God bless you.
I also acknowledge the support of my classmates and friends. Special thanks goes to Prosper
Sani, Ismael and Bismark, it is great having friends like you.
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DEDICATION
I dedicate this thesis to God Almighty for how far He has brought me. I thank you, father for
your love, blessings, guidance and protection during my stay in the African University of
Science and Technology, Abuja, Nigeria.
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TABLE OF CONTENT
ABSTRACT .................................................................................................................................................. i
ACKNOWLEDGEMENTS .......................................................................................................................... ii
DEDICATION ............................................................................................................................................. iii
TABLE OF CONTENT ................................................................................................................................iv
LIST OF FIGURES .................................................................................................................................... viii
LIST OF TABLES ........................................................................................................................................ xi
CHAPTER 1 ................................................................................................................................................. 1
PROBLEM DEFINITION ............................................................................................................................ 1
1.1 STATEMENT OF PROBLEM ..................................................................................................... 1
1.2 OBJECTIVES ............................................................................................................................... 2
1.3 METHODOLOGY ....................................................................................................................... 2
1.3.1 Flow chat .............................................................................................................................. 3
1.4 FACILITIES AND PERSONNEL ............................................................................................... 3
1.5 STRUCTURE OF REPORT ......................................................................................................... 4
CHAPTER 2 ................................................................................................................................................. 5
OVERVIEW OF STUDY AREA AND LITERATURE REVIEW ............................................................. 5
2.1 GEOLOGY OF THE NIGER DELTA ......................................................................................... 5
2.1.1 Geological Overview ............................................................................................................ 5
2.1.2 Structural Province ............................................................................................................... 5
2.1.3 Stratigraphy ........................................................................................................................... 5
2.1.4 Tectonics and Structure ........................................................................................................ 6
2.1.5 Lithology ............................................................................................................................... 7
2.1.6 Depo-belts ............................................................................................................................. 7
2.1.7 Hydrocarbon Source ............................................................................................................. 8
2.1.8 Reservoir Rock ..................................................................................................................... 8
2.2 GRAVITY SEDIMENT FLOW ................................................................................................... 9
2.2.1 Turbidity Currents............................................................................................................... 10
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2.2.2 Debris Flows ....................................................................................................................... 13
2.2.3 Slumps ................................................................................................................................ 14
2.2.4 Submarine Slope Canyon and Slope Channels ................................................................... 16
2.2.5 Submarine Canyon .............................................................................................................. 18
2.3 TYPES OF PETROPHYSICAL LOGS ..................................................................................... 19
2.3.1 Resistivity Log .................................................................................................................... 19
2.3.2 Gamma Ray Log ................................................................................................................. 20
2.3.3 Density Log ........................................................................................................................ 22
2.3.4 Neutron Log ........................................................................................................................ 23
2.3.5 Sonic Log ............................................................................................................................ 24
2.4 METHODS FOR PETROPHYSICAL ANALYSIS OF THIN BEDS/TURBIDITES .............. 24
2.4.1 Thin Bed Analysis Using Resistivity Borehole Image Tools ............................................. 24
2.4.2 Resistivity Anisotropy Method ........................................................................................... 26
2.5 MONTE CARLO SIMULATION/ RISK ANALYSIS SOFTWARE ....................................... 29
2.5.1 Introduction ......................................................................................................................... 29
2.5.2 Risk Simulator ........................................................................................................................... 29
CHAPTER 3 ............................................................................................................................................... 32
MATERIALS AND METHODS ............................................................................................................... 32
3.1 SUMMARISED FLOWCHART OF METHODOLOGY .......................................................... 32
3.2 OUTLINE OF METHODOLOGY ............................................................................................. 33
3.3 DETERMINATION OF LITHOLOGY FROM WIRE LINE LOGS ........................................ 34
3.4 ESTIMATION OF PETROPHYSICAL PARAMETERS ......................................................... 34
3.4.1 Net Pay Thickness (Net/Gross) ........................................................................................... 34
3.4.2 Shale Volume ...................................................................................................................... 35
3.5.3 Porosity ............................................................................................................................... 35
3.4.4 Water Saturation ................................................................................................................. 36
3.4.5 Net Pay ................................................................................................................................ 38
3.4.6 Permeability ........................................................................................................................ 38
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3.4.7 Hydrocarbons-in-place Volumes ........................................................................................ 39
3.5 CORES ....................................................................................................................................... 40
CHAPTER 4 ............................................................................................................................................... 41
DATA PROCESSING AND ANALYSIS ................................................................................................. 41
4.1 PROCESS OF EVALUATION .................................................................................................. 41
4.1.1 Reservoir Quality Index (RQI) ........................................................................................... 41
4.1.2 Flow Zone Index (FZI) ....................................................................................................... 41
4.1.3 Tiab Hydraulic Flow Unit (HT) ........................................................................................... 42
4.1.4 Normalised Reservoir Quality Index (nRQI) ...................................................................... 42
4.1.5 Normalised Porosity (Φz) .................................................................................................... 43
4.1.6 Stratigraphic Modified Lorenz Plot (SMLP) ...................................................................... 43
4.2 CALCULATION STOOIP FOR RESERVOIR 7 ...................................................................... 45
4.3 STOCHASTIC EVALUATION TECHNIQUES ....................................................................... 47
4.3.1 Graphs obtained from Stochastic Modelling of STOOIP for reservoir 7 ........................... 48
4.4 ANALYSIS OF FLOW UNITS FOR RESERVOIR 7 ............................................................... 55
4.4.1 Analysis of Well 01 ............................................................................................................ 56
4.4.2 Analysis of Well 02 ............................................................................................................ 58
4.4.3 Analysis of Well 03 ............................................................................................................ 61
4.4.4 Analysis of Well 04 ............................................................................................................ 63
4.4.5 Analysis of Well 05 ............................................................................................................ 66
4.4.6 Analysis of Well 06 ............................................................................................................ 66
4.5 CALCULATION OF STOOIP USING FLOW UNITS ............................................................. 66
4.6 CALCULATION OF STOOIP FOR RESERVOIR 6 ................................................................ 68
4.7 STOCHASTIC EVALUATION TECHNIQUES (RESERVOIR 6) .......................................... 70
4.7.1 Graphs obtained from Stochastic Modelling of STOOIP for Reservoir 6 .......................... 71
4.8 ANALYSIS OF FLOW UNITS FOR RESERVOIR 6 ............................................................... 78
4.8.1 Analysis of Well 02 ............................................................................................................ 79
4.8.2 Analysis of Well 03 ............................................................................................................ 81
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4.8.3 Analysis of other wells ....................................................................................................... 84
4.9 CALCULATION OF STOOIP USING FLOW UNITS (RESERVOIR 6) ................................ 84
CHAPTER 5 ............................................................................................................................................... 85
DISCUSSION AND CONCLUSION ........................................................................................................ 85
5.1 DISCUSSION ............................................................................................................................. 85
5.1.1 Flow Unit Identification for Reservoir 7 ............................................................................ 85
5.1.2 Uncertainty Analysis for Reservoir 7 ................................................................................. 86
5.1.3 Flow Unit Identification for Reservoir 6 ............................................................................ 86
5.1.4 Uncertainty Analysis for Reservoir 6 ................................................................................. 87
5.2 CONCLUSIONS ........................................................................................................................ 88
NOMENCLATURE ................................................................................................................................... 90
REFERENCES ........................................................................................................................................... 91
APPENDIX A: ADDITIONAL FIGURES FOR CHAPTER 4 (RESERVOIR 7) .................................... 95
APPENDIX B: ADDITIONAL TABLES FOR CHAPTER 4 (RESERVOIR 7) .................................... 100
APPENDIX C: ADDITIONAL FIGURES FOR CHAPTER 4 (RESERVOIR 6) ................................... 101
APPENDIX D: ADDITIONAL TABLES FOR CHAPTER 4 (RESERVOIR 6) .................................... 105
APPENDIX E: DATA OF WELL 01 FOR FLOW UNIT CHARTS FOR RESERVOIR 7 .................... 106
APPENDIX F: DATA OF WELL 02 FOR FLOW UNIT CHARTS FOR RESERVOIR 7 .................... 108
APPENDIX G: DATA OF WELL 03 FOR FLOW UNIT CHARTS FOR RESERVOIR 7 ................... 110
APPENDIX H: DATA OF WELL 04 FOR FLOW UNIT CHARTS FOR RESERVOIR 7 ................... 113
APPENDIX I: DATA OF WELL 02 FOR FLOW UNIT CHARTS FOR RESERVOIR 6 ..................... 115
APPENDIX J: DATA OF WELL 03 FOR FLOW UNIT CHARTS FOR RESERVOIR 6 .................... 117
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LIST OF FIGURES Figure 1. 1: Flow chart of methods adopted in conducting research ............................................. 3
Figure 2. 1: Schematic play map showing the Niger Delta Depo-belts. ......................................... 9
Figure 2. 2: Differences in transport and deposition by turbidity currents and debris flow. .... 10
Figure 2. 3: Structure of head and body of turbidity current advancing into deep water. ........ 11
Figure 2. 4: Ideal Bouma sequence showing Ta, Tb, Tc, Td, and Te divisions . ......................... 13
Figure 2. 5: Schematic illustration of head and toe of slumps. ..................................................... 15
Figure 2. 6: Difference between slide, slump, debris flow and turbidity current process. ......... 16
Figure 2. 7: Schematic illustration of slope and deep marine environments. .............................. 17
Figure 2. 8: Illustration of section views across a A) canyon B) slope channel or gully. ............ 17
Figure 3. 1: Flow chart showing the processes involved in analysis of data. ............................... 32
Figure 3. 2: Graph showing the determination of porosity cutoff for delineation of pay zone. 38
Figure 3. 3: Relationship between core data and log data for quality control. ........................... 40
Figure 4. 1: Log view of petrophysical parameters on Schlumburger Techlog Software. ......... 45
Figure 4. 2: Graph of Relative Probabilities for calculated STOOIPs. ....................................... 48
Figure 4. 3: Graph of Cumulative Frequencies of calculated STOOIPs. .................................... 49
Figure 4. 4: Graph of Probability Density Functions for STOOIPs calculated. ......................... 50
Figure 4. 5: Tornado Chart of Correlation Coefficients for Input Parameters on STOOIP. .... 51
Figure 4. 6: Tornado Chart of Regression Coefficients for input Parameters on STOOIP. ..... 52
Figure 4. 7: Tornado Chart of effects of input parameters on STOOIP. .................................... 53
Figure 4. 8: Spider Chart of impact of input parameters on output STOOIP ............................ 54
Figure 4. 9: Graph of RQI versus Normalised Porosity of reservoir for well 01. ....................... 57
Figure 4. 10: SMLP of the reservoir of interest for well 01........................................................... 57
Figure 4. 11: nRQI plot of the reservoir of interest for well 01. ................................................... 58
Figure 4. 12: Graph of RQI versus Normalised Porosity of reservoir for well 02. ..................... 59
Figure 4. 13: SMLP of the reservoir of interest for well 02........................................................... 60
Figure 4. 14: nRQI plot of the reservoir of interest for well 02. ................................................... 60
Figure 4. 15: Graph of RQI versus Normalised Porosity of reservoir for well 03. ..................... 62
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Figure 4. 16: SMLP of the reservoir of interest for well 03........................................................... 62
Figure 4. 17: nRQI plot of the reservoir of interest for well 03. ................................................... 63
Figure 4. 18: Graph of RQI versus Normalised Porosity of reservoir for well 04. ..................... 64
Figure 4. 19: SMLP of the reservoir of interest for well 04........................................................... 65
Figure 4. 20: nRQI plot of the reservoir of interest for well 04. ................................................... 65
Figure 4. 21: Log view of petrophysical parameters on Schlumburger Techlog Software. ....... 68
Figure 4. 22: Graph of Relative Probabilities for calculated STOOIPs. ..................................... 71
Figure 4. 23: Graph of Cumulative Frequencies of calculated STOOIPs. .................................. 72
Figure 4. 24: Graph of Probability Density Functions for STOOIPs calculated. ....................... 73
Figure 4. 25: Tornado Chart of Correlation Coefficients for Input Parameters on STOOIP. .. 74
Figure 4. 26: Tornado Chart of Regression Coefficients for input Parameters on STOOIP. ... 75
Figure 4. 27: Tornado Chart of effects of input parameters on STOOIP ................................... 76
Figure 4. 28: Spider Chart of impact of input parameters on output STOOIP .......................... 77
Figure 4. 29: Graph of RQI versus Normalised Porosity of reservoir for well 02. ..................... 80
Figure 4. 30: SMLP of the reservoir of interest for well 02........................................................... 80
Figure 4. 31: nRQI plot of the reservoir of interest for well 02. ................................................... 81
Figure 4. 32: Graph of RQI versus Normalised Porosity of reservoir for well 03. ..................... 82
Figure 4. 33: SMLP of the reservoir of interest for well 03........................................................... 83
Figure 4. 34: nRQI plot of the reservoir of interest for well 03. ................................................... 83
Figure A. 1: Spider Charts showing impact of input parameters on STOOIP. .......................... 95
Figure A. 2: Tornado Charts of effect of input Parameters on STOOIP. ................................... 95
Figure A. 3: Tornado Charts of regression coefficients for input parameters on STOOIP. ..... 96
Figure A. 4: Tornado Charts of correlation coefficients for input parameters on STOOIP. .... 96
Figure A. 5: Shows the Relative Probability Graphs of calculated STOOIPs. ........................... 97
Figure A. 6: Cumulative Frequency Graphs of calculated STOOIPs .......................................... 97
Figure A. 7: Schlumbuger Techlog log view of reservoir 7 in well 01 to well 04......................... 98
Figure A. 8: Regressions for flow units in well 01 to well 04 for reservoir 7. .............................. 99
Figure C. 1: Spider Charts showing impact of input parameters on STOOIP ......................... 101
Figure C. 2: Tornado Charts of effect of input Parameters on STOOIP .................................. 101
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Figure C. 3: Tornado Charts of regression coefficients for input parameters on STOOIP. ... 102
Figure C. 4: Tornado Charts of correlation coefficients for input parameters on STOOIP. .. 102
Figure C. 5: Shows the Probability Density Function Graphs of calculated STOOIPs. .......... 103
Figure C. 6: Cumulative Frequency Graphs of calculated STOOIPs ........................................ 103
Figure C. 7: Schlumbuger Techlog log view of reservoir 6 in well 02 and well 03. .................. 104
Figure C. 8: Regressions for flow units in well 02 and well 03 for reservoir 6. ......................... 104
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LIST OF TABLES
Table 4. 1: Shows the values obtained for input parameters for the calculation of STOOIP ... 46
Table 4. 2: Deterministic STOOIP for various reservoirs and entire field. ................................ 46
Table 4. 3: Distributions fitted for input parameters for stochastic analysis. ............................. 47
Table 4. 4: Table showing flow units present in reservoir 7 and their properties. ..................... 55
Table 4. 5: Calculation of STOOIP for each flow unit and entire reservoir. .............................. 67
Table 4. 6: Shows the values obtained for input parameters for the calculation of STOOIP ... 69
Table 4. 7: Deterministic STOOIP for various reservoirs and entire field. ................................ 69
Table 4. 8: Distributions fitted for input parameters for stochastic analysis .............................. 70
Table 4. 9: Flow units present in reservoir 7 and their properties. .............................................. 78
Table 4. 10: Calculation of STOOIP for each flow unit and entire reservoir. ............................ 84
Table B. 1: Summary of statistics for STOOIP simulation runs. ............................................... 100
Table D. 1: Summary of statistics for STOOIP simulation runs ................................................ 105
1
CHAPTER 1
PROBLEM DEFINITION
1.1 STATEMENT OF PROBLEM
Globally, significant amounts of hydrocarbon volumes in silici-clastic reservoirs are contained in
thin-bedded turbidite pay zones. These include hydrocarbon resources located in channel-
complex reservoirs composed of various genetic reservoir units which ranges from clean channel
lag and storey axis sands with a high net-to-gross to thin-bedded levee over-bank deposits
containing lower sand fractions. The significant discovery of these types of highly prolific thin-
bedded turbidite sand reservoirs in deep waters of the Niger Delta petroleum province in recent
times has shifted more attention to the zone. This has resulted in increased exploration activity
within the deep water Nigerian asset.
A significant proportion of the pay in both onshore and Deep Water (DW) Nigeria fields is mud
rich and inter-channel beds. Key uncertainties of reservoir models are the distribution of
properties as well as connectivity of these thin-bedded reservoirs. Thin beds can be subdivided
into; “thin sand beds” if they are 20 to 60 inches, and “very thin beds” if they are less than 4 to 8
inches or less. The main distinction is that in thin beds you can measure petrophysical properties
such as porosity and water saturation, although with some difficulty, whereas in very thin beds
you have to extrapolate those values from a nearby thick bed. These variations within formations
are not always observed with standard logging methods. They are often thus characterised by
low resistivity and low contrast pay layers. These complexities present major challenges during
the study of these reservoir sands and can cause a significant deviation during interpretation.
Efficient identification of the net pay zones, porosity, water saturation and ultimately the amount
of original hydrocarbons in place within the reservoir are paramount to achieving complete
petrophysical evaluation. The best and most accurate way to estimate these parameters is core
analysis but the cost of obtaining core data for all the wells and well-sections is highly
prohibitive. The standard practice therefore is to obtain petrophysical core data for some well-
sections and augment this data with data obtained from petrophysical logs. This method is
economical but introduces a higher level of uncertainty into the petrophysical evaluation
exercise.
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Given the high cost associated with petroleum exploration projects especially so for exploration
in deep water environments, it is imperative that investors know the degree of risks going
forward with a particular project after the petrophysical properties have been estimated. The
uncertainty in the accuracy of log data as well as the sensitivity of estimated petrophysical
parameters must be considered during petrophysical analysis especially for thin bedded turbidite
reservoirs. This thesis work incorporates probability and sensitivity analysis in petrophysical
evaluation of deep water turbidite reservoirs in Niger Delta Petroleum Province using
conventional petrophysical core and log data.
1.2 OBJECTIVES
It is expected that the following will be achieved at the end of this research:
Petrophysical evaluation of turbidite sands in Niger Delta Basin using deterministic
methods.
Petrophysical evaluation of turbidite sands in Niger Delta Basin using stochastic or
probabilistic methods.
Stochastic modeling and uncertainty analysis of Petrophysical parameters within the deep
water turbiditic sands in Niger Delta asset.
Sensitivity analysis to establish key parameters affecting the estimation of the amount of
original hydrocarbon in place.
Flow unit characterisation of the tubiditic reservoirs in the Niger Delta asset.
1.3 METHODOLOGY
The methods used in this research include:
Data gathering
Data quality analysis and quality control.
Data Analysis which include;
Correlation and regression analysis
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Simulation runs
Calculations of parameters
Discussions and conclusions
1.3.1 Flow chat
Proposed Flow Chat for integrated petrophysical evaluation of turbidite sand reservoirs in the
Niger Delta Petroleum Province is as follows:
1.4 FACILITIES AND PERSONNEL
The facilities to be used for this project include:
Internet and library facilities at the African University of Science and Technology, Abuja.
Technical and academic expertise of supervisor
Computer Software which include;
Gamma Ray Log
Self-Potential Log
Delineate the clean
Sandstone reservoir
zones.
Density Log
Neutron Log
Estimate the Porosity.
Estimate the
original
Hydrocarbon
in Place (Oil
and Gas)
Estimate the fluid
composition.
Subject the results to sensitivity
analysis (Impose distributions on Net
thickness, porosity, fluid
composition).
Draw conclusion based on
outcome of sensitivity
analysis.
Resistivity Logs
Density-Neutron Logs
Figure 1. 1: Flow chart of methods adopted in conducting research
4
Schlumberger Techlog Application suite for Petrophysical and Core Analysis
@ Risk Simulation Modelling Tool
1.5 STRUCTURE OF REPORT
This report consist of five (5) chapters
The problem definition, objectives, methods and the facilities and persons that were
consulted during the process of carrying out this research are all outlined in this chapter. This
chapter introduces as well as gives a summary of the processes adopted in organising and
executing this research as well as the process of writing this thesis.
Chapter two gives in-depth information of relevant literature concerning this research. The
main topics handled in this chapter include an overview of the area of study and the
processes that culminate to creating these kind of areas and structures. In this chapter, the
present methods employed for the research area are also outlined. The sensitivity software is
also discussed in this chapter.
Chapter three talks about the specific method adopted in this research. The methods used to
estimate and establish the relevant parameters been investigated are each outlined in this
chapter. The significance of the various parameters estimated is also discussed in this
chapter.
Chapter four presents the outline of how all the analysis and preliminary interpretations of
the results were done. The formulae applied and the result from each is outlined in this
chapter. The manipulations of the data to obtain meaningful parameters are all outlined in
this chapter.
Chapter five covers the discussions, conclusions and recommendations. The full length
interpretation of the results from chapter four are carried out in this chapter.
5
CHAPTER 2
OVERVIEW OF STUDY AREA AND LITERATURE REVIEW
2.1 GEOLOGY OF THE NIGER DELTA
2.1.1 Geological Overview
The Niger Delta is located in the Gulf of Guinea and extends throughout the Niger Delta
Province. The delta has pro-graded southwestward from Eocene to present, forming series of
depo-belts that represent the most active portion of the delta at each stage of its development.
These depo-belts form one of the largest regressive deltas in the world with an area of about
300,000 km2 (Kulke, 1995). The sediment has an average thickness of about 10km in the centre
of the depo-belts and the estimated sediment volume is 500,000 km3 (Kaplan, 1994).
2.1.2 Structural Province
The onshore portion of the Niger Delta Province is described by the geology of southern Nigeria
and southwestern portions of Cameroon. It is bounded from the north by the Benin Flank, a
hinge line that trends east-northeast and is south of the West Africa basement massif. The
northeastern boundary is delineated by outcrops of the Cretaceous on the Abakaliki High. The
Calabar flank which is a hinge line bordering the precambrian is found at the east-south-east. In
offshore the boundary of the province is defined by the Cameroon volcanic line to the east, the
eastern boundary of the Dahomey Basin (the eastern-most West African transform-fault passive
margin) to the west, and the two kilometer sediment thickness contour or the 4000-meter
bathymetric contour in areas where sediment thickness is greater than two kilometers to the south
and southwest. The province covers 300,000Km2 and includes the geologic extent of the Tertiary
Niger Delta (Akata-Agbada) Petroleum System.
2.1.3 Stratigraphy
The Niger Delta Basin covers an area of about 75,000Km2 and is composed of an overall
regressive clastic sequence that reaches a maximum thickness of 9,000 metres to 12,000 metres
(29,500 ft. to 39,400 ft.). There are basically three distinct formations in the Niger Delta
representing pro-grading depositional facies that are distinguished mostly by their sand-shale
ratios.
6
The Akata Formation at the base of the delta is of marine origin and is composed of thick shale
sequence (potential source rock), turbidite sand (potential reservoirs in deep water) and minor
amounts of clay and silt. Beginning in the Paleocene and through the Recent, the Akata
Formation formed during low stands when terrestrial organic matter and clays were transported
to deep water areas characterised by low energy conditions and oxygen deficiency (Stacher,
1995). The formation underlies the entire delta, and is characteristically over pressured. The
approximate thickness of the Akata formation is 6,000m. The Agbada formation which overlies
the Akata was deposited beginning from Eocene and continues into the Recent. This formation
is the major petroleum bearing formation in the Niger Delta. The formation consists of paralic
silici-clastics approximately 3,700 meters thick. It represents the actual deltaic portion of the
sequence. The clastics accumulated in delta-front, delta-topset, and fluvio-deltaic environments.
The Agbada Formation is overlain by the third formation, the Benin Formation, a continental
latest Eocene to recent deposit of alluvial and upper coastal plain sands that are up to 2,000 m
thick, (Avbovbo, 1978).
2.1.4 Tectonics and Structure
The tectonic framework of the continental margin along the West Coast of equatorial Africa is
controlled by Cretaceous fracture zones in the form of trenches and ridges in the deep Atlantic.
The fracture zone ridges subdivide the margin into individual basins. In Nigeria, they form the
boundary faults of the Cretaceous Benue-Abakaliki Trough, which cuts far into the West African
shield. The trough represents a failed arm of a rift triple junction (aulacogen) associated with the
opening of the South Atlantic. In this region, rifting started in the Late Jurassic and persisted into
the Middle Cretaceous, (Lehner and De Ruiter, 1977). It is believed that rifting diminished in the
Niger Delta altogether in the Late Cretaceous.
Gravity tectonism became the primary deformational process after the end of rifting. Shale
mobility induced internal deformation and occurred in response to two processes (Kulke, 1995).
First, the formation of shale diapirs as a result of loading of poorly compacted, over-pressured,
and pro-delta and delta-slope clays (Akata Formation) by the higher density delta front sands
(Agbada Formation). Second, the occurrence of slope instability due to a lack of lateral, basin
ward, support for the under-compacted delta-slope clays (Akata Formation). Gravity tectonics
were completed for each depobelt before deposition of the Benin Formation and are expressed in
7
complex structures, including shale diapirs, roll-over anticlines, collapsed growth fault crests,
back-to-back features, and steeply dipping, closely spaced flank faults, (Evamy et al., 1978).
These faults mostly offset different parts of the Agbada Formation and flatten into detachment
planes near the top of the Akata Formation.
2.1.5 Lithology
Lithologies of Cretaceous rocks deposited in what is now the Niger Delta basin can only be
extrapolated from the exposed Cretaceous section in the next basin to the northeast--the
Anambra. From the Campanian through the Paleocene, the shoreline was concave into the
Anambra Basin (Hospers, 1965) resulting in convergent long shore drift cells that led to
formation of tide-dominated deltaic sedimentation for periods of sea transgressions and river
dominated sedimentation during periods of regressions (Reijers, 1997). Shallow marine clastics
were deposited farther offshore. These are represented by the Albian-Cenomanian Asu River
Group, Cenomanian-Santonian Eze-Aku and Awgu Shale, and Campanian/Maastrichtian Nkporo
Shale, among others in the Anambra Basin (Nwachukwu, 1972 Reijers). The distribution of Late
Cretaceous shale beneath the Niger Delta is unknown.
A major transgression referred to as the Sokoto transgression which occurred in Paleocene
(Reijers, 1997) began with the Imo Shale being deposited in the Anambra Basin to the northeast
and the Akata Shale in the Niger Delta Basin area to the southwest. In the Eocene, the coastline
shape became convexly curvilinear, the long shore drift cells switched to divergent and
sedimentation changed to being wave-dominated, (Reijers, 1997). Deposition of paralic
sediments fully began in the Niger Delta Basin at this time and as the sediments prograded south,
the coastline became progressively more convex seaward.
2.1.6 Depo-belts
Deposition of the three formations occurred in each of the five off lapping siliciclastics
sedimentation cycles that make up the Niger Delta. These cycles (depo-belts) are 30-60
kilometers wide, prograded south-westward 250 kilometers over oceanic crust into the Gulf of
Guinea (Stacher, 1995). These are defined by syn-sedimentary faulting that resulted from the
different rates of subsidence and sediment supply (Doust and Omatsola, 1990). Each depo-belt is
a distinct unit that corresponds to changes in regional dip of the delta. The depo-belts are
8
bounded landward by growth faults and seaward by large counter-regional faults or the growth
fault of the next seaward belt (Evamy, Doust and Omatsola, 1990).
Five main depo-belts are generally recognized, with each of them exhibiting their own
sedimentation, deformation, and petroleum history (Doust and Omatsola, 1990). The northern
delta province, which overlies relatively shallow basement, has the oldest growth faults that are
generally rotational, evenly spaced with increased steepness seaward. The central delta province
has depo-belts with well-defined structures such as successively deeper rollover crests that shift
seaward for any given growth fault. The distal delta province is the most structurally complex
due to internal gravity tectonics on the modern continental slope.
2.1.7 Hydrocarbon Source
Much discussion has been made about the source rock for petroleum in the Niger Delta. The
main possibilities including variable contributions from the marine shale inter-bedded with
paralic sandstone in the Agbada Formation and the marine Akata shale. Based on organic matter
content and type (Evamy, 1978) proposed that both the marine shale (Akata Formation) and the
shale inter-bedded with paralic sandstone (Lower Agbada Formation) were the source rocks for
the Niger Delta oils.
However, Stacher proposes that the Akata Formation is the only source rock volumetrically
significant and whose burial depth is consistent with the depth of the oil window as well as the
level of maturity of the oil.
2.1.8 Reservoir Rock
Petroleum in the Niger Delta is recovered from sandstone and unconsolidated sands
predominantly in the Agbada Formation. The depositional environment and the depth of burial
control the characteristics of the reservoirs in the Agbada Formation. Reservoir rocks are
frequently Eocene to Pliocene in age, and are often stacked (Evamy, 1978). Based on reservoir
geometry and quality, Kulke describes the most important reservoir types as point bars of
distributary channels and coastal barrier bars intermittently cut by sand-filled channels. The grain
size of the reservoir sandstone is highly variable with fluvial sandstones tending to be coarser
than their delta front counterparts; point bars fine upward, and barrier bars tend to have the best
grain sorting. Much of this sandstone is nearly unconsolidated, some with a minor component of
9
argillo-silicic cement (Kulke, 1995). Porosity only slowly decreases with depth because of the
young age of the sediment and the coolness of the delta complex.
Figure 2. 1: Schematic play map showing the Niger Delta Depo-belts.
2.2 GRAVITY SEDIMENT FLOW
The movement of mixture of particles and water down a slope as a result of the influence of
gravity is known as sediment gravity flow (Middleton and Hampton, 1973). There are four major
types of sediment gravity flow which include; Grain flow, Fluidised sediment flow, Debris flow
and Turbidity currents.
Grain flow describes grains held in suspension by grain to grain collisions. For fluidised
sediment flows, grains are held in suspension by inter-granular flow and fluid escaping upward
through the grains as they settle. In debris flow however, grains are held in suspension by matrix
strength. Grains are held together in turbidity current by fluid turbulence. Sediment gravity flows
have different forms of support mechanisms. These support mechanisms depends some variables
10
such as flow conditions, the concentration and types of particles, and grain-size distribution of
the particles in the flow (Mulder and Alexander, 2001).
In this study, Turbidity current flow and Debris flow will be reviewed since they are the main
types of gravity sediment flow responsible for deposition of turbidite sands such as those seen in
offshore Niger Delta. These mechanisms are similar but have significant differences as seen in
Figure 2.2 which shows the differences between transportation and depositional processes for
turbidity current flow and debris flow.
Figure 2. 2: Differences in transport and deposition by turbidity currents and debris flow (after
Shanmugam, 2000).
2.2.1 Turbidity Currents
2.2.1.1 Formation
Turbidity currents are Newtonian flows in which the sediments are buoyed by turbulence in the
current. This current moves down slopes due to gravity and density difference between the flow
and the surrounding ambient fluid. The flow loses its ability to support the sediment with coarse
and dense grains when the velocity of the turbulence reduces. The coarse and denser grains are
therefore the first to settle out from suspension (Middleton, 1993; Shanmugam, 1997; Boggs,
11
2006). Turbidity currents can occur in any part of the system, be it proximal or distal. Turbidity
currents can also occur above debris flow due to flow transformation in density-stratified flows.
2.2.1.2 Morphology
Turbidity currents are made up of a head, body and tail (figure 2.3). The thickness of the head of
turbidity current is two times the rest of the flow and is defined by intense turbulence. The body
of the turbidity current is stable and uniform as well as characterised by steadier flow. It however
moves faster than the head. The concentration of sediments in the tail diminishes rapidly when it
mixes with the surrounding water and becomes more dilute (Boggs, 2006).
Figure 2. 3: Structure of head and body of turbidity current advancing into deep water (after
Boggs, 2006).
2.2.1.3 Deposits
Sediments which are deposited by turbidity currents are called turbidites. Turbidity currents are
defined by the high concentrations of sediments they have. They tend to form thick bedded
successions which consist of coarse-grained sandstones or gravel. The sedimentary structures
which are from high density flow with coarse grains may grade upward to finer grained deposits.
These expose traction structures such as laminations and small-scale cross bedding. These kinds
of turbidites are normally deposited in the main submarine fan transport channel.
12
Low density flows are associated with low sediment concentration. Deposits from these are
characterised by thin bedded, graded deposits with lamination and cross-bedding. These
turbidites characteristically represent over bank deposits or thin sheet deposits which is further
away from the source (Lowe, 1976; Boggs, 2006).
Turbidite sediments which are coarse-grained, massive and poorly laminated are those whose
site of deposition is close to the source within the main transport channel where suspended
sediment concentrations are high. Coarse-grained turbidites are deposited within the main
channel and can be also observed at considerable distance from the source. There may also be
deposition of thin, fine-grained turbidites near the source, where turbidity currents overflow the
banks of a channel. Away from the source, turbidity current deposits become progressively more
dilute and spread out over the seafloor (Boggs, 2006).
2.2.1.4 Turbidite Models
The Bouma sequence describes the ideal sequence of sedimentary structures in a turbidite beds
(figure 8) (Bouma, 1962). This ideal sequence comprises five structural units labeled as Ta, Tb,
Tc, Td and Te which are stacked in vertical sequence. The layer “Ta” is the lower divisions of
the Bouma sequence that may be structureless or graded to granule. “Tb” is the second division
of the Bouma sequence with parallel-laminated sandstone. The third division of the sequence is
“Tc” which is made up of current rippled laminated sandstone. Next division is the “Td”,
containing parallel laminated finer-grained and silty deposits. The last division of the Bouma
sequence “Te”, is a pelitic division. The complete Bouma sequence is rarely perceived at an
outcrop. The reason for this is the fact that the top layers may have been eroded away as a result
of turbidity flows of high sediment concentration that have ability to be erosive (Mulder and
Alexander, 2001).
The “Ta” and “Tb” units are frequently observed in thick, coarse-grained turbidites whereas “Tc”
and “Te” units are normally absent or poorly developed in thick, coarse-grained turbidites. The
Bouma sequence is still a subject of discussion and doubt to some geologists. The “Te” pelitic
unit may be hemi-pelagic mudstone which is not part of the turbidite sequence (Figure 2.4). In
most turbidite sequences, the “Td” with parallel laminated unit may be absent, thus the turbidite
beds will only be made up of only a lower parallel-laminated unit (Tb) and an upper cross-
13
laminated unit (Tc) (Boggs, 2006). Middleton and Hampton (1973) proposed that the entire
sequence is a product of turbidity current. Lowe (1982) is of the view that the “Ta” division is
not a member of the Bouma sequence. According to Lowe, the Ta division is considered as a
deposit of high density turbidity current, while “Tb”, “Tc” and “Td” divisions are considered to
be deposits of low density turbidity current (Figure 2.4). According to Shanmugam (1997), the
“Ta” is considered as turbidity current if it is normally graded, otherwise it is a product of a
sandy debris flow. “Tb”, “Tc” and “Td” divisions are considered to be deposits of bottom-current
reworking.
Figure 2. 4: Ideal Bouma sequence showing Ta, Tb, Tc, Td, and Te divisions ( after Shanmugam,
1997).
2.2.2 Debris Flows
Flow that is described by high viscosity and sediment concentration is known as debris flow. It is
also classified as plastic flow as it may often be reinforced by a matrix of sand or mud
(Middleton, 1993). This kind of flow can occur in both subaerial and subaqueous environments
as the trend in the Niger Delta development period.
Debris flows with slow-moving laminate slurry can originate on steep slopes more than 10º, but
they can continue flowing across large distance on gentle slope 5 º or less. Debris flow can also
be in the form of fast-moving semi-rigid plug of material that contains aquaplanes over a basal
14
shearing layer as a result of the lack of friction. With the buildup of pore pressure in the basal
zone as well as the that resulting from water entrapment under a plug of material, a slow-moving
debris flow can be transformed into a fast moving debris flow (Stow and Johansson, 2000).
Debris flows comprise the motion of large poorly sorted combinations of clastic material. These
may range from boulder-size to fine gravel, sand, silty sand or mud matrix. The Debris flow is
characterized by a vicious frontal impact surging and flow cessation on steep slope. The total
mass of debris flow as well as the flowing muds is deposited quickly.
The cessation of movement occurs when the shear stress due to gravity becomes less than the
yield strength of the base of the moving material. The whole mass then ceases to flow and
freezes at that point (Boggs, 2006). Due to plastic rheology of debris flow, the flow freezes
immediately after shear stress becomes less than internal shear stress strength of the sediment
water mixture, then the formation of thrust fault and compressional ridges is caused by the
freezing process.
2.2.2.1 Debris-Flow Deposits
The main characteristic of debris flow deposits is the occurrence of thick, poorly sorted units
which lack internal layering. They are also poorly developed in clastic fabric, irregular mounded
tops as well as tapered flow margins (Pickering et al., 1989). Grading of debris flow is usually
poor, but both normal and reverse grading may occur (Boggs, 2006). Deposits of debris flow
material are known as debrite. Conventionally, debris flows are considered as moving mass of
rock, clay minerals and water, which may be viewed as plastic flow (Lowe, 1982).
2.2.3 Slumps
One of the many mass flows that show order and coherence is referred to as slump. Slumps are
one of the coherent mass flows and when the shear strength of the sediment on the slope is
surpassed by the slope shear stresses then there is the possible occurrence of slump. Slumps
consist of large different kinds of deformed sediments. The lithology of slumps is various, it can
be only mudstone or sandstones bed which is pulled-apart or rolled-up (Walker and Posamentier,
2006). The most important facies of slumps are mudstones whose deposition is relatively rapid.
Slumps are described by tensional fractures at the head and compression and folding at toe.
15
The indication of folding and shearing is observed in sediments of slumps. Folds in slumps can
be in the given direction of slump movement. The distance of transportation of material with this
method varies widely. Transport distance of slump can vary from a few meters to hundreds of
kilometres across basin floors.
The initial deposition of sandstones in slumps is rapid therefore trapping in it a lot of fluid which
at the period has not yet been expelled. This fluid is subsequently sealed by impermeable shale
and mudstone units. As deposition continues, the lithostatic load would increase accompanied by
a rising fluid pressure for trapped fluids that are not able to escape. One key mechanism in the
formation of slumps is the occurrence of bed failure along weak planes and layers of high pore
pressure. In the course of de-watering of sediments, deposits may move a few meters so that
these sediments units would be recognised as slumps (Figure 2.6). Given that the sediments are
transported over long distances, deposits may be established as debris flow (Figure 2.6).
Figure 2. 5: Schematic illustration of head and toe of slumps.
16
Figure 2. 6: Difference between slide, slump, debris flow and turbidity current process.
Slumps are generally made up of one or two beds which are characterised by un-deformed
bedding below as well as above the slump horizon and the presence of coherent beds that are
rolled-up in the interior of the slump.
2.2.4 Submarine Slope Canyon and Slope Channels
Submarine canyons and gullies are characterised by features which show a history of erosion that
are thought to have taken place on a slope. The size of a submarine canyon is generally bigger
than gullies, but there are no standardised sizes criteria to differentiate between them. Submarine
canyons are steep sided valleys looking more like escapement that incise the continental slope
and shelf. Submarine canyons serve as major channels for transportation of sediments from the
land and continental shelf to the basin floor/sea floor. The major difference between canyons and
slope channels is the full confinement of sediment gravity flows within the walls of the canyons
whereas in slope channels or gullies, the sediments are not fully confined by channel walls
(figure 2.8).
Levee channel deposits are generally witnessed outside the channel or gullies due to the fact that
the channel does not fully confine the flow of the sediments. In canyons, where the flows are
completely confined, levee formation does not take place. Both canyons and slope conduits can
be made deeper by the passage of turbidity currents, but canyons walls experience mass wasting
17
events and tend to grow wider as compared to slope channels. The section of high sinuously
channel deposits are seen in the canyon trace which is positioned above the canyon floor.
Figure 2. 7: Schematic illustration of slope and deep marine environments.
Figure 2. 8: Illustration of section views across a A) canyon B) slope channel or gully ( after
Walker, 1984).
Channels are characterised by sharp erosional bases and up-dip. Channel fill is mostly confined
to the depression and they are frequently eroded into the sea floor. Merged stacking pattern of
channels are typically observed in canyons and valleys that are mid-slope and proximal fill of
these channels. The source area as well as the sedimentary slope determines the nature of the
channel deposits. As a result of this dependency, the sands are less likely to be merged and fine
18
sediments may be inter-bedded in between sands deposits. At the base of slope where channels
emerge from canyons and valleys in the slope, channel widths may be in the range of 3km to
about 200km (Posamentier and Kolla, 2003).
Most of the deep marine channels are characterized by meandering systems that have moderate
to high sinuously feature. High-amplitude seismic reflection is determined by sand rich channel.
Elongate shape of channel is shaped in the down dip area. The shape of channel in the form of
gull wings is formed by proximal levee deposits closer to the canyon mouth. Erosion of channels
frequently occurs in the mid fan to distal parts of the base of shelf margin slope.
Description and estimation of turbidity reservoir channels are very challenging, even for
occasions in which high quality seismic data is available. This is principally due to variable
facies and complex stratigraphy of turbidity channel. Diverse processes make channel sinuously
and these include; erosion, lateral stacking accretion and sea floor topography. The distribution
of reservoir facies is predominantly dependent on the different style of sinuosity of the channel.
Continual cutting and filling structures can be seen in many turbidity channels. These
developments have major repercussions for reservoir and non-reservoir distribution (Mayalla,
2006). Four main facies can be recognised in a turbidity reservoir channel (Mayalla, 2006).
These include:
Basal lag of coarse sand/conglomerate, mud-clast conglomerate or shale drapes.
Slumps and debris flows which may have been derived locally from collapse of channel
walls or as a result of long distance transportation.
High net-gross stack channels from the best quality reservoirs.
Low net to gross sinuous channel levee caps that the channel fill and which may spill
away from the original erosional confinement. Additionally, during high stand periods,
channel is occupied by mud-dominated deposits.
2.2.5 Submarine Canyon
The specifications for the classification of modern canyons are comparatively narrow, deeply
engraved, steep-sided, often sinuous valley showing a V-shaped cross-section. Most canyons
19
originate close to the continental shelf break and in general extend to the basin. Canyons are also
created near the mouths of the large rivers such as the Mississippi river. The significant factors
that control the formation of submarine canyons include the tectonic setting and changes of sea
level. The seismic reflection pattern of mud-dominated canyon is described by moderate to low
amplitude, discontinuous disordered contorted seismic reflection, which show mass transport
sediments like slides and debris flows (Posamentier and Kolla, 2003)
Isolated threads of sandy channels are also detected in seismic section of canyons, which are
characterised by high amplitude continuous or discontinuous seismic reflections at and close to
the canyon base or embedded within canyon fill near the canyon base. After the canyons or
channels have been bandoned, fine grain sediments are deposited in most of the canyons. When
the level of the sea rises, sediment supply of canyons is in the form of slump and slide material
from the canyon or slope channel walls with extra contribution of hemi-pelagic mud and silt that
steadily settle down over the area covered by the slope and in the canyon. During rapid sea level
rise, mass wasting of sediments fills the bulk of canyons thus making the fill principally part of
the transgressive and high stand systems tracts.
Facies of canyon sediments ranges from debrite to turbidite deposits. Mud-dominated deposits of
canyons are characterised by debris flows with minimal interior organization. Isolated channel
deposits can be seen within canyons and these are marked by turbidite facies. The units in the
Bouma facies sequence A and B, are frequently found in isolated channel deposits with the
absence of C, D and E units due to erosion by turbidity currents which passed through channel.
There is often the formation of isolated channel with levees in the middle or upper part of the
canyon fills or within the confines of the canyon walls. This situation can be shaping in as
turbidity flow sweeps across the relatively flat floor of a incompletely filled canyon.
2.3 TYPES OF PETROPHYSICAL LOGS
2.3.1 Resistivity Log
Resistivity logging is a method of well logging that works by characterising the rock or sediment
in a borehole by measuring its electrical resistivity. Resistivity is a fundamental material property
which represents how strongly a material opposes the flow of electric current. In these logs,
resistivity is measured using electrical probes to eliminate the resistance of the contact leads. The
20
mud or fluid in the well must have electrical conductance in order to allow these types of logs to
be run.
Resistivity logging is sometimes applied in mineral exploration and water-well drilling, but most
commonly for formation evaluation in oil and gas industry. Most rock materials are essentially
insulators, while their enclosed fluids conduct electric current. Hydrocarbon fluids however do
not conduct electricity due to their infinite resistive nature. When a formation is porous and
contains salty water, overall resistivity will be lower. When the formation contains hydrocarbon,
or contains very low porosity, its resistivity will be higher. Higher resistivity values may indicate
a hydrocarbon bearing formation.
Fluids used during drilling sometimes invade the formation and the resistivity from this invaded
zone is measured by the tool as well as a deeper resistivity where there has not been any fluid
invasion. For this reason, several resistivity tools with different investigation lengths are used to
measure the formation resistivity. If water based mud is used and oil is displaced, deeper
resistivity logs (or those of the "virgin zone") will show higher resistivity than the invaded zone.
If oil based mud is used and water is displaced, deeper logs will show higher conductivity than
the invaded zone. This provides not only an indication of the fluids present, but also, at least
qualitatively, whether the formation is permeable or not.
2.3.2 Gamma Ray Log
Gamma ray logging is a method of measuring naturally occurring gamma radiation to
characterise the rock or sediment in a borehole or drill hole. It is a wire-line logging method used
in mining, mineral exploration, water-well drilling and for formation evaluation in oil and gas
industry. Different types of rocks emit different amounts and different spectra of natural gamma
radiation. Shales typically emit more gamma rays than other sedimentary rocks, such as
sandstone, gypsum, salt, coal, dolomite, or limestone. This is due to the fact that radioactive
potassium is a common component in the clay and the amount of clay is directly proportional to
the amount of radiation released. The cation exchange capacity of clay causes it to adsorb
uranium and thorium. This difference in radioactivity between shales and sandstones/carbonate
rocks allows the gamma tool to differentiate between shales and non-shales.
21
The gamma ray log, like other types of well logging processes is conducted by lowering an
instrument down the drill hole and recording the amount of gamma radiations relative to depth.
Gamma radiation is generally recorded in API units, a measurement originated by the petroleum
industry. Gamma logs are attenuated by diameter of the borehole because of the properties of the
fluid filling the borehole, but because gamma logs are most often used in a qualitative way,
corrections are usually not necessary.
Some elements and their decay chains are responsible for the radiations that are emitted by rocks.
These include: potassium, thorium and uranium. Shales often contain potassium as part of their
clay content, and tend to absorb uranium and thorium as well. A common gamma-ray log records
the total radiation, and cannot distinguish between the radioactive elements, while a spectral
gamma ray log is able to distinguish between them.
For standard GR logs the value measured is calculated from thorium in ppm, Uranium in ppm
and potassium in percent. GR API = 8 × Uranium concentration in ppm + 4 × thorium
concentration in ppm + 15 × potassium concentration in percent. Due to the weight of uranium
concentration in the calculation anomalous concentrations of uranium can cause clean sand
reservoirs to appear shaley. Spectral Gamma ray is used to provide an individual reading for each
element so anomalies in concentration can be found and interpreted.
An advantage of the gamma log over some other types of well logs is that it works through the
steel and cement walls of cased boreholes. Although concrete and steel absorb some of the
gamma radiation, enough travels through the steel and cement to allow qualitative
determinations.
Sometimes non-shales also have elevated levels of gamma radiation. Sandstone can contain
uranium mineralization, potassium feldspar, clay filling, or rock fragments that cause it to have
higher-than usual gamma readings. Coal and dolomite may contain absorbed uranium.
Evaporites deposits may contain potassium minerals such as carnallite. When this is the case,
spectral gamma ray logging can be done to identify these anomalies.
22
2.3.3 Density Log
Medium energy gamma rays are emitted into formation and detected. The number of these rays
detected depends on amount of Compton Scattering which depends on electron density of
formation. The electron density is related to bulk density.
To determine porosity, the medium-energy gamma rays emitted into the formation collide with
electrons in the formation. At each collision, a gamma ray loses some, but not all, of its energy
to the electron and then continues with reduced energy. This type of interaction is known as
Compton scattering. The scattered gamma rays reaching a detector at a fixed distance from the
point of emission are counted as an indication of the formation density. The number of Compton
scattering collisions is related directly to the number of electrons in the formation. Therefore, the
response of the density tool is determined essentially by the electron density (the number of
electrons per cubic cm) of the formation.
Electron density is related to the true bulk density in gm/cc, which in turn depends on the density
of the rock matrix, the formation porosity and the density of the pore fluids.
For a pure element, the electron density index, which is proportional to the electron density, is
defined as:
A
Zbe
2*
where:
ρe is the electron density index
ρb is the bulk density
Z is the atomic number of the element
A is the atomic weight of the element.
The density tool is calibrated in a fresh water filled limestone formation of high purity to give
an apparent density that is related to the electron density index by ρa = 1.0704ρe - 0.1883.
For liquid filled sandstones, limestones and dolomites, the apparent density read by the tool
23
is practically equal to bulk density of the formation. The bulk density of a clean formation is
given by: 1mafb
This equation can be solved for porosity, but the matrix and fluid densities must either be known
or assumed. In most cases, the fluid density is assumed to be 1.0 gm/cc whereas the density for
sandstone matrix is assumed to be 2.65gm/cc. The depth of investigation of the density log is
relatively shallow. Therefore, in most permeable formations, the pore fluid is considered to be
the drilling mud filtrate along with any residual hydrocarbons. When residual hydrocarbon
saturations are fairly high, this can cause the calculated porosity values to be greater than the true
porosity. This effect should always be corrected.
2.3.4 Neutron Log
In this method, high energy neutrons are emitted into formation. The number of neutrons that are
captured are detected and the point of their capture from the transmission point recorded by two
receivers. This effect is mainly due to the amount of hydrogen in formation. This wire-line log
method is used in conjunction with the density log to indicate presence of gas in formation,
identification of GOC (gas oil contact) as well as identify the lithology of the formation.
The principle behind the neutron logging method is as follows; A neutron sonde which contains
a radioactive source emits fast neutrons into the formation. These neutrons loose energy as they
collide with the nuclei of the atoms in the formation and this process continues until the energy
of the neutrons has declined to the thermal energy. A peak in the distribution of thermal neutrons
will be created at a shorter or longer distance from the source, depending on the effectiveness of
the formation to slow the neutrons.
The ability of the formation to slow down neutrons is determined largely by the amount of
hydrogen present. This is because the nucleus of a hydrogen atom, a proton, has approximately
the same mass as a neutron, and causes the maximum amount of energy to be lost by the
neutrons for each collision.
Two neutron detectors are used to locate the position of the peak in the thermal neutron
distribution. The distance of this peak from the neutron source is interpreted in terms of the
24
amount of hydrogen present in the formation. This can then be translated into the amount of
hydrocarbon or water present.
2.3.5 Sonic Log
The typical sonic logging tool will consist of transmitters and receivers placed in the wellbore.
The transmitter generates pressure pulse in the borehole fluid. When this pulse reaches the
borehole wall, Primary and Secondary wave-fronts are generated in the formation. As the waves
travel away from the source in the formation, the portions near the wellbore create pressure
disturbances in the borehole fluid. These fluid waves are called head waves and they move
at the same velocity as the wave-fronts that created them. It is these head waves that are recorded
by sonic logging tools.
2.4 METHODS FOR PETROPHYSICAL ANALYSIS OF THIN BEDS/TURBIDITES
The recent discovery of significant amounts of hydrocarbons in thin beds has necessitated the
need to re-focus on obtaining a better understanding of these formations. Much work has been
carried out all in an effort to increase confidence in the petrophysical analysis of these kinds of
reservoirs. The most common among these techniques include: 1. Thin bed analysis using
resistivity borehole image tools. 2. Resistivity Anisotropy.
These are discussed below:
2.4.1 Thin Bed Analysis Using Resistivity Borehole Image Tools
The resistivity borehole image method is one of the techniques used in reservoir characterisation
of turbidite sand sequences. This technique allows for the enhancement of the resolution of
standard logs. This can be achieved by using high resolution shallow resistivity log recorded by
borehole imager. This technique improves the normal log resolution enables better understanding
of the true layer properties.
2.4.1.1 Workflow
1. Input of resampled depth matched logs.
2. Delineate the bed boundaries using the resistivity log.
3. The various lithofacies are identified and classified.
25
4. Filters are created for each facies.
5. Square logs are generated by applying the filters to each of the logs.
6. Optimization of iteration
7. The output logs have higher resolution. These include the RT, GR, RHOB, and NPHI logs.
8. Volumetric computation of shale volume, porosity and saturation are then carried out.
2.4.1.2 Bed Boundary Identification
For this method, the boundaries are delineated using inflection points in SRES data. This can be
achieved by manual methods or by the use of software. The software delineates the bed
boundaries using maximum slope change (second derivative method) in SRES log.
2.4.1.3 Classification and Identification of Different Lithofacies
In this method, the litho-facies are subdivided into three main litho-facies. These include sand,
silt, shale and two other supplementary facies labelled wet and tight. Litho-facies can be
recognised by the use of normal logs and volume of shale. Higher resistivity indicates sands,
moderate resistivity indicates silt and low resistivity indicates shale. The density and the neutron
logs are used to identify the hydrocarbon bearing zones. Oil Based Mud invaded wet sand and
silt can be differentiated by the deep resistivity curve. Low invaded water wet sand and shale can
be distinguished using volume of shale curve. The litho-facies model of sand, silt and shale can
be defined by using threshold values of shale volume as well as standard input logs. The deep
resistivity log and the bulk density are used to delineate the auxiliary litho-facies which may be
wet or tight.
2.4.1.4 Optimization of Iteration
After generation of the initial set of square logs optimiser would check whether the squared logs
are corresponding to the standard log from which they were generated or not Given that they do
not match, then optimiser iteratively changes the average value for each log for each facies to get
a best match.
26
The generated data is adjusted by the use of the parameters gotten from core data. The
petrophysical parameters are then computed using the adjusted log values.
2.4.1.5 Limitations
1. The computation is based on modeled curves, in which the facies classification is completely
dependent on the person interpreting.
2. Hard streaks may also be picked as hydrocarbon bearing sand zones.
3. The resolution achieved from these operations is still not able to capture sand laminae that are
less than an inch. This may lead to resource underestimation.
4. Zones with thin shale layers within sand may also be over looked therefore overestimate the
net sand.
5. The sampling interval of the final output becomes very small or extremely fine. This means it
cannot be used in geo-cellular model building for property population as the number of cells in
the model goes to 100’s of million. The essence of the technique is lost in up-scaling for realistic
and practically workable geo-cellular model.
2.4.2 Resistivity Anisotropy Method
The 3D resistivity anisotropy method was developed as an improvement of the resolution ability
of the image logs. This enabled the study of sand beds which are thinner than the resolution of
the image logs. The resistivity of the sand layers is measured in the horizontal as well as the
vertical directions that is both parallel and perpendicular to the sand and shale layers.
The horizontal resistivity, Rh is generally affected by the presence of conductive shale layers as
it views the layers as resistors in parallel. The resistivity is therefore decreased. The vertical
resistivity, Rv on the other hand views the sand-shale layers to be series resistors and measures
the resistivity as such. By using the Rv (vertical resistivity) and Rh (horizontal resistivity),
resistivity of the sand and shale in both vertical and horizontal directions are estimated using
established equations. The set of equations used to achieve this are listed below:
27
sd
sd
sh
sh
h R
V
R
V
R
1…………….. (1)
sdsdshshv RVRVR ** ……… (2)
1 sdsh VV …………………..…. (3)
The equations are established on the assumptions that sands are isotropic whereas shales show
anisotropy (Transversely Isotropic). Rv shale and Rh shale are the critical input parameters for the
estimation of Rsd. These are measured from the clean shale zone.
2.4.2.1 Generalised flowchart of laminated shaly sands
The porosity, volume of shale and water saturation are the key parameters needed for resource
estimation of sand layers. Volume of shale is the most critical of all the parameters and controls
the other two parameters. It is therefore imperative that the value for Vsh is accurate. This is
achieved by using more than one technique in estimation of Vsh and also needs to be
corroborated with external data such as core data. The values of Vsh and total porosity are used in
the Thomas Stieber method to find shale distribution.
For this model, there are three categories of shale distributions which include.
1. Laminated- layer of shale found in the sand.
2. Dispersed shale which is found on sand grains or pore filling.
3. Structural sand sized shale particles in load bearing position within the rock.
The shale distribution as well as the porosity can be computed form Thomas-Stieber cross-plot,
where Volume of shale is plotted on X-axis and the total porosity on Y-axis. Based on the
position of data points in this cross plot, laminar (Vl), dispersed (Vd), structural (Vs) shale
volumes and porosity of sand laminae can be established using following equations.
28
For the cases where the amount of dispersed shale is small, then the Archie equation can be used
directly to estimate the hydrocarbon saturation. Other equations that can be used given that the
shale volume is significant include the Waxman-smith equation.
2.4.2.2 Limitations
1. The presence of calcareous sand streak or any other electrically anisotropic layer (like calcite)
will enhance the Rv. This leads to an overestimation of Rsd. This higher Rsd will give greater
saturation.
3. Silt is mostly present in clastic environments but the presence of any third facies like silt or
calcite is not taken into consideration by this technique. In view of the effects of a third facies in
the estimation of Rv and Rh, the computation becomes significantly more difficult.
4. Sand is considered to be isotropic in this method. It is however not true since laminations
(planar and cross-bedding) are quite common. The lack of consideration of internal anisotropy
renders this method less accurate and this leads to over-estimation of hydrocarbon volume.
5. Higher shale anisotropy may also lead to an increment in Rv in the shaly sand reservoir and
may therefore push down the contact by a few meters if existent near the contact.
29
2.5 MONTE CARLO SIMULATION/ RISK ANALYSIS SOFTWARE
2.5.1 Introduction
The need to quantify uncertainty associated with petrophysical parameters determined in the
field has been an essential part in the development of Petrophysics. Many attempts have been
made to fully understand and describe the various uncertainties associated with petrophysical
parameters. The application of Monte Carlo simulation method to quantify uncertainties has
brought great enhancement in the accuracy of results from uncertain inputs. The technique was
first applied in a manufacturing company considering a new product line and has since been
adopted by other industries including the oil and gas industry.
To apply this method, the estimate of probability distributions of input parameters such as
porosity and water saturation are determined. The distributions are then combined through
simulation to estimate a probability distribution of the output parameter, say the STOOIP (Stock
Tank Oil Originally in Place). A decision can then be made on whether to move to the next phase
of the project, given the probability of certain outcomes. Monte Carlo has also been applied in
the simulation of economic models for exploration prospects, to estimate risk and manage
performance associated with drilling.
The following outlines the various aspects of simulation and its importance as a tool for
uncertainty determination.
2.5.2 Risk Simulator
Risk Simulator is a Monte Carlo simulation, forecasting, and optimization software. It is written
in Microsoft .NET C# and functions with Excel as an add-in. The different functions in software
applications are briefly described below.
2.5.2.1 Simulation Module
The Simulation Module allows you to:
Run simulations in your existing Excel-based models
Generate and extract simulation forecasts (distributions of results)
Perform distributional fitting (automatically finding the best-fitting statistical
30
distribution)
Compute correlations (maintain relationships among simulated random variables)
Identify sensitivities (creating tornado and sensitivity charts)
Test statistical hypotheses (finding statistical differences between pairs of forecasts)
Run bootstrap simulation (testing the robustness of result statistics)
Run custom and nonparametric simulations (simulations using historical data without
specifying any distributions or their parameters for forecasting without data or applying
expert opinion forecasts)
2.5.2.2 Forecasting Module
The Forecasting Module can be used to generate:
Automatic time-series forecasts (with and without seasonality and trend)
Automatic ARIMA (automatically generate the best-fitting ARIMA forecasts)
Basic Econometrics (modified multivariate regression forecasts)
Box-Jenkins ARIMA (econometric forecasts)
GARCH Models (forecasting and modeling volatility)
J-Curves (exponential growth forecasts)
Markov Chains (market share and dynamics forecast)
Multivariate regressions (modeling linear and nonlinear relationships among variables)
Nonlinear extrapolations (curve fitting)
S-Curves (logistic growth forecasts)
Spline Curves (interpolating and extrapolating missing values)
Stochastic processes (random walks, mean-reversions, jump-diffusion, and mixed
processes)
31
2.5.2.3 Optimisation Module
The Optimisation Module is used for optimizing multiple decision variables subject to
constraints to maximize or minimize an objective. It can be run as a static optimization, as a
dynamic optimization under uncertainty together with Monte Carlo simulation, or as a stochastic
optimisation. The software can handle linear and nonlinear optimizations with integer and
continuous variables.
The Real Options Super Lattice Solver (SLS) is another standalone software that complements
Risk Simulator, used for solving simple to complex real options problems.
32
CHAPTER 3
MATERIALS AND METHODS
3.1 SUMMARISED FLOWCHART OF METHODOLOGY
Gamma Ray Log
Density Log
Neutron Log
Resistivity Logs
Delineate Gross Sand
Delineate Pay zones
Estimate Total Porosity
Delineate Net Pay
Estimate Volume of
shale (Vsh)
Estimate Effective
Porosity
Calculate Permeability Estimate Water
Saturation (Sw)
Establish Porosity
Cutoff
Establish Sw Cutoff
Calculate the Stock Tank Original Oil in
Place
Pick out Permeability-
Porosity Data
Establish Flow Units
Run results on @Risk
Software
Plot Data Calculate RQI and Фz
Sensitivity Analysis
Correlate Flow Units
Deterministic Result
Probabilistic Result
+
Figure 3. 1: Flow chart showing the processes involved in analysis of data.
33
3.2 OUTLINE OF METHODOLOGY
The approach adopted for analysis of the corrected petrophysical log data is as follows:
1. The gamma ray log was used in Techlog to delineate the sand zones. This was done after
setting the baseline value of gamma ray reading for sand to 75gapi. The gamma ray log is
also employed in establishing the volume of shale for each of the gross sand zones
delineated. This is achieved by first calculating the gamma ray index and then using the
gamma ray index in the Dressler Atlas equation to evaluate the volume of shale.
2. The density log was used to estimate the total porosity for all the gross sand zones. The
estimated porosity is then corrected using the relationship between the core and the log data.
The porosities are averaged over the sand zones to generate a more representative porosity.
The effective porosity is determined from the corrected porosity by adjusting the calculated
porosity for volume of shale present.
3. The resistivity as well as density and neutron logs are used in techlog log-view to obtain
zones of hydrocarbons. These logs are used to establish the zones of hydrocarbons - the net
pay zone. The zones with hydrocarbons are recognized due to their higher resistivities. This
is especially so when the deep resistivity log reading is relatively higher than the shallow
resistivity reading. The nature of this type of reservoir does not allow the resistivity
differences to show clearly though.
4. The permeability within the gross sand zone is calculated from established equations. Some
of the parameters involved in this calculation include: effective porosity, irreducible water
saturation and cementation factor.
5. The permeability is used to establish net pay cutoff for porosity. The cutoffs are established
as deterministic cutoff which is fixed at one value and the probabilistic cutoff which ranges
from a lower limit to an upper limit within the distribution fitting during @Risk simulation.
6. The permeability is used with the porosity to establish the flow units within the reservoir
sands. This is done to establish the possible flow path of liquids during production as well as
to establish the best intervals for perforation.
34
7. The sensitivity of the calculated stock tank oil originally in place to total porosity, shale
volume and water saturation is assessed using sensitivity analysis tool in @Risk simulator.
This is to establish how these input parameters affect the final evaluated STOOIP.
3.3 DETERMINATION OF LITHOLOGY FROM WIRE LINE LOGS
The interpretation of the log data was carried out for each of the wells using all the logs that were
acquired in the systematic methodology adopted above. This was done after the core data
obtained alongside the log data was used to correct the log data. Since there was core data for
only one well, the correction was first made for that well before it was extended to the other
wells.
The lithology basically of sand and/or shale was corroborated and compared at given depths to
the gamma ray logs horizontally. These interpretations were also carried out for other logs which
include: resistivity, sonic and density-neutron. The lithology was noted and matched to the core
for depths for which all the logs gave the same interpretation. There was quality checking in
areas where the various logs gave incoherent interpretations. This was done in order to identify
reasons for the errors as well as to correct the mismatch in the interpretations.
3.4 ESTIMATION OF PETROPHYSICAL PARAMETERS
The petrophysical parameters of interest were estimated using well established methods and
methods which have been known to work perfectly in the Niger Delta Petroleum province. The
petrophysical parameters of interest were those that were to be used in the estimation of the
reserves in the area of study. The procedure used for these estimations is described in the
following:
3.4.1 Net Pay Thickness (Net/Gross)
Net to Gross ratio is the ratio of the sum of the thicknesses of the net pay zone to the total
thickness or depth of the well. The gross thickness is gotten by measuring from the top of the
well to the bottom while for the net thickness is composed of the aggregation of delineated net
pay zones as established with the various petrophysical logs.
From this point, the ratio of the net to gross reservoir thickness is estimated for each of the wells.
An average net to gross is calculated to include the impact of all the wells net to gross values.
35
3.4.2 Shale Volume
It is often expected that the zones delineated by the gamma ray log as sand are not actually 100%
sand but a combination of predominantly sand and some amount of shale or clay. The volume of
shale (Vsh), in these sand bodies can be estimated by means of the following equations.
The gamma ray index IGR is first calculated from the gamma ray log as presented below:
minmax
minlog
GRGR
GRGRIGR
…………………. a
Where:
IGR is the gamma ray index
GRlog is the Gamma Ray Log reading of the formation
GRmin is the Gamma Ray for a complete sand matrix zone (Clay free zone)
GRmax is the Gamma Ray for a complete shale zone (100% Clay zone)
The Volume of shale is then determined using the gamma ray index obtained above in the
following: Dressler Atlas equation for calculating volume of shale for unconsolidated sandstone.
12*083.0*7.3
GRI
shV …………………. b
3.5.3 Porosity
Porosity is the ratio of the volume of pore spaces in a rock to the total volume of the rock.
Primary porosity is the porosity developed during the original sedimentation process by which
the rock was formed. In reports, it is often referred to in terms of percentages, while in
calculations a decimal fraction is used. The porosity of the reservoir in this report is estimated by
using the density log. The porosity of the reservoir was calculated as shown in the following
equations:
36
fma
bmaTD
Where,
ФT =ФTD = Total Porosity estimated from density log
ρma = Matrix (or grain) density
ρb = Bulk density (as obtained from the tool and hence includes porosity and grain density)
ρf = Density of the fluid.
Following the above calculation, the effective porosity was then determined using the equation
given below:
fma
shmash
fma
bmae V
*
Where:
Фe = Effective porosity
ρsh = Density of shale
fma
shmashV
* is the Clay bound water
(ρma = 2.65g/cc, ρf = 1.0g/cc, ρsh = 2.6g/cc)
3.4.4 Water Saturation
Water saturation refers to the ratio of water volume to that of the pore volume of the rock. Water
bound to the clay is not inclusive. This means shale corrections must be made if there is the
presence of shale. This is taken care of during the determination of the shale volume.
37
Water saturation is estimated from the effective porosity and the resistivity logs. Just as it is done
for porosity, saturation data is usually stated in percentage units but for the sake of calculations
the decimal fraction is used. Porosity refers to the capacity of the rock to hold fluids whereas
saturation is the fraction of this capacity that is actually filled with any particular fluid. The
hydrocarbon saturation can be calculated directly using the water saturation.
The Archie Equation is employed in the estimation of water saturation. The irreducible water
saturation is estimated using the water saturation and the effective porosity. The bulk water
volume is first calculated for each depth of the reservoir and the lowest constant value is
obtained as the irreducible water saturation. The equations are as shown below:
n
t
m
e
ww
R
RaS
1
*
*
(a = 1.0, m = 2, n = 2)
Where:
Rt = Deep Resistivity
Rw = Down hole water resistivity
Фe = Effective porosity
Sw = water saturation
a = Archie’s exponent
m = cementation factor
n = Saturation exponent, it is the gradient of the line defined on the plot.
wSBVW *
BVW is Bulk Volume Water
Sw is Water saturation
38
3.4.5 Net Pay
The porosity cut off is determined by the use of the permeability-porosity cross-plot and
applying the rule of thumb for base permeability to the estimation of the porosity cutoffs. The
porosity cut off for oil zones correspond to permeability equal to 1mD whereas for the gas zones,
the permeability applied to obtain cut off porosity is 0.1mD.
The shale volume cutoff applied was 45%. The cut-off applied for water saturation was also
45%. The reservoir is defined by porosity as determined from the permeability-porosity cutoff
analysis with a shale volume of less than 45%. The reservoir is considered to contain significant
amount of hydrocarbon when the water saturation is less than 60%. The following figure shows
the determination of porosity net pay cutoff for oil.
Figure 3. 2: Graph showing the determination of porosity cutoff for delineation of pay zone.
3.4.6 Permeability
Permeability controls the ability of fluid to migrate through the reservoir. Permeability is
essential in the study of subsurface fluid movement. This is so because it is one of the most
essential parameters in the prediction of fluid flow patterns. Normally, the permeability should
increases with increasing porosity, grain size as well as improved sorting in sandstone reservoirs.
39
The permeability, despite the fact that is a key parameter cannot still be obtained directly from
well logs. It is therefore estimated from indirect methods such as the use of well-established and
applicable empirical correlations. In this project the Timur equation and the Morris Biggs Oil
equation which are experimental relations are adopted to estimate the permeability. The values of
permeability obtained from these methods are then averaged as the permeability. The following
is an outline of the equations employed:
Timur Equation:
2
4.4
*8581wi
e
SK
Morris Biggs Oil Equation:
2
6
*62500wi
e
SK
Where:
K = permeability
Φe = effective porosity
Swi = irreducible water saturation
3.4.7 Hydrocarbons-in-place Volumes
Both deterministic and probabilistic approaches were adopted to evaluate the original
hydrocarbon-in-place for the reservoir. The deterministic method was carried out using the mean
weighted averages of porosity, water saturation, gross rock volumes and net-to-gross ratios
whereas the probabilistic method comprised a series of parameters with weights for which a
sensitivity analysis is run.
40
3.5 CORES
The data derived from core is presumed to be more accurate than the wire line log data and it is
used to basically calibrate the log data. They are also used as a reference to corroborate the
lithology interpretation obtained from wire line logs. The parameters obtained from the cores in
essence presents proper understanding of wire line logs and provide an interpreter real
subsurface lithologies. This process describes quality control process. The following shows the
relationship between the core and log data for porosity which is used for quality control
purposes.
Figure 3. 3: Relationship between core data and log data for quality control.
41
CHAPTER 4
DATA PROCESSING AND ANALYSIS
4.1 PROCESS OF EVALUATION
For the purpose of this research work, two reservoirs are analysed here. The reservoirs of interest
are the two deepest reservoirs designated reservoir 7 and reservoir 6 respectively. Reservoir 7 is
present in four wells whereas reservoir 6 is present in two wells. The deterministic values of
STOOIP is first calculated for each reservoir. The value of STOOIP obtained for deterministic
method is subjected to uncertainty analysis. To achieve this, the input parameters are fit with
distributions, the objective variable (in this case Net Pay Thickness) is chosen for different cases
and the uncertainty analysis run with the output being the STOOIP obtained from the
deterministic method.
The next stage of the analysis involve the delineation of the flow units using different methods
and finally the calculation of a deterministic STOOIP with consideration to the flow units
present. Some of the parameters needed in the evaluation are discussed below;
4.1.1 Reservoir Quality Index (RQI)
This concept was introduced by Amaefule et al. It is used to express the relationship between
porosity and permeability of a reservoir unit. This takes into consideration the pore-throat, pore
and grain distribution, and other macroscopic parameters. In using this method, permeability is
expressed in millidarcies and porosity as a fraction. RQI is expressed mathematically as:
e
KRQI
0314.0
4.1.2 Flow Zone Index (FZI)
FZI is found on the RQI versus normalized porosity plot. The FZI is the intercept of a straight
line on RQI axis at a normalized porosity value of 1. Samples with different FZI values will lie
on other parallel lines. Samples that lie on the same straight line have similar pore throat
characteristics and, therefore, constitute a flow unit. Straight lines of slopes equal to unity should
be expected primarily in clean sandstone formations. Slopes greater than one indicate a shaly
formation.
42
The flow zone indicator (FZI) is a unique parameter that includes the geological attributes of the
texture and mineralogy in the structure of distinct pore geometrical facies. In general, rocks
containing authogenic pore lining, pore filling and pore bridging clay as well as fine grained,
poorly sorted sands tend to exhibit high surface area and high tortuosity, hence low FZI. In
contrast, less shaly, coarse-grained, and well-sorted sand exhibit a lower surface area, low shape
factor, lower tortuosity, and higher FZI. Different depositional environments and digenetic
processes control the geometry of the reservoir and consequently the flow zone index (Tiab, D.
2004).
4.1.3 Tiab Hydraulic Flow Unit (HT)
Hydraulic flow unit is a continuous body over a specific reservoir volume that practically
possesses constant petrophysical and fluid properties, which uniquely characterize its static and
dynamic communication with the wellbore. Tiab, Tiab et al., and Amaefule et al. developed a
technique for identifying and characterising a formation having similar hydraulic characteristics,
or flow units, based on the microscopic measurements of rock core samples. This technique is
based on a modified Kozeny–Carman equation and the concept of mean hydraulic radius.
The hydraulic flow units for this thesis work are obtained from the equation below, this equation
is used to describe hydraulic flow units in a macroscopic scale:
2
1
FZIHT
4.1.4 Normalised Reservoir Quality Index (nRQI)
The normalized RQI plot is obtained from a plot of depth against cumulative normalized values
of RQI. The normalization and summation of the RQI values are carried out starting from the
bottom of the reservoir.
In this plot consistent zones are characterized by straight lines with the slope of the line
indicating the overall reservoir quality within a particular depth interval. The lower the slope the
better the reservoir quality. The equation below is used in generating the cumulative normalized
RQI’s at different depths.
43
n
x i
i
i
x i
i
k
k
nRQI
1
1
4.1.5 Normalised Porosity (Φz)
The normalized porosity is obtained using the equation below:
e
e
z
1
4.1.6 Stratigraphic Modified Lorenz Plot (SMLP)
Stratigraphic Modified Lorenz Plot (SMLP) for a reservoir is obtained by computing on a foot-
by-foot basis the percent flow capacity (permeability-thickness, kh) and percent flow storage
(porosity – thickness, Φh). The flow capacity is subsequently plotted against the storage
capacity.
The shape of SMLP curve reveals the flow and storage qualities of the reservoir. These are
categorized as follows:
Sections with steep slopes are associated with a high percentage of reservoir flow capacity,
and therefore, a high production potential.
Sections with flat behaviour have storage capacity but little flow capacity and are typically
reservoir baffles.
Sections with neither flow nor storage capacity are considered seals.
The equations below indicate the calculation of flow capacity and storage capacity respectively.
44
n
i
ii
L
i
ii
h
h
h
1
1
L= 1, 2….,n
n
i
ii
L
i
ii
hk
hk
kh
1
1 L=1, 2,…n
n is the total number of reservoir layers i
Φi is the porosity of layer i
ki is the permeability of layer i, and hi is the net thickness of layer i.
The layers are numbered in order from the shallowest layer i = 1 to the deepest layer i = L
45
4.2 CALCULATION STOOIP FOR RESERVOIR 7
The STOOIP is calculated for each of the reservoirs in the field. The values for the input
parameters are read from the log view of the logs on Schlumburger techlog software as shown
below. (Tables of parameters found in Appendix E to H)
These values are then averaged using arithmetic averaging method to get a representative value
for each parameter to be used in STOOIP calculation. The table below is a summary of the input
parameters for the various reservoirs in the six wells under consideration. The shaded portion
represents the reservoir of interest.
Figure 4. 1: Log view of petrophysical parameters on Schlumburger Techlog Software.
46
Table 4. 1: Shows the values obtained for input parameters for the calculation of STOOIP
Reservoir Name
Top, ft Bottom, ft Total Porosity
(фT)
Shale Volume
(Vsh)
Water Saturation
(Sw)
Net Pay Thickness
(h), ft
W4R1 9086.32 9123.65 0.2641 0.0405 0.0795 37.3300
W5R1 9059.41 9094.13 0.2658 0.6005 0.1399 34.7200
W6R1 8992.57 9075.03 0.2154 0.2716 0.3711 82.4600
W5R2 9231.28 9294.65 0.2126 0.4458 0.1652 63.3700
W6R2 9247.78 9305.07 0.2264 0.1563 0.2026 57.2900
W5R3 9496.04 9544.66 0.1823 0.3121 0.1817 48.6200
W6R3 9530.77 9590.66 0.1974 0.2957 0.3469 59.8900
W1R4 10056.60 10116.50 0.2360 0.0402 0.4410 59.9000
W5R4 9829.38 9871.92 0.2181 0.2795 0.1446 42.5400
W6R4 9864.10 9901.43 0.2091 0.1176 0.2047 37.3300
W4R5 11318.90 11334.90 0.2357 0.0484 0.0952 16.0000
W3R5 11329.40 11389.30 0.2203 0.2585 0.3169 59.9000
W3R6 11895.70 12038.90 0.1954 0.0294 0.1308 143.2000
W2R6 12039.80 12177.80 0.1595 0.1229 0.4308 138.0000
W1R7 12102.00 12223.50 0.2501 0.0734 0.3418 121.5000
W2R7 12084.10 12216.90 0.1894 0.1563 0.3425 132.8000
W3R7 12309.80 12545.00 0.1548 0.1180 0.3415 235.2000
W4R7 12490.90 12637.60 0.2024 0.0496 0.1125 146.7000
The STOOIP for the reservoir is calculated using the average (arithmetic) values of the input
parameters in the STOOIP equation below.
oi
wshTT
B
SVhAN
1*****7758
The following table shows the calculation of STOOIP for each reservoir and the entire field.
Table 4. 2: Deterministic STOOIP for various reservoirs and entire field.
Reservoir Name
Total Porosity
(фT)
Shale Volume
(Vsh)
Water Saturation
(Sw)
Net Pay Thickness (h), ft
Oil Formation Volume
Factor, (Boi)
Area (A),
Acres
STOOIP (N), STB
R1 0.2484 0.3042 0.1968 51.50 1.25 400 1.78E+07
R2 0.2195 0.3010 0.1839 60.33 1.25 400 1.88E+07
R3 0.1899 0.3039 0.2643 54.25 1.25 400 1.31E+07
R4 0.2211 0.1458 0.2634 46.59 1.25 400 1.61E+07
R5 0.2280 0.1534 0.2061 37.95 1.25 400 1.44E+07
R6 0.1774 0.0761 0.2808 140.60 1.25 400 4.12E+07
R7 0.1992 0.0993 0.2846 159.05 1.25 400 5.07E+07
Total STOOIP of Field, STB 1.72E+08
47
Name Cell Sim# Graph Min Mean Max 5% 95% Errors
Category: R7
R7 / Total Porosity (?) B8NP15
00.1422275 0.21 0.3059437 0.1788924 0.2444794 0
R7 / Total Porosity (?) B8NP16
00.1422275 0.21 0.3059437 0.1788924 0.2444794 0
R7 / Total Porosity (?) B8NP17
00.1422275 0.21 0.3059437 0.1788924 0.2444794 0
R7 / Shale Volume (Vsh) C8NP15
0-0.02946091 0.1000004 0.2344921 0.04735057 0.1526224 0
R7 / Shale Volume (Vsh) C8NP16
0-0.02946091 0.1000004 0.2344921 0.04735057 0.1526224 0
R7 / Shale Volume (Vsh) C8NP17
0-0.02946091 0.1000004 0.2344921 0.04735057 0.1526224 0
R7 / Water Saturation (Sw) D8NP15
00.1476079 0.379998 0.8990614 0.2535177 0.543927 0
R7 / Water Saturation (Sw) D8NP16
00.1476079 0.379998 0.8990614 0.2535177 0.543927 0
R7 / Water Saturation (Sw) D8NP17
00.1476079 0.379998 0.8990614 0.2535177 0.543927 0
R7 / Net Pay Thickness (h), ft E8NP15
0150 150 150 150 150 0
R7 / Net Pay Thickness (h), ft E8NP16
0160 160 160 160 160 0
R7 / Net Pay Thickness (h), ft E8NP17
0170 170 170 170 170 0
4.3 STOCHASTIC EVALUATION TECHNIQUES
The stochastic method of evaluating the reservoir is carried out to enable a better understanding
of the values obtained from the deterministic method. The parameters are fitted with
distributions. These distributions indicate the occurrence and probability of occurrence of the
various input parameters. The distributions are determined by plotting the data available to
obtain trend or chosen from known trends that such parameters often follow. Other parameters
such as area and formation oil volume factor were assumed to be constant, that is 400acres and
1.25 respectively. The table below shows the table of the distributions and objective variable
selected for the stochastic modelling.
Table 4. 3: Distributions fitted for input parameters for stochastic analysis.
48
4.3.1 Graphs obtained from Stochastic Modelling of STOOIP for reservoir 7
4.3.1.1 Relative Probability
The relative probability measures the relative probability of occurrence of the different outputs,
in this case the Stock tank oil originally in place. The three different scenarios are plotted
together on the same graph. It is clearly shown from the graph above that the probability of
obtaining the most probable STOOIP increases with decreasing net pay thickness. At 150 feet
the frequency of the most probable value is over 10% of all possible outcomes. This reduces for
160 feet and further decreases at 170 feet.
The most probable values for the output STOOIP is 46.4MMSTB, 49.5MMSTB and
52.6MMSTB for 150 feet, 160 feet and 170 feet respectively. It is observed from the graph that
the spread of values, that is the standard deviations for the output do not differ by a wide range
for all the simulation sets. The standard deviations increase with increasing net-pay thickness.
The range of values is 7.8MMSTB for 150 feet of net pay, 8.3MMSTB for 160 feet and then
8.9MMSTB for 170 feet of net pay thickness.
Figure 4. 2: Graph of Relative Probabilities for calculated STOOIPs.
49
4.3.1.2 Cumulative Frequency
This graph shows the various cumulative frequencies of the different possible outcomes from the
simulations. The trends observed above indicates that there is no significant difference for the
cumulative frequencies of the three different scenarios. In all the cases, the frequency starts with
a low gradient and peaks sharply before another low gradient is experienced at the end. About
90% of the relatively higher frequency occurring values is found within a narrow bracket. This
means the frequencies of the outputs are very high between this narrow window. This is in
coherence with the behavior of the output in the relative frequency histogram.
The frequencies observed for the various scenarios show that at 150 feet the window is at a lower
STOOIP than at 160 feet and in the same way at 170 feet. This trend is expected since the net
pay thickness is directly proportional to the STOOIP. This means an increase in net pay
thickness directly translates into an increase in STOOIP. The trends are however observed to be
the same. This means the frequency behavior of the output is the same for all the cases.
Figure 4. 3: Graph of Cumulative Frequencies of calculated STOOIPs.
50
4.3.1.3 Probability Density Function (PDF)
The probability density function is a function of a continuous variable such that the integral of
the function over a specific region yields the probability that its value will fall within the region.
It can be observed from the above three distributions that the highest probability density
functions decrease with increasing net pay thickness.
The highest, highest PDF is observed when the net pay thickness is 150 feet for the reservoir
followed by a relative lower highest PDF for 160 feet with the lowest highest PDF recorded
when the net pay thickness is 170 feet.
The PDF shows a relative normal distribution of the output for all the cases of simulation. The
output is mainly ranging from 20MMSTB to 80MMSTB for net pay off 170 feet. The PDF is
low at the lower limit of the output and gradually increases to a peak value at about 54MMSTB
before descending gradually to a very low value at the higher limit. The same distribution is
observed in the 150 feet and the 160 feet simulations where the lower limits are 15MMSTB and
18MMSTB with upper limits of 73MMSTB and 75MMSTB respectively.
Figure 4. 4: Graph of Probability Density Functions for STOOIPs calculated.
51
4.3.1.4 Correlation Coefficient
The correlation coefficient serves to describe the degree to which two or more variables are
related to each other. It also describes the amount of change that is recorded for one variable per
unit change of the other. It is observed from the tornado plots above that the water saturation has
the highest correlation coefficient followed by the total porosity and shale volume follow
respectively.
The directions of the projections for the total porosity shows a positive relationship. This means
that the STOOIP increases per unit increase in total porosity. For every unit of total porosity
added, the STOOIP increases by a factor of 0.53 for all the three selected thicknesses. It however
decreases for both water saturation and shale volume considering the direction of their
projections. There is 0.79 and 0.20 decrease in the STOOIP for a unit increase in water saturation
and shale volume respectively. This implies that, the effect of every inaccuracy on the STOOIP
is 0.53, 0.79 and 0.20 for total porosity, water saturation and shale volume respectively.
The correlation coefficients are the same for the three simulation cases ran. The trend also
supports the interpretations obtained from the other methods that the water saturation is the key
Figure 4. 5: Tornado Chart of Correlation Coefficients for Input Parameters on STOOIP.
52
input factor in the calculation of the STOOIP, followed by the total porosity and then shale
volume.
4.3.1.5 Regression Coefficient
The regression coefficient is a statistical quantity used to describe the statistical relationship
between a random variable and one or more independent variables. In the case above, the output
STOOIP is the random variable and each of the input parameters represent independent variables
necessary to calculate the output STOOIP. It is observed from the regression coefficients on the
tornado charts above that the relationship between the STOOIP and the water saturation is the
highest and negative. The net total porosity has the second highest degree of regression with the
output STOOIP but positive. The shale volume shows the lowest correlation which is a negative
relationship.
Figure 4. 6: Tornado Chart of Regression Coefficients for input Parameters on STOOIP.
53
The observations above are same for all the three circumstances simulated by Monte Carlo
simulation software. They also show coherence with the other tornado plots and serve to lay
more emphasis on the importance of the water saturation on the calculation of the STOOIP.
4.3.1.6 Tornado Chart (Mean Output)
The charts above are used to ascertain the impact of each of the input parameters on the output
parameter (STOOIP). It can be viewed from the three different scenarios that the water saturation
has the greatest impact on the calculated STOOIP whereas the least impact is from the shale
volume. The total porosity has impact which is in between the water saturation and shale
volume.
The direction of the projections from the base indicates the type of relationship that the output
value has with the output value. The total porosity shows a positive correlation whereas the water
saturation and shale volume have a negative impact on the output (STOOIP).
All these values were obtained with some degree of uncertainty which made it necessary to test
their sensitivities with respect to the output (STOOIP) estimated. The information from the
Figure 4. 7: Tornado Chart of effects of input parameters on STOOIP.
54
tornado charts above indicates that care should be applied, in order of preference to obtaining
accurate estimates of water saturation, total porosity and shale volume of reservoir 7.
4.3.1.7 Spider chart
These charts are very similar to the tornado charts in the sense that they also employed in
determining the sensitivity of the input parameters on the output. It is observed that the water
saturation shows the greatest degree of deviation from the horizontal and is the only parameter
trending NE to SW, that is a positive relationship. The steepness of the trend is observed to
increase as it moves away from the Centre. This shows that the sensitivity of the output
(STOOIP) increases with increasing input values.
Observing the NW to SE trending input parameters, it is observed that the water saturation shows
much steeper trend as the output parameter decreases relative to the shale volume. This means
the output is more sensitive to water saturation at lower and higher levels of STOOIP. The trend
Figure 4. 8: Spider Chart of impact of input parameters on output STOOIP
55
also indicates a negative relationship in which output increases with decreasing input and vice
versa.
The three scenarios run all show the same trend therefore it can be concluded that the trend or
behavior of the input parameters to the output is independent of the different net pay thicknesses.
4.4 ANALYSIS OF FLOW UNITS FOR RESERVOIR 7
The flow units within the reservoirs observed were delineated using three different techniques.
These include; Reservoir Quality Index versus Normalised Porosity graphs, Normalised
Reservoir Quality Index graph and Stratigraphic Modified Lorenz Plot. The last two methods
were used to validate the results observed in the first graph. The main reservoir of interest was
the seventh reservoir.
In summary the table below shows the FZI’s, gradient, regressions and the wells of occurrence
for each of the flow units;
Table 4. 4: Table showing flow units present in reservoir 7 and their properties.
Flow Unit Gradient FZI HT
(µm2)
R2 Wells of
occurrence
A 2.9 42.05 5.66E-04 0.86 2,3
B 2.67 12.08 6.85E-03 0.93 2,3,4
C 2.3 2.13 2.20E-01 0.99 1,3,4
D 2.46 1.55 4.17E-01 0.85 3,4
56
4.4.1 Analysis of Well 01
This well intercepts four out of the seven reservoir sands that were delineated. There were no log
records for the upper part of this well. This caused the first three reservoirs to be missed out. It is
observed from the respective graphs of RQI versus Normalized Porosity, normalised RQI and
Stratigraphic Modified Lorenz Plot that this well contains only one flow unit for the reservoir of
interest (Reservoir 7).
The possible cause for the presence of a single flow unit in this well compared to many flow
units in the other wells may be due to pinch-out of some flow units. The truncation of these flow
units causes their absence in some wells.
The quality of the reservoir flow units can be determined from the plots above. The gradient of
the flow unit in the normalized porosity line indicates the flow unit quality. High gradient
characterize poor quality whereas lower gradient is indicative of better reservoir quality.
Turbidite environments are characterised by high shale volumes and erratic environment. This is
due to the turbulent depositional regime from which these kinds of reservoirs are formed. The
point at which well 1 intercepts the reservoir may therefore contain less flow units compared to
other wells that intercept the same reservoir sand at some other point. The tendency of different
number of flow units in turbidite sands such as the ones in the Niger Delta therefore lies in the
nature of their deposition. It is observed from the graphs that the flow unit has some small partial
discontinuous boundaries probably the blockage caused by presence of shale. This is what causes
the small kinks on the normalized RQI graph and SML plot.
57
FU C
FZI =2.3
FU C
Figure 4. 9: Graph of RQI versus Normalised Porosity of reservoir for well 01.
Figure 4. 10: SMLP of the reservoir of interest for well 01.
58
4.4.2 Analysis of Well 02
The data present indicates that well 2 penetrates four out of the seven reservoir sands present in
the field. There were no log records present for the upper part of the well. There were no logs
present for some portions of the well. It is possible this part for which there were no logs
intercepts the other reservoirs that were not identified. It is observed from the respective graphs
of RQI versus Normalised Porosity, Normalised RQI graph and SML Plot that this well contains
two out of the four flow units present in the reservoir of interest (Reservoir 7).
The cause for this may be due to pinch out. The reservoir sand may have been pinching gradually
in the direction up to the point well 2 intercepts it. The presence of many flow units in well 3
with fewer flow units in well 2 is caused by truncation of the some of the flow units. The nature
of the depositional environment may also be possible cause for having only two flow units in the
reservoir at the point well 2 crosscuts the reservoir. Turbidite environments are associated with
heterogeneity which is responsible for the truncation of some other flow units.
FU C
Figure 4. 11: nRQI plot of the reservoir of interest for well 01.
59
Another possible cause of what is happening in well 2 may be due to the presence of an
unconformity between the point of well 3 and well 2. This may have led to the washing away of
the area occupied by the other flow units present in well 3 thereby terminating them. The other
flow units observed in well 3 therefore may not be continuous to well 2. It is also observed from
the log-view graph on techlog software that, there is a fault between well 2 and well 3.
Turbidite environments are erratic considering the way they were formed. This means the
variation between two locations for the same lithologic unit is greater compared to a less
turbulent depositional environments. It is therefore possible for well 2 to exhibit different
properties relative to the other wells for the same reservoir sand unit.
The quality of the reservoir flow units can be determined from the plots above. The gradient of
the flow unit in the normalized porosity line indicates the flow unit quality. High gradient
characterize poor quality whereas lower gradient is indicative of better reservoir quality.
FU A
FU B
FZI=42.05
FZI=12.08
Figure 4. 12: Graph of RQI versus Normalised Porosity of reservoir for well 02.
60
FU A
FU B
FU A
FU B
Figure 4. 13: SMLP of the reservoir of interest for well 02
Figure 4. 14: nRQI plot of the reservoir of interest for well 02.
61
4.4.3 Analysis of Well 03
Well 3 gives the most complete view of the reservoir from a single well. All the flow units in the
reservoir can be observed in this well. This well, like the other wells had no log records present
for most of its upper part. There is possibility the first three reservoirs may have been missed out
due to this.
It is observed from the respective graphs of RQI versus Porosity, Normalised RQI and SML Plot
that, this well shows all four flow units present within the reservoir of interest (Reservoir 7). This
well shows the most complete picture of the reservoir under investigation.
It is expected that the number of flow units in turbidite reservoirs are relatively many. This is due
to the high volumes of shale present in turbidite sands compared to other reservoir types. High
volumes of shale can cause discontinuities within the unit thereby petitioning the reservoir into
many flow units. Well 3 intercepts the reservoir at a point where more the flow units are present
as compared to the other wells.
The erratic nature of turbidite sands causes heterogeneities to exist within a reservoir at different
directions. This property is the reason for the presence of differences between the various wells
intercepting the reservoir as well as the different zonations within the same well.
The quality of the reservoir flow units can be determined from the plots above. The gradient of
the flow unit in the normalized porosity line indicates the flow unit quality. High gradient
characterize poor quality whereas lower gradient is indicative of better reservoir quality.
62
FU A FU B FU C
FU D
FZI=42.05
FZI=12.08
FZI=2.13
FZI=1.55
FU A
FU B
FU C
FU D
FU C
Figure 4. 15: Graph of RQI versus Normalised Porosity of reservoir for well 03.
Figure 4. 16: SMLP of the reservoir of interest for well 03.
63
4.4.4 Analysis of Well 04
This well intercepts four out of the seven reservoir sands present in the field. This includes the
reservoir of interest (Reservoir 7). No log records were present for most of the upper portions of
this well. The unidentified reservoirs may be within this unlogged zone. This is because the
upper three reservoirs were the ones that were not delineated in this well.
It is observed from the respective graphs of RQI versus Normalised Porosity, Normalised RQI
graph and SML Plot that this well intercepts three out of the four flow units present in the
reservoir. Probable cause for the observation above vary but the most likely reason is pinch out.
It is observed from the log view on techlog software that the reservoir unit thins out from well 3
towards well 4. Much of the reservoir unit may have pinched out at the point well 4 intercepted
the reservoir sand. Some of the other flow units that were not present might have been truncated.
The nature of the depositional environment may also be possible explanation for having fewer
flow units in the reservoir at well 4. Turbidite environments are mostly erratic in nature. The
point at which well 4 intercepts the reservoir may therefore be significantly different and contain
fewer flow units. It is observed from the graphs that the flow units contain some minor partial
FU A
FU B
FU C
FU D
Figure 4. 17: nRQI plot of the reservoir of interest for well 03.
64
discontinuities within. This is observed in minor and not continuous kinks in the normalized RQI
and SMLP graphs.
The quality of the reservoir flow units can be determined from the plots above. The gradient of
the flow unit in the normalized porosity line indicates the flow unit quality. High gradient
characterize poor quality whereas lower gradient is indicative of better reservoir quality.
FU B FU C FU D
FZI=12.08 FZI=2.13
FZI=1.55
Figure 4. 18: Graph of RQI versus Normalised Porosity of reservoir for well 04.
65
FU B
FU C
FU D
FU B
FU C
FU D
Figure 4. 19: SMLP of the reservoir of interest for well 04.
Figure 4. 20: nRQI plot of the reservoir of interest for well 04.
66
4.4.5 Analysis of Well 05
This well intercepts four out of the seven reservoir sands present in the field excluding the
reservoir of interest. No log records were present for most of the lower parts of the well. The
unidentified reservoirs may be within these zones for which there were no logs. This is because
the lower three reservoirs were not delineated in this well. The reservoir of interest could not be
identified within this well. The reservoir of interest is the deepest of all the seven reservoirs.
There were however no log records for this part (deepest) of this well.
4.4.6 Analysis of Well 06
This well intercepts four out of the seven reservoir sands present in the field. No log records
were present for most of the lower parts of the well. The reservoirs that were not delineated in
this well may be within the zones that there were no logs. The reservoir of interest could not be
delineated from this well. The reservoir of interest is the deepest of all the reservoirs. There were
however no log records for the deeper part of the well.
4.5 CALCULATION OF STOOIP USING FLOW UNITS
The Stock Tank Original Oil in Place (STOOIP) is calculated for each flow unit identified. This
is compared to the deterministic STOOIP obtained without consideration to flow units. The
difference between these two values gives an estimate of the amount oil in place that has no
direct conduit to the wellbore. The following assumptions are made in calculating STOOIP for
each flow unit.
1. The net pay thickness from the wells was assumed to be uniform and was calculated from
the average of the net pay thicknesses across each well.
2. Each well is assumed to cover an area of 100 acres, the number of wells a particular flow
unit traverses is used to estimate the area in STOOIP calculation.
The following table is the summary of the calculation of STOOIP for the reservoir:
67
Table 4. 5: Calculation of STOOIP for each flow unit and entire reservoir.
Flow Unit Total Porosity
(ф)
Shale Volume
(Vsh)
Water Saturation
(Sw)
Net Pay Thickness
(h), ft
Area (A),
Acres
Oil Formation Volume
Factor, (Boi)
STOOIP, STB
A 0.1665 0.0826 0.2561 70.54 200 1.25 9.95E+06
B 0.2067 0.1096 0.2411 36.09 300 1.25 9.39E+06
C 0.2121 0.1014 0.2682 62.33 300 1.25 1.62E+07
D 0.1975 0.0889 0.2444 60.70 200 1.25 1.02E+07
Stock Tank Oil Originally in Place, STB 4.58E+07
68
4.6 CALCULATION OF STOOIP FOR RESERVOIR 6
The STOOIP is calculated for each of the reservoirs in the field. The values for the input
parameters are read from the log view of the logs on techlog software as shown below. (Tables
of parameters found in Appendix I and J)
These values are averaged to get a representative values for each parameter to be used in
STOOIP calculation. The table below is a summary of the input parameters for the various
reservoirs in the six wells under consideration. The shaded portion represents the reservoir of
interest.
Figure 4. 21: Log view of petrophysical parameters on Schlumburger Techlog Software.
69
Table 4. 6: Shows the values obtained for input parameters for the calculation of STOOIP
Reservoir Name
Top, ft Bottom, ft Total Porosity
(фT)
Shale Volume
(Vsh)
Water Saturation
(Sw)
Net Pay Thickness
(h), ft
W4R1 9086.32 9123.65 0.2641 0.0405 0.0795 37.3300
W5R1 9059.41 9094.13 0.2658 0.6005 0.1399 34.7200
W6R1 8992.57 9075.03 0.2154 0.2716 0.3711 82.4600
W5R2 9231.28 9294.65 0.2126 0.4458 0.1652 63.3700
W6R2 9247.78 9305.07 0.2264 0.1563 0.2026 57.2900
W5R3 9496.04 9544.66 0.1823 0.3121 0.1817 48.6200
W6R3 9530.77 9590.66 0.1974 0.2957 0.3469 59.8900
W1R4 10056.60 10116.50 0.2360 0.0402 0.4410 59.9000
W5R4 9829.38 9871.92 0.2181 0.2795 0.1446 42.5400
W6R4 9864.10 9901.43 0.2091 0.1176 0.2047 37.3300
W4R5 11318.90 11334.90 0.2357 0.0484 0.0952 16.0000
W3R5 11329.40 11389.30 0.2203 0.2585 0.3169 59.9000
W3R6 11895.70 12038.90 0.1954 0.0294 0.1308 143.2000
W2R6 12039.80 12177.80 0.1595 0.1229 0.4308 138.0000
W1R7 12102.00 12223.50 0.2501 0.0734 0.3418 121.5000
W2R7 12084.10 12216.90 0.1894 0.1563 0.3425 132.8000
W3R7 12309.80 12545.00 0.1548 0.1180 0.3415 235.2000
W4R7 12490.90 12637.60 0.2024 0.0496 0.1125 146.7000
The STOOIP for the reservoir is calculated using the average (arithmetic) values of the input
parameters in the STOOIP equation below.
oi
wshTT
B
SVhAN
1*****7758
The following table shows the calculation of STOOIP for each reservoir and the entire field.
Table 4. 7: Deterministic STOOIP for various reservoirs and entire field.
Reservoir Name
Total Porosity
(фT)
Shale Volume
(Vsh)
Water Saturation
(Sw)
Net Pay Thickness
(h), ft
Oil Formation
Volume Factor, (Boi)
Area, (A)
Acres
STOOIP (N), STB
R1 0.2484 0.3042 0.1968 51.50 1.25 400 1.78E+07
R2 0.2195 0.3010 0.1839 60.33 1.25 400 1.88E+07
R3 0.1899 0.3039 0.2643 54.25 1.25 400 1.31E+07
R4 0.2211 0.1458 0.2634 46.59 1.25 400 1.61E+07
R5 0.2280 0.1534 0.2061 37.95 1.25 400 1.44E+07
R6 0.1774 0.0761 0.2808 140.60 1.25 400 4.12E+07
R7 0.1992 0.0993 0.2846 159.05 1.25 400 5.07E+07
Total STOOIP of Field, STB 1.72E+08
70
Name Cell Graph Function Min Mean Max
Category: R6
R6 / Total Porosity (?) B7RiskNormal(0.177449161033153,0.04,RiskS
tatic(0.177449161033153))-∞ 0.1774492 +∞
R6 / Shale Volume (Vsh) C7RiskNormal(0.0761412543751624,0.03,Risk
Static(0.0761412543751624))-∞ 0.07614125 +∞
R6 / Water Saturation (Sw) D7RiskLognorm(0.25,0.1,RiskShift(0.1),RiskSt
atic(0.28080773025422))0.1 0.35 +∞
R6 / Net Pay Thickness (h), ft E7 RiskSimtable({140,130,150})
4.7 STOCHASTIC EVALUATION TECHNIQUES (RESERVOIR 6)
The stochastic method of evaluating the reservoir is carried out to enable a better understanding
of the values obtained from the deterministic method. The parameters are fitted with
distributions. These distributions indicate the occurrence and probability of occurrence of the
various input parameters. The distributions are determined by plotting the data available to
obtain a trend or chosen from known trends that such parameters frequently follow. Other
parameters such as area and formation oil volume factor are assumed to be constant, that is 400
acres and 1.25 respectively. The table below shows the distributions and objective variable
selected for the stochastic modelling.
Table 4. 8: Distributions fitted for input parameters for stochastic analysis
71
4.7.1 Graphs obtained from Stochastic Modelling of STOOIP for Reservoir 6
4.7.1.1 Relative Probability
The relative probability measures the relative probability of occurrence of the different outputs,
in this case the Stock tank oil originally in place. The three different scenarios are plotted
together on the same graph. It is clearly shown from the graph above that the probability of
obtaining the most probable STOOIP increases with decreasing net pay thickness. At 130 feet
the frequency of the most probable value is about 9% of all possible outcomes. This reduces for
140 feet and further decreases at 150 feet at 8% and less than 8% respectively.
The most probable values for the output STOOIP is 34.3MMSTB, 37.5MMSTB and
38.6MMSTB for 130 feet, 140 feet and 150 feet respectively. It is observed from the graph that
the spread of values, that is the standard deviations for the output do not differ by a wide range
for all the simulation sets. The deviations become substantial for increasing net-pay thickness.
Figure 4. 22: Graph of Relative Probabilities for calculated STOOIPs.
72
4.7.1.2 Cumulative Frequency
This graph shows the various cumulative frequencies of the different possible outcomes from the
simulations. The trends observed above indicates that there is no significant difference for the
cumulative frequencies of the three different cases of net pay thickness. In all the cases, the
frequency starts with a low gradient and peaks sharply before another low gradient is
experienced at the end. About 90% of the relatively higher frequency occurring values is found
within a narrow bracket. This means the frequencies of the outputs are very high between this
narrow window. This is in coherence with the behavior of the output in the relative frequency
histogram.
The frequencies observed for the various scenarios show that at 130 feet the window has lower
STOOIP than at 140 feet and 150 feet in that order. This trend is expected since the net pay
thickness is directly proportional to the STOOIP. This means an increase in net pay thickness
directly translates into an increase in STOOIP. The trends are however observed to be the same
meaning the frequency behavior of the output is the same for all the cases.
Figure 4. 23: Graph of Cumulative Frequencies of calculated STOOIPs.
73
4.7.1.3 Probability Density Function (PDF)
The probability density function is a function of a continuous variable such that the integral of
the function over a specific region yields the probability that its value will fall within the region.
It can be observed from the above three distributions that the highest probability density
functions decrease with increasing net pay thickness.
The highest, highest PDF is observed when the net pay thickness is 130 feet for the reservoir
followed by a relative lower highest PDF for 140 feet with the lowest highest PDF recorded
when the net pay thickness is 150 feet for the reservoir net pay.
The PDF shows a relative normal distribution of the output for all the cases of simulation. The
output is mainly ranging from 10MMSTB to 76MMSTB for net pay of 150 feet. The PDF is low
at the lower limit of the output and gradually increases to a peak value at about 38MMSTB
before descending gradually to lower values towards the higher limit. The same distribution is
observed in the 140 feet and the 150 feet simulations.
Figure 4. 24: Graph of Probability Density Functions for STOOIPs calculated.
74
4.7.1.4 Correlation Coefficient
The correlation coefficient serves to describe the degree to which two or more variables are
related to each other. It also describes the amount of change that is recorded for one variable per
unit change of the other. It is observed from the tornado plots above that the total porosity has
the highest correlation coefficient followed by the water saturation and shale volume
respectively.
The directions of the projections for the total porosity shows a positive relationship. This means
that the STOOIP increases per unit increase in total porosity. For every unit of total porosity
added, the STOOIP increases by a factor of 0.81 for all the three selected thicknesses. It however
decreases for both water saturation and shale volume considering the direction of their
projections. There is 0.51 and 0.11 decrease in the STOOIP for a unit increase in water saturation
and shale volume respectively. This implies, the effect of every inaccuracy on the STOOIP is
0.81, 0.51 and 0.11 for total porosity, water saturation and shale volume respectively.
The correlation coefficients are the same for the three simulation cases ran. The trend also
supports the interpretations obtained from the other methods that the total porosity is the key
Figure 4. 25: Tornado Chart of Correlation Coefficients for Input Parameters on STOOIP.
75
input parameter in the calculation of the STOOIP, followed by the water volume and then shale
volume.
4.7.1.5 Regression Coefficient
The regression coefficient is a statistical quantity used to describe the statistical relationship
between a random variable and one or more independent variables. In the case above, the output
STOOIP is the random variable and each of the input parameters represent independent variables
necessary to calculate the output STOOIP. It is observed from the regression coefficients on the
tornado charts above that the relationship between the STOOIP and the total porosity is the
highest and positive. The water saturation has the second highest degree of regression with the
output STOOIP but negative. The shale volume shows the lowest correlation and is a negative
relationship.
The observations above are same for all the three circumstances simulated by Monte Carlo
simulation software. They also show coherence with the other tornado plots and serve to lay
more emphasis on the importance of the total porosity on the calculation of the STOOIP.
Figure 4. 26: Tornado Chart of Regression Coefficients for input Parameters on STOOIP.
76
4.7.1.6 Tornado Chart (Mean Output)
The charts above are used to ascertain the impact of each of the input parameters on the output
parameter (STOOIP). It can be viewed from the three different scenarios that total porosity has
the greatest impact on the calculated STOOIP whereas the least impact is from the shale volume.
The water saturation has impact which is in between the total porosity and shale volume.
The direction and extent of the projections from the base indicates the type and extent of
relationship whether positive or negative, that the output value has with the output value. The
total porosity shows a greater positive correlation whereas the water saturation and shale volume
have more negative impact on the output (STOOIP).
All these values were obtained with some degree of uncertainty which made it necessary to test
their sensitivities with respect to the output (STOOIP) estimated. The information from the
tornado charts above indicates that care should be applied, in order of preference to obtaining
Figure 4. 27: Tornado Chart of effects of input parameters on STOOIP
77
accurate estimates of total porosity, water saturation and shale volume of reservoir 6 in the X
field of the Niger Delta.
4.7.1.7 Spider chart
These charts are very similar to the tornado charts in the sense that they also employed in
determining the sensitivity of the input parameters on the output. It is observed that total porosity
shows the greatest degree of deviation from the horizontal and is the only parameter trending NE
to SW, which is indicative of a positive relationship. The steepness of the trend is observed to
increase as it moves away from the Centre. This shows that the sensitivity of the output
(STOOIP) increases with increasing input values.
Observing the NW to SE trending input parameters, it is observed that the water saturation shows
much steeper trend as the output parameter decreases relative to the shale volume. This means
the output is more sensitive to water saturation at lower and higher levels of STOOIP relative to
shale volume. The trend also indicates a negative relationship in which output increases with
decreasing input and vice versa.
Figure 4. 28: Spider Chart of impact of input parameters on output STOOIP
78
The three scenarios run all show the same trend therefore it can be concluded that the trend or
behavior of the input parameters to the output is independent of the different net pay thicknesses.
4.8 ANALYSIS OF FLOW UNITS FOR RESERVOIR 6
The flow units within the reservoirs observed were delineated using three different techniques.
These include; Reservoir Quality Index versus Porosity graph, Normalised Reservoir Quality
Index graph and Stratigraphic Modified Lorenz Plot. The last two methods were used to validate
the results observed in the first graph. The main reservoir of interest was the sixth reservoir (R6).
In summary the table below shows the FZI’s, gradient, regressions and the wells of occurrence
for each of the flow units;
Table 4. 9: Flow units present in reservoir 7 and their properties.
Flow Unit Gradient FZI HT R2 Wells of occurrence
E 2.75 43.87 5.20E-04 0.84 2,3
F 2.92 22.01 2.06E-03 0.91 2,3
79
4.8.1 Analysis of Well 02
The data present indicates that well 2 penetrates four out of the seven reservoir sands present in
the field. There were no log records present for the upper part of the well. There were no logs
present for some portions of the well. It is possible this part for which there were no logs
intercepts the other reservoirs that were not identified. It is observed from the respective graphs
of RQI versus Normalised Porosity, Normalised RQI graph and SML Plot that this well contains
two flow units. These are the flow units that have been identified in the reservoir (Reservoir 6).
Comparing the number of flow units in this reservoir to the flow units in reservoir 7, it is
observed that, reservoir 6 has less number of flow units which show a better quality. This implies
that, the amount of clay in reservoir 7 is relatively high. The clay present in reservoir 6 has not
been able to form complete discontinuities between the different compartments of the reservoir.
Turbidite environments are erratic considering the way they were formed. This means the
variation between two locations for the same lithologic unit is greater compared to a less
turbulent depositional environments. It is therefore possible for well 2 to exhibit different
properties relative to the other wells for the same reservoir sand unit.
The quality of the reservoir flow units can be determined from the plots above. The gradient of
the flow unit in the normalized RQI graph indicates the flow unit quality. High gradient
characterise poor quality whereas lower gradient is indicative of better reservoir quality. High
FZI in the RQI versus normalised porosity plot indicates good reservoir quality whereas lower
values of FZI are indicative of lesser reservoir quality.
The following plots were used to delineate the flow units; The RQI versus normalized porosity
was the main graph used whilst the other graphs were used to validate the outcome from the
former.
80
Figure 4. 29: Graph of RQI versus Normalised Porosity of reservoir for well 02.
Figure 4. 30: SMLP of the reservoir of interest for well 02.
FU E
FU F
FU E FU F
FZI=43.87 FZI=22.01
81
Figure 4. 31: nRQI plot of the reservoir of interest for well 02.
4.8.2 Analysis of Well 03
Well 03 gives a complete view of the reservoir from a single-well point of view. The flow units
identified in the sixth reservoir are both present in this well. This well, like the other wells had no
log records present for most of its upper part. There is possibility the first three reservoirs may
have been missed out due to this.
It is observed from the respective graphs of RQI versus Porosity, Normalised RQI and SML Plot
that, this well shows both flow units present within the reservoir of interest (Reservoir 6). It is
expected that the number of flow units in turbidite reservoirs are relatively many for a small net
pay thickness. This is due to the high volumes of shale present in turbidite sands compared to
other reservoir types. High volumes of shale can cause discontinuities within the unit thereby
petitioning the reservoir into many flow units.
The erratic nature of turbidite sands causes heterogeneities to exist within a reservoir at different
directions. This property is the reason for the presence of at least two flow units in a relatively
smaller thickness of turbidite sand. The small kinks present on the SMLP and normalized RQI
graph indicate discontinuities that are not totally sealed. This points to the presence of significant
FU E
FU F
82
amounts of clay within the reservoir. The quality of the reservoir flow units can be determined
from the plots below. The gradient of the flow unit line in the normalized RQI plot indicates the
quality of the flow unit. High gradient characterize poor quality whereas lower gradient is
indicative of better reservoir quality.
Figure 4. 32: Graph of RQI versus Normalised Porosity of reservoir for well 03.
FZI=43.87
FZI=22.01
FU E FU F
83
Figure 4. 33: SMLP of the reservoir of interest for well 03.
Figure 4. 34: nRQI plot of the reservoir of interest for well 03.
FU F
FU E
FU F
FU E
84
4.8.3 Analysis of other wells
This reservoir is not intercepted by wells 01, 04, 05 and 06. These wells will not be discussed for
reservoir 6.
4.9 CALCULATION OF STOOIP USING FLOW UNITS (RESERVOIR 6)
The Stock Tank Original Oil in Place (STOOIP) was calculated for each of the flow units
identified. This is compared to the deterministic STOOIP obtained without consideration of the
flow units. The difference between these two values gives an estimate of the amount of
estimation due to oil in place that has no direct conduit to the well. The following assumptions
were made in calculating STOOIP for each flow unit.
1. The net pay thickness from the wells was assumed to be uniform and was calculated from
the average of the net pay thicknesses across each well.
2. Each well is assumed to cover an area of 100 acres, the number of wells a particular flow
unit traverses is used to estimate the area in STOOIP calculation.
The following table is the summary of the calculation of STOOIP for each well and the total
STOOIP for the entire reservoir.
Table 4. 10: Calculation of STOOIP for each flow unit and entire reservoir.
Flow Unit Total
Porosity
(фT)
Shale
Volume
(Vsh)
Water
Saturation
(Sw)
Net Pay
Thickness
(h), ft
Area
(A),
Acres
Oil
Formation
Volume
Factor, (Boi)
STOOIP,
STB
E 0.1901 0.1277 0.0686 60.70 200 1.25 1.16E+07
F 0.1759 0.1626 0.1156 78.74 200 1.25 1.27E+07
Stock Tank Oil Originally in Place, STB 2.44E+07
85
CHAPTER 5
DISCUSSION AND CONCLUSION
5.1 DISCUSSION
The deposition of turbidite sands is such that, there is high degree of uncertainty for most
parameters, logged and calculated using the conventional petrophysical methodologies. This
makes it difficult to study and predict what will happen with further development. The
incorporation of uncertainty analysis is therefore necessary. This allows for the analysis of a
range of possible outcomes and the chances that these may be the case going forward.
5.1.1 Flow Unit Identification for Reservoir 7
As observed from the reservoir of interest, it is composed of clean sands that are inter-bedded
with shale intercalations. There is the presence of dirty sand having very high shale
compositions. The above mentioned characteristics are the cause of many flow units within the
relatively thin reservoir (reservoir 7). The number of flow units vary from well to well. This
confirms the erratic nature of turbidite beds in the Niger Delta Petroleum Province. Well 03
contains the highest number of flow units (four flow units) whereas well 01 contains the least
number of flow units (one flow unit). This is evidence to the possibility of pinching out of the
reservoir.
It is observed from the log view plot of the petrophysical logs that the reservoir of interest is not
continuous. There is a fault? or a fold? between well 02 and well 03. These wells are displaced
relative to each other. Well 03 and well 04 are displaced in the down-throw side (if fault) whiles
well 02 and well1 are displaced on the up-throw side.
The combination of complex reservoir depositional environment and latter geological
disturbance results in very high heterogeneity in the reservoir. This justifies the need for
uncertainty analysis on any result from this reservoir.
In order to produce from this reservoir, there is the need for proper placement of producing wells
as well as injection wells if needs be. In order for proper well placement, more information is
required. However, from the information available; from the core analysis and well logs, it is
easy to predict that the producing wells will be placed near the location of well 03 or will be well
86
03 in order to produce from reservoir 7. Well 03 cross-cuts the highest thickness of the reservoir
of interest and therefore the highest amount of hydrocarbons in the seventh reservoir. The
discontinuity from one well to the other implies that, perforations for production will not be
located at the same level throughout the reservoir. Care must therefore be taken when designing
where to perforate.
5.1.2 Uncertainty Analysis for Reservoir 7
The uncertainty analysis run on the calculated STOOIP produced a wide range of possibilities.
The differences seen in the output attest the fact that turbidite formations are erratic and have the
possibility of changing drastically within a short range of distances.
The range varies from a little over 7MMSTB to about 84.97MMSTB. This means that, going
forward, there is the probability that the STOOIP will be less than 8MMSTB or more than 84.97
MMSTB. Plans must therefore be made for any of the possible situations and the possibilities
that lie within them.
The range of possible outcomes as discussed above have different probabilities of occurring
however. The focus must therefore be put on ranges with higher probabilities of occurrence.
From the probability density function and the probability distribution functions, it is observed
that the STOOIPs with highest probability of occurrence include; 46.4MMSTB, 49.4MMSTB
and 52.5MMSTB respectively for net-pay thickness of 150ft, 160ft and 170ft.
The next important output of the uncertainty analysis is the sensitivity of the various input
parameters on the output. The water saturation is seen to exhibit the highest sensitivity with the
output. This implies that, the change in output per unit change in water saturation is highest
compared to the rest of the other input parameters. Extra care must therefore be taken to ensure
that, values calculated for water saturation in this reservoir are accurate. Any deviation from the
true value produces significant errors in the calculated output. Accurate estimation of the other
parameters is also important to accurate output calculation.
5.1.3 Flow Unit Identification for Reservoir 6
As observed from the reservoir of interest, the reservoir is composed of clean sands that are
inter-bedded with shale intercalations. There is presence of dirty sand having very high shale
compositions. The above mentioned characteristics are the cause of relatively many flow units
87
within the relatively thin reservoir (reservoir 6). The number of flow units in this reservoir are
less than those in reservoir 7 and the thickness of each reservoir is relatively thicker in this
reservoir. Both wells that intercept this reservoir contain the two flow units present. The
consistency as well as better reservoir quality for reservoir 6 indicates lower clay or shale
volumes especially of the smectite group in this reservoir. The absence of the reservoir in the
other wells apart from wells 02 and 03 shows that the reservoir is not extensive. This reservoir
may exist as an isolated unit.
Again, it is observed from the log view plot of the petrophysical logs that the reservoir of interest
is not continuous. There is a fault? or a fold? between well 02 and well 03. These wells are
displaced relative to each other. The presence of this same pattern of displacement in reservoir 7
confirms the presence of a fault or fold system. Well 03 is displaced in the down-throw side (if
fault) whereas well 02 is displaced on the up-throw side.
The combination of complex reservoir depositional environment and latter geological
disturbance results in very high heterogeneity in this reservoir. This justifies the need for
uncertainty analysis on any result from this reservoir.
5.1.4 Uncertainty Analysis for Reservoir 6
The uncertainty analysis run on the calculated STOOIP produced a wide range of possibilities.
The differences seen in the output attest the fact that turbidite formations are erratic and have the
possibility of giving drastically different outcomes for slight changes in parameters. This of
course is very likely.
The range varies from a little over 6.8MMSTB to about 83.8MMSTB. This means that, going
forward, there is the probability that the STOOIP will be less than 7MMSTB up to more than
83MMSTB. Plans must therefore be made for any of the possible situations and the possibilities
that lie between these extremes whiles taking cognizance of the probability of each outcome.
The range of possible outcomes as discussed above have different probabilities of occurring
however. The focus must therefore be put on ranges with higher probabilities of occurrence.
From the probability density function and the probability distribution functions, it is observed
that the highest probability of occurrences include; 43.1MMSTB, 46MMSTB and 48.8MMSTB
respectively for net-pay thickness of 130ft, 140ft and 150ft.
88
The next important output of the uncertainty analysis is the sensitivity of the various input
parameters on the output. The total porosity is seen to exhibit the highest sensitivity with the
output. This implies that, the change in output per unit change in total porosity is higher
compared to the rest of the other input parameters. Extra care must therefore be taken to ensure
that, values estimated for total porosity are accurate. Any deviation from the true value produces
significant errors in the calculated output. Accurate estimation of the other parameters is also
important to accurate output calculation. The result obtained above is not in consonance with that
for reservoir 7 where the water saturation has the highest relation.
5.2 CONCLUSIONS
Based on the analysis conducted on the reservoirs above, the following can be concluded:
I. The amount of oil originally in place based on deterministic evaluation methods is
50.07MMSTB for reservoir 7 and 41.2MMSTB for reservoir 6.
II. The amount of oil originally in place based on deterministic evaluation methods with the
incorporation of flow unit effect is 45.8MMSTB for reservoir 7. The contributions of each
of the flow units is as follows: Flow unit A=9.95MMSTB, Flow unit B=9.37MMSTB Flow
unit C=16.2MMSTB and Flow unit D=10.2MMSTB. For reservoir 6, the STOOIP obtained
is 24.4MMSTB. Flow unit E=11.7MMSTB and F=12.7MMSTB.
III. The range of the amount of oil in place based on stochastic evaluation methods for
reservoir 7 is between 7.7MMSTB and 75MMSTB for net pay thickness of 150ft,
8.2MMSTB and 80MMSTB for a net pay thickness of 160ft and 8.7MMSTB and
85MMSTB for a net pay thickness of 170ft. The total range therefore is between
7.7MMSTB and 85MMSTB. The following values are obtained for reservoir 6;
6.9MMSTB and 74MMSTB for net pay thickness of 130ft, 7.3MMSTB and 79MMSTB for
a net pay thickness of 140ft and 7.8MMSTB and 84MMSTB for a net pay thickness of
150ft. The total range therefore is between 6.9MMSTB and 84MMSTB.
IV. The most likely values for STOOIP, according to the stochastic model are 46MMSTB,
49MMSTB and 52MMSTB for 150ft, 160ft and 170ft respectively for reservoir 7. For
reservoir 6, the following were obtained; 43.1MMSTB, 46MMSTB and 48.8MMSTB for
130ft, 140ft and 150ft respectively.
89
V. The regression and correlation coefficients as well as the spider diagram show that the most
important parameters in reservoir 7 as regards the estimation of STOOIP include the
following; water saturation, total porosity and shale volume arranged in order of
importance. For reservoir 6, the total porosity has the highest sensitivity to STOOIP
followed by the water saturation and shale volume respectively.
VI. The following is a summarized view of the characteristics of the flow units present in the
two reservoirs;
The slopes for all the flow units on the RQI versus normalized porosity are greater
than 1. This points to the fact that, shale volume in each flow unit is high and by
extension high shale volume in the reservoir.
Comparing the flow unit quality using the three methods above, flow unit B is
observed to exhibit the best reservoir quality in reservoir 7. For well 04 however, flow
unit A shows the best quality whiles flow unit B shows the least quality. This
confirms the erratic nature of the turbiditic reservoirs in the Niger Delta Petroleum
province. Flow unit E exhibits superior quality for both wells for reservoir 6.
90
NOMENCLATURE
a = Archie’s Exponent
A =Area/ Atomic Weight of element
Boi = Oil Formation Volume Factor
BVW = Bulk Volume Water
FU = Flow Unit
FZI = Flow Zone Index
GRlog = Log reading for Gamma Ray
GRmax =Maximum Gamma Ray reading
GRmin = Minimum Gamma Ray reading
h = Net Pay Thickness
HT = Tiab Hydraulic Flow Unit
IGR = Gamma Ray Index
kh = Flow Capacity
K = Permeability
m = Cementation Factor
n = Saturation Exponent
nRQI = Normalised Reservoir Quality Index
N = Oil Originally in Place
PDF = Probability Density Function
R2 = Regression Coefficient
RQI = Reservoir Quality Index
Rt = Deep Resistivity
Rw = Water Resistivity
SMLP = Stratigraphic Modified Lorenz Plot
STOOIP = Stock Tank Original Oil in Place
Sw = water saturation
Swi =Irreducible Water Saturation
Vsh. = Shale Volume
Z = Atomic Number of Element
Φe = Effective Porosity
Φh = Storage Capacity
ΦT = Total Porosity
ΦTD = Total Porosity from Density log
Φz = Nomalised Porosity
ρa = Apparent Density of Electron
ρb =Bulk Density
ρe =Electron Density Index
ρf = Fluid Density
ρma = Matrix Density
ρsh =Shale Density
91
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APPENDIX A: ADDITIONAL FIGURES FOR CHAPTER 4 (RESERVOIR 7)
Figure A. 1: Spider Charts showing impact of input parameters on STOOIP.
Figure A. 2: Tornado Charts of effect of input Parameters on STOOIP.
96
Figure A. 3: Tornado Charts of regression coefficients for input parameters on STOOIP.
Figure A. 4: Tornado Charts of correlation coefficients for input parameters on STOOIP.
97
Figure A. 5: Shows the Relative Probability Graphs of calculated STOOIPs.
Figure A. 6: Cumulative Frequency Graphs of calculated STOOIPs
98
Figure A. 7: Schlumbuger Techlog log view of reservoir 7 in well 01 to well 04.
99
Figure A. 8: Regressions for flow units in well 01 to well 04 for reservoir 7.
100
Statistics Percentile
Minimum 8739705 5% 34796534
Maximum 84977045 10% 38297084
Mean 49453208 15% 40554022
Std Dev 8787478 20% 42284354
Variance 7.72198E+13 25% 43778037
Skewness -0.14916819 30% 45052167
Kurtosis 3.441394655 35% 46287742
Median 49751008 40% 47497434
Mode 52589384 45% 48699481
Left X 34796534 50% 49751008
Left P 5% 55% 50841131
Right X 63363578 60% 51885245
Right P 95% 65% 52900165
Diff X 28567044 70% 54044031
Diff P 90% 75% 55320175
#Errors 0 80% 56691802
Filter Min Off 85% 58144105
Filter Max Off 90% 60294121
#Filtered 0 95% 63363578
Summary Statistics for STOOIP, STB
Statistics Percentile
Minimum 8225605 5% 32749679
Maximum 79978395 10% 36044314
Mean 46544196 15% 38168491
Std Dev 8270567 20% 39797039
Variance 6.84023E+13 25% 41202858
Skewness -0.14916819 30% 42402040
Kurtosis 3.441394655 35% 43564934
Median 46824478 40% 44703468
Mode 49495891 45% 45834805
Left X 32749679 50% 46824478
Left P 5% 55% 47850476
Right X 59636309 60% 48833172
Right P 95% 65% 49788391
Diff X 26886630 70% 50864970
Diff P 90% 75% 52066047
#Errors 0 80% 53356990
Filter Min Off 85% 54723864
Filter Max Off 90% 56747408
#Filtered 0 95% 59636309
Summary Statistics for STOOIP, STB
Statistics Percentile
Minimum 7711505 5% 30702824
Maximum 74979745 10% 33791544
Mean 43635184 15% 35782960
Std Dev 7753657 20% 37309724
Variance 6.01192E+13 25% 38627679
Skewness -0.14916819 30% 39751912
Kurtosis 3.441394655 35% 40842125
Median 43897948 40% 41909501
Mode 46402397 45% 42970130
Left X 30702824 50% 43897948
Left P 5% 55% 44859821
Right X 55909039 60% 45781099
Right P 95% 65% 46676616
Diff X 25206215 70% 47685910
Diff P 90% 75% 48811919
#Errors 0 80% 50022178
Filter Min Off 85% 51303622
Filter Max Off 90% 53200695
#Filtered 0 95% 55909039
Summary Statistics for STOOIP, STB
APPENDIX B: ADDITIONAL TABLES FOR CHAPTER 4 (RESERVOIR 7)
Table B. 1: Summary of statistics for STOOIP simulation runs for 150ft, 160ft and 170ft respectively.
101
APPENDIX C: ADDITIONAL FIGURES FOR CHAPTER 4 (RESERVOIR 6)
Figure C. 1: Spider Charts showing impact of input parameters on STOOIP
Figure C. 2: Tornado Charts of effect of input Parameters on STOOIP
102
Figure C. 3: Tornado Charts of regression coefficients for input parameters on STOOIP.
Figure C. 4: Tornado Charts of correlation coefficients for input parameters on STOOIP.
103
Figure C. 5: Shows the Probability Density Function Graphs of calculated STOOIPs.
Figure C. 6: Cumulative Frequency Graphs of calculated STOOIPs
104
Figure C. 7: Schlumbuger Techlog log view of reservoir 6 in well 02 and well 03.
Figure C. 8: Regressions for flow units in well 02 and well 03 for reservoir 6.
105
Statistics Percentile
Minimum 6879140.492 5% 31000073
Maximum 73977730.79 10% 33940396
Mean 43661903.9 15% 35891956
Std Dev 7630741.447 20% 37418591
Variance 5.82282E+13 25% 38688670
Skewness -0.120608431 30% 39818016
Kurtosis 3.24030441 35% 40896269
Median 43743042.01 40% 41890664
Mode 43081813.32 45% 42842390
Left X 31000072.9 50% 43743042
Left P 5% 55% 44748651
Right X 55969392.21 60% 45671013
Right P 95% 65% 46646019
Diff X 24969319.31 70% 47688648
Diff P 90% 75% 48787436
#Errors 0 80% 49981211
Filter Min Off 85% 51512229
Filter Max Off 90% 53289921
#Filtered 0 95% 55969392
Summary Statistics for STOOIP, STB
Statistics Percentile
Minimum 7337749.858 5% 33066744
Maximum 78909579.51 10% 36203089
Mean 46572697.49 15% 38284754
Std Dev 8139457.543 20% 39913164
Variance 6.62508E+13 25% 41267915
Skewness -0.120608431 30% 42472551
Kurtosis 3.24030441 35% 43622687
Median 46659244.81 40% 44683375
Mode 45953934.21 45% 45698549
Left X 33066744.43 50% 46659245
Left P 5% 55% 47731894
Right X 59700685.03 60% 48715748
Right P 95% 65% 49755754
Diff X 26633940.6 70% 50867891
Diff P 90% 75% 52039932
#Errors 0 80% 53313291
Filter Min Off 85% 54946377
Filter Max Off 90% 56842582
#Filtered 0 95% 59700685
Summary Statistics for STOOIP, STB
Statistics Percentile
Minimum 7796359.224 5% 35133416
Maximum 83841428.23 10% 38465782
Mean 49483491.08 15% 40677551
Std Dev 8648173.64 20% 42407736
Variance 7.47909E+13 25% 43847160
Skewness -0.120608431 30% 45127085
Kurtosis 3.24030441 35% 46349105
Median 49575447.61 40% 47476086
Mode 48826055.1 45% 48554709
Left X 35133415.96 50% 49575448
Left P 5% 55% 50715137
Right X 63431977.84 60% 51760482
Right P 95% 65% 52865489
Diff X 28298561.89 70% 54047134
Diff P 90% 75% 55292427
#Errors 0 80% 56645372
Filter Min Off 85% 58380526
Filter Max Off 90% 60395243
#Filtered 0 95% 63431978
Summary Statistics for STOOIP, STB
APPENDIX D: ADDITIONAL TABLES FOR CHAPTER 4 (RESERVOIR 6)
Table D. 1: Summary of statistics for STOOIP simulation runs for 130ft, 140ft and 150ft respectively
106
Depth ΦT Φe K RQI Φz kh Φh nRQI
3688.54 0.2072 0.0929 0.0324 0.0185 0.1024 1.0000 1.0000 0.0004
3688.69 0.2341 0.1035 0.0794 0.0275 0.1155 1.0000 0.9985 0.0009
3688.84 0.2538 0.1097 0.1264 0.0337 0.1233 1.0000 0.9969 0.0015
3688.99 0.2639 0.1131 0.1622 0.0376 0.1276 0.9999 0.9952 0.0023
3689.15 0.2639 0.1146 0.1760 0.0389 0.1294 0.9999 0.9934 0.0030
3689.30 0.2613 0.1200 0.2014 0.0407 0.1364 0.9998 0.9916 0.0038
3689.45 0.2625 0.1264 0.2499 0.0441 0.1447 0.9998 0.9897 0.0047
3689.60 0.2756 0.1281 0.3578 0.0525 0.1469 0.9997 0.9877 0.0057
3689.76 0.2734 0.1239 0.3200 0.0505 0.1414 0.9996 0.9857 0.0067
3689.91 0.2538 0.1157 0.1928 0.0405 0.1309 0.9995 0.9837 0.0074
3690.06 0.2461 0.1131 0.1700 0.0385 0.1275 0.9994 0.9819 0.0082
3690.21 0.2566 0.1232 0.2908 0.0482 0.1405 0.9994 0.9801 0.0091
3690.37 0.2564 0.1325 0.4035 0.0548 0.1527 0.9993 0.9782 0.0102
3690.52 0.2356 0.1301 0.2678 0.0450 0.1496 0.9992 0.9761 0.0111
3690.67 0.2264 0.1289 0.2617 0.0448 0.1479 0.9991 0.9740 0.0119
3690.82 0.2413 0.1390 0.6043 0.0655 0.1615 0.9990 0.9720 0.0132
3690.98 0.2671 0.1558 1.6238 0.1014 0.1846 0.9989 0.9698 0.0152
3691.13 0.2892 0.1727 3.2419 0.1360 0.2088 0.9984 0.9674 0.0178
3691.28 0.3065 0.1874 4.9422 0.1612 0.2306 0.9975 0.9646 0.0209
3691.43 0.3089 0.1912 4.7597 0.1567 0.2364 0.9960 0.9617 0.0239
3691.59 0.3041 0.1910 3.6418 0.1371 0.2361 0.9946 0.9587 0.0266
3691.74 0.3077 0.1960 3.5061 0.1328 0.2439 0.9936 0.9557 0.0292
3691.89 0.3219 0.2041 4.1193 0.1411 0.2565 0.9926 0.9526 0.0319
3692.04 0.3213 0.2027 3.8749 0.1373 0.2543 0.9914 0.9493 0.0346
3692.20 0.2975 0.1900 2.6417 0.1171 0.2346 0.9902 0.9462 0.0368
3692.35 0.2630 0.1720 1.4479 0.0911 0.2078 0.9895 0.9432 0.0386
3692.50 0.2333 0.1515 0.6451 0.0648 0.1785 0.9890 0.9404 0.0399
3692.65 0.2318 0.1459 0.4065 0.0524 0.1708 0.9889 0.9380 0.0409
3692.80 0.2547 0.1574 0.6281 0.0627 0.1868 0.9887 0.9358 0.0421
3692.96 0.2878 0.1816 1.8554 0.1004 0.2219 0.9886 0.9333 0.0440
3693.11 0.3093 0.2064 3.6093 0.1313 0.2601 0.9880 0.9304 0.0466
3693.26 0.3244 0.2281 5.7008 0.1570 0.2956 0.9870 0.9272 0.0496
3693.41 0.3341 0.2415 8.1144 0.1820 0.3185 0.9853 0.9235 0.0531
3693.57 0.3310 0.2422 7.7765 0.1779 0.3196 0.9829 0.9198 0.0566
3693.72 0.3198 0.2373 6.5497 0.1650 0.3111 0.9807 0.9159 0.0598
3693.87 0.3084 0.2297 5.3775 0.1519 0.2982 0.9788 0.9122 0.0627
3694.02 0.3013 0.2146 4.0198 0.1359 0.2732 0.9772 0.9086 0.0653
3694.18 0.3085 0.2104 3.7977 0.1334 0.2664 0.9760 0.9052 0.0679
3694.33 0.3282 0.2222 5.0139 0.1492 0.2857 0.9749 0.9019 0.0708
3694.48 0.3478 0.2383 8.2901 0.1852 0.3129 0.9735 0.8984 0.0744
3694.63 0.3522 0.2445 9.6103 0.1968 0.3237 0.9711 0.8946 0.0782
3694.79 0.3456 0.2395 8.0294 0.1818 0.3149 0.9683 0.8908 0.0817
3694.94 0.3352 0.2272 6.2792 0.1651 0.2940 0.9659 0.8870 0.0849
3695.09 0.3239 0.2186 4.6298 0.1445 0.2798 0.9641 0.8834 0.0877
3695.24 0.3211 0.2260 4.7788 0.1444 0.2920 0.9628 0.8800 0.0905
3695.40 0.3312 0.2467 7.4464 0.1725 0.3275 0.9614 0.8764 0.0939
3695.55 0.3381 0.2569 10.2603 0.1985 0.3456 0.9592 0.8725 0.0977
3695.70 0.3377 0.2491 10.2088 0.2010 0.3318 0.9562 0.8684 0.1016
3695.85 0.3344 0.2404 8.0664 0.1819 0.3165 0.9533 0.8645 0.1051
3696.01 0.3353 0.2396 7.0939 0.1709 0.3150 0.9509 0.8607 0.1084
3696.16 0.3387 0.2409 7.5056 0.1753 0.3174 0.9489 0.8569 0.1118
3696.31 0.3462 0.2530 10.3380 0.2007 0.3387 0.9467 0.8532 0.1157
3696.46 0.3544 0.2684 14.1751 0.2282 0.3668 0.9437 0.8492 0.1201
3696.62 0.3529 0.2692 13.4437 0.2219 0.3684 0.9396 0.8449 0.1244
3696.77 0.3427 0.2535 10.1893 0.1991 0.3396 0.9356 0.8407 0.1283
3696.92 0.3299 0.2329 6.7184 0.1687 0.3035 0.9327 0.8367 0.1316
3697.07 0.3263 0.2280 5.7177 0.1572 0.2954 0.9307 0.8330 0.1346
3697.22 0.3314 0.2407 7.2896 0.1728 0.3170 0.9291 0.8294 0.1379
3697.38 0.3444 0.2597 11.0496 0.2048 0.3508 0.9269 0.8256 0.1419
3697.53 0.3558 0.2688 14.3928 0.2298 0.3676 0.9237 0.8215 0.1464
3697.68 0.3621 0.2727 15.9625 0.2402 0.3750 0.9195 0.8173 0.1510
3697.83 0.3595 0.2771 16.6868 0.2437 0.3832 0.9149 0.8130 0.1557
3697.99 0.3545 0.2796 16.9858 0.2448 0.3881 0.9101 0.8086 0.1605
3698.14 0.3514 0.2763 15.7389 0.2370 0.3817 0.9051 0.8042 0.1651
3698.29 0.3495 0.2724 14.6554 0.2303 0.3744 0.9005 0.7999 0.1695
3698.44 0.3495 0.2709 14.0944 0.2265 0.3715 0.8963 0.7956 0.1739
3698.60 0.3490 0.2730 14.6456 0.2300 0.3756 0.8922 0.7913 0.1784
3698.75 0.3476 0.2744 14.2777 0.2265 0.3782 0.8879 0.7870 0.1827
3698.90 0.3478 0.2735 13.1586 0.2178 0.3765 0.8838 0.7827 0.1870
3699.05 0.3508 0.2748 13.9531 0.2237 0.3790 0.8799 0.7784 0.1913
3699.21 0.3552 0.2785 16.1304 0.2390 0.3860 0.8759 0.7740 0.1959
3699.36 0.3572 0.2793 17.0082 0.2451 0.3874 0.8712 0.7696 0.2007
3699.51 0.3597 0.2860 18.9550 0.2556 0.4006 0.8662 0.7652 0.2056
3699.66 0.3653 0.2925 21.0791 0.2665 0.4135 0.8607 0.7607 0.2108
3699.82 0.3696 0.2952 21.8964 0.2705 0.4188 0.8546 0.7561 0.2160
3699.97 0.3635 0.2877 19.0362 0.2554 0.4039 0.8482 0.7515 0.2210
3700.12 0.3565 0.2764 15.1450 0.2324 0.3820 0.8427 0.7469 0.2255
3700.27 0.3537 0.2675 13.0115 0.2190 0.3652 0.8383 0.7426 0.2297
3700.42 0.3560 0.2627 12.8065 0.2193 0.3562 0.8345 0.7383 0.2340
3700.58 0.3554 0.2665 13.3999 0.2227 0.3633 0.8308 0.7342 0.2383
Depth ΦT Φe K RQI Φz kh Φh nRQI
3700.73 0.3506 0.2730 14.0830 0.2255 0.3755 0.8269 0.7300 0.2426
3700.88 0.3418 0.2711 12.7583 0.2154 0.3719 0.8228 0.7257 0.2468
3701.03 0.3310 0.2587 9.6537 0.1918 0.3490 0.8191 0.7214 0.2505
3701.19 0.3263 0.2456 7.5546 0.1741 0.3256 0.8163 0.7173 0.2539
3701.34 0.3294 0.2426 7.4031 0.1735 0.3202 0.8141 0.7135 0.2573
3701.49 0.3404 0.2565 10.4380 0.2003 0.3450 0.8119 0.7096 0.2611
3701.64 0.3555 0.2744 15.7845 0.2382 0.3782 0.8089 0.7056 0.2657
3701.80 0.3682 0.2842 19.8895 0.2627 0.3971 0.8043 0.7013 0.2708
3701.95 0.3693 0.2806 19.2723 0.2602 0.3901 0.7985 0.6968 0.2759
3702.10 0.3620 0.2747 16.6964 0.2448 0.3787 0.7929 0.6924 0.2806
3702.25 0.3581 0.2706 14.5647 0.2304 0.3709 0.7881 0.6880 0.2851
3702.41 0.3570 0.2647 12.8012 0.2184 0.3600 0.7838 0.6838 0.2893
3702.56 0.3527 0.2566 11.2103 0.2076 0.3451 0.7801 0.6796 0.2933
3702.71 0.3454 0.2509 9.6231 0.1945 0.3350 0.7768 0.6756 0.2971
3702.86 0.3450 0.2532 10.0057 0.1974 0.3390 0.7741 0.6716 0.3009
3703.02 0.3478 0.2548 10.8017 0.2044 0.3420 0.7711 0.6676 0.3049
3703.17 0.3459 0.2562 10.7058 0.2030 0.3445 0.7680 0.6636 0.3088
3703.32 0.3416 0.2597 10.9067 0.2035 0.3508 0.7649 0.6596 0.3127
3703.47 0.3436 0.2662 12.4894 0.2151 0.3627 0.7617 0.6555 0.3169
3703.63 0.3476 0.2750 14.7719 0.2302 0.3792 0.7581 0.6513 0.3214
3703.78 0.3544 0.2878 18.6382 0.2527 0.4040 0.7538 0.6469 0.3263
3703.93 0.3559 0.2959 22.1325 0.2716 0.4202 0.7484 0.6424 0.3315
3704.08 0.3507 0.2948 21.4526 0.2679 0.4180 0.7419 0.6377 0.3367
3704.23 0.3421 0.2911 17.8703 0.2460 0.4107 0.7357 0.6331 0.3415
3704.39 0.3347 0.2906 16.5744 0.2371 0.4097 0.7305 0.6285 0.3461
3704.54 0.3337 0.2873 16.2006 0.2358 0.4030 0.7257 0.6239 0.3506
3704.69 0.3351 0.2777 14.1278 0.2240 0.3845 0.7210 0.6194 0.3550
3704.84 0.3417 0.2722 13.6811 0.2226 0.3741 0.7168 0.6150 0.3593
3705.00 0.3457 0.2682 13.0155 0.2187 0.3665 0.7129 0.6107 0.3635
3705.15 0.3479 0.2685 13.1517 0.2198 0.3671 0.7091 0.6065 0.3678
3705.30 0.3444 0.2666 12.4099 0.2142 0.3635 0.7053 0.6022 0.3719
3705.45 0.3425 0.2637 11.3473 0.2060 0.3582 0.7017 0.5981 0.3759
3705.61 0.3456 0.2659 12.1444 0.2122 0.3622 0.6984 0.5939 0.3800
3705.76 0.3552 0.2761 15.6834 0.2367 0.3813 0.6948 0.5897 0.3846
3705.91 0.3652 0.2870 20.3214 0.2642 0.4026 0.6903 0.5854 0.3897
3706.06 0.3738 0.2965 24.3595 0.2846 0.4215 0.6844 0.5808 0.3952
3706.22 0.3761 0.2973 23.5896 0.2797 0.4231 0.6773 0.5762 0.4006
3706.37 0.3736 0.2920 21.7729 0.2711 0.4125 0.6704 0.5714 0.4059
3706.52 0.3647 0.2822 17.9025 0.2501 0.3931 0.6641 0.5669 0.4107
3706.67 0.3552 0.2731 14.1734 0.2262 0.3757 0.6589 0.5624 0.4151
3706.83 0.3524 0.2726 13.8900 0.2242 0.3747 0.6547 0.5581 0.4195
3706.98 0.3636 0.2851 18.2316 0.2511 0.3988 0.6507 0.5538 0.4243
3707.13 0.3728 0.2942 22.1546 0.2725 0.4169 0.6454 0.5493 0.4296
3707.28 0.3712 0.2923 21.6586 0.2703 0.4131 0.6390 0.5447 0.4348
3707.44 0.3652 0.2875 19.0924 0.2559 0.4036 0.6327 0.5401 0.4398
3707.59 0.3623 0.2885 18.2524 0.2498 0.4054 0.6271 0.5355 0.4446
3707.74 0.3591 0.2904 18.6030 0.2513 0.4092 0.6218 0.5310 0.4495
3707.89 0.3532 0.2873 17.4590 0.2448 0.4031 0.6164 0.5264 0.4542
3708.04 0.3441 0.2752 13.4860 0.2198 0.3797 0.6113 0.5219 0.4585
3708.20 0.3452 0.2711 12.6964 0.2149 0.3719 0.6074 0.5175 0.4626
3708.35 0.3567 0.2823 16.2720 0.2384 0.3933 0.6037 0.5133 0.4673
3708.50 0.3702 0.2948 21.7985 0.2700 0.4181 0.5990 0.5088 0.4725
3708.65 0.3750 0.2993 24.1863 0.2822 0.4272 0.5926 0.5041 0.4780
3708.81 0.3724 0.3035 25.2433 0.2864 0.4357 0.5856 0.4994 0.4835
3708.96 0.3702 0.3066 26.2965 0.2908 0.4422 0.5783 0.4947 0.4891
3709.11 0.3667 0.3035 24.1116 0.2799 0.4358 0.5706 0.4898 0.4945
3709.26 0.3572 0.2917 18.6474 0.2511 0.4118 0.5636 0.4850 0.4994
3709.42 0.3470 0.2773 14.4120 0.2264 0.3837 0.5582 0.4804 0.5038
3709.57 0.3421 0.2719 12.9832 0.2170 0.3734 0.5540 0.4761 0.5080
3709.72 0.3450 0.2759 14.1376 0.2248 0.3810 0.5502 0.4718 0.5123
3709.87 0.3444 0.2764 14.4490 0.2270 0.3820 0.5461 0.4674 0.5167
3710.03 0.3388 0.2749 13.1361 0.2171 0.3790 0.5419 0.4631 0.5209
3710.18 0.3332 0.2711 11.4618 0.2042 0.3718 0.5381 0.4587 0.5249
3710.33 0.3319 0.2644 10.4244 0.1972 0.3595 0.5348 0.4545 0.5287
3710.48 0.3213 0.2451 7.1131 0.1691 0.3248 0.5317 0.4503 0.5320
3710.64 0.3043 0.2277 4.4062 0.1381 0.2949 0.5297 0.4464 0.5347
3710.79 0.2932 0.2204 3.3547 0.1225 0.2827 0.5284 0.4428 0.5370
3710.94 0.3036 0.2336 4.6837 0.1406 0.3048 0.5274 0.4394 0.5398
3711.09 0.3287 0.2582 8.9478 0.1849 0.3480 0.5260 0.4357 0.5433
3711.25 0.3438 0.2707 12.7461 0.2155 0.3712 0.5235 0.4316 0.5475
3711.40 0.3298 0.2592 9.7680 0.1927 0.3500 0.5197 0.4273 0.5513
3711.55 0.3107 0.2481 6.5889 0.1618 0.3300 0.5169 0.4233 0.5544
3711.70 0.3126 0.2596 7.9692 0.1740 0.3506 0.5150 0.4193 0.5578
3711.85 0.3352 0.2877 15.4227 0.2299 0.4039 0.5127 0.4153 0.5622
3712.01 0.3555 0.3080 24.6415 0.2809 0.4450 0.5082 0.4107 0.5676
3712.16 0.3626 0.3127 28.5223 0.2999 0.4550 0.5010 0.4059 0.5735
3712.31 0.3585 0.3068 25.5172 0.2863 0.4427 0.4927 0.4009 0.5790
3712.46 0.3535 0.3002 22.1071 0.2695 0.4290 0.4853 0.3961 0.5842
3712.62 0.3474 0.2968 19.8057 0.2565 0.4220 0.4789 0.3914 0.5892
APPENDIX E: DATA OF WELL 01 FOR FLOW UNIT CHARTS FOR RESERVOIR 7
107
Depth ΦT Φe K RQI Φz kh Φh nRQI
3712.77 0.3415 0.2909 17.4545 0.2432 0.4102 0.4731 0.3867 0.5939
3712.92 0.3416 0.2861 16.3040 0.2371 0.4007 0.4680 0.3821 0.5985
3713.07 0.3491 0.2825 16.0639 0.2368 0.3938 0.4633 0.3776 0.6031
3713.23 0.3601 0.2821 17.4598 0.2470 0.3930 0.4586 0.3731 0.6079
3713.38 0.3612 0.2780 16.8434 0.2444 0.3850 0.4535 0.3687 0.6126
3713.53 0.3542 0.2740 14.8643 0.2313 0.3774 0.4487 0.3643 0.6171
3713.68 0.3471 0.2690 12.5154 0.2142 0.3680 0.4443 0.3600 0.6212
3713.84 0.3476 0.2698 12.6639 0.2151 0.3695 0.4407 0.3557 0.6254
3713.99 0.3537 0.2784 15.6009 0.2351 0.3858 0.4370 0.3515 0.6299
3714.14 0.3582 0.2825 17.4033 0.2464 0.3938 0.4325 0.3471 0.6347
3714.29 0.3579 0.2826 16.8788 0.2427 0.3940 0.4274 0.3427 0.6394
3714.45 0.3641 0.2918 19.9511 0.2596 0.4120 0.4225 0.3382 0.6444
3714.60 0.3735 0.3034 25.7961 0.2895 0.4356 0.4167 0.3336 0.6500
3714.75 0.3742 0.3036 26.6493 0.2942 0.4360 0.4092 0.3288 0.6557
3714.90 0.3550 0.2816 17.6562 0.2486 0.3920 0.4014 0.3240 0.6605
3715.06 0.3355 0.2611 11.4667 0.2081 0.3533 0.3963 0.3196 0.6646
3715.21 0.3335 0.2631 11.4573 0.2072 0.3571 0.3930 0.3155 0.6686
3715.36 0.3417 0.2728 13.7437 0.2229 0.3751 0.3897 0.3113 0.6729
3715.51 0.3419 0.2724 14.1905 0.2266 0.3743 0.3856 0.3070 0.6773
3715.66 0.3388 0.2700 12.7742 0.2160 0.3698 0.3815 0.3027 0.6815
3715.82 0.3435 0.2756 14.2275 0.2256 0.3804 0.3778 0.2985 0.6858
3715.97 0.3524 0.2855 18.1985 0.2507 0.3995 0.3737 0.2941 0.6907
3716.12 0.3574 0.2929 20.6809 0.2639 0.4141 0.3684 0.2896 0.6958
3716.27 0.3587 0.2999 23.4100 0.2774 0.4284 0.3624 0.2850 0.7012
3716.43 0.3578 0.3069 25.4390 0.2859 0.4428 0.3556 0.2803 0.7067
3716.58 0.3521 0.3128 25.8924 0.2857 0.4551 0.3481 0.2754 0.7123
3716.73 0.3425 0.3129 24.0525 0.2753 0.4554 0.3406 0.2705 0.7176
3716.88 0.3285 0.3044 18.9264 0.2476 0.4377 0.3337 0.2656 0.7224
3717.04 0.2984 0.2813 13.3167 0.2160 0.3915 0.3281 0.2608 0.7266
3717.19 0.2715 0.2620 8.8588 0.1826 0.3551 0.3243 0.2563 0.7301
3717.34 0.2724 0.2637 6.9865 0.1616 0.3581 0.3217 0.2522 0.7332
3717.49 0.2964 0.2782 10.1569 0.1897 0.3854 0.3197 0.2480 0.7369
3717.65 0.3074 0.2675 9.8960 0.1910 0.3652 0.3167 0.2437 0.7406
3717.80 0.3007 0.2388 5.9218 0.1564 0.3138 0.3138 0.2394 0.7436
3717.95 0.3047 0.2335 5.7528 0.1559 0.3046 0.3121 0.2357 0.7466
3718.10 0.3272 0.2554 10.6871 0.2031 0.3429 0.3104 0.2320 0.7506
3718.26 0.3615 0.2859 23.1041 0.2823 0.4003 0.3073 0.2280 0.7560
3718.41 0.3899 0.3074 38.5817 0.3518 0.4438 0.3006 0.2235 0.7629
3718.56 0.4006 0.3185 47.6381 0.3840 0.4673 0.2894 0.2186 0.7703
3718.71 0.3955 0.3210 44.5710 0.3700 0.4728 0.2755 0.2136 0.7775
3718.87 0.3798 0.3086 32.4659 0.3221 0.4464 0.2626 0.2085 0.7837
3719.02 0.3650 0.2946 23.2858 0.2792 0.4176 0.2531 0.2037 0.7891
3719.17 0.3607 0.2918 21.7531 0.2711 0.4119 0.2464 0.1990 0.7944
3719.32 0.3582 0.2904 21.5439 0.2704 0.4093 0.2400 0.1944 0.7996
3719.47 0.3487 0.2766 16.2093 0.2404 0.3823 0.2338 0.1898 0.8042
3719.63 0.3308 0.2555 10.2355 0.1987 0.3432 0.2291 0.1855 0.8081
3719.78 0.3184 0.2452 7.9619 0.1789 0.3248 0.2261 0.1815 0.8116
3719.93 0.3207 0.2513 8.3084 0.1805 0.3357 0.2238 0.1776 0.8151
3720.08 0.3351 0.2671 12.0065 0.2105 0.3644 0.2214 0.1736 0.8191
3720.24 0.3458 0.2770 15.9229 0.2381 0.3830 0.2179 0.1694 0.8237
3720.39 0.3470 0.2807 16.1534 0.2382 0.3902 0.2133 0.1651 0.8284
3720.54 0.3464 0.2847 16.5564 0.2394 0.3981 0.2085 0.1606 0.8330
3720.69 0.3521 0.2913 18.2203 0.2483 0.4110 0.2037 0.1561 0.8378
3720.85 0.3565 0.2928 19.0416 0.2532 0.4141 0.1984 0.1515 0.8427
3721.00 0.3581 0.2918 19.8501 0.2590 0.4121 0.1929 0.1469 0.8477
3721.15 0.3533 0.2880 18.5044 0.2517 0.4044 0.1871 0.1423 0.8526
3721.30 0.3524 0.2862 18.1091 0.2498 0.4009 0.1817 0.1378 0.8574
3721.46 0.3544 0.2861 18.5816 0.2531 0.4007 0.1765 0.1333 0.8623
3721.61 0.3539 0.2879 19.1090 0.2558 0.4043 0.1711 0.1288 0.8673
3721.76 0.3520 0.2886 18.8657 0.2539 0.4057 0.1655 0.1242 0.8722
3721.91 0.3507 0.2925 19.3583 0.2554 0.4135 0.1601 0.1197 0.8772
3722.07 0.3528 0.3030 22.3943 0.2699 0.4348 0.1544 0.1151 0.8824
3722.22 0.3458 0.3043 21.6928 0.2651 0.4373 0.1479 0.1103 0.8875
3722.37 0.3358 0.2980 19.0995 0.2514 0.4246 0.1416 0.1055 0.8924
3722.52 0.3371 0.2994 19.3087 0.2522 0.4273 0.1360 0.1008 0.8973
3722.68 0.3473 0.3077 23.6417 0.2752 0.4444 0.1304 0.0961 0.9026
3722.83 0.3568 0.3137 28.6012 0.2998 0.4572 0.1235 0.0912 0.9084
3722.98 0.3576 0.3106 27.6555 0.2963 0.4506 0.1152 0.0863 0.9141
3723.13 0.3552 0.3043 24.4564 0.2815 0.4374 0.1072 0.0814 0.9196
3723.28 0.3537 0.3045 23.0881 0.2734 0.4377 0.1001 0.0766 0.9249
3723.44 0.3496 0.3046 21.8560 0.2660 0.4380 0.0934 0.0718 0.9300
3723.59 0.3448 0.3002 19.6938 0.2543 0.4289 0.0870 0.0670 0.9350
3723.74 0.3424 0.2954 18.5943 0.2491 0.4192 0.0813 0.0623 0.9398
3723.89 0.3453 0.2970 19.1070 0.2519 0.4224 0.0759 0.0576 0.9447
3724.05 0.3510 0.3065 21.3813 0.2623 0.4420 0.0703 0.0529 0.9497
3724.20 0.3567 0.3154 25.2253 0.2808 0.4607 0.0641 0.0481 0.9552
3724.35 0.3662 0.3248 29.8492 0.3010 0.4809 0.0568 0.0431 0.9610
3724.50 0.3761 0.3356 34.1043 0.3165 0.5052 0.0481 0.0380 0.9671
3724.66 0.3785 0.3405 35.6709 0.3214 0.5163 0.0381 0.0327 0.9734
Depth ΦT Φe K RQI Φz kh Φh nRQI
3724.81 0.3651 0.3255 27.2754 0.2874 0.4827 0.0278 0.0273 0.9789
3724.96 0.3479 0.3030 18.2486 0.2437 0.4347 0.0199 0.0222 0.9836
3725.11 0.3395 0.2886 14.3891 0.2217 0.4057 0.0146 0.0174 0.9879
3725.27 0.3354 0.2810 13.1254 0.2146 0.3909 0.0104 0.0129 0.9921
3725.42 0.3283 0.2703 11.2629 0.2027 0.3703 0.0066 0.0084 0.9960
3725.57 0.3301 0.2653 11.3627 0.2055 0.3612 0.0033 0.0042 1.0000
108
Depth ΦT Φe K RQI Φz kh Φh nRQI
3683.05 0.1167 0.0471 0.0000 0.0000 0.0494 1.0000 1.0000 0.0000
3683.20 0.1479 0.0601 0.0014 0.0048 0.0639 1.0000 0.9990 0.0000
3683.36 0.2205 0.1029 0.1984 0.0436 0.1147 1.0000 0.9978 0.0002
3683.51 0.3018 0.1777 9.1199 0.2250 0.2160 1.0000 0.9956 0.0009
3683.66 0.3408 0.2452 62.7184 0.5022 0.3249 1.0000 0.9919 0.0026
3683.81 0.3446 0.2788 105.3597 0.6104 0.3866 0.9997 0.9868 0.0046
3683.97 0.3423 0.2947 107.2538 0.5991 0.4178 0.9993 0.9810 0.0066
3684.12 0.3456 0.3051 113.0515 0.6044 0.4390 0.9989 0.9749 0.0087
3684.27 0.3466 0.3040 110.8316 0.5996 0.4367 0.9985 0.9685 0.0107
3684.42 0.3304 0.2778 183.7666 0.8076 0.3847 0.9981 0.9622 0.0134
3684.58 0.3027 0.2384 60.4320 0.5000 0.3130 0.9974 0.9564 0.0151
3684.73 0.2736 0.2025 31.7444 0.3931 0.2539 0.9972 0.9514 0.0164
3684.88 0.2342 0.1634 1.8218 0.1048 0.1953 0.9971 0.9472 0.0167
3685.03 0.1861 0.1202 0.0766 0.0251 0.1366 0.9971 0.9438 0.0168
3685.18 0.1440 0.0824 0.0008 0.0030 0.0898 0.9971 0.9413 0.0168
3685.34 0.1297 0.0637 0.0000 0.0001 0.0680 0.9971 0.9395 0.0168
3685.49 0.1305 0.0557 0.0000 0.0000 0.0589 0.9971 0.9382 0.0168
3685.64 0.1339 0.0523 0.0000 0.0005 0.0552 0.9971 0.9371 0.0168
3685.79 0.1330 0.0518 0.0001 0.0016 0.0546 0.9971 0.9360 0.0168
3685.95 0.1346 0.0553 0.0002 0.0020 0.0586 0.9971 0.9349 0.0168
3686.10 0.1423 0.0591 0.0003 0.0023 0.0629 0.9971 0.9337 0.0168
3686.25 0.1507 0.0601 0.0003 0.0022 0.0639 0.9971 0.9325 0.0168
3686.40 0.1513 0.0588 0.0001 0.0014 0.0624 0.9971 0.9313 0.0168
3686.56 0.1490 0.0576 0.0001 0.0010 0.0611 0.9971 0.9300 0.0168
3686.71 0.1468 0.0552 0.0001 0.0010 0.0585 0.9971 0.9288 0.0169
3686.86 0.1497 0.0551 0.0003 0.0023 0.0583 0.9971 0.9277 0.0169
3687.01 0.1632 0.0648 0.0055 0.0091 0.0693 0.9971 0.9265 0.0169
3687.17 0.1990 0.0903 0.1192 0.0361 0.0993 0.9971 0.9252 0.0170
3687.32 0.2514 0.1311 1.1491 0.0930 0.1509 0.9971 0.9233 0.0173
3687.47 0.2835 0.1699 2.8990 0.1297 0.2047 0.9971 0.9206 0.0178
3687.62 0.2739 0.1791 2.6246 0.1202 0.2182 0.9970 0.9170 0.0182
3687.78 0.2386 0.1555 1.1430 0.0851 0.1842 0.9970 0.9133 0.0184
3687.93 0.2115 0.1295 0.4366 0.0577 0.1488 0.9970 0.9100 0.0186
3688.08 0.2045 0.1230 0.3677 0.0543 0.1402 0.9970 0.9074 0.0188
3688.23 0.2187 0.1387 1.1719 0.0913 0.1610 0.9970 0.9048 0.0191
3688.39 0.2528 0.1733 6.4487 0.1915 0.2096 0.9970 0.9019 0.0198
3688.54 0.2981 0.2221 34.3262 0.3904 0.2855 0.9970 0.8983 0.0211
3688.69 0.3319 0.2645 84.4267 0.5610 0.3595 0.9969 0.8937 0.0229
3688.84 0.3368 0.2751 92.6405 0.5762 0.3796 0.9965 0.8881 0.0249
3688.99 0.3237 0.2647 68.3879 0.5047 0.3601 0.9962 0.8824 0.0266
3689.15 0.3158 0.2636 56.4137 0.4594 0.3579 0.9959 0.8769 0.0281
3689.30 0.3142 0.2723 51.2951 0.4309 0.3743 0.9957 0.8714 0.0295
3689.45 0.2823 0.2489 19.7312 0.2796 0.3313 0.9955 0.8657 0.0305
3689.60 0.2138 0.1798 1.3483 0.0860 0.2193 0.9955 0.8605 0.0308
3689.76 0.1573 0.1156 0.0309 0.0162 0.1307 0.9955 0.8568 0.0308
3689.91 0.1376 0.0824 0.0013 0.0040 0.0898 0.9955 0.8544 0.0308
3690.06 0.1393 0.0674 0.0004 0.0023 0.0723 0.9955 0.8526 0.0308
3690.21 0.1399 0.0594 0.0002 0.0017 0.0632 0.9955 0.8512 0.0309
3690.37 0.1424 0.0609 0.0002 0.0016 0.0649 0.9955 0.8500 0.0309
3690.52 0.1506 0.0657 0.0004 0.0023 0.0703 0.9955 0.8487 0.0309
3690.67 0.1567 0.0629 0.0005 0.0027 0.0671 0.9955 0.8474 0.0309
3690.82 0.1504 0.0499 0.0001 0.0010 0.0526 0.9955 0.8460 0.0309
3690.98 0.1374 0.0405 0.0000 0.0000 0.0422 0.9955 0.8450 0.0309
3691.13 0.1333 0.0401 0.0000 0.0000 0.0418 0.9955 0.8442 0.0309
3691.28 0.1406 0.0445 0.0000 0.0004 0.0466 0.9955 0.8433 0.0309
3691.43 0.1515 0.0526 0.0001 0.0015 0.0555 0.9955 0.8424 0.0309
3691.59 0.1567 0.0609 0.0004 0.0026 0.0648 0.9955 0.8413 0.0309
3691.74 0.1506 0.0615 0.0002 0.0017 0.0655 0.9955 0.8400 0.0309
3691.89 0.1427 0.0559 0.0000 0.0007 0.0593 0.9955 0.8388 0.0309
3692.04 0.1355 0.0515 0.0000 0.0002 0.0543 0.9955 0.8376 0.0309
3692.20 0.1335 0.0497 0.0000 0.0009 0.0523 0.9955 0.8365 0.0309
3692.35 0.1395 0.0523 0.0013 0.0049 0.0551 0.9955 0.8355 0.0309
3692.50 0.1499 0.0583 0.0176 0.0173 0.0619 0.9955 0.8344 0.0310
3692.65 0.1611 0.0730 0.0624 0.0290 0.0787 0.9955 0.8332 0.0311
3692.80 0.1781 0.1014 0.0671 0.0255 0.1128 0.9955 0.8317 0.0312
3692.96 0.1969 0.1265 0.0609 0.0218 0.1448 0.9955 0.8295 0.0312
3693.11 0.1908 0.1169 0.0412 0.0187 0.1323 0.9955 0.8269 0.0313
3693.26 0.1779 0.0926 0.0558 0.0244 0.1020 0.9955 0.8245 0.0314
3693.41 0.2124 0.1026 0.4290 0.0642 0.1143 0.9955 0.8225 0.0316
3693.57 0.2851 0.1594 3.8330 0.1540 0.1896 0.9955 0.8204 0.0321
3693.72 0.3219 0.2164 11.6355 0.2303 0.2761 0.9954 0.8171 0.0329
3693.87 0.3015 0.2146 7.4267 0.1847 0.2732 0.9954 0.8126 0.0335
3694.02 0.2652 0.1791 2.4854 0.1170 0.2182 0.9954 0.8081 0.0339
3694.18 0.2391 0.1590 1.1885 0.0858 0.1891 0.9954 0.8043 0.0342
3694.33 0.1890 0.1295 0.1996 0.0390 0.1488 0.9954 0.8010 0.0343
3694.48 0.1436 0.0932 0.0108 0.0107 0.1028 0.9954 0.7983 0.0343
3694.63 0.1225 0.0685 0.0003 0.0020 0.0736 0.9954 0.7964 0.0343
3694.79 0.1235 0.0564 0.0000 0.0006 0.0598 0.9954 0.7950 0.0344
3694.94 0.1279 0.0469 0.0000 0.0006 0.0492 0.9954 0.7938 0.0344
3695.09 0.1358 0.0421 0.0000 0.0010 0.0439 0.9954 0.7928 0.0344
Depth ΦT Φe K RQI Φz kh Φh nRQI
3695.24 0.1350 0.0398 0.0000 0.0007 0.0415 0.9954 0.7919 0.0344
3695.40 0.1307 0.0394 0.0000 0.0003 0.0410 0.9954 0.7911 0.0344
3695.55 0.1302 0.0414 0.0000 0.0004 0.0432 0.9954 0.7903 0.0344
3695.70 0.1379 0.0449 0.0001 0.0011 0.0470 0.9954 0.7894 0.0344
3695.85 0.1473 0.0469 0.0002 0.0020 0.0492 0.9954 0.7885 0.0344
3696.01 0.1467 0.0464 0.0002 0.0020 0.0487 0.9954 0.7875 0.0344
3696.16 0.1437 0.0469 0.0002 0.0019 0.0493 0.9954 0.7865 0.0344
3696.31 0.1425 0.0471 0.0002 0.0018 0.0495 0.9954 0.7856 0.0344
3696.46 0.1495 0.0470 0.0003 0.0023 0.0493 0.9954 0.7846 0.0344
3696.62 0.1515 0.0449 0.0002 0.0023 0.0470 0.9954 0.7836 0.0344
3696.77 0.1467 0.0429 0.0002 0.0019 0.0448 0.9954 0.7827 0.0344
3696.92 0.1425 0.0434 0.0002 0.0019 0.0453 0.9954 0.7818 0.0344
3697.07 0.1438 0.0475 0.0003 0.0026 0.0499 0.9954 0.7809 0.0344
3697.22 0.1519 0.0525 0.0007 0.0035 0.0554 0.9954 0.7799 0.0344
3697.38 0.1605 0.0564 0.0010 0.0042 0.0597 0.9954 0.7788 0.0345
3697.53 0.1612 0.0571 0.0009 0.0040 0.0605 0.9954 0.7776 0.0345
3697.68 0.1537 0.0576 0.0007 0.0034 0.0611 0.9954 0.7764 0.0345
3697.83 0.1425 0.0551 0.0002 0.0021 0.0583 0.9954 0.7752 0.0345
3697.99 0.1405 0.0519 0.0001 0.0016 0.0547 0.9954 0.7741 0.0345
3698.14 0.1382 0.0476 0.0001 0.0013 0.0500 0.9954 0.7730 0.0345
3698.29 0.1355 0.0459 0.0001 0.0011 0.0481 0.9954 0.7720 0.0345
3698.44 0.1312 0.0448 0.0000 0.0006 0.0469 0.9954 0.7710 0.0345
3698.60 0.1288 0.0438 0.0000 0.0004 0.0458 0.9954 0.7701 0.0345
3698.75 0.1313 0.0432 0.0000 0.0006 0.0451 0.9954 0.7692 0.0345
3698.90 0.1300 0.0406 0.0000 0.0008 0.0423 0.9954 0.7683 0.0345
3699.05 0.1276 0.0408 0.0001 0.0018 0.0425 0.9954 0.7675 0.0345
3699.21 0.1445 0.0530 0.0033 0.0078 0.0559 0.9954 0.7666 0.0345
3699.36 0.1926 0.0879 0.1455 0.0404 0.0964 0.9954 0.7655 0.0347
3699.51 0.2597 0.1460 3.3321 0.1500 0.1710 0.9954 0.7637 0.0352
3699.66 0.3148 0.1990 21.8801 0.3293 0.2484 0.9953 0.7606 0.0363
3699.82 0.3379 0.2189 46.8517 0.4594 0.2803 0.9953 0.7565 0.0378
3699.97 0.3382 0.2177 55.0810 0.4995 0.2782 0.9951 0.7519 0.0395
3700.12 0.3272 0.2063 45.7883 0.4678 0.2600 0.9949 0.7474 0.0411
3700.27 0.3090 0.1845 27.3483 0.3823 0.2262 0.9947 0.7431 0.0423
3700.42 0.2872 0.1594 11.8151 0.2704 0.1896 0.9946 0.7392 0.0432
3700.58 0.2605 0.1332 4.1027 0.1743 0.1537 0.9946 0.7359 0.0438
3700.73 0.2341 0.1116 1.0439 0.0961 0.1256 0.9946 0.7331 0.0441
3700.88 0.2135 0.0967 0.2482 0.0503 0.1071 0.9945 0.7308 0.0443
3701.03 0.1981 0.0897 0.1156 0.0356 0.0986 0.9945 0.7288 0.0444
3701.19 0.1949 0.0984 0.1893 0.0435 0.1092 0.9945 0.7269 0.0446
3701.34 0.2214 0.1348 1.6799 0.1108 0.1558 0.9945 0.7249 0.0449
3701.49 0.2692 0.1949 28.4880 0.3796 0.2421 0.9945 0.7221 0.0462
3701.64 0.3084 0.2524 126.6087 0.7033 0.3376 0.9944 0.7180 0.0486
3701.80 0.3205 0.2780 242.3523 0.9272 0.3850 0.9940 0.7127 0.0517
3701.95 0.3196 0.2771 213.5719 0.8717 0.3834 0.9931 0.7069 0.0546
3702.10 0.3212 0.2704 153.3611 0.7478 0.3706 0.9923 0.7012 0.0571
3702.25 0.3204 0.2580 99.1769 0.6156 0.3478 0.9917 0.6955 0.0592
3702.41 0.2993 0.2259 28.4611 0.3524 0.2919 0.9913 0.6902 0.0603
3702.56 0.2515 0.1664 2.7862 0.1285 0.1996 0.9912 0.6854 0.0608
3702.71 0.2046 0.1102 0.1834 0.0405 0.1239 0.9912 0.6820 0.0609
3702.86 0.1784 0.0797 0.0257 0.0179 0.0866 0.9912 0.6797 0.0610
3703.02 0.1692 0.0661 0.0092 0.0117 0.0707 0.9912 0.6780 0.0610
3703.17 0.1621 0.0609 0.0049 0.0089 0.0649 0.9912 0.6766 0.0610
3703.32 0.1679 0.0652 0.0083 0.0112 0.0697 0.9912 0.6754 0.0611
3703.47 0.1904 0.0821 0.0487 0.0242 0.0895 0.9912 0.6740 0.0611
3703.63 0.2065 0.0953 0.1009 0.0323 0.1053 0.9912 0.6723 0.0613
3703.78 0.1868 0.0799 0.0225 0.0167 0.0868 0.9912 0.6703 0.0613
3703.93 0.1527 0.0583 0.0025 0.0065 0.0619 0.9912 0.6686 0.0613
3704.08 0.1440 0.0584 0.0028 0.0069 0.0620 0.9912 0.6674 0.0614
3704.23 0.1670 0.0789 0.0255 0.0178 0.0856 0.9912 0.6662 0.0614
3704.39 0.1953 0.0980 0.1183 0.0345 0.1087 0.9912 0.6646 0.0615
3704.54 0.2020 0.0988 0.1359 0.0368 0.1096 0.9912 0.6625 0.0617
3704.69 0.1896 0.0902 0.0754 0.0287 0.0991 0.9912 0.6605 0.0617
3704.84 0.1803 0.0857 0.0635 0.0270 0.0938 0.9912 0.6586 0.0618
3705.00 0.1872 0.0891 0.0964 0.0327 0.0978 0.9912 0.6568 0.0619
3705.15 0.2002 0.0955 0.1556 0.0401 0.1055 0.9912 0.6549 0.0621
3705.30 0.2095 0.0997 0.2138 0.0460 0.1107 0.9912 0.6529 0.0622
3705.45 0.2127 0.1010 0.2316 0.0475 0.1124 0.9912 0.6509 0.0624
3705.61 0.2176 0.1034 0.2867 0.0523 0.1153 0.9912 0.6488 0.0626
3705.76 0.2316 0.1126 0.5324 0.0683 0.1269 0.9912 0.6466 0.0628
3705.91 0.2442 0.1254 1.0136 0.0893 0.1433 0.9912 0.6443 0.0631
3706.06 0.2484 0.1362 1.7403 0.1122 0.1577 0.9912 0.6416 0.0635
3706.22 0.2518 0.1460 3.1616 0.1461 0.1709 0.9912 0.6388 0.0640
3706.37 0.2705 0.1627 7.7142 0.2162 0.1943 0.9912 0.6358 0.0647
3706.52 0.2869 0.1772 21.7809 0.3482 0.2153 0.9911 0.6324 0.0659
3706.67 0.2951 0.1919 74.1528 0.6172 0.2375 0.9910 0.6287 0.0679
3706.83 0.3166 0.2185 140.0869 0.7951 0.2796 0.9908 0.6247 0.0706
3706.98 0.3474 0.2381 175.8000 0.8533 0.3124 0.9902 0.6201 0.0734
3707.13 0.3491 0.2163 96.9505 0.6648 0.2760 0.9896 0.6151 0.0757
APPENDIX F: DATA OF WELL 02 FOR FLOW UNIT CHARTS FOR RESERVOIR 7
109
Depth ΦT Φe K RQI Φz kh Φh nRQI
3707.28 0.3067 0.1591 7.6012 0.2171 0.1892 0.9892 0.6107 0.0764
3707.44 0.2552 0.1104 0.7938 0.0842 0.1241 0.9892 0.6073 0.0767
3707.59 0.2205 0.0879 0.2921 0.0573 0.0963 0.9892 0.6050 0.0769
3707.74 0.2013 0.0863 0.2231 0.0505 0.0944 0.9892 0.6032 0.0770
3707.89 0.2031 0.1080 0.7019 0.0801 0.1211 0.9892 0.6014 0.0773
3708.04 0.2302 0.1511 9.0369 0.2428 0.1780 0.9892 0.5992 0.0781
3708.20 0.2771 0.2067 204.3406 0.9872 0.2606 0.9892 0.5960 0.0814
3708.35 0.3135 0.2477 577.9396 1.5169 0.3292 0.9884 0.5917 0.0865
3708.50 0.3235 0.2615 1034.1470 1.9746 0.3541 0.9862 0.5865 0.0931
3708.65 0.3216 0.2584 705.0332 1.6401 0.3485 0.9823 0.5811 0.0986
3708.81 0.3194 0.2493 427.0956 1.2996 0.3321 0.9797 0.5757 0.1029
3708.96 0.3224 0.2513 358.0578 1.1852 0.3357 0.9781 0.5705 0.1069
3709.11 0.3308 0.2693 508.1616 1.3640 0.3686 0.9768 0.5653 0.1115
3709.26 0.3425 0.2933 1132.1860 1.9510 0.4149 0.9749 0.5597 0.1180
3709.42 0.3459 0.3019 2204.4370 2.6833 0.4324 0.9706 0.5535 0.1270
3709.57 0.3450 0.3020 4286.1230 3.7410 0.4326 0.9624 0.5472 0.1395
3709.72 0.3408 0.3003 9204.3670 5.4973 0.4292 0.9464 0.5410 0.1579
3709.87 0.3367 0.2982 12303.5000 6.3784 0.4248 0.9118 0.5347 0.1793
3710.03 0.3347 0.2952 7222.5550 4.9115 0.4189 0.8658 0.5285 0.1957
3710.18 0.3336 0.2908 3895.1500 3.6344 0.4100 0.8387 0.5223 0.2079
3710.33 0.3310 0.2856 2294.1300 2.8145 0.3997 0.8241 0.5163 0.2173
3710.48 0.3271 0.2795 1621.5120 2.3919 0.3878 0.8156 0.5103 0.2253
3710.64 0.3261 0.2765 1426.9810 2.2558 0.3821 0.8095 0.5045 0.2328
3710.79 0.3293 0.2793 1506.0590 2.3057 0.3876 0.8041 0.4987 0.2405
3710.94 0.3367 0.2880 1901.0960 2.5513 0.4044 0.7985 0.4929 0.2491
3711.09 0.3418 0.2951 2555.2490 2.9218 0.4187 0.7914 0.4869 0.2589
3711.25 0.3419 0.2961 3220.2140 3.2747 0.4206 0.7818 0.4808 0.2698
3711.40 0.3415 0.2982 4377.6970 3.8046 0.4249 0.7697 0.4746 0.2826
3711.55 0.3462 0.3051 4859.5540 3.9630 0.4390 0.7534 0.4684 0.2958
3711.70 0.3503 0.3104 4953.6670 3.9665 0.4502 0.7351 0.4620 0.3091
3711.85 0.3493 0.3091 5697.7420 4.2629 0.4475 0.7166 0.4555 0.3234
3712.01 0.3445 0.3021 4868.4280 3.9864 0.4328 0.6953 0.4491 0.3367
3712.16 0.3423 0.2982 4072.6120 3.6695 0.4249 0.6770 0.4428 0.3490
3712.31 0.3438 0.2978 3786.7050 3.5405 0.4242 0.6618 0.4366 0.3608
3712.46 0.3415 0.2953 3546.5530 3.4411 0.4191 0.6476 0.4303 0.3724
3712.62 0.3343 0.2873 3088.1510 3.2556 0.4031 0.6343 0.4242 0.3833
3712.77 0.3298 0.2773 2739.3040 3.1211 0.3836 0.6228 0.4182 0.3937
3712.92 0.3316 0.2691 2277.8100 2.8888 0.3682 0.6125 0.4124 0.4034
3713.07 0.3338 0.2606 717.6343 1.6478 0.3525 0.6040 0.4068 0.4089
3713.23 0.3365 0.2558 438.6222 1.3002 0.3438 0.6013 0.4014 0.4132
3713.38 0.3417 0.2596 731.5939 1.6668 0.3507 0.5997 0.3961 0.4188
3713.53 0.3481 0.2723 1276.3620 2.1497 0.3742 0.5969 0.3907 0.4260
3713.68 0.3462 0.2851 1464.3060 2.2503 0.3988 0.5921 0.3850 0.4335
3713.84 0.3455 0.2973 3839.0890 3.5683 0.4230 0.5867 0.3790 0.4455
3713.99 0.3522 0.3046 5408.4790 4.1840 0.4381 0.5722 0.3728 0.4595
3714.14 0.3605 0.3092 3626.9380 3.4010 0.4475 0.5521 0.3665 0.4709
3714.29 0.3622 0.3107 5680.5600 4.2457 0.4508 0.5385 0.3601 0.4851
3714.45 0.3599 0.3108 6465.9910 4.5292 0.4509 0.5172 0.3536 0.5002
3714.60 0.3555 0.3067 6703.5480 4.6419 0.4425 0.4930 0.3471 0.5158
3714.75 0.3505 0.2991 6157.4230 4.5056 0.4266 0.4678 0.3407 0.5309
3714.90 0.3439 0.2907 4831.9330 4.0482 0.4099 0.4448 0.3345 0.5444
3715.06 0.3398 0.2866 4327.2430 3.8580 0.4018 0.4268 0.3284 0.5573
3715.21 0.3428 0.2896 4838.6790 4.0587 0.4077 0.4105 0.3224 0.5709
3715.36 0.3464 0.2906 5128.8020 4.1713 0.4097 0.3924 0.3164 0.5849
3715.51 0.3437 0.2862 4084.7240 3.7515 0.4009 0.3731 0.3103 0.5974
3715.66 0.3380 0.2790 2999.7340 3.2558 0.3870 0.3579 0.3044 0.6083
3715.82 0.3418 0.2777 2827.3420 3.1683 0.3845 0.3467 0.2986 0.6189
3715.97 0.3461 0.2793 3296.4220 3.4116 0.3874 0.3361 0.2927 0.6303
3716.12 0.3454 0.2835 3280.9030 3.3782 0.3956 0.3238 0.2869 0.6416
3716.27 0.3424 0.2871 3078.6460 3.2514 0.4028 0.3114 0.2810 0.6525
3716.43 0.3428 0.2915 3527.9420 3.4546 0.4114 0.2999 0.2750 0.6641
3716.58 0.3393 0.2900 3328.7570 3.3640 0.4085 0.2867 0.2689 0.6754
3716.73 0.3307 0.2857 2762.6570 3.0875 0.4000 0.2742 0.2629 0.6857
3716.88 0.3242 0.2836 2452.6890 2.9203 0.3958 0.2639 0.2570 0.6955
3717.04 0.3227 0.2836 2481.5940 2.9374 0.3958 0.2547 0.2510 0.7053
3717.19 0.3192 0.2800 2355.7980 2.8800 0.3889 0.2454 0.2451 0.7149
3717.34 0.3132 0.2767 1986.4190 2.6605 0.3825 0.2366 0.2393 0.7238
3717.49 0.3136 0.2823 1791.3650 2.5013 0.3934 0.2292 0.2335 0.7322
3717.65 0.3233 0.2922 1647.9850 2.3581 0.4128 0.2225 0.2277 0.7401
3717.80 0.3316 0.2983 1093.2480 1.9010 0.4250 0.2163 0.2215 0.7465
3717.95 0.3299 0.2974 3519.1240 3.4156 0.4233 0.2122 0.2153 0.7579
3718.10 0.3241 0.2919 2843.2170 3.0987 0.4123 0.1990 0.2092 0.7683
3718.26 0.3229 0.2872 2069.4350 2.6653 0.4030 0.1884 0.2031 0.7772
3718.41 0.3268 0.2867 1576.5570 2.3284 0.4020 0.1806 0.1971 0.7850
3718.56 0.3313 0.2890 3033.8030 3.2172 0.4065 0.1747 0.1911 0.7957
3718.71 0.3392 0.2952 3616.9650 3.4756 0.4189 0.1634 0.1851 0.8074
3718.87 0.3456 0.2997 2299.5540 2.7505 0.4279 0.1499 0.1789 0.8166
3719.02 0.3426 0.3000 3175.5890 3.2304 0.4287 0.1412 0.1727 0.8274
3719.17 0.3326 0.2963 2130.2190 2.6623 0.4211 0.1294 0.1664 0.8363
Depth ΦT Φe K RQI Φz kh Φh nRQI
3719.32 0.3287 0.2952 1181.2700 1.9863 0.4188 0.1214 0.1602 0.8430
3719.47 0.3307 0.2953 2388.8530 2.8243 0.4190 0.1169 0.1541 0.8524
3719.63 0.3355 0.2977 2392.8040 2.8151 0.4239 0.1080 0.1479 0.8618
3719.78 0.3367 0.2937 1640.4110 2.3468 0.4158 0.0990 0.1417 0.8697
3719.93 0.3395 0.2917 1055.2940 1.8886 0.4119 0.0929 0.1356 0.8760
3720.08 0.3415 0.2900 841.2045 1.6910 0.4085 0.0889 0.1295 0.8817
3720.24 0.3447 0.2883 995.1403 1.8450 0.4050 0.0858 0.1235 0.8878
3720.39 0.3467 0.2850 1613.3010 2.3625 0.3986 0.0821 0.1175 0.8957
3720.54 0.3437 0.2795 3512.2710 3.5201 0.3879 0.0760 0.1115 0.9075
3720.69 0.3395 0.2765 2142.4150 2.7638 0.3823 0.0629 0.1057 0.9168
3720.85 0.3359 0.2779 1093.2640 1.9693 0.3849 0.0548 0.0999 0.9234
3721.00 0.3331 0.2766 631.5874 1.5004 0.3824 0.0508 0.0941 0.9284
3721.15 0.3327 0.2784 768.7755 1.6500 0.3858 0.0484 0.0884 0.9339
3721.30 0.3393 0.2875 2640.1300 3.0092 0.4034 0.0455 0.0826 0.9440
3721.46 0.3513 0.2998 3043.7980 3.1638 0.4282 0.0357 0.0766 0.9546
3721.61 0.3559 0.3020 2106.5740 2.6223 0.4327 0.0242 0.0703 0.9634
3721.76 0.3539 0.2932 979.5233 1.8150 0.4148 0.0163 0.0640 0.9694
3721.91 0.3527 0.2885 630.0834 1.4674 0.4055 0.0127 0.0579 0.9743
3722.07 0.3539 0.2965 652.0508 1.4726 0.4214 0.0103 0.0519 0.9793
3722.22 0.3505 0.3019 716.4249 1.5296 0.4325 0.0079 0.0457 0.9844
3722.37 0.3419 0.2967 575.0782 1.3824 0.4218 0.0052 0.0394 0.9890
3722.52 0.3347 0.2912 511.3123 1.3157 0.4109 0.0030 0.0333 0.9934
3722.68 0.3241 0.2798 194.8327 0.8286 0.3885 0.0011 0.0272 0.9962
3722.83 0.3034 0.2463 80.5016 0.5677 0.3268 0.0004 0.0213 0.9981
3722.98 0.2739 0.1971 22.5588 0.3359 0.2455 0.0001 0.0162 0.9992
3723.13 0.2428 0.1596 3.1710 0.1400 0.1898 0.0000 0.0121 0.9997
3723.28 0.2145 0.1367 0.3773 0.0522 0.1583 0.0000 0.0088 0.9999
3723.44 0.1866 0.1161 0.0665 0.0238 0.1313 0.0000 0.0059 0.9999
3723.59 0.1608 0.0935 0.0155 0.0128 0.1031 0.0000 0.0035 1.0000
3723.74 0.1464 0.0753 0.0020 0.0051 0.0814 0.0000 0.0016 1.0000
110
Depth ΦT Φe K RQI Φz kh Φh nRQI
3752.09 0.1278 0.0396 0.0000 0.0000 0.0412 1.0000 1.0000 0.0000
3752.24 0.1007 0.0336 0.0000 0.0000 0.0347 1.0000 0.9995 0.0000
3752.39 0.0696 0.0274 0.0000 0.0000 0.0282 1.0000 0.9990 0.0000
3752.55 0.2334 0.1159 0.3087 0.0512 0.1312 1.0000 0.9986 0.0003
3752.70 0.3293 0.2063 15.9711 0.2763 0.2599 1.0000 0.9970 0.0017
3752.85 0.2967 0.2185 12.2025 0.2347 0.2796 0.9996 0.9941 0.0030
3753.00 0.2033 0.1554 0.4382 0.0527 0.1840 0.9992 0.9911 0.0033
3753.16 0.1461 0.1027 0.0088 0.0092 0.1145 0.9992 0.9890 0.0033
3753.31 0.1987 0.1197 0.0501 0.0203 0.1360 0.9992 0.9875 0.0034
3753.46 0.1726 0.0874 0.0010 0.0034 0.0958 0.9992 0.9859 0.0035
3753.61 0.1422 0.0598 0.0000 0.0000 0.0636 0.9992 0.9847 0.0035
3753.76 0.1428 0.0517 0.0000 0.0000 0.0545 0.9992 0.9839 0.0035
3753.92 0.1451 0.0507 0.0000 0.0000 0.0534 0.9992 0.9831 0.0035
3754.07 0.1415 0.0523 0.0000 0.0005 0.0551 0.9992 0.9824 0.0035
3754.22 0.1439 0.0643 0.0008 0.0036 0.0687 0.9992 0.9817 0.0035
3754.37 0.1261 0.0727 0.0076 0.0102 0.0784 0.9992 0.9808 0.0035
3754.53 0.1062 0.0776 0.0202 0.0160 0.0841 0.9992 0.9798 0.0036
3754.68 0.2593 0.2213 27.8393 0.3522 0.2842 0.9992 0.9787 0.0055
3754.83 0.3102 0.2866 144.4546 0.7049 0.4018 0.9985 0.9757 0.0093
3754.98 0.2747 0.2631 80.1029 0.5479 0.3570 0.9946 0.9717 0.0122
3755.14 0.2685 0.2646 70.5337 0.5127 0.3598 0.9924 0.9680 0.0149
3755.29 0.2574 0.2547 41.8385 0.4025 0.3417 0.9905 0.9644 0.0171
3755.44 0.2618 0.2490 29.3860 0.3411 0.3315 0.9894 0.9609 0.0189
3755.59 0.2775 0.2534 22.1505 0.2936 0.3394 0.9886 0.9574 0.0205
3755.75 0.2427 0.2088 11.6154 0.2342 0.2639 0.9880 0.9539 0.0217
3755.90 0.2017 0.1495 2.0650 0.1167 0.1757 0.9877 0.9510 0.0223
3756.05 0.1488 0.0865 0.0083 0.0097 0.0947 0.9876 0.9489 0.0224
3756.20 0.1303 0.0566 0.0000 0.0000 0.0599 0.9876 0.9477 0.0224
3756.36 0.1350 0.0504 0.0000 0.0000 0.0531 0.9876 0.9470 0.0224
3756.51 0.1591 0.0564 0.0001 0.0013 0.0598 0.9876 0.9463 0.0224
3756.66 0.1557 0.0537 0.0000 0.0008 0.0568 0.9876 0.9455 0.0224
3756.81 0.1398 0.0487 0.0000 0.0000 0.0512 0.9876 0.9447 0.0224
3756.97 0.1304 0.0460 0.0000 0.0000 0.0482 0.9876 0.9441 0.0224
3757.12 0.1402 0.0508 0.0000 0.0000 0.0535 0.9876 0.9434 0.0224
3757.27 0.1356 0.0509 0.0000 0.0000 0.0536 0.9876 0.9427 0.0224
3757.42 0.1242 0.0476 0.0000 0.0000 0.0500 0.9876 0.9420 0.0224
3757.57 0.1415 0.0545 0.0000 0.0002 0.0576 0.9876 0.9414 0.0224
3757.73 0.1510 0.0587 0.0000 0.0007 0.0624 0.9876 0.9406 0.0224
3757.88 0.1363 0.0526 0.0000 0.0000 0.0555 0.9876 0.9398 0.0224
3758.03 0.1242 0.0463 0.0000 0.0000 0.0486 0.9876 0.9391 0.0224
3758.18 0.1295 0.0459 0.0000 0.0000 0.0481 0.9876 0.9384 0.0224
3758.34 0.1319 0.0454 0.0000 0.0000 0.0475 0.9876 0.9378 0.0224
3758.49 0.1301 0.0444 0.0000 0.0000 0.0464 0.9876 0.9372 0.0224
3758.64 0.1264 0.0440 0.0000 0.0000 0.0460 0.9876 0.9365 0.0224
3758.79 0.1219 0.0448 0.0000 0.0000 0.0469 0.9876 0.9359 0.0224
3758.95 0.1336 0.0507 0.0000 0.0000 0.0534 0.9876 0.9353 0.0224
3759.10 0.1457 0.0559 0.0000 0.0006 0.0592 0.9876 0.9346 0.0224
3759.25 0.1638 0.0632 0.0005 0.0028 0.0674 0.9876 0.9338 0.0224
3759.40 0.1297 0.0505 0.0000 0.0000 0.0532 0.9876 0.9330 0.0224
3759.56 0.1233 0.0467 0.0000 0.0000 0.0490 0.9876 0.9323 0.0224
3759.71 0.1274 0.0446 0.0000 0.0000 0.0467 0.9876 0.9316 0.0224
3759.86 0.1379 0.0460 0.0000 0.0000 0.0482 0.9876 0.9310 0.0224
3760.01 0.1310 0.0443 0.0000 0.0000 0.0463 0.9876 0.9304 0.0224
3760.17 0.0981 0.0471 0.0000 0.0000 0.0494 0.9876 0.9297 0.0224
3760.32 0.1688 0.1054 0.1086 0.0319 0.1178 0.9876 0.9291 0.0226
3760.47 0.2847 0.2106 13.3760 0.2503 0.2668 0.9876 0.9276 0.0239
3760.62 0.2408 0.1850 3.4587 0.1358 0.2270 0.9873 0.9247 0.0247
3760.78 0.2645 0.1932 4.0102 0.1431 0.2394 0.9872 0.9222 0.0254
3760.93 0.2397 0.1648 1.9204 0.1072 0.1973 0.9870 0.9195 0.0260
3761.08 0.1638 0.1077 0.1860 0.0413 0.1207 0.9870 0.9172 0.0262
3761.23 0.2318 0.1521 2.1953 0.1193 0.1793 0.9870 0.9157 0.0269
3761.39 0.2203 0.1461 1.2357 0.0913 0.1712 0.9869 0.9136 0.0273
3761.54 0.1317 0.0854 0.0072 0.0091 0.0934 0.9869 0.9116 0.0274
3761.69 0.2728 0.1579 0.5688 0.0596 0.1874 0.9869 0.9104 0.0277
3761.84 0.2382 0.1142 0.0581 0.0224 0.1289 0.9869 0.9082 0.0278
3761.99 0.2015 0.0804 0.0062 0.0087 0.0874 0.9869 0.9066 0.0279
3762.15 0.1845 0.0664 0.0011 0.0040 0.0712 0.9869 0.9055 0.0279
3762.30 0.1860 0.0650 0.0007 0.0032 0.0695 0.9869 0.9046 0.0279
3762.45 0.1885 0.0645 0.0007 0.0032 0.0689 0.9869 0.9037 0.0279
3762.60 0.1931 0.0653 0.0009 0.0038 0.0699 0.9869 0.9028 0.0280
3762.76 0.1886 0.0658 0.0009 0.0036 0.0705 0.9869 0.9019 0.0280
3762.91 0.1936 0.0727 0.0043 0.0076 0.0784 0.9869 0.9010 0.0280
3763.06 0.1905 0.0783 0.0134 0.0130 0.0850 0.9869 0.9000 0.0281
3763.21 0.1922 0.0901 0.0403 0.0210 0.0990 0.9869 0.8989 0.0282
3763.37 0.1915 0.1085 0.1570 0.0378 0.1218 0.9869 0.8976 0.0284
3763.52 0.2208 0.1490 1.2879 0.0923 0.1750 0.9869 0.8961 0.0289
3763.67 0.2131 0.1529 0.6117 0.0628 0.1805 0.9868 0.8941 0.0292
3763.82 0.1803 0.1179 0.0171 0.0120 0.1336 0.9868 0.8920 0.0293
3763.98 0.1151 0.0611 0.0000 0.0000 0.0650 0.9868 0.8903 0.0293
Depth ΦT Φe K RQI Φz kh Φh nRQI
3764.13 0.1163 0.0492 0.0000 0.0000 0.0518 0.9868 0.8895 0.0293
3764.28 0.2327 0.0867 0.0328 0.0193 0.0949 0.9868 0.8888 0.0294
3764.43 0.2075 0.0746 0.0065 0.0093 0.0806 0.9868 0.8876 0.0294
3764.59 0.1643 0.0583 0.0002 0.0018 0.0619 0.9868 0.8866 0.0295
3764.74 0.1490 0.0525 0.0001 0.0013 0.0555 0.9868 0.8858 0.0295
3764.89 0.1465 0.0538 0.0005 0.0030 0.0568 0.9868 0.8850 0.0295
3765.04 0.1482 0.0627 0.0047 0.0086 0.0669 0.9868 0.8843 0.0295
3765.19 0.1401 0.0742 0.0278 0.0192 0.0801 0.9868 0.8834 0.0296
3765.35 0.1467 0.0966 0.2106 0.0464 0.1069 0.9868 0.8824 0.0299
3765.50 0.1690 0.1294 1.3457 0.1013 0.1486 0.9868 0.8811 0.0304
3765.65 0.1984 0.1675 6.3056 0.1926 0.2012 0.9868 0.8793 0.0314
3765.80 0.2261 0.2035 20.3839 0.3142 0.2555 0.9866 0.8769 0.0331
3765.96 0.2306 0.2158 31.9400 0.3820 0.2752 0.9861 0.8741 0.0352
3766.11 0.2144 0.2029 25.6420 0.3530 0.2546 0.9852 0.8711 0.0370
3766.26 0.2271 0.2125 40.2930 0.4323 0.2699 0.9845 0.8683 0.0394
3766.41 0.2422 0.2226 52.4328 0.4819 0.2863 0.9834 0.8654 0.0419
3766.57 0.2355 0.2125 38.4711 0.4225 0.2698 0.9820 0.8623 0.0442
3766.72 0.2328 0.2019 34.2422 0.4090 0.2529 0.9810 0.8594 0.0464
3766.87 0.1941 0.1539 2.8582 0.1353 0.1819 0.9800 0.8566 0.0471
3767.02 0.1504 0.1018 0.0354 0.0185 0.1134 0.9800 0.8544 0.0472
3767.18 0.1378 0.0747 0.0012 0.0040 0.0808 0.9800 0.8530 0.0472
3767.33 0.1481 0.0633 0.0004 0.0026 0.0676 0.9800 0.8520 0.0472
3767.48 0.1645 0.0576 0.0009 0.0040 0.0611 0.9800 0.8511 0.0472
3767.63 0.1393 0.0438 0.0000 0.0008 0.0458 0.9800 0.8503 0.0473
3767.79 0.1473 0.0467 0.0000 0.0005 0.0490 0.9800 0.8497 0.0473
3767.94 0.1445 0.0511 0.0000 0.0004 0.0539 0.9800 0.8491 0.0473
3768.09 0.1492 0.0687 0.0004 0.0023 0.0737 0.9800 0.8483 0.0473
3768.24 0.1324 0.0820 0.0078 0.0097 0.0893 0.9800 0.8474 0.0473
3768.40 0.2521 0.1943 9.0561 0.2144 0.2411 0.9800 0.8463 0.0485
3768.55 0.3079 0.2590 52.1483 0.4455 0.3496 0.9797 0.8436 0.0508
3768.70 0.2858 0.2284 14.5314 0.2504 0.2961 0.9783 0.8400 0.0522
3768.85 0.2448 0.1632 0.7087 0.0654 0.1951 0.9779 0.8368 0.0525
3769.00 0.1427 0.0721 0.0003 0.0019 0.0777 0.9779 0.8346 0.0525
3769.16 0.1088 0.0429 0.0000 0.0000 0.0449 0.9779 0.8336 0.0525
3769.31 0.1298 0.0466 0.0000 0.0001 0.0488 0.9779 0.8330 0.0525
3769.46 0.1384 0.0508 0.0001 0.0017 0.0535 0.9779 0.8323 0.0526
3769.61 0.1487 0.0565 0.0003 0.0023 0.0599 0.9779 0.8316 0.0526
3769.77 0.1590 0.0654 0.0013 0.0045 0.0700 0.9779 0.8308 0.0526
3769.92 0.2127 0.0985 0.0845 0.0291 0.1092 0.9779 0.8299 0.0527
3770.07 0.2401 0.1280 0.5098 0.0627 0.1468 0.9779 0.8286 0.0531
3770.22 0.2674 0.1679 5.1641 0.1741 0.2018 0.9779 0.8268 0.0540
3770.38 0.2669 0.1968 24.0828 0.3474 0.2450 0.9777 0.8245 0.0559
3770.53 0.2664 0.2233 47.2699 0.4568 0.2876 0.9771 0.8217 0.0583
3770.68 0.2661 0.2406 73.4669 0.5487 0.3168 0.9758 0.8186 0.0612
3770.83 0.2676 0.2499 101.4141 0.6326 0.3331 0.9738 0.8153 0.0646
3770.99 0.2738 0.2568 125.2733 0.6935 0.3455 0.9711 0.8119 0.0683
3771.14 0.2647 0.2461 93.8650 0.6132 0.3265 0.9677 0.8083 0.0716
3771.29 0.2724 0.2532 93.3083 0.6028 0.3390 0.9652 0.8049 0.0748
3771.44 0.2639 0.2285 39.5298 0.4130 0.2962 0.9627 0.8014 0.0770
3771.60 0.1688 0.1278 1.4581 0.1060 0.1466 0.9616 0.7982 0.0776
3771.75 0.1591 0.1100 0.4816 0.0657 0.1235 0.9616 0.7964 0.0779
3771.90 0.1293 0.0849 0.0180 0.0144 0.0928 0.9615 0.7949 0.0780
3772.05 0.0855 0.0508 0.0000 0.0000 0.0535 0.9615 0.7937 0.0780
3772.21 0.1120 0.0514 0.0000 0.0000 0.0542 0.9615 0.7930 0.0780
3772.36 0.1181 0.0413 0.0000 0.0000 0.0431 0.9615 0.7923 0.0780
3772.51 0.1326 0.0437 0.0000 0.0007 0.0457 0.9615 0.7918 0.0780
3772.66 0.1429 0.0510 0.0003 0.0023 0.0538 0.9615 0.7911 0.0780
3772.81 0.2239 0.1039 0.1115 0.0325 0.1160 0.9615 0.7904 0.0782
3772.97 0.2924 0.1838 6.0677 0.1804 0.2252 0.9615 0.7890 0.0792
3773.12 0.2946 0.2311 21.4819 0.3027 0.3005 0.9614 0.7864 0.0808
3773.27 0.2315 0.1905 3.0659 0.1260 0.2353 0.9608 0.7833 0.0815
3773.42 0.1032 0.0727 0.0000 0.0000 0.0784 0.9607 0.7806 0.0815
3773.58 0.0919 0.0527 0.0000 0.0000 0.0556 0.9607 0.7796 0.0815
3773.73 0.1486 0.0828 0.0154 0.0135 0.0903 0.9607 0.7789 0.0815
3773.88 0.2995 0.1994 12.4528 0.2481 0.2491 0.9607 0.7777 0.0829
3774.03 0.2595 0.1903 8.8226 0.2138 0.2351 0.9604 0.7750 0.0840
3774.19 0.1774 0.1174 0.2293 0.0439 0.1330 0.9601 0.7723 0.0842
3774.34 0.1984 0.1053 0.1164 0.0330 0.1177 0.9601 0.7707 0.0844
3774.49 0.1978 0.0863 0.0682 0.0279 0.0945 0.9601 0.7693 0.0846
3774.64 0.2178 0.0865 0.1027 0.0342 0.0946 0.9601 0.7681 0.0847
3774.80 0.1835 0.0670 0.0172 0.0159 0.0718 0.9601 0.7669 0.0848
3774.95 0.2023 0.0688 0.0279 0.0200 0.0739 0.9601 0.7659 0.0849
3775.10 0.3362 0.1173 1.3041 0.1047 0.1329 0.9601 0.7650 0.0855
3775.25 0.2832 0.1037 0.6738 0.0801 0.1157 0.9601 0.7634 0.0859
3775.41 0.1581 0.0556 0.0061 0.0104 0.0589 0.9601 0.7619 0.0860
3775.56 0.1779 0.0600 0.0074 0.0110 0.0639 0.9601 0.7611 0.0860
3775.71 0.2581 0.0967 0.3228 0.0574 0.1071 0.9601 0.7603 0.0863
3775.86 0.2487 0.1172 1.0049 0.0920 0.1327 0.9601 0.7590 0.0868
3776.02 0.2624 0.1525 6.2025 0.2002 0.1800 0.9600 0.7574 0.0879
APPENDIX G: DATA OF WELL 03 FOR FLOW UNIT CHARTS FOR RESERVOIR 7
111
Depth ΦT Φe K RQI Φz kh Φh nRQI
3776.17 0.2738 0.1892 31.7371 0.4067 0.2333 0.9599 0.7552 0.0901
3776.32 0.2791 0.2233 76.5544 0.5815 0.2874 0.9590 0.7526 0.0932
3776.47 0.2844 0.2473 134.8779 0.7333 0.3285 0.9569 0.7495 0.0971
3776.63 0.2508 0.2217 82.9084 0.6072 0.2849 0.9533 0.7461 0.1003
3776.78 0.2541 0.2207 104.1867 0.6822 0.2832 0.9511 0.7430 0.1040
3776.93 0.2553 0.2212 127.7916 0.7547 0.2840 0.9483 0.7400 0.1080
3777.08 0.2578 0.2277 172.5345 0.8644 0.2948 0.9448 0.7369 0.1126
3777.23 0.2518 0.2285 182.3246 0.8871 0.2961 0.9401 0.7338 0.1174
3777.39 0.2641 0.2445 309.2788 1.1168 0.3236 0.9352 0.7306 0.1233
3777.54 0.2706 0.2509 401.9777 1.2568 0.3350 0.9269 0.7272 0.1300
3777.69 0.2699 0.2489 397.8896 1.2554 0.3314 0.9160 0.7237 0.1367
3777.84 0.2614 0.2391 321.7604 1.1519 0.3142 0.9053 0.7203 0.1429
3778.00 0.2685 0.2438 378.4404 1.2372 0.3224 0.8966 0.7170 0.1495
3778.15 0.2772 0.2486 443.3077 1.3258 0.3309 0.8864 0.7136 0.1566
3778.30 0.2815 0.2509 467.5580 1.3554 0.3350 0.8745 0.7102 0.1638
3778.45 0.2800 0.2514 457.7683 1.3400 0.3357 0.8618 0.7067 0.1710
3778.61 0.2677 0.2422 352.1971 1.1974 0.3196 0.8495 0.7032 0.1774
3778.76 0.2721 0.2460 381.6612 1.2367 0.3263 0.8399 0.6998 0.1840
3778.91 0.2721 0.2453 368.6499 1.2173 0.3250 0.8296 0.6964 0.1905
3779.06 0.2771 0.2522 418.8843 1.2796 0.3373 0.8197 0.6930 0.1973
3779.22 0.2723 0.2531 404.3094 1.2549 0.3389 0.8084 0.6895 0.2040
3779.37 0.2724 0.2566 412.4081 1.2587 0.3453 0.7975 0.6860 0.2107
3779.52 0.2690 0.2529 357.8782 1.1812 0.3385 0.7863 0.6825 0.2171
3779.67 0.2696 0.2517 340.5656 1.1550 0.3363 0.7767 0.6790 0.2232
3779.83 0.2606 0.2422 262.8411 1.0344 0.3196 0.7675 0.6755 0.2287
3779.98 0.2390 0.2214 148.4847 0.8133 0.2843 0.7604 0.6721 0.2331
3780.13 0.2267 0.2090 98.4247 0.6814 0.2642 0.7564 0.6691 0.2367
3780.28 0.2230 0.2050 82.1512 0.6285 0.2579 0.7537 0.6662 0.2401
3780.43 0.2290 0.2106 87.7690 0.6411 0.2668 0.7515 0.6633 0.2435
3780.59 0.2402 0.2212 98.8467 0.6637 0.2841 0.7491 0.6604 0.2471
3780.74 0.2324 0.2133 65.6717 0.5510 0.2711 0.7465 0.6574 0.2500
3780.89 0.2435 0.2218 68.6385 0.5524 0.2850 0.7447 0.6544 0.2529
3781.04 0.2168 0.1956 26.0774 0.3625 0.2432 0.7428 0.6513 0.2549
3781.20 0.1942 0.1702 8.3540 0.2200 0.2051 0.7421 0.6486 0.2561
3781.35 0.1375 0.1112 0.3349 0.0545 0.1251 0.7419 0.6463 0.2563
3781.50 0.1509 0.1084 0.2031 0.0430 0.1216 0.7419 0.6447 0.2566
3781.65 0.1811 0.1192 0.3358 0.0527 0.1353 0.7419 0.6432 0.2569
3781.81 0.1936 0.1256 0.4296 0.0581 0.1437 0.7419 0.6416 0.2572
3781.96 0.2127 0.1423 0.8455 0.0765 0.1659 0.7419 0.6398 0.2576
3782.11 0.1870 0.1269 0.3521 0.0523 0.1454 0.7418 0.6379 0.2579
3782.26 0.1501 0.1017 0.0621 0.0245 0.1132 0.7418 0.6361 0.2580
3782.42 0.1530 0.1029 0.0621 0.0244 0.1147 0.7418 0.6347 0.2581
3782.57 0.1595 0.1059 0.0806 0.0274 0.1185 0.7418 0.6333 0.2583
3782.72 0.1393 0.0905 0.0218 0.0154 0.0995 0.7418 0.6318 0.2583
3782.87 0.1479 0.0922 0.0298 0.0178 0.1015 0.7418 0.6306 0.2584
3783.03 0.1453 0.0883 0.0245 0.0165 0.0969 0.7418 0.6293 0.2585
3783.18 0.2041 0.1272 0.4192 0.0570 0.1457 0.7418 0.6281 0.2588
3783.33 0.1944 0.1284 0.4125 0.0563 0.1473 0.7418 0.6263 0.2591
3783.48 0.1768 0.1218 0.2489 0.0449 0.1386 0.7418 0.6245 0.2594
3783.64 0.1544 0.1077 0.0941 0.0294 0.1207 0.7418 0.6228 0.2595
3783.79 0.1510 0.1038 0.0769 0.0270 0.1158 0.7418 0.6213 0.2597
3783.94 0.1853 0.1259 0.3972 0.0558 0.1440 0.7418 0.6199 0.2600
3784.09 0.1972 0.1338 0.7092 0.0723 0.1545 0.7418 0.6182 0.2604
3784.24 0.2037 0.1385 0.9230 0.0811 0.1608 0.7418 0.6163 0.2608
3784.40 0.2123 0.1451 1.2468 0.0920 0.1697 0.7417 0.6144 0.2613
3784.55 0.2051 0.1403 0.9544 0.0819 0.1632 0.7417 0.6124 0.2617
3784.70 0.1947 0.1332 0.6384 0.0687 0.1537 0.7417 0.6104 0.2621
3784.85 0.1815 0.1239 0.3486 0.0527 0.1415 0.7417 0.6086 0.2624
3785.01 0.2145 0.1426 1.2203 0.0919 0.1663 0.7417 0.6069 0.2629
3785.16 0.2545 0.1578 2.8165 0.1326 0.1874 0.7416 0.6049 0.2636
3785.31 0.1920 0.1067 0.1919 0.0421 0.1195 0.7415 0.6027 0.2638
3785.46 0.1451 0.0707 0.0102 0.0119 0.0761 0.7415 0.6012 0.2639
3785.62 0.1524 0.0660 0.0060 0.0095 0.0707 0.7415 0.6002 0.2639
3785.77 0.1805 0.0726 0.0150 0.0143 0.0783 0.7415 0.5993 0.2640
3785.92 0.1676 0.0663 0.0097 0.0120 0.0710 0.7415 0.5983 0.2640
3786.07 0.2256 0.0895 0.0982 0.0329 0.0983 0.7415 0.5974 0.2642
3786.23 0.2610 0.1061 0.2712 0.0502 0.1187 0.7415 0.5962 0.2645
3786.38 0.2769 0.1200 0.8092 0.0815 0.1364 0.7415 0.5947 0.2649
3786.53 0.1853 0.0864 0.0786 0.0300 0.0945 0.7415 0.5930 0.2651
3786.68 0.0957 0.0449 0.0000 0.0007 0.0470 0.7415 0.5918 0.2651
3786.84 0.1207 0.0521 0.0003 0.0023 0.0549 0.7415 0.5912 0.2651
3786.99 0.1339 0.0532 0.0009 0.0041 0.0562 0.7415 0.5905 0.2651
3787.14 0.1749 0.0708 0.0281 0.0198 0.0762 0.7415 0.5898 0.2652
3787.29 0.2904 0.1284 2.5892 0.1410 0.1473 0.7415 0.5888 0.2660
3787.45 0.1921 0.0915 0.1721 0.0431 0.1008 0.7414 0.5870 0.2662
3787.60 0.1541 0.0747 0.0320 0.0206 0.0807 0.7414 0.5857 0.2663
3787.75 0.2144 0.1049 0.4478 0.0649 0.1171 0.7414 0.5847 0.2667
3787.90 0.2041 0.1056 0.5258 0.0701 0.1180 0.7414 0.5832 0.2670
3788.05 0.2361 0.1326 2.4624 0.1353 0.1529 0.7414 0.5818 0.2678
Depth ΦT Φe K RQI Φz kh Φh nRQI
3788.21 0.1894 0.1164 1.0792 0.0956 0.1317 0.7413 0.5800 0.2683
3788.36 0.2464 0.1657 15.5992 0.3047 0.1986 0.7413 0.5783 0.2699
3788.51 0.2221 0.1645 18.0817 0.3292 0.1969 0.7409 0.5760 0.2717
3788.66 0.2419 0.1931 50.5381 0.5080 0.2393 0.7404 0.5738 0.2744
3788.82 0.2077 0.1731 27.0924 0.3929 0.2093 0.7390 0.5711 0.2765
3788.97 0.1856 0.1598 17.3761 0.3274 0.1903 0.7383 0.5687 0.2782
3789.12 0.1960 0.1715 30.1332 0.4162 0.2070 0.7378 0.5665 0.2804
3789.27 0.2631 0.2277 223.3244 0.9833 0.2949 0.7370 0.5641 0.2857
3789.43 0.3142 0.2630 680.6837 1.5974 0.3569 0.7310 0.5609 0.2942
3789.58 0.2800 0.2265 284.7142 1.1134 0.2928 0.7126 0.5573 0.3002
3789.73 0.2738 0.2150 195.6296 0.9471 0.2740 0.7050 0.5542 0.3052
3789.88 0.2825 0.2136 183.8687 0.9212 0.2717 0.6997 0.5512 0.3102
3790.04 0.2927 0.2152 193.0499 0.9404 0.2743 0.6947 0.5482 0.3152
3790.19 0.2858 0.2088 142.8851 0.8214 0.2639 0.6895 0.5453 0.3196
3790.34 0.2934 0.2121 116.6962 0.7365 0.2692 0.6857 0.5424 0.3235
3790.49 0.2515 0.1787 32.1234 0.4210 0.2176 0.6825 0.5394 0.3257
3790.65 0.2877 0.2044 78.4673 0.6152 0.2569 0.6816 0.5370 0.3290
3790.80 0.2665 0.1958 56.4633 0.5332 0.2435 0.6795 0.5341 0.3319
3790.95 0.2064 0.1560 10.7543 0.2607 0.1848 0.6780 0.5314 0.3333
3791.10 0.1228 0.0889 0.1097 0.0349 0.0976 0.6777 0.5293 0.3335
3791.26 0.2354 0.1530 2.2997 0.1217 0.1806 0.6777 0.5280 0.3341
3791.41 0.1649 0.0962 0.2316 0.0487 0.1065 0.6776 0.5259 0.3344
3791.56 0.1139 0.0627 0.0190 0.0173 0.0669 0.6776 0.5246 0.3345
3791.71 0.1152 0.0613 0.0046 0.0086 0.0653 0.6776 0.5237 0.3345
3791.87 0.1367 0.0687 0.0111 0.0126 0.0738 0.6776 0.5228 0.3346
3792.02 0.1055 0.0606 0.0061 0.0099 0.0645 0.6776 0.5219 0.3346
3792.17 0.2065 0.1457 5.5452 0.1937 0.1705 0.6776 0.5211 0.3357
3792.32 0.2527 0.2133 64.9507 0.5479 0.2712 0.6775 0.5190 0.3386
3792.47 0.2527 0.2361 102.3793 0.6538 0.3091 0.6757 0.5161 0.3421
3792.63 0.2343 0.2295 96.3863 0.6436 0.2978 0.6730 0.5128 0.3455
3792.78 0.2352 0.2336 139.8832 0.7685 0.3047 0.6704 0.5096 0.3496
3792.93 0.2563 0.2548 289.2141 1.0578 0.3420 0.6666 0.5064 0.3553
3793.08 0.2542 0.2522 282.0067 1.0501 0.3372 0.6588 0.5029 0.3609
3793.24 0.2436 0.2415 199.8276 0.9033 0.3183 0.6512 0.4994 0.3657
3793.39 0.2515 0.2474 222.8788 0.9424 0.3287 0.6458 0.4960 0.3707
3793.54 0.2516 0.2404 187.2064 0.8762 0.3165 0.6398 0.4926 0.3754
3793.69 0.2344 0.2143 91.0671 0.6473 0.2727 0.6347 0.4893 0.3789
3793.85 0.2358 0.2067 69.2835 0.5749 0.2605 0.6323 0.4863 0.3819
3794.00 0.2344 0.1993 47.9032 0.4868 0.2489 0.6304 0.4834 0.3845
3794.15 0.2548 0.2100 67.6161 0.5635 0.2658 0.6291 0.4807 0.3876
3794.30 0.2590 0.2068 82.2497 0.6263 0.2606 0.6273 0.4778 0.3909
3794.46 0.3095 0.2423 269.7897 1.0477 0.3198 0.6250 0.4749 0.3965
3794.61 0.3230 0.2510 306.1224 1.0965 0.3352 0.6178 0.4716 0.4024
3794.76 0.3062 0.2365 178.3506 0.8622 0.3098 0.6095 0.4681 0.4070
3794.91 0.2952 0.2276 223.4616 0.9840 0.2946 0.6047 0.4648 0.4122
3795.07 0.3183 0.2508 648.8133 1.5970 0.3348 0.5987 0.4617 0.4207
3795.22 0.2185 0.1801 81.1550 0.6666 0.2196 0.5811 0.4582 0.4243
3795.37 0.2323 0.1996 157.7724 0.8827 0.2494 0.5789 0.4557 0.4290
3795.52 0.2572 0.2271 350.7630 1.2342 0.2937 0.5746 0.4529 0.4356
3795.67 0.2147 0.1923 132.8082 0.8252 0.2381 0.5652 0.4498 0.4400
3795.83 0.2130 0.1926 143.2434 0.8563 0.2386 0.5616 0.4471 0.4446
3795.98 0.2209 0.2008 181.7334 0.9446 0.2513 0.5577 0.4444 0.4496
3796.13 0.2372 0.2158 287.7935 1.1467 0.2752 0.5528 0.4417 0.4558
3796.28 0.2448 0.2211 359.3048 1.2659 0.2838 0.5450 0.4387 0.4625
3796.44 0.2533 0.2258 435.8394 1.3794 0.2917 0.5354 0.4356 0.4699
3796.59 0.2650 0.2341 566.1364 1.5440 0.3057 0.5236 0.4325 0.4781
3796.74 0.2353 0.2076 284.4537 1.1623 0.2620 0.5083 0.4292 0.4843
3796.89 0.2177 0.1929 186.6416 0.9768 0.2390 0.5006 0.4264 0.4896
3797.05 0.2221 0.1979 217.3259 1.0406 0.2467 0.4956 0.4237 0.4951
3797.20 0.2235 0.1990 230.2495 1.0680 0.2485 0.4897 0.4210 0.5008
3797.35 0.2284 0.2018 256.6476 1.1199 0.2528 0.4835 0.4182 0.5068
3797.50 0.2256 0.1987 235.3127 1.0805 0.2480 0.4766 0.4154 0.5126
3797.66 0.2128 0.1882 172.8754 0.9517 0.2318 0.4702 0.4127 0.5177
3797.81 0.2167 0.1934 203.9660 1.0197 0.2398 0.4655 0.4100 0.5231
3797.96 0.2162 0.1945 211.2150 1.0348 0.2414 0.4601 0.4074 0.5286
3798.11 0.2104 0.1921 195.5441 1.0019 0.2377 0.4544 0.4047 0.5340
3798.27 0.2189 0.2031 271.3705 1.1476 0.2549 0.4491 0.4020 0.5401
3798.42 0.2296 0.2136 364.1746 1.2964 0.2717 0.4418 0.3992 0.5470
3798.57 0.2225 0.2058 288.9477 1.1767 0.2591 0.4320 0.3963 0.5533
3798.72 0.2199 0.2018 261.6651 1.1307 0.2528 0.4241 0.3934 0.5594
3798.88 0.2096 0.1920 192.1994 0.9936 0.2376 0.4171 0.3906 0.5647
3799.03 0.1962 0.1792 125.3401 0.8304 0.2183 0.4119 0.3879 0.5691
3799.18 0.2136 0.1937 203.0224 1.0165 0.2403 0.4085 0.3855 0.5745
3799.33 0.2169 0.1948 212.0090 1.0358 0.2420 0.4030 0.3828 0.5801
3799.48 0.2399 0.2153 378.9680 1.3173 0.2744 0.3973 0.3801 0.5871
3799.64 0.2367 0.2131 345.3807 1.2642 0.2708 0.3871 0.3771 0.5938
3799.79 0.2301 0.2084 291.8994 1.1751 0.2633 0.3777 0.3741 0.6001
3799.94 0.2242 0.2031 232.2477 1.0619 0.2548 0.3699 0.3713 0.6058
3800.09 0.2356 0.2106 275.4731 1.1357 0.2668 0.3636 0.3684 0.6119
112
Depth ΦT Φe K RQI Φz kh Φh nRQI
3800.25 0.2585 0.2276 440.5982 1.3815 0.2947 0.3562 0.3655 0.6192
3800.40 0.3130 0.2707 1282.9840 2.1615 0.3713 0.3443 0.3624 0.6308
3800.55 0.3001 0.2572 915.7422 1.8735 0.3463 0.3095 0.3586 0.6408
3800.70 0.3312 0.2801 1467.7140 2.2728 0.3892 0.2849 0.3551 0.6529
3800.86 0.3363 0.2790 1341.3390 2.1772 0.3870 0.2451 0.3512 0.6646
3801.01 0.3003 0.2454 593.5043 1.5442 0.3252 0.2090 0.3473 0.6728
3801.16 0.2488 0.2044 176.9945 0.9240 0.2569 0.1930 0.3439 0.6777
3801.31 0.2268 0.1903 96.4647 0.7069 0.2351 0.1882 0.3411 0.6815
3801.47 0.2048 0.1756 50.8054 0.5341 0.2130 0.1856 0.3385 0.6844
3801.62 0.2241 0.1953 89.2948 0.6714 0.2427 0.1842 0.3360 0.6880
3801.77 0.2269 0.2018 94.1017 0.6781 0.2528 0.1818 0.3333 0.6916
3801.92 0.2175 0.1986 64.5549 0.5661 0.2479 0.1793 0.3305 0.6946
3802.08 0.2244 0.2060 59.1110 0.5319 0.2594 0.1776 0.3278 0.6974
3802.23 0.2320 0.2046 49.5093 0.4884 0.2572 0.1760 0.3249 0.7000
3802.38 0.2362 0.1907 34.1592 0.4202 0.2357 0.1746 0.3221 0.7023
3802.53 0.2572 0.1803 29.7986 0.4037 0.2199 0.1737 0.3194 0.7044
3802.69 0.2882 0.1700 13.7990 0.2829 0.2049 0.1729 0.3170 0.7060
3802.84 0.2540 0.1311 1.2566 0.0972 0.1509 0.1725 0.3146 0.7065
3802.99 0.2299 0.1163 0.6841 0.0762 0.1316 0.1725 0.3128 0.7069
3803.14 0.2950 0.1601 6.7567 0.2040 0.1906 0.1725 0.3112 0.7080
3803.29 0.3159 0.1799 12.6580 0.2634 0.2194 0.1723 0.3089 0.7094
3803.45 0.2902 0.1683 12.0173 0.2653 0.2024 0.1719 0.3065 0.7108
3803.60 0.2854 0.1666 10.4090 0.2482 0.1999 0.1716 0.3041 0.7121
3803.75 0.3093 0.1789 11.6713 0.2536 0.2179 0.1713 0.3018 0.7135
3803.90 0.2968 0.1709 12.4252 0.2678 0.2061 0.1710 0.2993 0.7149
3804.06 0.3241 0.1904 32.3734 0.4094 0.2352 0.1707 0.2970 0.7171
3804.21 0.3299 0.2090 66.7610 0.5612 0.2643 0.1698 0.2943 0.7201
3804.36 0.2847 0.1988 47.8671 0.4872 0.2481 0.1680 0.2914 0.7227
3804.51 0.3005 0.2276 87.0939 0.6142 0.2947 0.1667 0.2887 0.7260
3804.67 0.3109 0.2474 121.3351 0.6953 0.3288 0.1644 0.2855 0.7297
3804.82 0.3143 0.2538 154.4730 0.7746 0.3402 0.1611 0.2821 0.7338
3804.97 0.2713 0.2131 42.6847 0.4444 0.2707 0.1569 0.2786 0.7362
3805.12 0.2078 0.1469 2.1909 0.1213 0.1722 0.1558 0.2756 0.7368
3805.28 0.2098 0.1401 3.7389 0.1622 0.1629 0.1557 0.2736 0.7377
3805.43 0.3016 0.2349 192.1124 0.8980 0.3070 0.1556 0.2717 0.7425
3805.58 0.2278 0.1991 60.5321 0.5475 0.2486 0.1504 0.2684 0.7454
3805.73 0.1843 0.1675 19.5592 0.3393 0.2012 0.1488 0.2657 0.7472
3805.89 0.1590 0.1467 8.3019 0.2362 0.1720 0.1483 0.2633 0.7485
3806.04 0.1736 0.1616 17.9891 0.3313 0.1927 0.1481 0.2613 0.7503
3806.19 0.1633 0.1526 18.7700 0.3483 0.1800 0.1476 0.2591 0.7521
3806.34 0.1567 0.1461 19.2986 0.3609 0.1711 0.1471 0.2570 0.7541
3806.50 0.1859 0.1728 59.6477 0.5834 0.2089 0.1466 0.2549 0.7572
3806.65 0.1833 0.1685 56.6675 0.5759 0.2026 0.1449 0.2525 0.7603
3806.80 0.1944 0.1769 84.1086 0.6847 0.2149 0.1434 0.2502 0.7639
3806.95 0.2128 0.1932 161.6400 0.9083 0.2395 0.1411 0.2478 0.7688
3807.10 0.2167 0.1984 204.1206 1.0071 0.2476 0.1368 0.2451 0.7741
3807.26 0.2213 0.2057 262.3900 1.1215 0.2590 0.1313 0.2423 0.7801
3807.41 0.2179 0.2037 263.8307 1.1300 0.2558 0.1242 0.2395 0.7862
3807.56 0.2142 0.2007 248.9691 1.1060 0.2510 0.1171 0.2367 0.7921
3807.71 0.2027 0.1889 176.7376 0.9604 0.2329 0.1103 0.2339 0.7972
3807.87 0.1938 0.1795 135.0550 0.8614 0.2187 0.1056 0.2313 0.8018
3808.02 0.1952 0.1792 138.5393 0.8730 0.2184 0.1019 0.2288 0.8065
3808.17 0.1793 0.1632 78.4972 0.6886 0.1950 0.0982 0.2263 0.8101
3808.32 0.1915 0.1741 114.0504 0.8037 0.2108 0.0961 0.2240 0.8144
3808.48 0.1848 0.1688 90.1100 0.7255 0.2030 0.0930 0.2216 0.8183
3808.63 0.1742 0.1607 62.6021 0.6198 0.1914 0.0905 0.2193 0.8216
3808.78 0.2033 0.1901 161.0867 0.9140 0.2348 0.0889 0.2171 0.8265
3808.93 0.2060 0.1940 166.9106 0.9211 0.2407 0.0845 0.2144 0.8314
3809.09 0.2066 0.1935 147.3315 0.8665 0.2399 0.0800 0.2117 0.8360
3809.24 0.1904 0.1758 73.6283 0.6426 0.2133 0.0760 0.2091 0.8395
3809.39 0.1987 0.1822 84.6034 0.6767 0.2228 0.0740 0.2066 0.8431
3809.54 0.2089 0.1934 116.1320 0.7695 0.2397 0.0718 0.2041 0.8472
3809.70 0.2299 0.2151 181.2907 0.9115 0.2741 0.0686 0.2014 0.8521
3809.85 0.2282 0.2139 109.1026 0.7092 0.2720 0.0637 0.1985 0.8559
3810.00 0.2156 0.2008 49.4916 0.4930 0.2512 0.0608 0.1955 0.8585
3810.15 0.2108 0.1945 33.1790 0.4101 0.2415 0.0594 0.1927 0.8607
3810.31 0.2107 0.1878 26.5875 0.3736 0.2312 0.0585 0.1900 0.8627
3810.46 0.2746 0.2203 71.1467 0.5643 0.2826 0.0578 0.1874 0.8657
3810.61 0.1282 0.0844 0.0532 0.0249 0.0921 0.0559 0.1844 0.8658
3810.76 0.0880 0.0452 0.0000 0.0005 0.0473 0.0559 0.1832 0.8658
3810.91 0.2266 0.0953 0.1628 0.0410 0.1054 0.0559 0.1826 0.8660
3811.07 0.2679 0.1134 0.5843 0.0713 0.1279 0.0559 0.1812 0.8664
3811.22 0.2314 0.1050 0.2511 0.0486 0.1173 0.0559 0.1797 0.8667
3811.37 0.2414 0.1163 0.4200 0.0597 0.1316 0.0559 0.1782 0.8670
3811.52 0.2173 0.1084 0.3264 0.0545 0.1216 0.0559 0.1766 0.8673
3811.68 0.1650 0.0833 0.0566 0.0259 0.0908 0.0559 0.1751 0.8674
3811.83 0.1833 0.0926 0.0862 0.0303 0.1021 0.0559 0.1739 0.8676
3811.98 0.2219 0.1134 0.3609 0.0560 0.1279 0.0559 0.1727 0.8679
3812.13 0.2665 0.1373 1.3322 0.0978 0.1591 0.0558 0.1711 0.8684
Depth ΦT Φe K RQI Φz kh Φh nRQI
3812.29 0.2653 0.1356 1.0485 0.0873 0.1569 0.0558 0.1692 0.8689
3812.44 0.2756 0.1415 1.4004 0.0988 0.1648 0.0558 0.1673 0.8694
3812.59 0.2541 0.1338 0.8046 0.0770 0.1545 0.0557 0.1654 0.8698
3812.74 0.2546 0.1375 0.8235 0.0768 0.1594 0.0557 0.1635 0.8702
3812.90 0.2465 0.1345 0.6577 0.0694 0.1554 0.0557 0.1616 0.8706
3813.05 0.2608 0.1419 0.8339 0.0761 0.1654 0.0557 0.1597 0.8710
3813.20 0.2570 0.1426 0.6528 0.0672 0.1663 0.0557 0.1578 0.8714
3813.35 0.2664 0.1530 0.9578 0.0786 0.1806 0.0556 0.1558 0.8718
3813.51 0.2528 0.1516 0.9384 0.0781 0.1787 0.0556 0.1537 0.8722
3813.66 0.2481 0.1565 1.1872 0.0865 0.1855 0.0556 0.1516 0.8727
3813.81 0.2587 0.1706 2.3454 0.1164 0.2057 0.0556 0.1494 0.8733
3813.96 0.2370 0.1615 1.6001 0.0988 0.1926 0.0555 0.1471 0.8738
3814.12 0.1836 0.1251 0.2248 0.0421 0.1430 0.0555 0.1448 0.8740
3814.27 0.1928 0.1294 0.2836 0.0465 0.1486 0.0554 0.1431 0.8743
3814.42 0.2004 0.1325 0.3871 0.0537 0.1527 0.0554 0.1413 0.8746
3814.57 0.2106 0.1378 0.5879 0.0649 0.1598 0.0554 0.1395 0.8749
3814.72 0.2199 0.1415 0.6488 0.0672 0.1649 0.0554 0.1375 0.8753
3814.88 0.1668 0.1057 0.0719 0.0259 0.1182 0.0554 0.1356 0.8754
3815.03 0.2454 0.1574 2.1826 0.1169 0.1868 0.0554 0.1341 0.8760
3815.18 0.2615 0.1801 12.0726 0.2571 0.2197 0.0553 0.1319 0.8774
3815.33 0.2488 0.1813 18.0444 0.3133 0.2214 0.0550 0.1294 0.8791
3815.49 0.2252 0.1745 19.6805 0.3335 0.2114 0.0545 0.1269 0.8809
3815.64 0.2467 0.1956 54.1981 0.5227 0.2432 0.0540 0.1245 0.8837
3815.79 0.2189 0.1775 28.0003 0.3943 0.2159 0.0525 0.1218 0.8858
3815.94 0.1519 0.1262 2.6188 0.1430 0.1445 0.0518 0.1194 0.8865
3816.10 0.1470 0.1256 2.8981 0.1508 0.1436 0.0517 0.1176 0.8873
3816.25 0.1589 0.1385 6.7271 0.2188 0.1608 0.0516 0.1159 0.8885
3816.40 0.1689 0.1508 10.7829 0.2655 0.1776 0.0514 0.1140 0.8899
3816.55 0.1797 0.1653 15.9723 0.3087 0.1980 0.0511 0.1119 0.8916
3816.71 0.1970 0.1863 33.6062 0.4218 0.2289 0.0507 0.1096 0.8938
3816.86 0.2024 0.1959 42.4249 0.4621 0.2436 0.0498 0.1070 0.8963
3817.01 0.1958 0.1916 33.7831 0.4169 0.2370 0.0487 0.1043 0.8985
3817.16 0.1646 0.1615 11.0696 0.2600 0.1926 0.0478 0.1016 0.8999
3817.32 0.1491 0.1458 6.3640 0.2075 0.1706 0.0475 0.0994 0.9010
3817.47 0.1332 0.1299 3.4024 0.1607 0.1493 0.0473 0.0974 0.9019
3817.62 0.1085 0.1061 0.9647 0.0947 0.1187 0.0472 0.0956 0.9024
3817.77 0.0974 0.0957 0.5283 0.0738 0.1058 0.0472 0.0941 0.9028
3817.93 0.1068 0.1044 1.0363 0.0989 0.1166 0.0471 0.0928 0.9033
3818.08 0.1250 0.1208 2.9382 0.1549 0.1374 0.0471 0.0913 0.9041
3818.23 0.1572 0.1506 13.0539 0.2924 0.1773 0.0470 0.0897 0.9057
3818.38 0.1713 0.1644 24.0626 0.3799 0.1968 0.0467 0.0876 0.9077
3818.53 0.1613 0.1553 17.4234 0.3326 0.1839 0.0460 0.0853 0.9095
3818.69 0.1615 0.1553 18.0543 0.3385 0.1839 0.0456 0.0831 0.9113
3818.84 0.1597 0.1534 17.9786 0.3400 0.1812 0.0451 0.0810 0.9131
3818.99 0.1545 0.1490 15.8150 0.3235 0.1751 0.0446 0.0789 0.9149
3819.14 0.1519 0.1471 14.9486 0.3166 0.1725 0.0442 0.0768 0.9165
3819.30 0.1475 0.1418 12.8591 0.2990 0.1653 0.0438 0.0748 0.9181
3819.45 0.1589 0.1508 20.9525 0.3701 0.1776 0.0434 0.0728 0.9201
3819.60 0.1666 0.1572 29.0999 0.4272 0.1865 0.0429 0.0707 0.9224
3819.75 0.1639 0.1555 27.3598 0.4166 0.1841 0.0421 0.0685 0.9246
3819.91 0.1492 0.1425 15.9463 0.3322 0.1662 0.0413 0.0664 0.9264
3820.06 0.1444 0.1385 13.5215 0.3102 0.1608 0.0409 0.0644 0.9281
3820.21 0.1724 0.1673 43.9195 0.5087 0.2010 0.0405 0.0625 0.9308
3820.36 0.1927 0.1891 91.0402 0.6889 0.2332 0.0393 0.0602 0.9345
3820.52 0.1930 0.1901 91.4034 0.6886 0.2347 0.0369 0.0576 0.9381
3820.67 0.1864 0.1810 69.3065 0.6144 0.2210 0.0344 0.0549 0.9414
3820.82 0.1899 0.1809 70.9364 0.6219 0.2208 0.0325 0.0524 0.9447
3820.97 0.1890 0.1788 65.9298 0.6029 0.2178 0.0306 0.0499 0.9480
3821.13 0.1876 0.1787 63.4757 0.5918 0.2176 0.0289 0.0474 0.9511
3821.28 0.1819 0.1748 52.7507 0.5455 0.2118 0.0271 0.0450 0.9540
3821.43 0.1944 0.1867 77.3800 0.6393 0.2295 0.0257 0.0425 0.9574
3821.58 0.1835 0.1753 51.5365 0.5385 0.2125 0.0236 0.0399 0.9603
3821.74 0.1851 0.1762 53.4948 0.5471 0.2139 0.0222 0.0375 0.9632
3821.89 0.1847 0.1766 52.2640 0.5402 0.2145 0.0208 0.0351 0.9661
3822.04 0.1869 0.1801 55.1024 0.5492 0.2197 0.0194 0.0326 0.9691
3822.19 0.1949 0.1898 73.0115 0.6159 0.2342 0.0179 0.0301 0.9723
3822.34 0.1986 0.1950 80.5775 0.6384 0.2422 0.0159 0.0275 0.9758
3822.50 0.1733 0.1697 31.4780 0.4277 0.2044 0.0138 0.0248 0.9780
3822.65 0.1672 0.1630 23.3474 0.3758 0.1947 0.0129 0.0225 0.9800
3822.80 0.1997 0.1950 71.1077 0.5997 0.2422 0.0123 0.0202 0.9832
3822.95 0.2113 0.2077 108.0506 0.7162 0.2621 0.0104 0.0175 0.9871
3823.11 0.2179 0.2148 129.4446 0.7709 0.2735 0.0074 0.0146 0.9912
3823.26 0.2145 0.2096 85.9784 0.6360 0.2652 0.0040 0.0117 0.9946
3823.41 0.1991 0.1929 36.9266 0.4344 0.2390 0.0016 0.0087 0.9969
3823.56 0.1822 0.1745 15.0433 0.2915 0.2114 0.0006 0.0061 0.9985
3823.72 0.1722 0.1587 7.8608 0.2210 0.1886 0.0002 0.0037 0.9996
3823.87 0.1268 0.1059 0.4741 0.0664 0.1185 0.0000 0.0015 1.0000
113
Depth ΦT Φe K RQI Φz kh Φh nRQI
3807.66 0.1313 0.0468 0.0007 0.0039 0.0491 1.0000 1.0000 0.0000
3807.81 0.1448 0.0625 0.0720 0.0337 0.0666 1.0000 0.9993 0.0001
3807.96 0.1847 0.1114 4.3185 0.1955 0.1254 1.0000 0.9984 0.0005
3808.12 0.2343 0.1773 53.8948 0.5475 0.2155 1.0000 0.9968 0.0016
3808.27 0.2827 0.2375 202.8595 0.9178 0.3114 0.9998 0.9942 0.0034
3808.42 0.2692 0.2304 148.9636 0.7983 0.2994 0.9990 0.9908 0.0050
3808.57 0.2712 0.2296 233.6708 1.0018 0.2979 0.9985 0.9874 0.0070
3808.73 0.2602 0.2248 799.9034 1.8731 0.2900 0.9976 0.9841 0.0108
3808.88 0.2705 0.2310 927.4870 1.9896 0.3004 0.9947 0.9808 0.0148
3809.03 0.2667 0.2344 455.9179 1.3848 0.3062 0.9913 0.9775 0.0176
3809.18 0.2716 0.2329 383.9347 1.2750 0.3036 0.9896 0.9741 0.0201
3809.34 0.2719 0.2358 361.8493 1.2299 0.3086 0.9882 0.9707 0.0226
3809.49 0.2755 0.2343 364.4196 1.2385 0.3059 0.9868 0.9673 0.0251
3809.64 0.2764 0.2407 449.6284 1.3570 0.3171 0.9855 0.9639 0.0278
3809.79 0.2772 0.2449 472.3990 1.3791 0.3243 0.9838 0.9604 0.0306
3809.95 0.2748 0.2446 440.9723 1.3333 0.3238 0.9821 0.9568 0.0333
3810.10 0.2707 0.2453 414.6020 1.2909 0.3251 0.9805 0.9533 0.0359
3810.25 0.2735 0.2490 433.1706 1.3096 0.3316 0.9789 0.9497 0.0385
3810.40 0.2800 0.2539 448.6869 1.3200 0.3403 0.9773 0.9461 0.0411
3810.56 0.2755 0.2445 350.0950 1.1881 0.3237 0.9757 0.9424 0.0435
3810.71 0.2778 0.2448 346.5196 1.1814 0.3241 0.9744 0.9389 0.0459
3810.86 0.2752 0.2426 343.4175 1.1814 0.3203 0.9731 0.9353 0.0483
3811.01 0.2680 0.2335 303.7582 1.1326 0.3046 0.9718 0.9318 0.0506
3811.17 0.2615 0.2225 136.4718 0.7777 0.2861 0.9707 0.9284 0.0521
3811.32 0.2679 0.2234 92.5621 0.6392 0.2877 0.9702 0.9252 0.0534
3811.47 0.2806 0.2290 157.8036 0.8243 0.2970 0.9699 0.9220 0.0551
3811.62 0.2828 0.2238 198.6772 0.9356 0.2883 0.9693 0.9186 0.0569
3811.77 0.2552 0.1847 105.2594 0.7495 0.2266 0.9686 0.9154 0.0584
3811.93 0.2095 0.1375 3.4862 0.1581 0.1594 0.9682 0.9127 0.0588
3812.08 0.1982 0.1182 0.3179 0.0515 0.1341 0.9682 0.9107 0.0589
3812.23 0.2686 0.1583 7.1809 0.2115 0.1881 0.9682 0.9090 0.0593
3812.38 0.2844 0.1691 69.6481 0.6373 0.2035 0.9681 0.9067 0.0606
3812.54 0.2895 0.1892 104.7622 0.7389 0.2333 0.9679 0.9042 0.0621
3812.69 0.2870 0.2062 153.4978 0.8567 0.2598 0.9675 0.9015 0.0638
3812.84 0.2840 0.2295 152.2764 0.8089 0.2978 0.9669 0.8985 0.0654
3812.99 0.2803 0.2423 191.5631 0.8829 0.3197 0.9664 0.8952 0.0672
3813.15 0.2831 0.2520 662.1786 1.6095 0.3370 0.9657 0.8917 0.0704
3813.30 0.2800 0.2548 1227.3790 2.1794 0.3419 0.9632 0.8880 0.0748
3813.45 0.2822 0.2545 1230.0270 2.1829 0.3414 0.9587 0.8843 0.0792
3813.60 0.2813 0.2580 1199.2390 2.1410 0.3476 0.9542 0.8806 0.0835
3813.76 0.2878 0.2580 1220.3470 2.1597 0.3476 0.9497 0.8769 0.0878
3813.91 0.2933 0.2638 1337.8130 2.2359 0.3584 0.9453 0.8731 0.0923
3814.06 0.3036 0.2768 1742.5280 2.4915 0.3827 0.9403 0.8693 0.0973
3814.21 0.3055 0.2888 2176.0740 2.7256 0.4061 0.9339 0.8653 0.1028
3814.37 0.3046 0.2915 2378.3180 2.8361 0.4115 0.9259 0.8611 0.1085
3814.52 0.3006 0.2868 2194.1940 2.7464 0.4022 0.9171 0.8569 0.1140
3814.67 0.2976 0.2782 2076.4870 2.7130 0.3853 0.9090 0.8527 0.1195
3814.82 0.2968 0.2758 2125.5310 2.7564 0.3809 0.9013 0.8487 0.1250
3814.97 0.2969 0.2775 2413.3210 2.9284 0.3840 0.8935 0.8447 0.1309
3815.13 0.3011 0.2862 2693.0130 3.0460 0.4009 0.8846 0.8407 0.1370
3815.28 0.2987 0.2882 2891.6440 3.1453 0.4049 0.8747 0.8365 0.1433
3815.43 0.2946 0.2823 2731.2100 3.0888 0.3933 0.8640 0.8323 0.1495
3815.58 0.2882 0.2782 2454.7810 2.9495 0.3854 0.8539 0.8282 0.1554
3815.74 0.2853 0.2757 2385.5510 2.9209 0.3806 0.8449 0.8242 0.1613
3815.89 0.2799 0.2714 2158.5450 2.8003 0.3725 0.8361 0.8202 0.1669
3816.04 0.2745 0.2660 1967.6070 2.7005 0.3624 0.8281 0.8162 0.1724
3816.19 0.2709 0.2629 1910.6780 2.6767 0.3567 0.8209 0.8124 0.1777
3816.35 0.2716 0.2648 1980.1390 2.7152 0.3602 0.8138 0.8086 0.1832
3816.50 0.2696 0.2600 1776.2930 2.5954 0.3513 0.8065 0.8047 0.1884
3816.65 0.2621 0.2480 1448.0570 2.3993 0.3298 0.8000 0.8009 0.1932
3816.80 0.2555 0.2396 1139.0140 2.1652 0.3150 0.7946 0.7973 0.1976
3816.96 0.2705 0.2510 1529.1600 2.4509 0.3351 0.7905 0.7939 0.2025
3817.11 0.2419 0.2252 780.8735 1.8491 0.2906 0.7848 0.7902 0.2062
3817.26 0.2282 0.2112 500.7128 1.5291 0.2677 0.7819 0.7870 0.2093
3817.41 0.2100 0.1927 304.9847 1.2493 0.2387 0.7801 0.7839 0.2118
3817.57 0.2518 0.2246 788.3799 1.8604 0.2896 0.7790 0.7811 0.2155
3817.72 0.2761 0.2417 1276.6490 2.2819 0.3188 0.7761 0.7778 0.2201
3817.87 0.2799 0.2455 1314.2240 2.2972 0.3255 0.7713 0.7743 0.2247
3818.02 0.2794 0.2506 1342.5460 2.2985 0.3343 0.7665 0.7708 0.2294
3818.18 0.2720 0.2495 1204.6500 2.1818 0.3325 0.7616 0.7671 0.2337
3818.33 0.2692 0.2479 1070.3800 2.0634 0.3296 0.7571 0.7635 0.2379
3818.48 0.2676 0.2490 1039.5230 2.0290 0.3315 0.7532 0.7599 0.2420
3818.63 0.2659 0.2483 986.8389 1.9794 0.3304 0.7493 0.7563 0.2459
3818.78 0.2700 0.2522 1009.0360 1.9862 0.3372 0.7457 0.7527 0.2499
3818.94 0.2708 0.2474 894.9664 1.8884 0.3288 0.7420 0.7491 0.2537
3819.09 0.2803 0.2548 1015.1960 1.9819 0.3420 0.7387 0.7455 0.2577
3819.24 0.2834 0.2589 1009.0220 1.9602 0.3494 0.7349 0.7418 0.2617
3819.39 0.2846 0.2625 1042.0320 1.9783 0.3560 0.7312 0.7380 0.2656
3819.55 0.2839 0.2614 980.8373 1.9233 0.3540 0.7274 0.7342 0.2695
Depth ΦT Φe K RQI Φz kh Φh nRQI
3819.70 0.2852 0.2609 980.9854 1.9253 0.3531 0.7238 0.7304 0.2734
3819.85 0.2867 0.2606 974.4288 1.9200 0.3525 0.7201 0.7266 0.2772
3820.00 0.2867 0.2535 868.6895 1.8381 0.3396 0.7165 0.7228 0.2809
3820.16 0.2711 0.2333 370.8766 1.2519 0.3043 0.7133 0.7191 0.2834
3820.31 0.2507 0.2075 179.1475 0.9226 0.2619 0.7120 0.7158 0.2853
3820.46 0.2404 0.1918 103.2955 0.7287 0.2374 0.7113 0.7128 0.2867
3820.61 0.2474 0.1902 123.3165 0.7995 0.2349 0.7109 0.7100 0.2883
3820.77 0.2680 0.1955 160.8833 0.9008 0.2430 0.7105 0.7072 0.2902
3820.92 0.2558 0.1748 27.0076 0.3903 0.2118 0.7099 0.7044 0.2909
3821.07 0.2592 0.1656 16.9847 0.3180 0.1984 0.7098 0.7018 0.2916
3821.22 0.2683 0.1753 49.3962 0.5271 0.2126 0.7097 0.6994 0.2926
3821.38 0.2944 0.2081 283.4290 1.1589 0.2628 0.7095 0.6969 0.2950
3821.53 0.3047 0.2412 1010.1690 2.0321 0.3179 0.7085 0.6939 0.2991
3821.68 0.3037 0.2591 875.3193 1.8252 0.3497 0.7047 0.6904 0.3027
3821.83 0.2946 0.2648 709.2515 1.6250 0.3602 0.7015 0.6866 0.3060
3821.99 0.2944 0.2679 697.1362 1.6018 0.3659 0.6989 0.6828 0.3092
3822.14 0.2965 0.2708 1074.7310 1.9781 0.3714 0.6963 0.6789 0.3132
3822.29 0.2978 0.2688 1192.1010 2.0911 0.3676 0.6924 0.6750 0.3174
3822.44 0.2940 0.2671 1046.1130 1.9651 0.3644 0.6880 0.6710 0.3213
3822.59 0.2872 0.2595 820.1694 1.7652 0.3505 0.6841 0.6672 0.3249
3822.75 0.2821 0.2561 672.4925 1.6089 0.3443 0.6811 0.6634 0.3281
3822.90 0.2769 0.2515 592.3880 1.5238 0.3361 0.6786 0.6597 0.3312
3823.05 0.2771 0.2536 609.5233 1.5393 0.3398 0.6764 0.6561 0.3343
3823.20 0.2735 0.2472 555.0873 1.4879 0.3284 0.6742 0.6524 0.3372
3823.36 0.2709 0.2434 610.2863 1.5722 0.3218 0.6721 0.6488 0.3404
3823.51 0.2707 0.2419 757.4346 1.7569 0.3192 0.6699 0.6453 0.3439
3823.66 0.2787 0.2528 1786.6530 2.6398 0.3383 0.6671 0.6417 0.3492
3823.81 0.2850 0.2588 1559.1710 2.4372 0.3492 0.6605 0.6381 0.3541
3823.97 0.2910 0.2578 826.7019 1.7782 0.3473 0.6548 0.6343 0.3577
3824.12 0.2946 0.2480 313.9615 1.1172 0.3298 0.6517 0.6306 0.3600
3824.27 0.2971 0.2335 280.4148 1.0882 0.3046 0.6506 0.6270 0.3621
3824.42 0.2842 0.1954 123.9100 0.7907 0.2429 0.6495 0.6236 0.3637
3824.58 0.2479 0.1396 1.8452 0.1142 0.1622 0.6491 0.6208 0.3640
3824.73 0.1954 0.0786 0.0112 0.0119 0.0853 0.6491 0.6187 0.3640
3824.88 0.1505 0.0459 0.0001 0.0017 0.0481 0.6491 0.6176 0.3640
3825.03 0.1877 0.0470 0.0011 0.0047 0.0493 0.6491 0.6169 0.3640
3825.19 0.2432 0.0703 0.0276 0.0197 0.0756 0.6491 0.6162 0.3640
3825.34 0.3022 0.1211 2.0224 0.1283 0.1378 0.6491 0.6152 0.3643
3825.49 0.3312 0.1913 60.0650 0.5564 0.2365 0.6491 0.6135 0.3654
3825.64 0.3287 0.2344 137.0719 0.7593 0.3062 0.6488 0.6107 0.3669
3825.80 0.3077 0.2460 131.0937 0.7248 0.3263 0.6483 0.6073 0.3684
3825.95 0.2919 0.2420 153.8520 0.7917 0.3192 0.6478 0.6037 0.3700
3826.10 0.2860 0.2416 191.2421 0.8834 0.3186 0.6473 0.6002 0.3718
3826.25 0.2848 0.2346 231.9326 0.9874 0.3064 0.6466 0.5967 0.3737
3826.41 0.2850 0.2230 200.0888 0.9405 0.2870 0.6457 0.5933 0.3756
3826.56 0.2884 0.2110 64.1597 0.5476 0.2674 0.6450 0.5900 0.3767
3826.71 0.3047 0.2188 95.9511 0.6576 0.2800 0.6447 0.5870 0.3781
3826.86 0.3154 0.2280 227.5326 0.9920 0.2953 0.6444 0.5838 0.3800
3827.01 0.3046 0.2243 95.8294 0.6491 0.2891 0.6435 0.5805 0.3813
3827.17 0.2854 0.2081 21.8110 0.3214 0.2628 0.6432 0.5773 0.3820
3827.32 0.2716 0.2001 22.5051 0.3330 0.2501 0.6431 0.5742 0.3827
3827.47 0.2835 0.2168 135.6101 0.7853 0.2768 0.6430 0.5713 0.3842
3827.62 0.2915 0.2380 229.8526 0.9759 0.3123 0.6425 0.5682 0.3862
3827.78 0.2974 0.2530 317.2051 1.1118 0.3387 0.6417 0.5647 0.3884
3827.93 0.2940 0.2620 335.8181 1.1242 0.3550 0.6405 0.5611 0.3907
3828.08 0.2924 0.2665 328.5863 1.1025 0.3634 0.6393 0.5573 0.3929
3828.23 0.2886 0.2638 356.4447 1.1542 0.3583 0.6381 0.5534 0.3952
3828.39 0.2879 0.2587 367.4780 1.1835 0.3490 0.6367 0.5496 0.3976
3828.54 0.2870 0.2559 368.4863 1.1916 0.3439 0.6354 0.5458 0.4000
3828.69 0.2817 0.2506 376.9652 1.2177 0.3345 0.6340 0.5421 0.4024
3828.84 0.2733 0.2356 393.4805 1.2833 0.3081 0.6326 0.5385 0.4050
3829.00 0.2496 0.2018 65.4434 0.5655 0.2528 0.6312 0.5350 0.4062
3829.15 0.2334 0.1790 16.6313 0.3026 0.2181 0.6310 0.5321 0.4068
3829.30 0.2355 0.1812 41.8270 0.4771 0.2213 0.6309 0.5295 0.4077
3829.45 0.2651 0.2171 254.4029 1.0750 0.2773 0.6307 0.5269 0.4099
3829.61 0.2885 0.2517 538.6392 1.4524 0.3364 0.6298 0.5238 0.4128
3829.76 0.2964 0.2655 683.7432 1.5934 0.3615 0.6278 0.5201 0.4160
3829.91 0.2884 0.2594 509.7018 1.3919 0.3502 0.6253 0.5162 0.4188
3830.06 0.2780 0.2511 548.9642 1.4682 0.3353 0.6234 0.5125 0.4218
3830.21 0.2688 0.2497 730.0985 1.6979 0.3328 0.6214 0.5088 0.4252
3830.37 0.2687 0.2506 995.6309 1.9791 0.3344 0.6187 0.5052 0.4291
3830.52 0.2724 0.2533 1058.1040 2.0295 0.3392 0.6150 0.5016 0.4332
3830.67 0.2783 0.2563 1138.0100 2.0923 0.3446 0.6111 0.4979 0.4374
3830.82 0.2837 0.2627 1347.5630 2.2489 0.3563 0.6069 0.4942 0.4419
3830.98 0.2894 0.2642 1484.6250 2.3540 0.3590 0.6020 0.4904 0.4467
3831.13 0.2933 0.2685 1692.4950 2.4928 0.3671 0.5965 0.4865 0.4517
3831.28 0.2900 0.2661 1660.9410 2.4808 0.3626 0.5902 0.4826 0.4567
3831.43 0.2812 0.2656 1572.1650 2.4156 0.3617 0.5841 0.4788 0.4615
3831.59 0.2726 0.2622 1442.0880 2.3285 0.3555 0.5783 0.4749 0.4662
APPENDIX H: DATA OF WELL 04 FOR FLOW UNIT CHARTS FOR RESERVOIR 7
114
Depth ΦT Φe K RQI Φz kh Φh nRQI
3831.74 0.2699 0.2594 1424.5160 2.3267 0.3503 0.5730 0.4711 0.4709
3831.89 0.2701 0.2568 1388.0930 2.3085 0.3455 0.5677 0.4673 0.4755
3832.04 0.2702 0.2518 1318.4220 2.2721 0.3365 0.5626 0.4636 0.4801
3832.20 0.2692 0.2487 1253.0620 2.2290 0.3310 0.5578 0.4600 0.4846
3832.35 0.2683 0.2471 1211.6630 2.1988 0.3282 0.5531 0.4564 0.4890
3832.50 0.2655 0.2497 1205.2230 2.1817 0.3327 0.5487 0.4528 0.4934
3832.65 0.2634 0.2452 1083.8520 2.0875 0.3249 0.5442 0.4492 0.4975
3832.81 0.2619 0.2432 1036.2820 2.0498 0.3213 0.5402 0.4456 0.5017
3832.96 0.2599 0.2349 833.2590 1.8701 0.3071 0.5364 0.4421 0.5054
3833.11 0.2559 0.2348 854.0964 1.8940 0.3068 0.5333 0.4386 0.5092
3833.26 0.2532 0.2322 739.2206 1.7716 0.3024 0.5302 0.4353 0.5128
3833.42 0.2579 0.2366 821.3022 1.8498 0.3100 0.5275 0.4319 0.5165
3833.57 0.2631 0.2419 899.5884 1.9149 0.3191 0.5244 0.4284 0.5203
3833.72 0.2661 0.2441 934.7195 1.9430 0.3230 0.5211 0.4249 0.5243
3833.87 0.2670 0.2493 955.5724 1.9440 0.3321 0.5177 0.4214 0.5282
3834.02 0.2666 0.2458 799.7538 1.7910 0.3260 0.5142 0.4178 0.5318
3834.18 0.2671 0.2496 802.2776 1.7801 0.3327 0.5112 0.4142 0.5353
3834.33 0.2674 0.2512 789.5543 1.7604 0.3355 0.5082 0.4106 0.5389
3834.48 0.2644 0.2560 755.5102 1.7058 0.3441 0.5053 0.4069 0.5423
3834.63 0.2577 0.2525 677.5007 1.6266 0.3377 0.5025 0.4032 0.5456
3834.79 0.2494 0.2434 549.0982 1.4913 0.3217 0.5001 0.3996 0.5486
3834.94 0.2417 0.2317 358.9581 1.2359 0.3016 0.4980 0.3960 0.5510
3835.09 0.2360 0.2217 148.2296 0.8120 0.2848 0.4967 0.3927 0.5527
3835.24 0.2400 0.2225 130.4282 0.7602 0.2863 0.4962 0.3895 0.5542
3835.40 0.2506 0.2318 163.3363 0.8336 0.3017 0.4957 0.3862 0.5559
3835.55 0.2599 0.2372 225.4118 0.9680 0.3110 0.4951 0.3829 0.5578
3835.70 0.2478 0.2181 165.6619 0.8654 0.2789 0.4943 0.3794 0.5596
3835.85 0.2376 0.1805 15.4745 0.2907 0.2203 0.4936 0.3763 0.5601
3836.01 0.2449 0.1661 3.3602 0.1412 0.1992 0.4936 0.3736 0.5604
3836.16 0.2770 0.1799 52.3920 0.5359 0.2194 0.4936 0.3712 0.5615
3836.31 0.2998 0.2235 220.9693 0.9874 0.2878 0.4934 0.3686 0.5635
3836.46 0.2984 0.2429 264.3647 1.0360 0.3208 0.4926 0.3654 0.5656
3836.62 0.2878 0.2466 239.3995 0.9784 0.3273 0.4916 0.3618 0.5675
3836.77 0.2833 0.2428 216.4947 0.9377 0.3206 0.4907 0.3583 0.5694
3836.92 0.2767 0.2300 178.1083 0.8737 0.2988 0.4899 0.3547 0.5712
3837.07 0.2738 0.2057 109.7908 0.7254 0.2590 0.4892 0.3514 0.5726
3837.23 0.2764 0.1789 48.4590 0.5168 0.2178 0.4888 0.3484 0.5737
3837.38 0.2938 0.1644 43.4861 0.5108 0.1967 0.4887 0.3458 0.5747
3837.53 0.3060 0.1622 58.7370 0.5975 0.1937 0.4885 0.3434 0.5759
3837.68 0.3105 0.1768 100.0773 0.7471 0.2147 0.4883 0.3411 0.5774
3837.83 0.3126 0.2022 228.6012 1.0559 0.2534 0.4879 0.3385 0.5795
3837.99 0.3182 0.2330 470.2708 1.4108 0.3037 0.4871 0.3356 0.5824
3838.14 0.3268 0.2618 871.2328 1.8115 0.3546 0.4853 0.3322 0.5860
3838.29 0.3337 0.2826 1523.5660 2.3057 0.3939 0.4821 0.3284 0.5906
3838.44 0.3271 0.2890 1823.7280 2.4945 0.4064 0.4765 0.3243 0.5956
3838.60 0.3124 0.2795 1998.6800 2.6552 0.3880 0.4698 0.3201 0.6010
3838.75 0.3018 0.2776 1874.8070 2.5805 0.3843 0.4624 0.3161 0.6062
3838.90 0.2930 0.2662 1517.1640 2.3707 0.3627 0.4555 0.3120 0.6109
3839.05 0.2907 0.2640 1443.3650 2.3217 0.3587 0.4499 0.3082 0.6156
3839.21 0.2926 0.2551 1320.7940 2.2596 0.3424 0.4446 0.3043 0.6201
3839.36 0.2929 0.2561 1431.1720 2.3471 0.3444 0.4397 0.3006 0.6248
3839.51 0.2987 0.2613 1671.7270 2.5118 0.3537 0.4345 0.2969 0.6299
3839.66 0.2910 0.2581 1738.6290 2.5773 0.3478 0.4283 0.2931 0.6351
3839.82 0.2834 0.2525 1289.9200 2.2443 0.3378 0.4219 0.2894 0.6396
3839.97 0.2791 0.2506 1382.1030 2.3320 0.3344 0.4171 0.2857 0.6443
3840.12 0.2784 0.2536 1572.5630 2.4724 0.3398 0.4120 0.2821 0.6492
3840.27 0.2731 0.2494 1453.8030 2.3976 0.3322 0.4062 0.2784 0.6540
3840.43 0.2572 0.2354 1061.1370 2.1083 0.3078 0.4009 0.2748 0.6583
3840.58 0.2505 0.2295 911.4554 1.9788 0.2979 0.3969 0.2714 0.6623
3840.73 0.2505 0.2309 944.7200 2.0083 0.3003 0.3936 0.2680 0.6663
3840.88 0.2502 0.2289 937.4958 2.0097 0.2968 0.3901 0.2647 0.6703
3841.04 0.2524 0.2314 1035.5110 2.1004 0.3011 0.3867 0.2614 0.6745
3841.19 0.2487 0.2302 976.9363 2.0455 0.2991 0.3828 0.2580 0.6787
3841.34 0.2512 0.2369 1196.7230 2.2318 0.3104 0.3792 0.2547 0.6831
3841.49 0.2491 0.2367 1103.9260 2.1446 0.3100 0.3748 0.2512 0.6875
3841.65 0.2458 0.2322 1005.2750 2.0661 0.3024 0.3707 0.2478 0.6916
3841.80 0.2508 0.2378 1198.8830 2.2297 0.3119 0.3670 0.2444 0.6961
3841.95 0.2536 0.2407 1235.4380 2.2494 0.3171 0.3626 0.2410 0.7006
3842.10 0.2641 0.2508 1577.5500 2.4902 0.3348 0.3581 0.2375 0.7056
3842.25 0.2671 0.2498 1590.2970 2.5054 0.3330 0.3522 0.2338 0.7106
3842.41 0.2716 0.2505 1669.8680 2.5639 0.3341 0.3464 0.2302 0.7158
3842.56 0.2730 0.2534 1801.5130 2.6474 0.3395 0.3402 0.2266 0.7211
3842.71 0.2755 0.2538 1796.0390 2.6413 0.3402 0.3336 0.2229 0.7264
3842.86 0.2830 0.2592 2103.3900 2.8286 0.3499 0.3270 0.2192 0.7321
3843.02 0.2863 0.2549 1920.9870 2.7259 0.3421 0.3192 0.2155 0.7376
3843.17 0.2815 0.2486 1666.5610 2.5709 0.3309 0.3121 0.2118 0.7427
3843.32 0.2750 0.2417 1460.2110 2.4406 0.3187 0.3060 0.2082 0.7476
3843.47 0.2781 0.2486 1639.4330 2.5498 0.3309 0.3006 0.2047 0.7528
3843.63 0.2887 0.2616 2188.5830 2.8721 0.3542 0.2946 0.2011 0.7585
Depth ΦT Φe K RQI Φz kh Φh nRQI
3843.78 0.2990 0.2695 2553.0710 3.0563 0.3689 0.2864 0.1972 0.7647
3843.93 0.2942 0.2676 2439.0270 2.9979 0.3653 0.2771 0.1933 0.7707
3844.08 0.2850 0.2602 1949.1340 2.7174 0.3518 0.2681 0.1895 0.7762
3844.24 0.2833 0.2626 2098.5070 2.8071 0.3561 0.2609 0.1857 0.7818
3844.39 0.2859 0.2640 2088.6530 2.7931 0.3586 0.2532 0.1819 0.7874
3844.54 0.2873 0.2645 2083.8410 2.7869 0.3597 0.2454 0.1780 0.7930
3844.69 0.2764 0.2567 1727.8250 2.5759 0.3454 0.2378 0.1742 0.7982
3844.85 0.2736 0.2513 1545.3250 2.4622 0.3357 0.2314 0.1705 0.8031
3845.00 0.2799 0.2564 1700.6210 2.5572 0.3448 0.2257 0.1668 0.8083
3845.15 0.2878 0.2637 1953.9900 2.7028 0.3582 0.2194 0.1631 0.8137
3845.30 0.2955 0.2755 2460.5000 2.9672 0.3803 0.2122 0.1593 0.8197
3845.45 0.2948 0.2757 2449.1680 2.9597 0.3806 0.2032 0.1553 0.8256
3845.61 0.2940 0.2683 2156.8420 2.8154 0.3667 0.1941 0.1513 0.8313
3845.76 0.2809 0.2516 1466.5930 2.3972 0.3363 0.1862 0.1474 0.8361
3845.91 0.2777 0.2515 1404.4470 2.3465 0.3360 0.1808 0.1438 0.8408
3846.06 0.2808 0.2564 1545.8700 2.4384 0.3447 0.1756 0.1401 0.8457
3846.22 0.2822 0.2603 1671.3980 2.5161 0.3519 0.1699 0.1364 0.8508
3846.37 0.2746 0.2510 1316.8690 2.2746 0.3350 0.1637 0.1326 0.8553
3846.52 0.2618 0.2452 1060.4300 2.0650 0.3248 0.1589 0.1290 0.8595
3846.67 0.2590 0.2422 969.9840 1.9872 0.3196 0.1550 0.1254 0.8635
3846.83 0.2580 0.2429 978.2171 1.9927 0.3208 0.1514 0.1219 0.8675
3846.98 0.2557 0.2377 819.8885 1.8442 0.3118 0.1478 0.1184 0.8712
3847.13 0.2574 0.2399 847.1472 1.8661 0.3155 0.1447 0.1149 0.8749
3847.28 0.2613 0.2417 898.7640 1.9147 0.3188 0.1416 0.1114 0.8788
3847.44 0.2764 0.2556 1167.2280 2.1220 0.3433 0.1383 0.1079 0.8830
3847.59 0.2877 0.2681 1482.9000 2.3351 0.3664 0.1340 0.1042 0.8877
3847.74 0.2979 0.2796 1818.3340 2.5322 0.3881 0.1285 0.1003 0.8928
3847.89 0.2971 0.2803 1733.2130 2.4691 0.3895 0.1219 0.0963 0.8978
3848.05 0.2939 0.2807 1686.3780 2.4338 0.3903 0.1154 0.0922 0.9027
3848.20 0.2979 0.2849 1790.5920 2.4893 0.3984 0.1092 0.0881 0.9077
3848.35 0.3036 0.2903 1858.4660 2.5123 0.4091 0.1026 0.0840 0.9127
3848.50 0.3131 0.2939 1976.5830 2.5751 0.4162 0.0958 0.0798 0.9179
3848.66 0.3088 0.2924 1764.8590 2.4395 0.4132 0.0885 0.0755 0.9228
3848.81 0.3080 0.2859 1547.5890 2.3101 0.4004 0.0820 0.0713 0.9274
3848.96 0.3022 0.2781 1223.2100 2.0826 0.3852 0.0763 0.0671 0.9316
3849.11 0.3023 0.2745 1088.6660 1.9774 0.3784 0.0718 0.0631 0.9356
3849.26 0.3013 0.2780 1079.2660 1.9563 0.3851 0.0677 0.0591 0.9395
3849.42 0.3040 0.2800 1081.3900 1.9512 0.3890 0.0638 0.0551 0.9434
3849.57 0.3081 0.2773 1039.6710 1.9225 0.3838 0.0598 0.0510 0.9473
3849.72 0.3120 0.2736 1004.9370 1.9032 0.3766 0.0560 0.0470 0.9511
3849.87 0.3112 0.2723 972.9786 1.8771 0.3741 0.0522 0.0430 0.9549
3850.03 0.3089 0.2713 977.2264 1.8847 0.3722 0.0487 0.0391 0.9587
3850.18 0.3085 0.2798 1135.5450 2.0003 0.3885 0.0451 0.0351 0.9627
3850.33 0.3102 0.2825 1275.7280 2.1102 0.3937 0.0409 0.0311 0.9669
3850.48 0.3065 0.2783 1399.1300 2.2266 0.3855 0.0362 0.0270 0.9714
3850.64 0.2983 0.2672 1660.0690 2.4749 0.3647 0.0310 0.0229 0.9764
3850.79 0.2927 0.2566 1765.7370 2.6047 0.3452 0.0249 0.0191 0.9816
3850.94 0.2871 0.2489 2589.4550 3.2028 0.3314 0.0184 0.0153 0.9881
3851.09 0.2655 0.2248 1804.7170 2.8131 0.2901 0.0088 0.0117 0.9937
3851.25 0.2249 0.1841 383.4342 1.4332 0.2256 0.0022 0.0085 0.9966
3851.40 0.1789 0.1410 180.1098 1.1224 0.1641 0.0007 0.0058 0.9988
3851.55 0.1472 0.1058 22.7358 0.4603 0.1183 0.0001 0.0037 0.9998
3851.70 0.1356 0.0879 0.6999 0.0886 0.0964 0.0000 0.0022 0.9999
3851.86 0.1265 0.0644 0.0608 0.0305 0.0688 0.0000 0.0009 1.0000
115
Depth ΦT Φe K RQI Φz kh Φh nRQI
3625.60 0.1903 0.0816 0.0216 0.0162 0.0889 1.0000 1.0000 0.0000
3625.75 0.2180 0.0983 0.0887 0.0298 0.1090 1.0000 0.9988 0.0001
3625.90 0.2332 0.1064 0.2249 0.0457 0.1191 1.0000 0.9974 0.0002
3626.05 0.2438 0.1120 0.5042 0.0666 0.1261 1.0000 0.9958 0.0003
3626.21 0.2550 0.1244 1.3385 0.1030 0.1421 1.0000 0.9942 0.0005
3626.36 0.2658 0.1439 3.8110 0.1616 0.1681 1.0000 0.9924 0.0009
3626.51 0.2692 0.1591 8.3877 0.2280 0.1893 1.0000 0.9903 0.0013
3626.66 0.2734 0.1685 17.8925 0.3236 0.2026 1.0000 0.9880 0.0020
3626.82 0.2814 0.1734 33.4981 0.4365 0.2097 0.9999 0.9855 0.0029
3626.97 0.2868 0.1786 66.1281 0.6042 0.2174 0.9998 0.9830 0.0041
3627.12 0.2865 0.1901 153.7163 0.8928 0.2348 0.9996 0.9804 0.0060
3627.27 0.2822 0.2100 419.5852 1.4036 0.2658 0.9991 0.9777 0.0089
3627.43 0.2808 0.2329 748.0430 1.7797 0.3035 0.9979 0.9746 0.0125
3627.58 0.2876 0.2504 912.1481 1.8951 0.3341 0.9956 0.9712 0.0164
3627.73 0.2998 0.2642 648.1052 1.5553 0.3590 0.9929 0.9676 0.0196
3627.88 0.3040 0.2681 464.8216 1.3075 0.3663 0.9909 0.9637 0.0223
3628.03 0.2949 0.2593 418.5417 1.2616 0.3500 0.9895 0.9598 0.0249
3628.19 0.2782 0.2473 316.7660 1.1237 0.3286 0.9882 0.9561 0.0272
3628.34 0.2665 0.2426 294.1485 1.0933 0.3204 0.9873 0.9524 0.0295
3628.49 0.2622 0.2453 375.0780 1.2278 0.3250 0.9864 0.9489 0.0320
3628.64 0.2578 0.2449 434.0341 1.3220 0.3243 0.9852 0.9453 0.0347
3628.80 0.2563 0.2459 495.3870 1.4093 0.3261 0.9839 0.9418 0.0376
3628.95 0.2591 0.2498 375.4925 1.2173 0.3330 0.9824 0.9382 0.0401
3629.10 0.2675 0.2561 386.0942 1.2192 0.3443 0.9813 0.9346 0.0426
3629.25 0.2709 0.2565 453.1191 1.3198 0.3450 0.9801 0.9308 0.0453
3629.41 0.2679 0.2524 424.1728 1.2873 0.3376 0.9788 0.9271 0.0480
3629.56 0.2662 0.2534 419.4022 1.2773 0.3395 0.9775 0.9234 0.0506
3629.71 0.2684 0.2605 511.3362 1.3911 0.3523 0.9762 0.9198 0.0535
3629.86 0.2804 0.2763 792.2367 1.6815 0.3817 0.9747 0.9160 0.0569
3630.02 0.2975 0.2918 1182.4280 1.9987 0.4121 0.9723 0.9119 0.0611
3630.17 0.3061 0.2957 1335.8360 2.1107 0.4197 0.9687 0.9077 0.0654
3630.32 0.2932 0.2775 896.0117 1.7842 0.3841 0.9646 0.9034 0.0691
3630.47 0.2662 0.2487 482.0715 1.3824 0.3310 0.9619 0.8994 0.0719
3630.63 0.2516 0.2347 310.6972 1.1426 0.3066 0.9605 0.8957 0.0743
3630.78 0.2561 0.2393 308.8167 1.1279 0.3146 0.9595 0.8923 0.0766
3630.93 0.2679 0.2518 318.4794 1.1166 0.3366 0.9586 0.8888 0.0789
3631.08 0.2720 0.2590 318.6284 1.1014 0.3495 0.9576 0.8852 0.0811
3631.24 0.2687 0.2589 265.2863 1.0052 0.3493 0.9567 0.8814 0.0832
3631.39 0.2672 0.2587 258.6854 0.9930 0.3490 0.9559 0.8776 0.0853
3631.54 0.2704 0.2621 342.0971 1.1345 0.3552 0.9551 0.8739 0.0876
3631.69 0.2806 0.2701 516.8422 1.3735 0.3701 0.9541 0.8701 0.0904
3631.84 0.2914 0.2769 750.6933 1.6349 0.3830 0.9525 0.8661 0.0938
3632.00 0.2938 0.2785 878.0602 1.7630 0.3861 0.9502 0.8621 0.0974
3632.15 0.2907 0.2772 790.6038 1.6769 0.3835 0.9476 0.8580 0.1009
3632.30 0.2904 0.2766 748.9970 1.6340 0.3824 0.9452 0.8540 0.1042
3632.45 0.2888 0.2735 569.4892 1.4329 0.3764 0.9429 0.8500 0.1072
3632.61 0.2845 0.2711 424.7618 1.2429 0.3719 0.9412 0.8460 0.1097
3632.76 0.2792 0.2685 363.8980 1.1560 0.3670 0.9399 0.8421 0.1121
3632.91 0.2782 0.2692 395.4553 1.2035 0.3683 0.9388 0.8382 0.1146
3633.06 0.2768 0.2693 397.5630 1.2066 0.3685 0.9376 0.8343 0.1171
3633.22 0.2759 0.2677 297.7110 1.0472 0.3655 0.9364 0.8303 0.1192
3633.37 0.2760 0.2655 137.9699 0.7158 0.3614 0.9355 0.8264 0.1207
3633.52 0.2747 0.2593 52.7214 0.4477 0.3501 0.9351 0.8226 0.1216
3633.67 0.2716 0.2494 21.0743 0.2886 0.3323 0.9349 0.8188 0.1222
3633.83 0.2478 0.2156 2.7075 0.1113 0.2748 0.9349 0.8152 0.1224
3633.98 0.1996 0.1555 0.1868 0.0344 0.1842 0.9349 0.8120 0.1225
3634.13 0.1543 0.0985 0.0042 0.0065 0.1092 0.9349 0.8098 0.1225
3634.28 0.1332 0.0663 0.0000 0.0005 0.0710 0.9349 0.8083 0.1225
3634.44 0.1322 0.0565 0.0000 0.0000 0.0599 0.9349 0.8074 0.1225
3634.59 0.1316 0.0560 0.0000 0.0004 0.0593 0.9349 0.8065 0.1225
3634.74 0.1407 0.0650 0.0009 0.0036 0.0695 0.9349 0.8057 0.1225
3634.89 0.1670 0.0878 0.0435 0.0221 0.0963 0.9349 0.8048 0.1226
3635.05 0.2155 0.1315 1.1785 0.0940 0.1514 0.9349 0.8035 0.1228
3635.20 0.2613 0.1810 4.9814 0.1647 0.2210 0.9349 0.8016 0.1231
3635.35 0.2816 0.2085 11.4011 0.2322 0.2634 0.9348 0.7990 0.1236
3635.50 0.2748 0.2038 12.0689 0.2416 0.2560 0.9348 0.7959 0.1241
3635.65 0.2653 0.1884 9.9678 0.2284 0.2321 0.9348 0.7930 0.1245
3635.81 0.2756 0.1934 24.4069 0.3528 0.2397 0.9347 0.7902 0.1253
3635.96 0.3020 0.2325 107.4931 0.6752 0.3029 0.9347 0.7874 0.1267
3636.11 0.3198 0.2763 405.2020 1.2024 0.3818 0.9343 0.7840 0.1291
3636.26 0.3232 0.3025 1384.8550 2.1247 0.4336 0.9331 0.7800 0.1335
3636.42 0.3212 0.3140 1182.8890 1.9271 0.4578 0.9289 0.7756 0.1375
3636.57 0.3155 0.3143 601.8949 1.3740 0.4584 0.9254 0.7710 0.1403
3636.72 0.3022 0.3009 327.1389 1.0353 0.4304 0.9235 0.7665 0.1424
3636.87 0.2891 0.2846 65.8812 0.4777 0.3979 0.9226 0.7621 0.1434
3637.03 0.2791 0.2674 32.8143 0.3478 0.3650 0.9224 0.7579 0.1441
3637.18 0.2626 0.2277 16.8171 0.2698 0.2949 0.9223 0.7540 0.1447
3637.33 0.2481 0.1834 8.6341 0.2154 0.2246 0.9222 0.7507 0.1451
3637.48 0.2604 0.1675 10.2811 0.2460 0.2012 0.9222 0.7481 0.1456
Depth ΦT Φe K RQI Φz kh Φh nRQI
3637.64 0.2982 0.1852 31.8257 0.4116 0.2273 0.9221 0.7456 0.1465
3637.79 0.3339 0.2154 104.8019 0.6926 0.2745 0.9220 0.7429 0.1479
3637.94 0.3588 0.2382 247.9943 1.0131 0.3127 0.9217 0.7398 0.1500
3638.09 0.3724 0.2533 442.4728 1.3125 0.3392 0.9210 0.7363 0.1527
3638.25 0.3770 0.2645 773.8450 1.6985 0.3595 0.9196 0.7326 0.1562
3638.40 0.3791 0.2745 1231.8040 2.1034 0.3784 0.9173 0.7288 0.1605
3638.55 0.3793 0.2889 2024.0820 2.6281 0.4064 0.9136 0.7248 0.1659
3638.70 0.3833 0.3148 3556.7690 3.3378 0.4594 0.9075 0.7206 0.1728
3638.86 0.3850 0.3377 4514.5580 3.6304 0.5099 0.8967 0.7160 0.1802
3639.01 0.3757 0.3385 4868.7620 3.7661 0.5116 0.8830 0.7111 0.1880
3639.16 0.3444 0.3159 3990.2460 3.5293 0.4617 0.8683 0.7062 0.1952
3639.31 0.3021 0.2808 4267.3130 3.8709 0.3904 0.8562 0.7016 0.2032
3639.46 0.2671 0.2498 3877.4050 3.9124 0.3329 0.8434 0.6975 0.2113
3639.62 0.2457 0.2301 4742.0800 4.5076 0.2989 0.8317 0.6939 0.2205
3639.77 0.2238 0.2127 2098.0380 3.1187 0.2701 0.8173 0.6905 0.2269
3639.92 0.2055 0.1985 753.6376 1.9348 0.2477 0.8109 0.6874 0.2309
3640.07 0.1972 0.1912 276.5573 1.1941 0.2365 0.8087 0.6845 0.2334
3640.23 0.2042 0.1978 228.6797 1.0676 0.2466 0.8078 0.6818 0.2356
3640.38 0.2111 0.2054 282.1344 1.1637 0.2585 0.8071 0.6789 0.2380
3640.53 0.2088 0.2036 257.6704 1.1170 0.2557 0.8063 0.6759 0.2403
3640.68 0.1998 0.1929 144.4886 0.8595 0.2389 0.8055 0.6729 0.2420
3640.84 0.1958 0.1826 96.3871 0.7213 0.2235 0.8051 0.6701 0.2435
3640.99 0.1992 0.1780 134.8182 0.8642 0.2165 0.8048 0.6675 0.2453
3641.14 0.2021 0.1753 241.9444 1.1665 0.2126 0.8044 0.6649 0.2477
3641.29 0.2017 0.1769 213.8360 1.0916 0.2150 0.8036 0.6623 0.2499
3641.45 0.2053 0.1872 206.8059 1.0437 0.2303 0.8030 0.6597 0.2521
3641.60 0.2210 0.2072 359.8281 1.3086 0.2613 0.8024 0.6570 0.2548
3641.75 0.2431 0.2280 686.1738 1.7228 0.2953 0.8013 0.6540 0.2583
3641.90 0.2597 0.2420 1021.0300 2.0394 0.3193 0.7992 0.6507 0.2625
3642.06 0.2702 0.2519 1562.4800 2.4729 0.3367 0.7961 0.6472 0.2676
3642.21 0.2781 0.2621 1720.0670 2.5435 0.3553 0.7914 0.6435 0.2728
3642.36 0.2912 0.2788 2219.4230 2.8016 0.3866 0.7862 0.6397 0.2786
3642.51 0.2986 0.2902 1401.4240 2.1820 0.4089 0.7795 0.6356 0.2831
3642.67 0.2998 0.2936 9349.0540 5.6035 0.4156 0.7753 0.6314 0.2946
3642.82 0.2985 0.2922 2942.1400 3.1507 0.4129 0.7469 0.6271 0.3011
3642.97 0.2948 0.2886 1998.3930 2.6129 0.4057 0.7380 0.6229 0.3065
3643.12 0.2882 0.2820 677.8126 1.5394 0.3927 0.7320 0.6187 0.3096
3643.27 0.2842 0.2767 1548.6190 2.3491 0.3825 0.7299 0.6146 0.3145
3643.43 0.2761 0.2696 1727.4300 2.5134 0.3691 0.7252 0.6106 0.3196
3643.58 0.2658 0.2620 1072.1970 2.0088 0.3550 0.7200 0.6066 0.3238
3643.73 0.2513 0.2470 1157.2410 2.1494 0.3280 0.7168 0.6028 0.3282
3643.88 0.2452 0.2361 821.5010 1.8520 0.3092 0.7133 0.5992 0.3320
3644.04 0.2522 0.2359 707.7954 1.7200 0.3087 0.7108 0.5958 0.3355
3644.19 0.2676 0.2458 457.2164 1.3543 0.3259 0.7086 0.5924 0.3383
3644.34 0.2796 0.2547 800.5283 1.7603 0.3418 0.7073 0.5888 0.3420
3644.49 0.2839 0.2601 1343.2280 2.2564 0.3516 0.7048 0.5851 0.3466
3644.65 0.2862 0.2647 1341.3230 2.2351 0.3600 0.7008 0.5813 0.3512
3644.80 0.2889 0.2682 847.4023 1.7651 0.3665 0.6967 0.5774 0.3548
3644.95 0.2921 0.2743 1518.9090 2.3367 0.3779 0.6942 0.5735 0.3596
3645.10 0.2884 0.2771 1934.9190 2.6238 0.3833 0.6896 0.5695 0.3650
3645.26 0.2849 0.2790 2498.8820 2.9715 0.3870 0.6837 0.5655 0.3711
3645.41 0.2836 0.2806 1371.5400 2.1952 0.3901 0.6761 0.5614 0.3757
3645.56 0.2821 0.2794 1571.1360 2.3548 0.3877 0.6720 0.5574 0.3805
3645.71 0.2749 0.2731 1258.7200 2.1317 0.3757 0.6673 0.5533 0.3849
3645.87 0.2642 0.2631 943.2285 1.8802 0.3570 0.6634 0.5493 0.3888
3646.02 0.2575 0.2565 1079.4090 2.0371 0.3449 0.6606 0.5455 0.3929
3646.17 0.2542 0.2534 757.6119 1.7169 0.3394 0.6573 0.5418 0.3965
3646.32 0.2469 0.2453 553.9868 1.4921 0.3251 0.6550 0.5381 0.3995
3646.48 0.2358 0.2320 430.3521 1.3524 0.3021 0.6533 0.5345 0.4023
3646.63 0.2255 0.2216 389.3759 1.3163 0.2846 0.6520 0.5311 0.4050
3646.78 0.2226 0.2196 520.0101 1.5280 0.2814 0.6509 0.5279 0.4082
3646.93 0.2248 0.2222 542.9550 1.5521 0.2857 0.6493 0.5247 0.4114
3647.08 0.2349 0.2320 522.3511 1.4900 0.3020 0.6477 0.5215 0.4144
3647.24 0.2496 0.2450 841.0093 1.8399 0.3244 0.6461 0.5181 0.4182
3647.39 0.2676 0.2569 1274.1200 2.2113 0.3457 0.6435 0.5145 0.4228
3647.54 0.2782 0.2575 1773.9190 2.6060 0.3469 0.6397 0.5108 0.4281
3647.69 0.2792 0.2514 2566.7420 3.1729 0.3358 0.6343 0.5070 0.4347
3647.85 0.2721 0.2430 2192.1850 2.9825 0.3210 0.6266 0.5034 0.4408
3648.00 0.2722 0.2431 1225.1000 2.2291 0.3212 0.6199 0.4999 0.4454
3648.15 0.2808 0.2508 1442.3700 2.3813 0.3348 0.6162 0.4963 0.4503
3648.30 0.2861 0.2596 2392.5460 3.0146 0.3506 0.6119 0.4927 0.4565
3648.46 0.2852 0.2661 3044.0740 3.3581 0.3627 0.6046 0.4889 0.4634
3648.61 0.2862 0.2738 4322.3990 3.9451 0.3771 0.5954 0.4850 0.4715
3648.76 0.2886 0.2784 3254.1290 3.3947 0.3858 0.5824 0.4811 0.4785
3648.91 0.2787 0.2670 2478.9880 3.0256 0.3642 0.5725 0.4770 0.4847
3649.07 0.2578 0.2450 1583.7680 2.5247 0.3245 0.5650 0.4731 0.4899
3649.22 0.2391 0.2273 870.7072 1.9435 0.2941 0.5602 0.4695 0.4939
3649.37 0.2339 0.2236 684.4438 1.7373 0.2880 0.5576 0.4662 0.4975
3649.52 0.2349 0.2261 1216.3230 2.3029 0.2922 0.5555 0.4630 0.5022
APPENDIX I: DATA OF WELL 02 FOR FLOW UNIT CHARTS FOR RESERVOIR 6
116
Depth ΦT Φe K RQI Φz kh Φh nRQI
3649.68 0.2378 0.2305 1280.8540 2.3408 0.2995 0.5519 0.4597 0.5070
3649.83 0.2444 0.2383 1091.5690 2.1251 0.3129 0.5480 0.4563 0.5114
3649.98 0.2579 0.2502 1168.5220 2.1460 0.3336 0.5447 0.4529 0.5158
3650.13 0.2722 0.2614 1068.6880 2.0077 0.3539 0.5412 0.4492 0.5199
3650.29 0.2798 0.2691 3119.6970 3.3811 0.3681 0.5379 0.4454 0.5269
3650.44 0.2732 0.2635 2724.8420 3.1930 0.3578 0.5285 0.4415 0.5335
3650.59 0.2616 0.2512 1790.4810 2.6508 0.3355 0.5202 0.4377 0.5389
3650.74 0.2530 0.2417 861.2364 1.8744 0.3187 0.5148 0.4340 0.5428
3650.89 0.2465 0.2377 686.7520 1.6876 0.3119 0.5122 0.4305 0.5462
3651.05 0.2409 0.2353 558.2523 1.5294 0.3077 0.5101 0.4271 0.5494
3651.20 0.2368 0.2277 483.5349 1.4469 0.2949 0.5084 0.4236 0.5524
3651.35 0.2405 0.2172 419.8590 1.3807 0.2774 0.5070 0.4203 0.5552
3651.50 0.2521 0.2076 292.0313 1.1776 0.2621 0.5057 0.4171 0.5576
3651.66 0.2648 0.2081 136.0903 0.8030 0.2627 0.5048 0.4141 0.5593
3651.81 0.2714 0.2177 92.8325 0.6484 0.2783 0.5044 0.4111 0.5606
3651.96 0.2777 0.2341 108.7005 0.6767 0.3056 0.5041 0.4079 0.5620
3652.11 0.2961 0.2570 238.2048 0.9560 0.3459 0.5038 0.4045 0.5640
3652.27 0.3245 0.2847 882.1608 1.7480 0.3979 0.5031 0.4008 0.5676
3652.42 0.3481 0.3114 1633.7940 2.2744 0.4522 0.5004 0.3966 0.5722
3652.57 0.3536 0.3250 2433.7340 2.7171 0.4815 0.4955 0.3921 0.5778
3652.72 0.3424 0.3191 3942.1180 3.4899 0.4687 0.4881 0.3874 0.5850
3652.88 0.3225 0.3024 3754.0940 3.4988 0.4334 0.4762 0.3827 0.5922
3653.03 0.3036 0.2872 1176.5230 2.0097 0.4029 0.4649 0.3784 0.5963
3653.18 0.2913 0.2784 2383.7090 2.9054 0.3858 0.4613 0.3742 0.6023
3653.33 0.2801 0.2685 1786.1080 2.5612 0.3670 0.4541 0.3701 0.6076
3653.49 0.2668 0.2541 815.2263 1.7784 0.3407 0.4487 0.3662 0.6112
3653.64 0.2583 0.2442 429.5084 1.3169 0.3231 0.4463 0.3625 0.6140
3653.79 0.2619 0.2442 979.2325 1.9883 0.3231 0.4450 0.3589 0.6180
3653.94 0.2764 0.2550 1933.6610 2.7342 0.3423 0.4420 0.3554 0.6237
3654.10 0.2891 0.2669 3841.4250 3.7667 0.3642 0.4362 0.3517 0.6314
3654.25 0.2931 0.2720 6370.7370 4.8055 0.3736 0.4245 0.3478 0.6413
3654.40 0.2869 0.2680 4866.7320 4.2315 0.3661 0.4053 0.3439 0.6500
3654.55 0.2755 0.2587 3012.5940 3.3885 0.3490 0.3905 0.3399 0.6570
3654.70 0.2701 0.2543 2268.2480 2.9654 0.3410 0.3814 0.3362 0.6631
3654.86 0.2699 0.2553 2173.3410 2.8973 0.3428 0.3746 0.3325 0.6690
3655.01 0.2721 0.2595 2432.6670 3.0400 0.3505 0.3680 0.3288 0.6753
3655.16 0.2707 0.2594 2902.4410 3.3216 0.3502 0.3607 0.3250 0.6821
3655.31 0.2687 0.2552 2491.7100 3.1028 0.3426 0.3519 0.3212 0.6885
3655.47 0.2630 0.2474 1569.0980 2.5008 0.3287 0.3443 0.3175 0.6937
3655.62 0.2597 0.2449 1365.4510 2.3448 0.3242 0.3396 0.3139 0.6985
3655.77 0.2657 0.2517 1548.7110 2.4632 0.3363 0.3355 0.3103 0.7035
3655.92 0.2783 0.2626 2308.7140 2.9442 0.3561 0.3308 0.3067 0.7096
3656.08 0.2842 0.2662 2574.6870 3.0878 0.3629 0.3238 0.3029 0.7160
3656.23 0.2823 0.2652 2249.5940 2.8918 0.3610 0.3160 0.2990 0.7219
3656.38 0.2802 0.2664 2579.9300 3.0898 0.3632 0.3092 0.2951 0.7283
3656.53 0.2887 0.2775 3277.4330 3.4127 0.3840 0.3014 0.2912 0.7353
3656.69 0.3028 0.2932 4144.9210 3.7336 0.4148 0.2915 0.2872 0.7430
3656.84 0.3158 0.3070 5754.0610 4.2991 0.4429 0.2789 0.2829 0.7518
3656.99 0.3218 0.3132 7100.9080 4.7281 0.4560 0.2616 0.2785 0.7615
3657.14 0.3221 0.3122 6296.6920 4.4597 0.4538 0.2402 0.2739 0.7707
3657.30 0.3192 0.3091 5286.8210 4.1063 0.4475 0.2211 0.2694 0.7791
3657.45 0.3141 0.3053 4446.1600 3.7896 0.4394 0.2051 0.2649 0.7869
3657.60 0.3095 0.3015 4420.6910 3.8019 0.4317 0.1916 0.2604 0.7948
3657.75 0.3064 0.3002 4801.8830 3.9716 0.4289 0.1783 0.2561 0.8029
3657.91 0.3092 0.3036 5142.4490 4.0869 0.4359 0.1638 0.2517 0.8113
3658.06 0.3098 0.3051 4606.3660 3.8583 0.4390 0.1482 0.2473 0.8193
3658.21 0.3074 0.3034 4328.2040 3.7506 0.4355 0.1343 0.2428 0.8270
3658.36 0.3013 0.2981 4692.7340 3.9397 0.4247 0.1212 0.2384 0.8351
3658.51 0.3004 0.2956 4556.6750 3.8988 0.4196 0.1070 0.2341 0.8431
3658.67 0.3004 0.2925 3505.6510 3.4374 0.4135 0.0933 0.2298 0.8502
3658.82 0.2961 0.2884 2941.6470 3.1714 0.4052 0.0826 0.2255 0.8567
3658.97 0.2849 0.2803 2356.0110 2.8789 0.3894 0.0738 0.2213 0.8626
3659.12 0.2717 0.2694 1930.4830 2.6582 0.3687 0.0666 0.2172 0.8681
3659.28 0.2618 0.2602 1334.8170 2.2490 0.3517 0.0608 0.2133 0.8727
3659.43 0.2567 0.2554 1106.0520 2.0663 0.3430 0.0568 0.2096 0.8770
3659.58 0.2521 0.2506 1018.6290 2.0019 0.3344 0.0534 0.2058 0.8811
3659.73 0.2516 0.2495 949.0610 1.9366 0.3324 0.0503 0.2022 0.8851
3659.89 0.2528 0.2497 1068.0470 2.0538 0.3327 0.0474 0.1985 0.8893
3660.04 0.2509 0.2465 1139.2390 2.1346 0.3272 0.0442 0.1949 0.8937
3660.19 0.2452 0.2410 822.3549 1.8344 0.3174 0.0408 0.1913 0.8975
3660.34 0.2424 0.2386 762.6118 1.7753 0.3133 0.0383 0.1878 0.9011
3660.50 0.2415 0.2372 758.4016 1.7756 0.3109 0.0360 0.1844 0.9048
3660.65 0.2364 0.2313 593.6260 1.5907 0.3009 0.0337 0.1809 0.9080
3660.80 0.2298 0.2276 514.2435 1.4927 0.2946 0.0319 0.1775 0.9111
3660.95 0.2229 0.2229 473.0695 1.4465 0.2869 0.0304 0.1742 0.9141
3661.11 0.2172 0.2150 339.0117 1.2469 0.2739 0.0289 0.1710 0.9167
3661.26 0.2123 0.2066 274.2213 1.1440 0.2604 0.0279 0.1679 0.9190
3661.41 0.2116 0.2049 271.1225 1.1423 0.2577 0.0271 0.1648 0.9214
3661.56 0.2173 0.2116 300.0183 1.1824 0.2684 0.0262 0.1619 0.9238
Depth ΦT Φe K RQI Φz kh Φh nRQI
3661.72 0.2247 0.2177 349.0954 1.2575 0.2782 0.0253 0.1588 0.9264
3661.87 0.2322 0.2206 406.8332 1.3484 0.2831 0.0243 0.1556 0.9292
3662.02 0.2390 0.2197 411.0126 1.3583 0.2815 0.0231 0.1524 0.9320
3662.17 0.2425 0.2135 329.5620 1.2336 0.2715 0.0218 0.1492 0.9345
3662.32 0.2395 0.2011 394.9744 1.3915 0.2518 0.0208 0.1461 0.9374
3662.48 0.2298 0.1873 326.9065 1.3117 0.2305 0.0196 0.1432 0.9400
3662.63 0.2228 0.1815 170.7525 0.9632 0.2217 0.0186 0.1405 0.9420
3662.78 0.2229 0.1838 91.3446 0.7000 0.2252 0.0181 0.1378 0.9435
3662.93 0.2287 0.1941 124.0874 0.7939 0.2408 0.0178 0.1352 0.9451
3663.09 0.2375 0.2102 417.3246 1.3991 0.2662 0.0175 0.1323 0.9480
3663.24 0.2497 0.2306 652.9528 1.6709 0.2997 0.0162 0.1293 0.9514
3663.39 0.2624 0.2483 640.8728 1.5952 0.3303 0.0142 0.1259 0.9547
3663.54 0.2682 0.2554 558.2917 1.4681 0.3430 0.0123 0.1223 0.9577
3663.70 0.2655 0.2518 313.0595 1.1072 0.3365 0.0106 0.1186 0.9600
3663.85 0.2616 0.2474 244.9768 0.9881 0.3287 0.0096 0.1149 0.9620
3664.00 0.2608 0.2476 285.1277 1.0655 0.3291 0.0089 0.1113 0.9642
3664.15 0.2619 0.2504 334.3707 1.1474 0.3340 0.0080 0.1077 0.9666
3664.31 0.2595 0.2490 253.8975 1.0026 0.3316 0.0070 0.1041 0.9686
3664.46 0.2556 0.2453 227.1844 0.9556 0.3250 0.0063 0.1004 0.9706
3664.61 0.2490 0.2400 160.9608 0.8132 0.3158 0.0056 0.0969 0.9723
3664.76 0.2405 0.2328 119.6143 0.7118 0.3034 0.0051 0.0934 0.9737
3664.92 0.2356 0.2280 124.6962 0.7343 0.2953 0.0047 0.0900 0.9753
3665.07 0.2360 0.2274 85.0228 0.6072 0.2943 0.0044 0.0867 0.9765
3665.22 0.2411 0.2312 72.9386 0.5577 0.3007 0.0041 0.0834 0.9777
3665.37 0.2441 0.2330 78.3667 0.5759 0.3037 0.0039 0.0800 0.9788
3665.53 0.2393 0.2265 72.2419 0.5607 0.2929 0.0036 0.0766 0.9800
3665.68 0.2381 0.2246 73.9652 0.5699 0.2896 0.0034 0.0733 0.9812
3665.83 0.2430 0.2291 88.5411 0.6173 0.2972 0.0032 0.0701 0.9824
3665.98 0.2467 0.2332 103.5891 0.6618 0.3041 0.0029 0.0667 0.9838
3666.14 0.2419 0.2318 80.0219 0.5834 0.3018 0.0026 0.0633 0.9850
3666.29 0.2308 0.2234 44.6294 0.4438 0.2876 0.0024 0.0599 0.9859
3666.44 0.2257 0.2199 34.7833 0.3949 0.2820 0.0022 0.0567 0.9867
3666.59 0.2245 0.2186 35.4245 0.3997 0.2797 0.0021 0.0535 0.9875
3666.74 0.2275 0.2191 41.2942 0.4310 0.2806 0.0020 0.0503 0.9884
3666.90 0.2324 0.2231 51.5411 0.4773 0.2871 0.0019 0.0471 0.9894
3667.05 0.2369 0.2279 59.7729 0.5085 0.2952 0.0017 0.0439 0.9905
3667.20 0.2413 0.2321 74.1530 0.5612 0.3023 0.0016 0.0406 0.9916
3667.35 0.2401 0.2299 100.6178 0.6568 0.2986 0.0013 0.0372 0.9930
3667.51 0.2340 0.2241 136.6899 0.7755 0.2888 0.0010 0.0338 0.9946
3667.66 0.2260 0.2176 78.5196 0.5964 0.2782 0.0006 0.0306 0.9958
3667.81 0.2205 0.2124 38.2878 0.4216 0.2696 0.0004 0.0274 0.9967
3667.96 0.2175 0.2084 22.9971 0.3298 0.2633 0.0003 0.0243 0.9973
3668.12 0.2175 0.2085 15.1920 0.2680 0.2635 0.0002 0.0213 0.9979
3668.27 0.2162 0.2084 13.4295 0.2520 0.2633 0.0002 0.0183 0.9984
3668.42 0.2172 0.2109 15.6877 0.2708 0.2672 0.0001 0.0152 0.9990
3668.57 0.2123 0.2044 17.7169 0.2924 0.2569 0.0001 0.0122 0.9996
3668.73 0.1887 0.1741 3.9818 0.1502 0.2108 0.0000 0.0092 0.9999
3668.88 0.1495 0.1244 0.2765 0.0468 0.1421 0.0000 0.0067 1.0000
3669.03 0.1242 0.0865 0.0112 0.0113 0.0947 0.0000 0.0048 1.0000
3669.18 0.1269 0.0704 0.0010 0.0038 0.0757 0.0000 0.0036 1.0000
3669.34 0.1320 0.0596 0.0002 0.0017 0.0633 0.0000 0.0026 1.0000
3669.49 0.1228 0.0471 0.0000 0.0000 0.0495 0.0000 0.0017 1.0000
3669.64 0.1110 0.0368 0.0000 0.0000 0.0382 0.0000 0.0010 1.0000
117
Depth ΦT Φe K RQI Φz kh Φh nRQI
3669.79 0.2737 0.1592 10.6295 0.2566 0.1893 1.0000 1.0000 0.0053
3669.94 0.3063 0.1871 26.7201 0.3752 0.2302 0.9997 0.9963 0.0096
3670.10 0.3345 0.2046 56.4539 0.5215 0.2573 0.9988 0.9920 0.0120
3670.25 0.2838 0.1692 14.1993 0.2877 0.2036 0.9971 0.9872 0.0147
3670.40 0.3230 0.1883 21.2367 0.3334 0.2321 0.9966 0.9833 0.0171
3670.55 0.2911 0.1705 14.4176 0.2888 0.2055 0.9960 0.9789 0.0184
3670.71 0.2182 0.1325 3.2374 0.1552 0.1528 0.9955 0.9749 0.0215
3670.86 0.2885 0.1874 26.1013 0.3706 0.2307 0.9954 0.9718 0.0268
3671.01 0.3224 0.2253 91.1340 0.6315 0.2908 0.9946 0.9674 0.0345
3671.16 0.3458 0.2533 220.7471 0.9269 0.3393 0.9918 0.9622 0.0405
3671.32 0.3270 0.2408 129.5220 0.7282 0.3172 0.9849 0.9563 0.0442
3671.47 0.3027 0.2155 41.8484 0.4376 0.2746 0.9808 0.9507 0.0460
3671.62 0.2720 0.1807 9.3937 0.2264 0.2206 0.9795 0.9457 0.0465
3671.77 0.1702 0.1049 0.2712 0.0505 0.1172 0.9792 0.9415 0.0510
3671.93 0.3245 0.1970 58.7855 0.5424 0.2454 0.9792 0.9390 0.0594
3672.08 0.3430 0.2220 234.0334 1.0195 0.2854 0.9774 0.9344 0.0703
3672.23 0.3572 0.2576 444.1821 1.3038 0.3470 0.9701 0.9293 0.0811
3672.38 0.3352 0.2662 456.0792 1.2996 0.3629 0.9563 0.9233 0.0931
3672.54 0.3304 0.2807 601.9818 1.4541 0.3902 0.9421 0.9171 0.1073
3672.69 0.3219 0.2822 826.6056 1.6995 0.3931 0.9234 0.9106 0.1232
3672.84 0.3127 0.2796 1036.4830 1.9120 0.3880 0.8975 0.9040 0.1379
3672.99 0.2944 0.2679 853.5988 1.7725 0.3659 0.8653 0.8975 0.1542
3673.15 0.3018 0.2791 1088.6820 1.9611 0.3872 0.8388 0.8913 0.1711
3673.30 0.3023 0.2834 1190.7680 2.0355 0.3954 0.8047 0.8847 0.1883
3673.45 0.3011 0.2854 1242.8600 2.0720 0.3994 0.7677 0.8782 0.2055
3673.60 0.2967 0.2860 1245.8150 2.0723 0.4006 0.7289 0.8715 0.2184
3673.75 0.2625 0.2550 617.4528 1.5450 0.3424 0.6902 0.8649 0.2309
3673.91 0.2588 0.2524 583.3832 1.5095 0.3377 0.6710 0.8589 0.2425
3674.06 0.2505 0.2441 479.6315 1.3919 0.3229 0.6527 0.8530 0.2567
3674.21 0.2715 0.2638 779.2977 1.7067 0.3583 0.6378 0.8474 0.2705
3674.36 0.2613 0.2527 706.1277 1.6600 0.3381 0.6135 0.8412 0.2813
3674.52 0.2382 0.2286 395.7489 1.3065 0.2964 0.5915 0.8353 0.2909
3674.67 0.2466 0.2326 312.5840 1.1510 0.3032 0.5792 0.8300 0.2990
3674.82 0.2561 0.2359 230.0650 0.9806 0.3087 0.5694 0.8246 0.3083
3674.97 0.2916 0.2635 334.1092 1.1180 0.3578 0.5623 0.8191 0.3160
3675.13 0.2812 0.2531 219.8390 0.9254 0.3389 0.5518 0.8130 0.3224
3675.28 0.2793 0.2463 149.6233 0.7739 0.3268 0.5450 0.8071 0.3276
3675.43 0.3253 0.2541 100.0338 0.6230 0.3407 0.5404 0.8014 0.3284
3675.58 0.2381 0.1470 1.5057 0.1005 0.1724 0.5372 0.7954 0.3285
3675.74 0.1522 0.0738 0.0041 0.0074 0.0797 0.5372 0.7920 0.3285
3675.89 0.0981 0.0425 0.0000 0.0000 0.0444 0.5372 0.7903 0.3285
3676.04 0.1262 0.0554 0.0001 0.0014 0.0586 0.5372 0.7893 0.3285
3676.19 0.1162 0.0509 0.0000 0.0003 0.0536 0.5372 0.7880 0.3285
3676.35 0.0989 0.0443 0.0000 0.0000 0.0463 0.5372 0.7868 0.3285
3676.50 0.1269 0.0596 0.0002 0.0018 0.0634 0.5372 0.7858 0.3286
3676.65 0.1264 0.0629 0.0003 0.0022 0.0672 0.5372 0.7844 0.3286
3676.80 0.1233 0.0641 0.0004 0.0025 0.0685 0.5372 0.7830 0.3287
3676.96 0.1511 0.0818 0.0136 0.0128 0.0891 0.5372 0.7815 0.3289
3677.11 0.1680 0.0942 0.0927 0.0311 0.1040 0.5372 0.7796 0.3297
3677.26 0.2108 0.1232 0.9405 0.0868 0.1405 0.5372 0.7774 0.3321
3677.41 0.3010 0.1833 15.8787 0.2923 0.2244 0.5372 0.7745 0.3337
3677.56 0.2519 0.1552 6.1695 0.1980 0.1837 0.5367 0.7702 0.3356
3677.72 0.2625 0.1626 8.2182 0.2233 0.1941 0.5365 0.7666 0.3372
3677.87 0.2387 0.1489 5.6624 0.1937 0.1749 0.5362 0.7628 0.3397
3678.02 0.2567 0.1679 14.9840 0.2966 0.2018 0.5360 0.7594 0.3432
3678.17 0.2679 0.1887 35.6021 0.4313 0.2326 0.5356 0.7555 0.3480
3678.33 0.2732 0.2097 68.3379 0.5669 0.2653 0.5345 0.7511 0.3533
3678.48 0.2742 0.2280 94.4843 0.6392 0.2953 0.5323 0.7462 0.3599
3678.63 0.2880 0.2548 163.9171 0.7964 0.3419 0.5294 0.7409 0.3674
3678.78 0.2962 0.2704 227.0260 0.9099 0.3705 0.5243 0.7350 0.3747
3678.94 0.2896 0.2653 202.6061 0.8677 0.3611 0.5172 0.7287 0.3817
3679.09 0.2867 0.2629 193.6605 0.8523 0.3566 0.5109 0.7225 0.3879
3679.24 0.2745 0.2532 139.3710 0.7366 0.3391 0.5049 0.7164 0.3934
3679.39 0.2729 0.2536 116.4299 0.6728 0.3398 0.5005 0.7105 0.3977
3679.55 0.2544 0.2352 62.8752 0.5134 0.3075 0.4969 0.7046 0.4019
3679.70 0.2608 0.2357 59.8947 0.5006 0.3083 0.4949 0.6991 0.4050
3679.85 0.2612 0.2195 31.3341 0.3752 0.2812 0.4931 0.6936 0.4066
3680.00 0.2481 0.1804 7.0780 0.1967 0.2202 0.4921 0.6885 0.4076
3680.16 0.2424 0.1427 1.8783 0.1139 0.1665 0.4919 0.6843 0.4080
3680.31 0.2021 0.1041 0.2830 0.0518 0.1161 0.4918 0.6810 0.4082
3680.46 0.1934 0.0897 0.0561 0.0248 0.0986 0.4918 0.6786 0.4088
3680.61 0.2523 0.1170 0.6779 0.0756 0.1325 0.4918 0.6765 0.4101
3680.77 0.2831 0.1372 3.0684 0.1485 0.1591 0.4918 0.6738 0.4123
3680.92 0.3019 0.1571 11.7990 0.2721 0.1864 0.4917 0.6706 0.4151
3681.07 0.3052 0.1661 19.2011 0.3376 0.1992 0.4913 0.6669 0.4166
3681.22 0.2657 0.1471 4.4573 0.1729 0.1725 0.4907 0.6630 0.4172
3681.38 0.2187 0.1202 0.6926 0.0754 0.1366 0.4906 0.6596 0.4209
3681.53 0.3372 0.1874 38.1374 0.4479 0.2306 0.4906 0.6568 0.4249
3681.68 0.2970 0.1710 40.5967 0.4838 0.2063 0.4894 0.6525 0.4304
Depth ΦT Φe K RQI Φz kh Φh nRQI
3681.83 0.3219 0.1990 87.9565 0.6602 0.2484 0.4881 0.6485 0.4371
3681.98 0.3269 0.2177 140.4509 0.7976 0.2783 0.4854 0.6439 0.4436
3682.14 0.3135 0.2253 143.2449 0.7918 0.2908 0.4810 0.6388 0.4492
3682.29 0.2825 0.2167 98.6903 0.6700 0.2767 0.4766 0.6336 0.4541
3682.44 0.2512 0.2036 72.2585 0.5916 0.2556 0.4735 0.6285 0.4579
3682.59 0.2162 0.1825 38.9832 0.4590 0.2232 0.4712 0.6238 0.4641
3682.75 0.2578 0.2214 121.9030 0.7367 0.2844 0.4700 0.6195 0.4720
3682.90 0.2897 0.2377 220.1035 0.9554 0.3119 0.4662 0.6144 0.4779
3683.05 0.2862 0.2128 108.1678 0.7079 0.2703 0.4594 0.6089 0.4801
3683.20 0.2415 0.1603 11.4597 0.2655 0.1909 0.4560 0.6039 0.4821
3683.36 0.2547 0.1554 9.4076 0.2443 0.1841 0.4556 0.6002 0.4857
3683.51 0.2849 0.1667 32.1229 0.4359 0.2000 0.4553 0.5965 0.4913
3683.66 0.2954 0.1777 80.0464 0.6664 0.2161 0.4543 0.5927 0.4983
3683.81 0.2990 0.1971 142.1387 0.8432 0.2455 0.4519 0.5885 0.5073
3683.97 0.3107 0.2299 275.6917 1.0872 0.2986 0.4474 0.5839 0.5153
3684.12 0.2859 0.2318 218.3305 0.9636 0.3018 0.4388 0.5786 0.5222
3684.27 0.2533 0.2165 149.0849 0.8239 0.2764 0.4320 0.5732 0.5297
3684.42 0.2342 0.2072 174.5670 0.9114 0.2614 0.4274 0.5682 0.5372
3684.58 0.2119 0.1928 156.7701 0.8955 0.2388 0.4220 0.5633 0.5417
3684.73 0.1693 0.1570 47.0919 0.5438 0.1862 0.4171 0.5588 0.5463
3684.88 0.1695 0.1591 50.3852 0.5588 0.1892 0.4156 0.5552 0.5498
3685.03 0.1501 0.1415 24.5322 0.4134 0.1648 0.4140 0.5515 0.5535
3685.18 0.1536 0.1434 28.9111 0.4458 0.1674 0.4133 0.5482 0.5610
3685.34 0.2017 0.1857 155.8836 0.9098 0.2280 0.4124 0.5449 0.5667
3685.49 0.1798 0.1648 78.6718 0.6861 0.1973 0.4075 0.5405 0.5740
3685.64 0.1953 0.1796 138.3421 0.8714 0.2189 0.4050 0.5367 0.5803
3685.79 0.1845 0.1696 100.6213 0.7648 0.2043 0.4007 0.5325 0.5871
3685.95 0.1874 0.1731 116.1458 0.8133 0.2094 0.3976 0.5286 0.5926
3686.10 0.1712 0.1603 71.6813 0.6639 0.1910 0.3940 0.5245 0.5967
3686.25 0.1502 0.1432 35.1071 0.4917 0.1671 0.3917 0.5208 0.6018
3686.40 0.1633 0.1563 60.2404 0.6164 0.1853 0.3906 0.5175 0.6073
3686.56 0.1675 0.1587 69.0460 0.6549 0.1887 0.3888 0.5138 0.6136
3686.71 0.1780 0.1666 97.0195 0.7576 0.2000 0.3866 0.5101 0.6216
3686.86 0.1962 0.1826 173.5577 0.9681 0.2234 0.3836 0.5063 0.6289
3687.01 0.1878 0.1750 137.3535 0.8797 0.2121 0.3782 0.5020 0.6335
3687.17 0.1550 0.1450 43.8253 0.5459 0.1696 0.3739 0.4979 0.6418
3687.32 0.1960 0.1833 186.9534 1.0028 0.2244 0.3725 0.4946 0.6505
3687.47 0.1999 0.1869 206.4147 1.0434 0.2299 0.3667 0.4903 0.6590
3687.62 0.1981 0.1853 197.1976 1.0243 0.2275 0.3603 0.4860 0.6712
3687.78 0.2285 0.2132 470.2043 1.4746 0.2710 0.3541 0.4816 0.6873
3687.93 0.2555 0.2376 899.1381 1.9318 0.3116 0.3395 0.4767 0.6918
3688.08 0.1549 0.1447 42.9258 0.5407 0.1692 0.3116 0.4712 0.6958
3688.23 0.1477 0.1394 33.9713 0.4901 0.1620 0.3103 0.4678 0.7020
3688.39 0.1724 0.1643 90.7835 0.7380 0.1966 0.3092 0.4646 0.7103
3688.54 0.1947 0.1863 191.4518 1.0065 0.2290 0.3064 0.4607 0.7249
3688.69 0.2414 0.2320 727.0987 1.7577 0.3022 0.3004 0.4564 0.7501
3688.84 0.2982 0.2889 2696.6350 3.0335 0.4063 0.2777 0.4510 0.7559
3688.99 0.1668 0.1618 78.2083 0.6904 0.1930 0.1939 0.4443 0.7688
3689.15 0.2291 0.2225 545.7479 1.5552 0.2861 0.1915 0.4405 0.7859
3689.30 0.2575 0.2499 1075.1700 2.0597 0.3331 0.1744 0.4353 0.7978
3689.45 0.2228 0.2178 451.2842 1.4294 0.2784 0.1410 0.4295 0.8138
3689.60 0.2516 0.2478 935.7182 1.9295 0.3295 0.1269 0.4244 0.8216
3689.76 0.1914 0.1892 169.6036 0.9401 0.2334 0.0978 0.4187 0.8327
3689.91 0.2207 0.2182 388.4979 1.3249 0.2791 0.0925 0.4143 0.8459
3690.06 0.2412 0.2376 616.1003 1.5989 0.3117 0.0804 0.4092 0.8508
3690.21 0.1662 0.1634 56.1704 0.5821 0.1953 0.0612 0.4037 0.8544
3690.37 0.1528 0.1495 29.1696 0.4386 0.1757 0.0595 0.3998 0.8582
3690.52 0.1580 0.1535 32.4106 0.4562 0.1814 0.0586 0.3964 0.8615
3690.67 0.1538 0.1478 24.0801 0.4008 0.1735 0.0576 0.3928 0.8663
3690.82 0.1838 0.1730 57.3053 0.5715 0.2092 0.0568 0.3894 0.8692
3690.98 0.1602 0.1459 17.6182 0.3450 0.1708 0.0550 0.3853 0.8710
3691.13 0.1444 0.1254 6.1472 0.2198 0.1434 0.0545 0.3819 0.8723
3691.28 0.1498 0.1220 3.2624 0.1623 0.1390 0.0543 0.3790 0.8755
3691.43 0.2357 0.1842 27.8182 0.3859 0.2257 0.0542 0.3762 0.8802
3691.59 0.2647 0.2081 66.4433 0.5611 0.2628 0.0533 0.3719 0.8869
3691.74 0.2887 0.2381 158.5005 0.8102 0.3125 0.0513 0.3671 0.8917
3691.89 0.2543 0.2184 74.0282 0.5782 0.2794 0.0463 0.3615 0.8942
3692.04 0.2077 0.1779 15.9072 0.2969 0.2164 0.0440 0.3564 0.8953
3692.20 0.1778 0.1420 2.6512 0.1357 0.1654 0.0435 0.3523 0.8959
3692.35 0.1440 0.1114 0.4796 0.0652 0.1254 0.0434 0.3490 0.8962
3692.50 0.1284 0.0953 0.1488 0.0392 0.1053 0.0434 0.3464 0.8966
3692.65 0.1447 0.1067 0.3165 0.0541 0.1194 0.0434 0.3442 0.8972
3692.80 0.1493 0.1106 0.4257 0.0616 0.1244 0.0434 0.3417 0.8977
3692.96 0.1484 0.1105 0.5186 0.0680 0.1242 0.0434 0.3391 0.8983
3693.11 0.1485 0.1121 0.6238 0.0741 0.1263 0.0434 0.3365 0.8990
3693.26 0.1499 0.1165 0.8416 0.0844 0.1319 0.0434 0.3339 0.8998
3693.41 0.1499 0.1211 1.1527 0.0969 0.1378 0.0433 0.3312 0.9007
3693.57 0.1472 0.1232 1.1867 0.0975 0.1405 0.0433 0.3284 0.9014
3693.72 0.1467 0.1265 1.1231 0.0936 0.1448 0.0433 0.3256 0.9022
APPENDIX J: DATA OF WELL 03 FOR FLOW UNIT CHARTS FOR RESERVOIR 6
118
Depth ΦT Φe K RQI Φz kh Φh nRQI
3693.87 0.1501 0.1318 1.1577 0.0931 0.1518 0.0432 0.3226 0.9028
3694.02 0.1485 0.1308 0.7621 0.0758 0.1505 0.0432 0.3195 0.9033
3694.18 0.1488 0.1263 0.3636 0.0533 0.1446 0.0432 0.3165 0.9035
3694.33 0.1424 0.1081 0.0509 0.0215 0.1212 0.0431 0.3135 0.9035
3694.48 0.1314 0.0817 0.0021 0.0050 0.0890 0.0431 0.3110 0.9035
3694.63 0.1318 0.0646 0.0007 0.0032 0.0691 0.0431 0.3091 0.9035
3694.79 0.0970 0.0406 0.0000 0.0000 0.0423 0.0431 0.3076 0.9035
3694.94 0.1356 0.0516 0.0000 0.0000 0.0544 0.0431 0.3067 0.9036
3695.09 0.2078 0.0724 0.0022 0.0055 0.0781 0.0431 0.3055 0.9036
3695.24 0.1428 0.0460 0.0000 0.0000 0.0482 0.0431 0.3038 0.9036
3695.40 0.1260 0.0398 0.0000 0.0000 0.0415 0.0431 0.3027 0.9036
3695.55 0.1396 0.0470 0.0000 0.0000 0.0493 0.0431 0.3018 0.9036
3695.70 0.1218 0.0426 0.0000 0.0000 0.0445 0.0431 0.3007 0.9036
3695.85 0.1319 0.0442 0.0000 0.0000 0.0463 0.0431 0.2997 0.9036
3696.01 0.1492 0.0456 0.0000 0.0000 0.0478 0.0431 0.2987 0.9036
3696.16 0.1076 0.0310 0.0000 0.0000 0.0320 0.0431 0.2976 0.9036
3696.31 0.1128 0.0338 0.0000 0.0000 0.0350 0.0431 0.2969 0.9036
3696.46 0.1393 0.0435 0.0000 0.0000 0.0455 0.0431 0.2961 0.9036
3696.62 0.1252 0.0375 0.0000 0.0000 0.0390 0.0431 0.2951 0.9036
3696.77 0.1062 0.0300 0.0000 0.0000 0.0309 0.0431 0.2942 0.9036
3696.92 0.1192 0.0341 0.0000 0.0000 0.0353 0.0431 0.2935 0.9036
3697.07 0.1445 0.0458 0.0000 0.0000 0.0479 0.0431 0.2927 0.9036
3697.22 0.1205 0.0417 0.0000 0.0000 0.0435 0.0431 0.2917 0.9036
3697.38 0.1072 0.0390 0.0000 0.0000 0.0406 0.0431 0.2907 0.9036
3697.53 0.1308 0.0506 0.0000 0.0000 0.0533 0.0431 0.2898 0.9036
3697.68 0.1583 0.0721 0.0025 0.0059 0.0778 0.0431 0.2886 0.9039
3697.83 0.2307 0.1277 0.1752 0.0368 0.1464 0.0431 0.2869 0.9041
3697.99 0.1884 0.1196 0.0540 0.0211 0.1358 0.0431 0.2840 0.9044
3698.14 0.2141 0.1415 0.1956 0.0369 0.1649 0.0431 0.2812 0.9047
3698.29 0.2186 0.1380 0.1519 0.0329 0.1601 0.0431 0.2779 0.9048
3698.44 0.2004 0.1136 0.0266 0.0152 0.1282 0.0431 0.2747 0.9048
3698.60 0.1745 0.0845 0.0016 0.0044 0.0924 0.0431 0.2720 0.9048
3698.75 0.1442 0.0601 0.0000 0.0000 0.0639 0.0431 0.2701 0.9049
3698.90 0.1545 0.0622 0.0001 0.0015 0.0663 0.0431 0.2687 0.9049
3699.05 0.1317 0.0612 0.0001 0.0010 0.0652 0.0431 0.2672 0.9049
3699.21 0.1450 0.0821 0.0033 0.0063 0.0895 0.0431 0.2658 0.9051
3699.36 0.1885 0.1188 0.0620 0.0227 0.1349 0.0431 0.2639 0.9054
3699.51 0.2285 0.1413 0.1550 0.0329 0.1645 0.0431 0.2611 0.9056
3699.66 0.2351 0.1307 0.0715 0.0232 0.1503 0.0431 0.2578 0.9056
3699.82 0.1739 0.0840 0.0009 0.0032 0.0916 0.0431 0.2548 0.9056
3699.97 0.1541 0.0648 0.0000 0.0002 0.0693 0.0431 0.2528 0.9056
3700.12 0.1709 0.0634 0.0001 0.0013 0.0677 0.0431 0.2513 0.9056
3700.27 0.1745 0.0589 0.0001 0.0012 0.0626 0.0431 0.2499 0.9056
3700.42 0.1998 0.0632 0.0006 0.0030 0.0675 0.0431 0.2485 0.9057
3700.58 0.2021 0.0616 0.0006 0.0030 0.0656 0.0431 0.2470 0.9057
3700.73 0.1379 0.0449 0.0000 0.0000 0.0470 0.0431 0.2456 0.9057
3700.88 0.1988 0.0693 0.0005 0.0027 0.0745 0.0431 0.2445 0.9057
3701.03 0.1476 0.0518 0.0000 0.0000 0.0546 0.0431 0.2429 0.9057
3701.19 0.1618 0.0540 0.0000 0.0000 0.0571 0.0431 0.2417 0.9057
3701.34 0.1788 0.0571 0.0001 0.0015 0.0605 0.0431 0.2405 0.9057
3701.49 0.1481 0.0508 0.0000 0.0004 0.0535 0.0431 0.2391 0.9057
3701.64 0.0745 0.0325 0.0000 0.0000 0.0336 0.0431 0.2380 0.9058
3701.80 0.1428 0.0823 0.0149 0.0134 0.0897 0.0431 0.2372 0.9066
3701.95 0.2387 0.1533 1.4779 0.0975 0.1810 0.0431 0.2353 0.9075
3702.10 0.2353 0.1744 1.9991 0.1063 0.2112 0.0431 0.2317 0.9079
3702.25 0.1941 0.1381 0.3233 0.0480 0.1602 0.0430 0.2276 0.9082
3702.41 0.1798 0.1236 0.1396 0.0334 0.1411 0.0430 0.2244 0.9085
3702.56 0.1861 0.1214 0.1355 0.0332 0.1382 0.0430 0.2216 0.9087
3702.71 0.1873 0.1186 0.1251 0.0322 0.1346 0.0430 0.2187 0.9090
3702.86 0.1829 0.1160 0.1100 0.0306 0.1312 0.0430 0.2160 0.9093
3703.02 0.1808 0.1175 0.1303 0.0331 0.1332 0.0430 0.2133 0.9096
3703.17 0.1858 0.1199 0.1682 0.0372 0.1362 0.0430 0.2105 0.9099
3703.32 0.1921 0.1216 0.1647 0.0365 0.1384 0.0430 0.2078 0.9102
3703.47 0.1970 0.1239 0.2221 0.0420 0.1414 0.0430 0.2049 0.9109
3703.63 0.2298 0.1461 1.0024 0.0822 0.1711 0.0430 0.2020 0.9117
3703.78 0.2309 0.1564 1.2763 0.0897 0.1854 0.0429 0.1986 0.9124
3703.93 0.2232 0.1588 1.2103 0.0867 0.1888 0.0429 0.1950 0.9132
3704.08 0.2249 0.1704 1.7331 0.1001 0.2054 0.0429 0.1913 0.9140
3704.23 0.2229 0.1720 1.6975 0.0987 0.2077 0.0428 0.1873 0.9148
3704.39 0.2210 0.1695 1.4681 0.0924 0.2041 0.0427 0.1833 0.9155
3704.54 0.2175 0.1629 1.3478 0.0903 0.1946 0.0427 0.1794 0.9162
3704.69 0.2205 0.1611 1.1398 0.0835 0.1921 0.0427 0.1756 0.9169
3704.84 0.2222 0.1603 1.0526 0.0805 0.1909 0.0426 0.1718 0.9175
3705.00 0.2191 0.1514 0.7592 0.0703 0.1784 0.0426 0.1681 0.9180
3705.15 0.2178 0.1432 0.5703 0.0627 0.1672 0.0426 0.1646 0.9186
3705.30 0.2226 0.1429 0.6188 0.0653 0.1667 0.0425 0.1613 0.9192
3705.45 0.2281 0.1482 0.8542 0.0754 0.1739 0.0425 0.1579 0.9198
3705.61 0.2271 0.1484 0.7591 0.0710 0.1743 0.0425 0.1545 0.9203
3705.76 0.2235 0.1443 0.5619 0.0620 0.1686 0.0425 0.1510 0.9207
Depth ΦT Φe K RQI Φz kh Φh nRQI
3705.91 0.2178 0.1372 0.4146 0.0546 0.1590 0.0425 0.1477 0.9211
3706.06 0.2092 0.1276 0.2599 0.0448 0.1462 0.0424 0.1445 0.9215
3706.22 0.2192 0.1275 0.2752 0.0461 0.1461 0.0424 0.1415 0.9219
3706.37 0.2307 0.1250 0.2456 0.0440 0.1428 0.0424 0.1385 0.9222
3706.52 0.2354 0.1216 0.2056 0.0408 0.1385 0.0424 0.1356 0.9225
3706.67 0.2272 0.1149 0.1480 0.0356 0.1298 0.0424 0.1328 0.9228
3706.83 0.2213 0.1102 0.1126 0.0317 0.1238 0.0424 0.1301 0.9230
3706.98 0.2255 0.1103 0.1174 0.0324 0.1239 0.0424 0.1276 0.9233
3707.13 0.2295 0.1112 0.1092 0.0311 0.1251 0.0424 0.1250 0.9234
3707.28 0.1989 0.0978 0.0335 0.0184 0.1085 0.0424 0.1224 0.9235
3707.44 0.1450 0.0731 0.0026 0.0059 0.0789 0.0424 0.1201 0.9235
3707.59 0.1251 0.0617 0.0001 0.0012 0.0658 0.0424 0.1184 0.9235
3707.74 0.1320 0.0607 0.0000 0.0001 0.0646 0.0424 0.1170 0.9235
3707.89 0.1517 0.0665 0.0003 0.0020 0.0712 0.0424 0.1156 0.9236
3708.04 0.1740 0.0790 0.0041 0.0072 0.0857 0.0424 0.1140 0.9242
3708.20 0.2816 0.1462 0.7945 0.0732 0.1712 0.0424 0.1122 0.9248
3708.35 0.2530 0.1508 0.9406 0.0784 0.1776 0.0424 0.1088 0.9256
3708.50 0.2493 0.1639 1.4507 0.0934 0.1960 0.0423 0.1053 0.9268
3708.65 0.2711 0.1882 3.7886 0.1409 0.2318 0.0423 0.1015 0.9276
3708.81 0.2386 0.1655 1.6650 0.0996 0.1983 0.0422 0.0971 0.9278
3708.96 0.1438 0.0975 0.0305 0.0176 0.1080 0.0421 0.0933 0.9284
3709.11 0.2175 0.1422 0.7691 0.0730 0.1658 0.0421 0.0910 0.9290
3709.26 0.2116 0.1367 0.7602 0.0740 0.1584 0.0421 0.0877 0.9298
3709.42 0.2170 0.1479 1.3685 0.0955 0.1736 0.0421 0.0845 0.9306
3709.57 0.1841 0.1370 1.3620 0.0990 0.1588 0.0420 0.0810 0.9349
3709.72 0.2782 0.2273 62.1597 0.5193 0.2941 0.0420 0.0779 0.9403
3709.87 0.2806 0.2457 105.5036 0.6507 0.3257 0.0401 0.0726 0.9461
3710.03 0.2735 0.2498 123.2449 0.6974 0.3330 0.0368 0.0669 0.9520
3710.18 0.2675 0.2493 127.5045 0.7101 0.3321 0.0329 0.0610 0.9580
3710.33 0.2645 0.2482 129.0083 0.7159 0.3301 0.0290 0.0552 0.9655
3710.48 0.2702 0.2548 210.3896 0.9023 0.3419 0.0250 0.0495 0.9726
3710.64 0.2481 0.2365 178.2490 0.8620 0.3098 0.0184 0.0435 0.9789
3710.79 0.2358 0.2280 130.7016 0.7519 0.2953 0.0128 0.0380 0.9843
3710.94 0.2304 0.2262 97.0453 0.6503 0.2924 0.0087 0.0327 0.9890
3711.09 0.2312 0.2301 74.0948 0.5635 0.2988 0.0057 0.0274 0.9927
3711.25 0.2265 0.2265 46.3572 0.4492 0.2929 0.0034 0.0221 0.9962
3711.40 0.2335 0.2329 41.2893 0.4180 0.3037 0.0020 0.0168 0.9986
3711.55 0.2179 0.2121 18.3237 0.2919 0.2691 0.0007 0.0114 0.9998
3711.70 0.1880 0.1718 3.9244 0.1501 0.2075 0.0001 0.0065 1.0000
3711.85 0.1343 0.1062 0.0357 0.0182 0.1188 0.0000 0.0025 1.0000
119
120
121