ENERGY RESOURCES CORP.
Pittcock Lease
BY
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
ENERGY RESOURCES CORP.
PITTCOCK LEASE
SUBMITTED TO
MEHRAN EHSAN
BY
DALE LEE, P.ENG.
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
OCTOBER 30, 2015
ii
TRANSMITTAL LETTER
Dale Lee, B.Tech, B.Sc., P.Eng.
President & CEO
Chetan Tewari, M.Eng.
Reservoir Engineer (E.I.T)
DL Petroleum Engineering and Consulting Limited
Box 21, Site 12, RR 7 (252 High Point Estates)
Calgary, Alberta, Canada T2P 2G7
T: 1-403-606-3093
E-mail: dalelee@dlengca
October 30, 2015
Mehran Ehsan
President & CEO
Standard Life Building
Suite 1290, 625 Howe St.,
Vancouver, BC Canada V6C 2T6
T: 1-604-259-2525 Ext: 101
F: 1-604-674-5113
E-mail: mehsan@energyresourcescorp.ca
Mehran Ehsan;
We are pleased to present this report on the Pittcock Lease in Texas, USA, for Energy Resources Corporation by DL Petroleum
Engineering and Consulting Limited.
iii
We have prepared a database to populate your USA data and/or future Canadian wells. We are able to show the dynamic results
within the database over SKYPE.
We would like to convey our gratitude for your support to DL Petroleum Engineering and Consulting Limited. Should you have any
questions, you may contact Dale Lee at dalelee@dleng.ca or call 1-403-606-3093.
Sincerely;
Dale Lee, P.Eng.
Cc: www.dleng.ca
Chetan Tewari, M.Eng.
iv
TABLE OF CONTENTS
TITLE PAGE
ii
TRANSMITTAL LETTER
iii
TABLE OF CONTENTS
v
DISCLAIMER
vii
EXECUTIVE SUMMARY
viii
LIST OF FIGURES
xii
LIST OF TABLES
xvii
INTRODUCTION
1
WELL PERFORMANCE
4
FIELD RELATIVE PERMEABILITY ANALYSIS
21
WELL ANALYSIS
31
CONCLUSIONS
36
RECOMMENDATIONS
38
APPENDIX 1
39
APPENDIX 2
59
v
REVISED APPENDIX
113
vi
DISCLAIMER
The opinions expressed in this report are based on the
Author’s best estimates of the data. They are subject to
the Author’s interpretation of the data provided by the
client and/or other databases. As such, the opinions
presented in this report cannot be guaranteed by neither
the Author nor DL Petroleum Engineering and
Consulting Limited.
vii
EXECUTIVE SUMMARY
The Pittcock Lease is located in the Stonewall County, part of the District 7B in the State of Texas in the Permian Basin and
producing through two members of the Tannehill Formations: Upper and Lower.
The purpose of this report is to study the available production, injection and petro-physical data to determine how to
optimize this underperforming waterflood with the aim to rejuvenate oil production. A study of the production and
existing injector showed that water injection had significant positive affect on oil production. Water injection was
discontinued from August 2007 to July 2013. Restarting injection resulted with some increased oil production; but the
rates with only the existing injector is not expected to improve swept efficiency within the two formations. The reason is
the injection channels have already created direct paths of least resistance to the various producing wells.
The solution presented in this report is to change the injection patterns by acquiring the two offset wells west of the lease.
Through controlled injection planning, the data suggest that it is possible to change the swept patterns and increase overall
oil production by maintaining balance voidage replacement operations.
It is very important to note that in order to achieve greater oil production, pressure and PVT (pressure-volume-temperate)
knowledge within the two formations is necessary to optimize production. The reason is that if relatively high gas
saturation zones have developed due to low pressures in the reservoir, new injection water will preferentially want to
travel through these gas saturation zones; the paths of least resistance and reduce oil ultimate recovery.
viii
The revised database incorporates wells in the vicinity of the Permex Petroleum waterflood. The revised database shows
19 wells with 36 completions. To evaluate the effect of the revised data on the conclusions and recommendations, the new
data was imported into OFM with all the areal plots were analyzed individually. The revised areal plots are available in the
Revised Appendix. The Authors were interested in understanding whether any of the new wells have contributed
significantly in changing the pool production dynamics. The first step was to analyze the effects of the injectors (Alias P-3
14207B0279073 & Alias P-1 14207B0279071) in the new database. Both these wells are shut-in injectors (SHI) with a
relatively short injection history. A detailed analysis shows no appreciable effects of these injectors in the wells in the
vicinity and overall pool dynamics.
ix
LIST OF FIGURES
Fig 1: Map of the USA showing IHS data coverage; the main source of data used in this report.
Fig 2: GIS Areal View of the Permex Petroleum’s Pittcock Lease in Stonewall County of Texas.
Fig. 3: Eleven (11) wells in the Pittcock lease with injection streamlines to production wells.
Fig. 4: Seven (7) wells in the Upper Tannehill showing their radii of investigation assuming radial flow.
Fig. 5: Five (5) wells in the Upper Tannehill showing their radii of investigation assuming radial flow.
Fig. 6: Initial reservoir pressure and cumulative oil, water & liquid produced and cumulative water injected curves for the
Tannehill formations.
Figure 7: Cumulative oil production map (Mbbl) for the entire producing pool (10 wells).
Figure 8: Cumulative oil production rate map (bbl/d) for the entire pool (10 wells).
Figure 9: Production plot for all 11 wells.
Figure 10: Cumulative rate plot; the Y-axes are showing cumulative rates (oil, gas, water, liquid and injection water) and
oil production rate. The X-axes are showing time (Date) on the top graph and cumulative oil (Kbbl) on the bottom graph.
Figure 11: An example of OFM’s output to for field calculated relative permeability data.
Figure 12: An example of OFM’s output to Excel. The red line is the history match of the 11 wells oil production rate
shown in green.
x
Figure 13: An example of OFM’s output to Excel using the 11 wells. The red line is the history match of the operated
wells; actual oil production rate shown in green.
Figure 14: Eleven (11) wells in the Pittcock lease with injection streamlines to production wells.
Figure 15: Cumulative oil production map (Mbbl) for the entire producing pool (10 wells).
Figure 16: Cumulative gas production map (MMcf) for the entire pool (10 wells).
Figure 17: Cumulative water production map (Mbbl) for the entire pool (10 wells).
Figure 18: Cumulative Liquid production map (Mbbl) for the entire pool (10 wells).
Figure 19: Cumulative water injected production map (Mbbl) for the entire pool (10 wells).
Figure 20: Cumulative water injection and liquid production map (Mbbl) for the entire pool (10 wells).
Figure 21: Cumulative oil production rate map (bbl/d) for the entire pool (10 wells).
Figure 22: Cumulative gas production rate map (Mcf/d) for the entire pool (10 wells).
Figure 23: Cumulative water production rate map (bbl/d) for the entire pool (11 wells).
Figure 24: Cumulative liquid production rate map (bbl/d) for the entire pool (10 wells).
Figure 25: Calendar day oil production rate map (bbl/d) for the entire pool (6 wells).
Figure 26: Calendar day gas production rate map (Mcf/d) for the entire pool (6 wells) – [No gas production recorded].
Figure 27: Calendar day water production rate map (bbl/d) for the entire pool (6 wells).
xi
Figure 28: Sub-Sea Upper Tannehill Formation Structure
Figure 29: Sub-Sea Lower Tannehill Formation Structure
Figure 30: Upper Tannehill Isopach.
Figure 31: Lower Tannehill Isopach.
Figure 32: Upper and Lower Tannehill Net Pay Combined.
Figure 33: Production for PITTCOCK 01 Alias: P-01
Figure 34: Fluid Ratios for PITTCOCK 01 Alias: P-01
Figure 35: Field Relative Permeability for PITTCOCK 01 Alias: P-01
Figure 36: Cumulative Rates for PITTCOCK 01 Alias: P-01
Figure 37: Chan Plots for PITTCOCK 01 Alias: P-01
Figure 38: Production for PITTCOCK 03 Alias: P-03
Figure 39: Fluid Ratios for PITTCOCK 03 Alias: P-03
Figure 40: Field Relative Permeability for PITTCOCK 03 Alias: P-03
Figure 41: Cumulative Rates for PITTCOCK 03 Alias: P-03
Figure 42: Chan Plots for PITTCOCK 03 Alias: P-03
xii
Figure 43: Production for PITTCOCK 04 Alias: P-04
Figure 44: Fluid Ratios for PITTCOCK 04 Alias: P-04
Figure 45: Field Relative Permeability for PITTCOCK 04 Alias: P-04
Figure 46: Cumulative Rates for PITTCOCK 04 Alias: P-04
Figure 47: Chan Plots for PITTCOCK 04 Alias: P-04
Figure 48: Production for PITTCOCK 05 Alias: P-05
Figure 49: Fluid Ratios for PITTCOCK 05 Alias: P-05
Figure 50: Field Relative Permeability for PITTCOCK 05 Alias: P-05
Figure 51: Cumulative Rates for PITTCOCK 05 Alias: P-05
Figure 52: Chan Plots for PITTCOCK 05 Alias: P-05
Figure 53: Production for PITTCOCK 06 Alias: P-06
Figure 54: Fluid Ratios for PITTCOCK 06 Alias: P-06
Figure 55: Field Relative Permeability for PITTCOCK 06 Alias: P-06
Figure 56: Cumulative Rates for PITTCOCK 06 Alias: P-06
Figure 57: Chan Plots for PITTCOCK 06 Alias: P-06
xiii
Figure 58: Production for PITTCOCK 07 Alias: P-07
Figure 59: Fluid Ratios for PITTCOCK 07 Alias: P-07
Figure 60: Field Relative Permeability for PITTCOCK 07 Alias: P-07
Figure 61: Cumulative Rates for PITTCOCK 07 Alias: P-07
Figure 62: Chan Plots for PITTCOCK 07 Alias: P-07
Figure 63: Production for PITTCOCK 08 Alias: P-08
Figure 64: Fluid Ratios for PITTCOCK 08 Alias: P-08
Figure 65: Field Relative Permeability for PITTCOCK 08 Alias: P-08
Figure 66: Cumulative Rates for PITTCOCK 08 Alias: P-08
Figure 67: Chan Plots for PITTCOCK 08 Alias: P-08
Figure 68: Production for PITTCOCK 10 Alias: P-10
Figure 69: Fluid Ratios for PITTCOCK 10 Alias: P-10
Figure 70: Field Relative Permeability for PITTCOCK 10 Alias: P-10
Figure 71: Cumulative Rates for PITTCOCK 10 Alias: P-10
Figure 72: Chan Plots for PITTCOCK 10 Alias: P-10
xiv
Figure 73: Production for PITTCOCK 11 Alias: P-11
Figure 74: Fluid Ratios for PITTCOCK 11 Alias: P-11
Figure 75: Field Relative Permeability for PITTCOCK 11 Alias: P-11
Figure 76: Cumulative Rates for PITTCOCK 11 Alias: P-11
Figure 77: Chan Plots for PITTCOCK 11 Alias: P-11
Figure 78: Production for PITTCOCK 12 Alias: P-12
Figure 79: Fluid Ratios for PITTCOCK 12 Alias: P-12
Figure 80: Field Relative Permeability for PITTCOCK 12 Alias: P-12
Figure 81: Cumulative Rates for PITTCOCK 12 Alias: P-12
Figure 82: Chan Plots for PITTCOCK 12 Alias: P-12
Figure 83: Revised Cumulative oil production map (Mbbl) for the entire producing pool (19 wells).
Figure 84: Revised Cumulative gas production map (MMcf) for the entire pool (19 wells)
Figure 85: Revised Cumulative water production map (Mbbl) for the entire pool (19 wells)
Figure 86: Revised Cumulative Liquid production map (Mbbl) for the entire pool (19 wells)
Figure 87: Revised Cumulative water injected production map (Mbbl) for the entire pool (19 wells)
xv
Figure 88: Revised Cumulative water injection and liquid production map (Mbbl) for the entire pool (19 wells)
Figure 89: Revised Cumulative oil production rate map (bbl/d) for the entire pool (19 wells)
Figure 90: Revised Cumulative gas production rate map (Mcf/d) for the entire pool (19 wells)
Figure 91: Revised Cumulative water production rate map (bbl/d) for the entire pool (19 wells)
Figure 92: Revised Cumulative liquid production rate map (bbl/d) for the entire pool (19 wells)
Figure 93: Revised Calendar day oil production rate map (bbl/d) for the entire pool (19 wells)
Figure 94: Revised Calendar day gas production rate map (Mcf/d) for the entire pool (19 wells) – [No gas production
recorded]
Figure 95: Revised Calendar day water production rate map (bbl/d) for the entire pool (19 wells)
xvi
LIST OF TABLES
Table 1: Production information for wells.
Table 2: Statistical results for the history match before waterflood eleven wells (11).
Table 3: Statistical results for the history match after waterflood eleven wells (11).
Table 4: Production information for wells.
Table 5: Pittcock # 14 Upper Formation Log Petro-Physical Analysis.
Table 6: Pittcock # 14 Lower Formation Log Petro-Physical Analysis.
xvii
INTRODUCTION
The Pittcock Lease is located in the Stonewall County, part of the District 7B in the State of Texas shown by dark green on
Figure 1. The wells analyzed are in the Permian Basin and producing through the Tannehill Formation.
Figure 1: Map of the USA showing IHS data coverage; the main source of data used in this report.
1
Figure 2 is a geographic information system (GIS) ground view of Permex Petroleum’s Pittcock Lease. The Pittcock # 14
well was not in the IHS US Data Online at the time the data for this report was extracted. Pittcock # 14 was superimposed
in Figure 3 for reference of its relative location.
Figure 2: GIS Areal View of the Permex Petroleum’s Pittcock Lease in Stonewall County of Texas.
2
The production data extracted from the IHS US online data has 11 wells in the Permex Petroleum’s waterflood: 6 Oil
producers, 1 Water Injector, 1 Water Supply, and 3 Plug & Abandoned. As of March 31, 2015, the lease produced 681 Mbbl
oil, 67 MMcf gas, 1779 Mbbl water, and injected 2605 Mbbl water. In addition, the Pittcock # 14 oil well was drilled in
October 2014 but was not included in the IHS information. The revised data base incorporates wells in the vicinity of the
Permex Petroleum’s waterflood. The revised data base shows 19 wells with 36 completions.
The purpose of this report is to analyze the fluid dynamics of the production data to estimate the areas within the reservoir
that are under performing to optimize the waterflood. One very important factor to mention is the lack of pressure data
collected and recorded for the producing formations.
Future reports can be refined as the operator collects new
information such as pressure data, pressure-volume-temperature (PVT) data, petro-physical data, and analyze the core
available. The new well logs from Pittcock #14 (not shown on Figure 2) has provided additional petro-physical
information: net pay, porosity and water saturation.
The results are summarized in the CONCLUSIONS and RECOMMENDATIONS sections. An overview of key points is given
in the EXECUTIVE SUMMARY.
3
WELL PERFORMANCE
The information gathered for this report is compiled into an OFM database. Figure 3 is an OFM map that shows the
Figure 3: Eleven (11) wells in the Pittcock lease with injection streamlines to production wells.
4
locations of Permex Petroleum wells including the new well Pittcock #14. Figure 3 has streamlines calculated based on
cumulative oil rate (bbl/d), cumulative water rate (bbl/d) and cumulative water injections rate (bbl/d). Cumulative oil
rate is the cumulative oil production (bbl) divided by the cumulative days (d) on oil production. The streamlines indicate
that all the producing wells have experienced an influence from the Pittcock # 11 injector. The streamlines fanning outside
the pool suggests some of the injection energy has gone outside the Pittcock lease.
The wells isolated for this report are in the Tannehill Upper and Lower formations. The data extracted from IHS US online
data has 11 wells in Permex Petroleum’s waterflood: 6 Oil producers, 1 Water Injector, 1 Water Supply, and 3 Plugged &
Abandonded. As of March 31, 2015, the Pittcock lease produced 681 Mbbl oil, 67 MMcf gas, 1779 Mbbl water, and injected
2605 Mbbl water. In addition is the new Pittcock # 14 well, drilled October 2014.
Figure 3 [as well as all production maps and plots] have the date, the cumulative oil production (Mbbl), cumulative gas
production (MMcf), cumulative water production (Mbbl), and cumulative water injection (Mbbl). The values displayed will
represent the well-filter used for the particular map or plot; for example, Figure 3 has the twelve wells penetrating both
Tannehill member. Figure 4 has the seven wells in the Upper Tannehill member and Figure 5 has the five wells in the
Lower Tannehill member.
The radius of investigation [R (ft)] for each well is calculated by:
0.5
𝑅 (𝑓𝑡) = [𝐶𝑢𝑚𝑂𝑖𝑙(𝑏𝑏𝑙)(
5.61𝑓𝑡 3
𝐵𝑜
)∗
]
1𝑏𝑏𝑙
𝜋(∅ ∗ (1 − 𝑆𝑤 − 𝑆𝑜𝑟 )) ∗ 𝑁𝑒𝑡𝑝𝑎𝑦(𝑓𝑡)
5

Assumptions: Average Oil Formation Volume Factor (𝐵𝑜 ) = 1.05 bbl/bbl; Residual Oil Saturation (𝑆𝑜𝑟 ) = 0.15 %

Upper Tannehill: Porosity (∅)= 19.35 %; Water Saturation (Sw) = 10.42 % [see Table 5 – End of Appendix 2]

Lower Tannehill: Porosity (∅)= 23.59 %; Water Saturation (Sw) = 39.91 % [see Table 6 – End of Appendix 2]

Weighted average for both Tannehill formations: Porosity (∅)= 21.96 %; Water Saturation (Sw) = 28.57 %
The petro-physical data came from the logs from Pittcock #14 and a breakdown of the analysis is given in Tables 5 & 6.
The circles shown in Figures 4 and 5 represent possible drainage radius for each well assuming an average formation
volume factor (Bo) is 1.05 bbl/bbl over the life of oil’s production. The value 1.05 bbl/bbl is likely to be high if the average
reservoir pressure is below the bubble point pressure over the life of the oil production; in this case then the radius circles
may be too big which could be a favourable scenario for remaining oil in place but not for recovering this oil. As presented,
the radius circles suggest that the Upper Tannehill has potential for remaining recoverable oil in the centre and the
northern part of the pool and the Lower Tannehill has potential for remaining recover oil around the boundaries also
toward the north end of the pool. The actual oil produced will have a different shape than a radial circle due to changing
permeability throughout the reservoir. Injector placement and injection rates are paramount in predicting and producing
these recoverable reserves.
Figure 6 is a plot of the initial pressure (2365 psia) and the cumulative oil, water & liquid production and cumulative water
injected curves for combined Tannehill members. This pressure is used to calculate the PVT properties for the Darcy’s
equation and relative permeability calculations. The database assumes constant pressure (due to the lack of
6
Figure 4: Seven (7) wells in the Upper Tannehill showing their radii of investigation assuming radial flow.
7
Figure 5: Five (5) wells in the Upper Tannehill showing their radii of investigation assuming radial flow.
8
other information) and the PVT data is from default correlations within OFM. This assumptions means that at best the PVT
values are an estimate; but, from a relative bases, they can provide a diagnostic of production trends. If recent
pressures and PVT data are collected for the reservoir, related graphs in this report can be recalibrated to match current
conditions
A summary of the production data, including the cumulative liquid rates, for the wells is given in Table 1. The production
data suggest that the wells with the highest cumulative liquid rate may have higher permeability due to their higher
cumulative liquid rate production; this estimation is made by examining Darcy’s law below. The colors in each column
range from red (lowest value) to green (highest value).
Darcy’s law is used to bring attention to the probability that permeability paths for new injection may intersect
permeability paths with injection flow already established in the pool. The path of least resistance would suggest that
water from new flow patterns should be more effective if the patterns were designed to flow from lower cumulative flow
rate wells towards higher flow rate wells. The wells with lower cumulative flow rates could be affected by either low
permeability or high skin factors that must be taken into consideration. An indirect way to determine if the wells flows are
affected by skin or from petro-physical characteristics is by examining logs and core data, when available. If it is expected
that wells should be behaving better, because of examining their petro-physical information, then pressure build-up (or
drawdown for injectors) tests could be run; these pressure tests also measure both effective permeability and skin.
9
Darcy’s law for radial flow for oil:
𝑞𝑜 = 𝑘𝑒𝑜 ∗
𝐶∗ℎ(𝑃𝑒 −𝑃𝑤 )
𝑟
𝜇𝑜 𝛽𝑜 [ln( 𝑒 )+𝑠]
;
𝑘𝑒𝑜 = 𝑘𝑟𝑜 ∗ 𝑘 ;
𝑞𝑜 ∝ 𝑘𝑒𝑜
𝑟𝑤
Where:
qo = oil flow rate, [STB/Day]
K = absolute rock permeability l, [md]
Keo = effective permeability to oil, [md]
Kro = relative permeability to oil, [md/md]
h = pay, [ft]
Pe = reservoir pressure, [psia]
Pw = wellbore pressure, [psia]
μo = Viscosity of oil, [cP]
βo = Formation volume factor for oil, [RB/STB]
re = Radius of investigation for well reservoir pressure, [ft]
rw = wellbore radius, [ft]
s = skin factor, [dimensionless]
C = (1/141.2)) for qo in [STB/Day]
10
1000
3000
2400
800
2400
1800
600
800
1200
400
400
600
200
600
0
0
0
0
1200
1980
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
Date
99
2000
01
02
03
04
05
06
07
08
09
10
11
12
13
14
15
1800
1200
All WELLs(11)
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 6: Initial reservoir pressure and cumulative oil, water & liquid produced and cumulative water injected curves for the
Tannehill formations.
11
Cumulative Water Inj ( Mbbl )
PITTCOCK LEASE TEXAS
Cumulative Liquid Prod ( Mbbl )
Cumulative Water Prod : 1778.55 Mbbl
Cumulative Water Inj : 2604.76 Mbbl
Cumulative Oil Prod ( Mbbl )
1600
ENERGY RESOURCES CORP.
Cumulative Oil Prod ( Mbbl ) All WELLs(11)
3000
CV.INTERPRES ( psia )
2000
Static Bottom Hole Pressure ( psia )
Cumulative Water Prod ( Mbbl )
Cumulative Water Prod ( Mbbl ) All WELLs(11)
Cumulative Oil Prod : 680.54 Mbbl
Cumulative Gas Prod : 67.06 MMcf
@name()
Well Name
date
Date
CV.CDOIL
Calander Day Oil
CV.WOR
Water Oil Ratio
CV.WCUT
Water Cut
CV.GOR
Gas Oil Ratio
CV.CUMOIL
Cumulative Oil
CV.CUMGAS
Cumulative Gas
CV.CUMWAT
Cumulative Water
CV.CUMLIQ
Cumulative Liquid (Oil & Water)
CV.CUMWINJ
Cumulative Injection Water
CV.CUMOILRate
Cumulative Oil Rate
CV.CUMGASRate
Cumulative Gas Rate
CV.CUMWAT
Cumulative Water Rate
CV.CUMLIQrate
Cumulative Liquid Rate
CV.CUMWINJrate Cumulative Water Injection Rate
@name()
date
PITTCOCK 01
PITTCOCK 03
PITTCOCK 04
PITTCOCK 06
PITTCOCK 08
PITTCOCK 10
PITTCOCK 07
PITTCOCK 05
PITTCOCK 12
PITTCOCK 11
PITTCOCK 13
3/31/2015
3/31/2015
3/31/2015
3/31/2015
3/31/2015
3/31/2015
10/31/1998
10/31/1996
11/30/1993
12/31/2014
@name()
date
PITTCOCK 01
PITTCOCK 03
PITTCOCK 04
PITTCOCK 06
PITTCOCK 08
PITTCOCK 10
PITTCOCK 07
PITTCOCK 05
PITTCOCK 12
PITTCOCK 11
PITTCOCK 13
3/31/2015
3/31/2015
3/31/2015
3/31/2015
3/31/2015
3/31/2015
10/31/1998
10/31/1996
11/30/1993
12/31/2014
CV.CDOIL
bbl/d
0.35
0.17
0.35
0.17
0.17
0.17
3.30
1.12
0.89
0.00
CV.WOR
bbl/bbl
19.53
29.28
19.53
29.28
29.28
29.28
55.54
31.63
2.84
CV.WCUT
%
95.13
96.70
95.13
96.70
96.70
96.70
98.23
96.94
73.93
CV.GOR
Mcf/bbl
0.08
0.08
0.06
CV.CUMLIQ CV.CUMWINJ CV.CUMOILRate CV.CUMGASRate
Mbbl
Mbbl
bbl/d
Mcf/d
244.84
8.85
0.91
187.09
7.86
0.80
528.76
13.41
1.28
170.60
5.56
0.59
627.52
9.23
0.88
209.91
3.66
0.28
244.43
10.67
1.08
208.48
13.73
1.44
20.18
4.57
0.41
17.29
2604.76
1.57
0.14
CV.CUMOIL
Mbbl
94.62
83.75
132.65
58.27
96.14
35.51
68.20
79.42
16.83
15.16
CV.CUMGAS
MMcf
9.70
8.53
12.68
6.20
9.16
2.67
6.91
8.33
1.53
1.36
CV.CUMWAT
Mbbl
150.22
103.34
396.12
112.33
531.39
174.39
176.22
129.05
3.35
2.13
CV.CUMWAT
Mbbl
150.22
103.34
396.12
112.33
531.39
174.39
176.22
129.05
3.35
2.13
CV.CUMLIQrate
bbl/d
22.91
17.56
53.44
16.29
60.26
21.61
38.23
36.05
5.48
1.79
CV.CUMWINJrate
bbl/d
269.95
Table 1: Production information for wells.
It can be seen by examining through Figures 7 & 8 that the wells shown with hotter colours (red – yellow) could have
tighter permeabilities and/or they could be affected by well bore skin. Another possible issue for the wells, being close to
the injectors, is that they may have relative permeability to oil limitations resulting from water breakthrough due to
12
direct communication with the injector [effectively, creating relative permeability worm-holes of paths of least resistance
for water traveling from injectors to producing wells].
The cumulative oil production map’s contours on Figure 7 is showing locations of higher oil production relative to locations
of low oil production. Red to yellow on the map indicates low production and dark-blue to magenta indicates high oil
production. If the actual zero edge boundary was determined, this boundary and data can easily be imported into OFM to
determine the OOIP (Original Oil In Place) and the ROIP (Remaining Oil In Place). Individual oil rate declines can be
estimated per well to estimate the different recovery factors throughout the reservoir. The cumulative oil rate production
map, Figure 8, is indicating locations of high effective permeability to oil (green to magenta).
Pressure support may improve areal sweep efficiency towards the production. The wells in the pool showing a higher
degree of red on the maps appear to have lower pressure support or skin. By estimating the fluid trends, through OFM, the
results can be confirmed with geology and by running tracers. Once permeability trends are estimated, suggestions for
converting wells into injectors may be made in order to re-pressurize the reservoir.
The caution with converting any of the wells into injectors is the unknown gas saturations levels in the pools. If the
conversions can be completed in a cost efficient process, the economic value may be profitable. If the gas saturation is high
the injection water will want to flow through the path of least resistance; e.g., through the high gas saturation zones.
13
The Pool’s PVT data and relative permeability measured from SCAL special core analysis can be used to estimate the
actual gas saturations at the well bores [see presentation on DL Petroleum Engineering and Consulting Ltd. websitei].
Pittcock #9 has core through the producing formation from (2890 ft to 2920 ft). If analyzed, this core may provide
important data like absolute permeability, porosity and net pay. In addition, special core analysis could provide relative
permeability data, connate water saturation and residual oil saturation; all of which are important for analyzing expected
reservoir fluid dynamic behavior and remain recoverable oil in place. The combination of the absolute and relative
permeability produces the effective permeability for the field; effective permeability can also be measured by running a
pressure buildup/drawdown field test for the producing zone. A properly designed and analyzed buildup/drawdown test
can give the current reservoir pressure for the reservoir.
The data is showing that if injection is too aggressive it can cause the cumulative oil rate curve to decrease with respect to
cumulative oil. Once optimum injection is reached, increasing the water injection rate can cause a decrease in cumulative
oil rate resulting in a loss of ultimate recoverable reserves. The data did show wells that responded positively to the
injector. The key is to know when to cut back injection and/or knowing when to shut off water at the wellbores when
breakthrough occurs.
A new injector is suggested for the field to change the sweep patterns to improve the sweep
efficiency.
14
The section below on FIELD RELATIVE PERMEABILITY ANALYSIS is dedicated to using the field relative permeability data,
calculated in OFM and using default PVT data, to estimate wells that have water breakthrough from the injector using
statistical techniques developed by the Author.
It is important to note that the pool’s oil rate increased corresponding to increasing water injection for a duration of steady
well count. The oil rate per well showed an increase in oil rate suggesting the injection can have a positive impact on the
Pool’s ultimate recovery if carefully maintained.
15
Figure 7: Cumulative oil production map (Mbbl) for the entire producing pool (10 wells).
16
Figure 8: Cumulative oil production rate map (bbl/d) for the entire pool (10 wells).
17
800
8
0.30
240
600
6
0.20
160
400
4
0.10
80
200
2
1980
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
Date
2000
01
02
03
04
05
06
07
08
09
10
11
12
13
14
15
0
PITTCOCK LEASE TEXAS
0
400
1000
0.40
320
800
8
0.30
240
600
6
0.20
160
400
4
0.10
80
200
2
0.00
0
0
0
100
500
1000
10
Cumulativ e Oil Prod ( Mbbl )
All WELLs(11)
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 9: Production plot for all 11 wells.
18
Wells on Oil Production
0.50
0
Wells on Oil Production All WELLs(11)
320
Water Rate (CD) ( bbl/d )
0.40
Water Inj Rate (CD) ( bbl/d )
10
Oil Rate (CD) ( bbl/d )
1000
Wells on Oil Production
Cumulative Water Prod : 1778.55 Mbbl
Cumulative Water Inj : 2604.76 Mbbl
400
0.00
Gas / Oil Ratio ( Mcf/bbl )
ENERGY RESOURCES CORP.
0.50
Oil Rate (CD) per Well ( bbl/d )
Gas / Oil Ratio ( Mcf/bbl ) All WELLs(11)
Gas / Oil Ratio ( Mcf/bbl )
Cumulative Oil Prod : 680.54 Mbbl
Cumulative Gas Prod : 67.06 MMcf
24
80
600
180
18
400
120
12
200
60
6
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
Date
98
99
2000
01
02
03
04
05
06
07
08
09
10
11
12
13
0
PITTCOCK LEASE TEXAS
20
0
300
30
800
240
24
600
180
18
400
120
12
200
60
6
20
0
0
0
0
1
5
10
50
Cumulativ e Oil Prod ( Kbbl )
100
500
1000
100
80
60
40
Oil Rate (CD) ( bbl/d )
82
CV.CUMGASRate ( Mcf/d ) All WELLs(11)
1980 81
40
CV.CUMGASRate ( Mcf/d )
1000
0
60
Oil Rate (CD) ( bbl/d ) All WELLs(11)
240
CV.CUMGASRate ( Mcf/d )
800
CV.CUMOILRate ( bbl/d )
100
CV.CUMLIQrate ( bbl/d )
30
Oil Rate (CD) ( bbl/d )
Cumulative Water Prod : 1778.55 Mbbl
Cumulative Water Inj : 2604.76 Mbbl
300
0
CV.CUMWINJrate ( bbl/d )
ENERGY RESOURCES CORP.
1000
CV.CUMWATrate ( bbl/d )
CV.CUMWINJrate ( bbl/d ) All WELLs(11)
CV.CUMWINJrate ( bbl/d )
Cumulative Oil Prod : 680.54 Mbbl
Cumulative Gas Prod : 67.06 MMcf
All WELLs(11)
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 10: Cumulative rate plot; the Y-axes are showing cumulative rates (oil, gas, water, liquid and injection water) and oil
production rate. The X-axes are showing time (Date) on the top graph and cumulative oil (Kbbl) on the bottom graph.
19
Figure 9 is a plot of the cumulative rate curves for the wells. The cumulative oil and cumulative liquid started off as the
same point and later a wedge divided these two curves. The cumulative water and the cumulative liquid curves started at
different points on the curve and began to merge together as water from the injectors began to cycle with the producers.
In the WELL ANALYSIS section, each well’s cumulative rate plot was analyzed and the individual plots are presented in the
APPENDICES.
A discussion in the FIELD RELATIVE PERMEABILITY ANALYSIS section will be completed prior to the WELL ANALYSIS
section because the field relative permeabilities have value in predicting the pool’s fluid saturation. Understanding the
pool’s fluid saturation dynamics leads to potential locations for injector conversions to potentially improve sweep in
regions of the Pool lacking optimal drainage.
20
FIELD RELATIVE PERMEABILITY ANALYSIS
The pools’ PVT data is required to calculate the formation volume factors and fluid viscosities so the actual gas saturations
at the well bores can be determined. Darcy’s law can be utilized by observing the following empirical relationships:
𝑘𝑟𝑔
𝑞𝑔 𝜇𝑔 𝛽𝑔
≅
;
𝑘𝑟𝑤 𝑞𝑤 𝜇𝑤 𝛽𝑤
𝑘𝑟𝑔 𝑞𝑔 𝜇𝑔 𝛽𝑔
≅
;
𝑘𝑟𝑜 𝑞𝑜 𝜇𝑜 𝛽𝑜
𝑘𝑟𝑤 𝑞𝑤 𝜇𝑤 𝛽𝑤
≅
𝑘𝑟𝑜
𝑞𝑜 𝜇𝑜 𝛽𝑜
Where:
qf = fluid flow rate, [STB/D]
krf = relative permeability to fluid, [md/md]
μf = Viscosity of fluid, [cP]
βf = Formation volume factor for fluid, [RB/STB]
f = fluid [gas (g) or oil (o) or water (w)]
The Alberta Energy Resources Conservation Board (ERCB) has made available in Alberta PVT data for pool’s and Reservoirs
corresponding to reservoir changing pressures over the life of the pools. The Author has extrapolated default PVT data for
Oil with similar °API from this source for OFM. As a result, the field relative permeabilities can be estimated for reservoir.
With the relative permeabilities calculated, they can be exported with the wells’ production and/or injection history to
generate a history matches of the wells’ production history for various segments of the wells’ life. Figures 11 & 12 along
with Table 2 show the OFM plots and tabular output to Excel for history matching the wells production history by
employing regression analysis.
21
320
240
160
8
900
6
240
180
120
6
160
120
80
60
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97 98
Date
99 2000 01
02
03
04
05
06
07
08
09
10
11
12
13
0
PITTCOCK LEASE TEXAS
40
0
0
400
300
320
240
240
180
160
120
80
4
60
40
2
0
0
0
600
2.0
300
1.0
80
0
0.0
0
10
50
100
Cumulativ e Oil Prod ( Kbbl )
500
1000
200
2
160
120
10
8
6
ZONE: Lower Tannehill, Upper Tannehill(10)
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 11: An example of OFM’s output to for field calculated relative permeability data.
22
Wells on Oil Production
3.0
82
4
Krg_Kro ZONE: Lower Tannehill, Upper Tannehill(10)
4.0
198081
80
Krg_Kro
900
5.0
0
Krg_Kro ZONE: Lower Tannehill, Upper Tannehill(10)
1200
0
Krg_Kro
1500
2
Oil Rate (CD) ( bbl/d )
0
4
Krw_Kro ZONE: Lower Tannehill, Upper Tannehill(10)
600
Wells on Oil Production ZONE: Lower Tannehill, Upper Tannehill(10)
8
Krg_Kro
1200
Krg_Kro
10
Oil Rate (CD) ( bbl/d )
200
Oil Rate (CD) ( bbl/d ) ZONE: Lower Tannehill, Upper Tannehill(10)
300
Krw_Kro
400
Wells on Oil Production
Cumulative Water Prod : 1778.55 Mbbl
Cumulative Water Inj : 2604.76 Mbbl
10
Krw_Kro
Water Inj Rate (CD) ( bbl/d )
ENERGY RESOURCES CORP.
1500
300
Water Inj Rate (CD) ( bbl/d )
Water Inj Rate (CD) ( bbl/d ):Completion: PITTCOCK 11
Cumulative Oil Prod : 680.54 Mbbl
Cumulative Gas Prod : 67.06 MMcf
Where:
CV.CUMOIL
CV.CDOIL
Krg_Krw
= Cumulative oil production, Kbbl
= Calendar day oil production rate bbl/d
𝑘𝑟𝑔
=𝑘
Krg_Kro
=𝑘
Krw_Kro
𝑟𝑤
𝑘𝑟𝑔
𝑟𝑜
𝑘𝑟𝑤
=𝑘
𝑟𝑜
CV.CDWINJ = Calendar day water injection rate bbl/d
CV.CNTOILW = Number of oil wells on production
Prd.CDOIL
= History match of the calendar day oil production rate bbl/d
23
SUMMARY OUTPUT
Regression Statistics
Multiple R
0.95082914
R Square
0.904076053
Adjusted R Square
0.90194441
Standard Error
25.79619368
Observations
139
ANOVA
df
Regression
Residual
Total
Intercept
Krg_Krw
Krg_Kro
Krw_Kro
3
135
138
SS
846687.1188
89834.8871
936522.0059
MS
F
Significance F
282229.0396 424.1216478
1.69052E-68
665.4436082
Coefficients Standard Error
t Stat
P-value
-978.4422854
67.09607826 -14.58270454 1.62442E-29
0.218092648
0.044161616 4.938511521 2.28634E-06
4.622255783
0.778605171 5.936585008 2.32761E-08
2547.588749
511.2665437 4.982897435 1.88467E-06
Lower 95%
Upper 95%
-1111.137681 -845.7468895
0.130754562 0.305430735
3.08241435 6.162097216
1536.460854 3558.716644
Table 2: Statistical results for the history match before waterflood eleven wells (11).
24
Statistical results in Table 5 are used to match the history of the calendar day oil production rate (red curve on Figure 9).
The key indicators in Table 5 are:

Multiple R = 0.95

R Square = 0.90

Observations = 139 (months)

F = 424

Significance F = 1.69 E-68

t Stat = -4.94 for Krg_Krw; 5.94 for Krg_Kro; 4.98 for Krw_Kro; -14.6 for Intercept

P – value = 2.3E-06 for Krg_Krw; 2.3E-08 for Krg_Kro; 1.9E-06 for Krw_Kro; 1.6E-29 for Intercept
The ideal regression fit would have:

Multiple R = 1.00

R Square = 1.00

Observations = Maximum

F = Maximum

Significance F = 1.00E-∞

t Stat = Maximum absolute value

P – value 1.00E-∞
25
The greater the limits as the values for Significance F and P-value approaches zero, or 1.00E-∞, the greater the
significances of the regression. In the example for Table 2, Krg_Kro has the most significant followed by Krg_Krw;
Krw_Kro has the least significance.
Figure 12: An example of OFM’s output to Excel. The red line is the history match of the 11 wells oil production rate shown in green.
26
In Table 2, the relative permeability of gas to oil (Krg_Kro) is the most significant other than the intercept. This is indicating
gas is coming out of solution or insufficient pressure support. The relative permeability of gas to water (Krg_Krw) is the
next significant variable suggesting gas is connected to the water zones or insufficient pressure support.
The relative
permeability of water to oil (Krw_Kro) is least significant indicating that water has not initially established a permeable
path through oil before the waterflood started. Looking at the data from after the waterflood, the following values were
calculated:
The key indicators in Table 3 are now:
•
Multiple R = 0.81
•
R Square = 0.65
•
Observations = 97 (months)
•
F = 59.3
•
Significance F = 1.61 E-21
•
t Stat = 5.81 for Krg_Krw; -6.20 for Krg_Kro; -9.18 Krw_Kro; 6.28 for Intercept
•
P – value 8.58E-08 for Krg_Krw; 1.85E-01 for Krg_Kro; 1.87 E-3 Krw_Kro
In Table 3, the relative permeability of water to oil (Krw_Kro) is now the dominant variable and most significant. This is
indicating injection water is now supporting the reservoir.
.
27
SUMMARY OUTPUT
Regression Statistics
Multiple R
0.810386292
R Square
0.656725942
Adjusted R Square
0.645652585
Standard Error
35.2783398
Observations
97
ANOVA
df
Regression
Residual
Total
Intercept
Krg_Krw
Krg_Kro
Krw_Kro
3
93
96
SS
221433.0362
115744.1971
337177.2333
MS
F
Significance F
73811.01207 59.30685336
1.61446E-21
1244.561259
Coefficients Standard Error
t Stat
P-value
12420.89616
1976.958636 6.282830576 1.05839E-08
0.775096304
0.133346913 5.812630265 8.57893E-08
-119.5949652
19.28068427 -6.202838218 1.51756E-08
-191.9123512
20.89706266 -9.183699845 1.09123E-14
Lower 95%
Upper 95%
8495.048117 16346.74421
0.510295762 1.039896846
-157.882583 -81.30734745
-233.4097761 -150.4149262
Table 3: Statistical results for the history match after waterflood eleven wells (11).
28
Figure 13: An example of OFM’s output to Excel using the 11 wells. The red line is the history match of the operated wells; actual oil
production rate shown in green.
29
The relative permeability of gas to oil (Krg_Kro) is least significant indicating that gas is not as significant factor coming
out of solution which is consistent with the concept of relative permeability worm-hole bypassing the oil and its associated
solution gas.
The purpose of presenting all these plots and tables is to illustrate how production data can be used to predict the fluid
dynamics within a pool or reservoir. One plot alone will not give a complete picture but looking at each of the plots in OFM
and Excel is reasonably simple and the technique is analogous to looking at a suite of logs when doing a petro-physical
analysis of a well. For the WELL ANALYSIS section, all for the aforementioned plots, as well as other plots available in OFM,
but not referred to in this report, are used to evaluate each well individually. The results for the wells are then compared
to compile a composite understanding for the two pools being evaluated.
The next section of the report, WELL ANALYSIS, is compiled by looking at the various plots in OFM and Excel to summarize
the wells’ performance within the pool.
30
WELL ANALYSIS
@name()
date
PITTCOCK 01
PITTCOCK 03
PITTCOCK 04
PITTCOCK 06
PITTCOCK 08
PITTCOCK 10
PITTCOCK 07
PITTCOCK 05
PITTCOCK 12
PITTCOCK 11
PITTCOCK 13
3/31/2015
3/31/2015
3/31/2015
3/31/2015
3/31/2015
3/31/2015
10/31/1998
10/31/1996
11/30/1993
12/31/2014
@name()
date
PITTCOCK 01
PITTCOCK 03
PITTCOCK 04
PITTCOCK 06
PITTCOCK 08
PITTCOCK 10
PITTCOCK 07
PITTCOCK 05
PITTCOCK 12
PITTCOCK 11
PITTCOCK 13
3/31/2015
3/31/2015
3/31/2015
3/31/2015
3/31/2015
3/31/2015
10/31/1998
10/31/1996
11/30/1993
12/31/2014
CV.CDOIL
bbl/d
0.35
0.17
0.35
0.17
0.17
0.17
3.30
1.12
0.89
0.00
CV.WOR
bbl/bbl
19.53
29.28
19.53
29.28
29.28
29.28
55.54
31.63
2.84
CV.WCUT
%
95.13
96.70
95.13
96.70
96.70
96.70
98.23
96.94
73.93
CV.GOR
Mcf/bbl
0.08
0.08
0.06
CV.CUMOIL
Mbbl
94.62
83.75
132.65
58.27
96.14
35.51
68.20
79.42
16.83
15.16
CV.CUMWAT CV.CUMWINJ CV.CUMOILRate CV.CUMGASRate CV.CUMLIQrate
Mbbl
Mbbl
bbl/d
Mcf/d
bbl/d
150.22
8.85
0.91
22.91
103.34
7.86
0.80
17.56
396.12
13.41
1.28
53.44
112.33
5.56
0.59
16.29
531.39
9.23
0.88
60.26
174.39
3.66
0.28
21.61
176.22
10.67
1.08
38.23
129.05
13.73
1.44
36.05
3.35
4.57
0.41
5.48
2.13
2604.76
1.57
0.14
1.79
CV.CUMGAS
MMcf
9.70
8.53
12.68
6.20
9.16
2.67
6.91
8.33
1.53
1.36
CV.CUMLIQ
Mbbl
244.84
187.09
528.76
170.60
627.52
209.91
244.43
208.48
20.18
17.29
CV.CUMWAT
Mbbl
150.22
103.34
396.12
112.33
531.39
174.39
176.22
129.05
3.35
2.13
CV.CUMWINJrate
bbl/d
269.95
Table 4: Production information for wells.
31
1. Production for Pittcock 01 Alias: P-01
 Monthly producing data for 3/31/815: Oil Rate = 0.3 m3/d, WOR = 19.5 m3/m3, WCUT = 95.1 %, GOR = scm/m3.
 Cumulative production maps: Oil = 94.6 Km3, Gas = 10 Kscm, Water = 150.2 Km3, Liquid = 244.8 Km3; Blue, Dark Blue,
Light Green, Light Green.
 Cumulative production rate maps (cumprod/cumdays) data for 3/31/815: Oil = 8.9 m3/d, Gas = 1 scm/d, Water = 14.1
m3/d, Liquid = 22.9 m3/d; Dark Green, Light Blue, Light Green, Light Green.
2. Production for Pittcock 03 Alias: P-03
 Monthly producing data for 3/31/815: Oil Rate = .2 m3/d, WOR = 29.3 m3/m3, WCUT = 96.7 %, GOR = scm/m3.
 Cumulative production maps: Oil = 83.7 Km3, Gas = 9 Kscm, Water = 103.3 Km3, Liquid = 187.1 Km3; Light Blue, Blue,
Light Green, Yellow.
 Cumulative production rate maps (cumprod/cumdays) data for 3/31/815: Oil = 7.9 m3/d, Gas = 1 scm/d, Water = 9.7
m3/d, Liquid = 17.6 m3/d; Dark Green, Dark Green, Yellow, Yellow.
3. Production for Pittcock 04 Alias: P-04
 Monthly producing data for 3/31/815: Oil Rate = .3 m3/d, WOR = 19.5 m3/m3, WCUT = 95.1 %, GOR = scm/m3.
 Cumulative production maps: Oil = 132.6 Km3, Gas = 13 Kscm, Water = 396.1 Km3, Liquid = 528.8 Km3; Magenta,
Magenta, Light Green, Blue.
 Cumulative production rate maps (cumprod/cumdays) data for 3/31/815: Oil = 13.4 m3/d, Gas = 1 scm/d, Water =
40.0 m3/d, Liquid = 53.4 m3/d; Dark Blue, Dark Blue, Magenta, Dark Blue.
32
4. Production for Pittcock 05 Alias: P-05
 Monthly producing data for 10/1996: Oil Rate = .2 m3/d, WOR = 29.3 m3/m3, WCUT = 96.7 %, GOR = scm/m3.
 Cumulative production maps: Oil = 58.3 Km3, Gas = 6 Kscm, Water = 112.3 Km3, Liquid = 170.6 Km3; Green, Dark
Green, Light Green, Yellow.
 Cumulative production rate maps (cumprod/cumdays) data for 10/1996: Oil = 13.7 m3/d, Gas = 1 scm/d, Water = 22.3
m3/d, Liquid = 36.1 m3/d; Magenta, Magenta, Dark Green, Light Blue.
5. Production for Pittcock 06 Alias: P-06
 Monthly producing data for 3/31/815: Oil Rate = .2 m3/d, WOR = 29.3 m3/m3, WCUT = 96.7 %, GOR = scm/m3.
 Cumulative production maps: Oil = 96.1 Km3, Gas = 9 Kscm, Water = 531.4 Km3, Liquid = 627.5 Km3; Green, Blue, Light
Green, Magenta.
 Cumulative production rate maps (cumprod/cumdays) data for 3/31/815: Oil = 5.6 m3/d, Gas = 1 scm/d, Water = 10.7
m3/d, Liquid = 16.3 m3/d; Light Green, Light Green, Yellow, Yellow.
6. Production for Pittcock 07 Alias: P-07
 Monthly producing data for 10/1998: Oil Rate = .2 m3/d, WOR = 29.3 m3/m3, WCUT = 96.7 %, GOR = scm/m3.
 Cumulative production maps: Oil = 35.5 Km3, Gas = 3 Kscm, Water = 174.4 Km3, Liquid = 89.9 Km3; Light-Blue, Yellow,
Orange, Light Green.
 Cumulative production rate maps (cumprod/cumdays) data for 10/1998: Oil = 10.7 m3/d, Gas = 1 scm/d, Water = 27.6
m3/d, Liquid = 38.2 m3/d; Blue, Blue, Light Blue, Light Blue.
33
7. Production for Pittcock 08 Alias: P-08
 Monthly producing data for 3/31/815: Oil Rate = 3.3 m3/d, WOR = 55.5 m3/m3, WCUT = 98.2 %, GOR = scm/m3.
 Cumulative production maps: Oil = 68.8 Km3, Gas = 7 Kscm, Water = 176.2 Km3, Liquid = 244.4 Km3; Blue, Dark Green,
Light Green, Light Green.
 Cumulative production rate maps (cumprod/cumdays) data for 3/31/815: Oil = 9.2 m3/d, Gas = 1 scm/d, Water = 51.0
m3/d, Liquid = 60.3 m3/d; Light Blue, Dark Green, Magenta, Magenta.
8. Production for Pittcock 10 Alias: P-10
 Monthly producing data for 3/31/815: Oil Rate = 1.1 m3/d, WOR = 31.6 m3/m3, WCUT = 96.9 %, GOR = scm/m3.
 Cumulative production maps: Oil = 79.4 Km3, Gas = 8 Kscm, Water = 129.1 Km3, Liquid = 88.5 Km3; Yellow, Light Blue,
Orange, Yellow.
 Cumulative production rate maps (cumprod/cumdays) data for 3/31/815: Oil = 3.7 m3/d, Gas = scm/d, Water = 18.0
m3/d, Liquid = 21.6 m3/d; Yellow, Orange, Green, Light Green.
9. Production for Pittcock 11 Alias: P-11 [Injector]
 Monthly producing data for 12/31/814: Oil Rate = .9 m3/d, WOR = 2.8 m3/m3, WCUT = 73.9 %, GOR = scm/m3.
 Cumulative production maps: Oil = 16.8 Km3, Gas = 2 Kscm, Water = 3.3 Km3, Liquid = 8.2 Km3; Orange, Orange, Red,
Red.
 Cumulative production rate maps (cumprod/cumdays) data for 12/31/814: Oil = 1.6 m3/d, Gas = scm/d, Water = .3
m3/d, Liquid = 1.8 m3/d; Orange, Red, Red, Red.
34
10. Production for Pittcock 12 Alias: P-12
 Monthly producing data for 11/1993: Oil Rate = .0 m3/d, WOR = .0 m3/m3, WCUT = .0 %, GOR = scm/m3.
 Cumulative production maps: Oil = 15.2 Km3, Gas = 1 Kscm, Water = 2.1 Km3, Liquid = 17.3 Km3; Orange, Orange, Red,
Red.
 Cumulative production rate maps (cumprod/cumdays) data for 11/1993: Oil = 4.6 m3/d, Gas = scm/d, Water = .9
m3/d, Liquid = 5.5 m3/d; Light Green, Yellow, Red, Red.
35
CONCLUSIONS
1. The Pittcock Lease is located in the Stonewall County, part of the District 7B in the State of Texas in the Permian
Basin and producing through the Tannehill formations (Figures 1 & 2).
2. The majority of the data presented is extracted from IHS US data online to March 31, 2015.
3. Stream Lines (Figure 3) shows the wells in the top north-west of the field have less interaction with the current
Injector.
4. Bubble Maps (Figures 4 & 5) show there is higher potential for remaining oil production from the north end of the
field in the upper Tannehill and around the perimeters on the pool in the lower Tannehill. Other animated data
created in OFM (not shown in this report) supports that the area in the northern part of the lower member is not
swept as well as the Upper member.
5. The existing injector had strong support in the waterflood (Figures 6 & 9). Its remaining influence is likely limited,
new injector(s) is/are needed to sweep the remaining un-swept oil to the oil wells. Pittcock #5 is NOT suggested as
a new injector. The offset wells in the neighboring lease #4 & #3 may be good injectors depending on the remaining
reservoir pressure.
36
6. Most of the oil production came from Pittcock wells #4, #8, #3, and #1 (Figures 7 & 8).
7. The cumulative fluid (oil, gas, water) rate plots show the existing injector has channeled water to all the producers.
Balanced injection is necessary to keep reservoir pressure up. Over injection will reduce the efficiency of the
injectors. Voidage Replacement Ratio (VRR) calculations can be calculated but is out of the current scope of this
report; a decision toward patterns and injectors are needed to base the VRR calculations upon.
8. The Intercept in Table 2 has a P-value of 1.6 E-29 and a t-Stat value of -14.6; these values are significantly greater
in magnitude than that of the relative permeability values [Krg_Krw, Krg_Kro, and Krw_Kro]. The field relative
permeability calculations show that before the waterflood the primary drive mechanism was not oil, water or gas
(Table 2 and Figs. 11 & 12). The Intercept in Table 2 is probably a reflection of pressure depletion within the
reservoir. After the waterflood the Krw_Kro has a P-value of 1.1 E-14 and a t-Stat value of -9.2 showing the injector
has a significant effect of the fluid drive mechanism until the water began to channel from the injector to the
producing wells. Once channeling begins, this clearly shows a new injector path is needed to sweep more oil.
9. The well analysis section is a detailed breakdown the Author used to analyze the two pools; Upper Tannehill and
Lower Tannehill. It is through analyzing this data as well as the plots in appendices 1 and 2 that the above
conclusions are made.
37
RECOMMENDATIONS
The recommended action items for the Pittcock Lease are:
1. Do NOT turn Pittcock # 5 into an Injector.
2. Evaluate the acquisition of the two offset wells API 433-81014 (#3) and API 433-33244 (#4) for the purpose of turn
them into injectors.
3. Evaluate controlled injection by injection into the Upper Tannehill separately from the Lower Tannehill.
4. Measure current reservoir pressures and PVT data.
5. Calibrate the waterflood design patterns by using voidage replacement ratio (VRR) calculations.
6. Measure the oil, gas and water production rates for each well, every month.
7. Measure the water injection rates and well head injection pressures for each injector, every month.
38
APPENDIX 1
39
FIGURES FOR WELL PERFORMANCE
Figure 14: Eleven (11) wells in the Pittcock lease with injection streamlines to production wells.
40
Figure 15: Cumulative oil production map (Mbbl) for the entire producing pool (10 wells).
41
Figure 16: Cumulative gas production map (MMcf) for the entire pool (10 wells).
42
Figure 17: Cumulative water production map (Mbbl) for the entire pool (10 wells).
43
Figure 18: Cumulative Liquid production map (Mbbl) for the entire pool (10 wells).
44
Figure 19: Cumulative water injected production map (Mbbl) for the entire pool (10 wells).
45
Figure 20: Cumulative water injection and liquid production map (Mbbl) for the entire pool (10 wells).
46
Figure 21: Cumulative oil production rate map (bbl/d) for the entire pool (10 wells).
47
Figure 22: Cumulative gas production rate map (Mcf/d) for the entire pool (10 wells).
48
Figure 23: Cumulative water production rate map (bbl/d) for the entire pool (11 wells).
49
Figure 24: Cumulative liquid production rate map (bbl/d) for the entire pool (10 wells).
50
Figure 25: Calendar day oil production rate map (bbl/d) for the entire pool (6 wells).
51
Figure 26: Calendar day gas production rate map (Mcf/d) for the entire pool (6 wells) – [No gas production recorded].
52
Figure 27: Calendar day water production rate map (bbl/d) for the entire pool (6 wells).
53
Figure 28: Sub-Sea Upper Tannehill Formation Structure
54
Figure 29: Sub-Sea Lower Tannehill Formation Structure
55
Figure 30: Upper Tannehill Isopach.
56
Figure 31: Lower Tannehill Isopach.
57
Figure 32: Upper and Lower Tannehill Net Pay Combined.
58
APPENDIX 2
59
OIL WELLS
60
800
0.8
0.30
60
600
0.6
0.20
40
400
0.4
0.10
20
200
0.2
1980
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
Date
2000
01
02
03
04
05
06
07
08
09
10
11
12
13
14
0
15
PITTCOCK LEASE TEXAS
0.0
100
1000
0.40
80
800
0.8
0.30
60
600
0.6
0.20
40
400
0.4
0.10
20
200
0.2
0.00
0
0
0.0
1
5
10
Cumulativ e Oil Prod ( Mbbl )
50
100
1.0
PITTCOCK 01
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 33: Production for PITTCOCK 01 Alias: P-01
61
Wells on Oil Production
0.50
0
Wells on Oil Production PITTCOCK 01
80
Water Rate (CD) ( bbl/d )
0.40
Water Inj Rate (CD) ( bbl/d )
1.0
Oil Rate (CD) ( bbl/d )
1000
Wells on Oil Production
Cumulative Water Prod : 150.22 Mbbl
Cumulative Water Inj : * Mbbl
100
0.00
Gas / Oil Ratio ( Mcf/bbl )
ENERGY RESOURCES CORP.
0.50
Oil Rate (CD) per Well ( bbl/d )
Gas / Oil Ratio ( Mcf/bbl ) PITTCOCK 01
Gas / Oil Ratio ( Mcf/bbl )
Cumulative Oil Prod : 94.62 Mbbl
Cumulative Gas Prod : 9.70 MMcf
0.75
100
1200
0.40
80
0.60
80
60
0.45
40
0.30
0.15
20
0.00
0
900
600
0.30
0.20
Water / Oil Ratio ( bbl/bbl )
100
Oil Rate (CD) ( bbl/d )
0.50
60
40
300
0.10
20
0
0.00
0
1500
0.50
100
0.75
100
1200
0.40
80
0.60
80
60
0.45
40
0.30
0.15
20
0.00
0
1980
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97 98
Date
99 2000 01
02
03
04
05
06
07
08
09
10
11
12
13
14
15
Water Cut ( % )
Cumulative Water Prod : 150.22 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1500
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
Cumulative Oil Prod : 94.62 Mbbl
Cumulative Gas Prod : 9.70 MMcf
300
0.10
20
0
0.00
0
1
5
10
50
Cumulativ e Water Prod ( Mbbl )
100
500
1000
60
40
PITTCOCK 01
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 34: Fluid Ratios s for PITTCOCK 01 Alias: P-01
62
Water Cut ( % )
0.20
Water / Oil Ratio ( bbl/bbl )
600
0.30
Oil Rate (CD) ( bbl/d )
900
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
PITTCOCK LEASE TEXAS
8
80
240
160
0.8
900
6
60
180
120
0.6
40
120
80
0.4
20
60
40
0.2
8
900
6
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97 98
Date
99 2000 01
02
03
04
05
06
07
08
09
10
11
12
13
Krg_Kro PITTCOCK 01
82
0
PITTCOCK LEASE TEXAS
0
0.0
100
300
200
80
240
160
0.8
60
180
120
0.6
40
120
80
0.4
60
40
0.2
0
0
0.0
600
4
300
2
20
0
0
0
1
5
10
Cumulativ e Oil Prod ( Kbbl )
50
100
1.0
PITTCOCK 01
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 35: Field Relative Permeability for PITTCOCK 01 Alias: P-01
63
Wells on Oil Production
1200
198081
Krg_Kro PITTCOCK 01
10
0
Krg_Kro
1500
0
Krg_Kro
2
Oil Rate (CD) ( bbl/d ) PITTCOCK 01
300
Oil Rate (CD) ( bbl/d )
4
Krw_Kro PITTCOCK 01
600
Wells on Oil Production PITTCOCK 01
1200
Wells on Oil Production
1.0
Krg_Kro
200
Krg_Kro
300
Oil Rate (CD) ( bbl/d )
100
Krw_Kro
10
Krw_Kro
Water Inj Rate (CD) ( bbl/d )
Cumulative Water Prod : 150.22 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1500
0
Water Inj Rate (CD) ( bbl/d )
Water Inj Rate (CD) ( bbl/d ):Completion: PITTCOCK 11
Cumulative Oil Prod : 94.62 Mbbl
Cumulative Gas Prod : 9.70 MMcf
4.0
80
600
60
3.0
400
40
2.0
200
20
1.0
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
Date
98
99
2000
01
02
03
04
05
06
07
08
09
10
11
12
0.0
13
PITTCOCK LEASE TEXAS
20
0
100
5.0
800
80
4.0
600
60
3.0
400
40
2.0
200
20
1.0
20
0
0
0.0
0
1
5
10
Cumulativ e Oil Prod ( Kbbl )
50
100
100
80
60
40
PITTCOCK 01
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 36: Cumulative Rates for PITTCOCK 01 Alias: P-01
64
Oil Rate (CD) ( bbl/d )
82
CV.CUMGASRate ( Mcf/d ) PITTCOCK 01
1980 81
40
CV.CUMGASRate ( Mcf/d )
1000
0
60
Oil Rate (CD) ( bbl/d ) PITTCOCK 01
80
CV.CUMGASRate ( Mcf/d )
800
CV.CUMOILRate ( bbl/d )
100
CV.CUMLIQrate ( bbl/d )
5.0
Oil Rate (CD) ( bbl/d )
Cumulative Water Prod : 150.22 Mbbl
Cumulative Water Inj : * Mbbl
100
0
CV.CUMWINJrate ( bbl/d )
ENERGY RESOURCES CORP.
1000
CV.CUMWATrate ( bbl/d )
CV.CUMWINJrate ( bbl/d ) PITTCOCK 01
CV.CUMWINJrate ( bbl/d )
Cumulative Oil Prod : 94.62 Mbbl
Cumulative Gas Prod : 9.70 MMcf
Cumulative Oil Prod : 94.62 Mbbl
Cumulative Gas Prod : 9.70 MMcf
ENERGY RESOURCES CORP.
Cumulative Water Prod : 150.22 Mbbl
Cumulative Water Inj : * Mbbl
3
10
100
Axis 1 PITTCOCK 01
Water / Oil Ratio ( bbl/bbl )
2
10
CHAN.DPrdWOR
80
CV.WORFIT
1
10
CHAN.dprdworFIT
Axis 2
0
Oil Rate (CD) ( bbl/d ) PITTCOCK 01
10
60
-1
10
40
-2
10
-3
10
20
-4
10
-5
10
0
10
2
10
3
4
10
5
10
CHAN.CumPrdDay s
PITTCOCK LEASE TEXAS
1
10
PITTCOCK 01
Cumulativ e Water/Oil Ratio ( bbl/bbl )
10
0
CHAN.DPrdWORCUM
-1
10
-2
10
10
-3
-4
10
10
10
-5
-6
-7
10
10
2
3
10
10
4
5
10
CHAN.CumPrdDay s
PITTCOCK 01
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 37: Chan Plots for PITTCOCK 01 Alias: P-01
65
800
0.8
0.30
60
600
0.6
0.20
40
400
0.4
0.10
20
200
0.2
1980
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
Date
2000
01
02
03
04
05
06
07
08
09
10
11
12
13
14
0
15
PITTCOCK LEASE TEXAS
0.0
100
1000
0.40
80
800
0.8
0.30
60
600
0.6
0.20
40
400
0.4
0.10
20
200
0.2
0.00
0
0
0.0
1
5
10
Cumulativ e Oil Prod ( Mbbl )
50
100
1.0
PITTCOCK 03
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 38: Production for PITTCOCK 03 Alias: P-03
66
Wells on Oil Production
0.50
0
Wells on Oil Production PITTCOCK 03
80
Water Rate (CD) ( bbl/d )
0.40
Water Inj Rate (CD) ( bbl/d )
1.0
Oil Rate (CD) ( bbl/d )
1000
Wells on Oil Production
Cumulative Water Prod : 103.34 Mbbl
Cumulative Water Inj : * Mbbl
100
0.00
Gas / Oil Ratio ( Mcf/bbl )
ENERGY RESOURCES CORP.
0.50
Oil Rate (CD) per Well ( bbl/d )
Gas / Oil Ratio ( Mcf/bbl ) PITTCOCK 03
Gas / Oil Ratio ( Mcf/bbl )
Cumulative Oil Prod : 83.75 Mbbl
Cumulative Gas Prod : 8.53 MMcf
0.75
100
1200
0.40
80
0.60
80
60
0.45
40
0.30
0.15
20
0.00
0
900
600
0.30
0.20
Water / Oil Ratio ( bbl/bbl )
100
Oil Rate (CD) ( bbl/d )
0.50
60
40
300
0.10
20
0
0.00
0
1500
0.50
100
0.75
100
1200
0.40
80
0.60
80
60
0.45
40
0.30
0.15
20
0.00
0
1980
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97 98
Date
99 2000 01
02
03
04
05
06
07
08
09
10
11
12
13
14
15
Water Cut ( % )
Cumulative Water Prod : 103.34 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1500
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
Cumulative Oil Prod : 83.75 Mbbl
Cumulative Gas Prod : 8.53 MMcf
300
0.10
20
0
0.00
0
1
5
10
50
Cumulativ e Water Prod ( Mbbl )
100
500
1000
60
40
PITTCOCK 03
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 39: Fluid Ratios s for PITTCOCK 03 Alias: P-03
67
Water Cut ( % )
0.20
Water / Oil Ratio ( bbl/bbl )
600
0.30
Oil Rate (CD) ( bbl/d )
900
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
PITTCOCK LEASE TEXAS
8
80
240
160
0.8
900
6
60
180
120
0.6
40
120
80
0.4
20
60
40
0.2
8
900
6
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97 98
Date
99 2000 01
02
03
04
05
06
07
08
09
10
11
12
13
Krg_Kro PITTCOCK 03
82
0
PITTCOCK LEASE TEXAS
0
0.0
100
300
200
80
240
160
0.8
60
180
120
0.6
40
120
80
0.4
60
40
0.2
0
0
0.0
600
4
300
2
20
0
0
0
1
5
10
Cumulativ e Oil Prod ( Kbbl )
50
100
1.0
PITTCOCK 03
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 40: Field Relative Permeability for PITTCOCK 03 Alias: P-03
68
Wells on Oil Production
1200
81
Krg_Kro PITTCOCK 03
10
0
Krg_Kro
1500
0
Krg_Kro
2
Oil Rate (CD) ( bbl/d ) PITTCOCK 03
300
Oil Rate (CD) ( bbl/d )
4
Krw_Kro PITTCOCK 03
600
Wells on Oil Production PITTCOCK 03
1200
Wells on Oil Production
1.0
Krg_Kro
200
Krg_Kro
300
Oil Rate (CD) ( bbl/d )
100
Krw_Kro
10
Krw_Kro
Water Inj Rate (CD) ( bbl/d )
Cumulative Water Prod : 103.34 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1500
0
Water Inj Rate (CD) ( bbl/d )
Water Inj Rate (CD) ( bbl/d ):Completion: PITTCOCK 11
Cumulative Oil Prod : 83.75 Mbbl
Cumulative Gas Prod : 8.53 MMcf
6.0
240
600
30
4.5
400
20
3.0
200
10
1.5
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
Date
98
99
2000
01
02
03
04
05
06
07
08
09
10
11
12
0.0
13
PITTCOCK LEASE TEXAS
60
0
50
7.5
800
40
6.0
600
30
4.5
400
20
3.0
200
10
1.5
60
0
0
0.0
0
10
50
100
300
240
180
120
Cumulativ e Oil Prod ( Kbbl )
PITTCOCK 03
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 41: Cumulative Rates for PITTCOCK 03 Alias: P-03
69
Oil Rate (CD) ( bbl/d )
82
CV.CUMGASRate ( Mcf/d ) PITTCOCK 03
81
120
CV.CUMGASRate ( Mcf/d )
1000
0
180
Oil Rate (CD) ( bbl/d ) PITTCOCK 03
40
Oil Rate (CD) ( bbl/d )
800
CV.CUMGASRate ( Mcf/d )
300
CV.CUMOILRate ( bbl/d )
7.5
CV.CUMLIQrate ( bbl/d )
50
0
CV.CUMWINJrate ( bbl/d )
Cumulative Water Prod : 103.34 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1000
CV.CUMWATrate ( bbl/d )
CV.CUMWINJrate ( bbl/d ) PITTCOCK 03
CV.CUMWINJrate ( bbl/d )
Cumulative Oil Prod : 83.75 Mbbl
Cumulative Gas Prod : 8.53 MMcf
Cumulative Oil Prod : 83.75 Mbbl
Cumulative Gas Prod : 8.53 MMcf
ENERGY RESOURCES CORP.
Cumulative Water Prod : 103.34 Mbbl
Cumulative Water Inj : * Mbbl
3
10
60
Axis 1 PITTCOCK 03
Water / Oil Ratio ( bbl/bbl )
2
10
CHAN.DPrdWOR
CV.WORFIT
1
10
45
CHAN.dprdworFIT
Axis 2
0
Oil Rate (CD) ( bbl/d ) PITTCOCK 03
10
-1
10
30
-2
10
-3
10
15
-4
10
-5
10
0
10
2
10
3
4
10
5
10
CHAN.CumPrdDay s
PITTCOCK LEASE TEXAS
1
10
PITTCOCK 03
Cumulativ e Water/Oil Ratio ( bbl/bbl )
10
0
CHAN.DPrdWORCUM
-1
10
-2
10
10
-3
-4
10
10
10
-5
-6
-7
10
10
2
3
10
10
4
5
10
CHAN.CumPrdDay s
PITTCOCK 03
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 42: Chan Plots for PITTCOCK 03 Alias: P-03
70
800
0.8
0.24
60
600
0.6
0.16
40
400
0.4
0.08
20
200
0.2
1980
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
Date
2000
01
02
03
04
05
06
07
08
09
10
11
12
13
14
15
0
PITTCOCK LEASE TEXAS
0.0
100
1000
0.32
80
800
0.8
0.24
60
600
0.6
0.16
40
400
0.4
0.08
20
200
0.2
0.00
0
0
0.0
1
5
10
50
Cumulativ e Oil Prod ( Mbbl )
100
500
1000
1.0
PITTCOCK 04
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 43: Production for PITTCOCK 04 Alias: P-04
71
Wells on Oil Production
0.40
0
Wells on Oil Production PITTCOCK 04
80
Water Rate (CD) ( bbl/d )
0.32
Water Inj Rate (CD) ( bbl/d )
1.0
Oil Rate (CD) ( bbl/d )
1000
Wells on Oil Production
Cumulative Water Prod : 396.12 Mbbl
Cumulative Water Inj : * Mbbl
100
0.00
Gas / Oil Ratio ( Mcf/bbl )
ENERGY RESOURCES CORP.
0.40
Oil Rate (CD) per Well ( bbl/d )
Gas / Oil Ratio ( Mcf/bbl ) PITTCOCK 04
Gas / Oil Ratio ( Mcf/bbl )
Cumulative Oil Prod : 132.65 Mbbl
Cumulative Gas Prod : 12.68 MMcf
0.75
100
1200
0.32
80
0.60
80
60
0.45
40
0.30
0.15
20
0.00
0
900
600
0.24
0.16
Water / Oil Ratio ( bbl/bbl )
100
Oil Rate (CD) ( bbl/d )
0.40
60
40
300
0.08
20
0
0.00
0
1500
0.40
100
0.75
100
1200
0.32
80
0.60
80
60
0.45
40
0.30
0.15
20
0.00
0
1980
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97 98
Date
99 2000 01
02
03
04
05
06
07
08
09
10
11
12
13
14
15
Water Cut ( % )
Cumulative Water Prod : 396.12 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1500
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
Cumulative Oil Prod : 132.65 Mbbl
Cumulative Gas Prod : 12.68 MMcf
300
0.08
20
0
0.00
0
1
5
10
50
Cumulativ e Water Prod ( Mbbl )
100
500
1000
60
40
PITTCOCK 04
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 44: Fluid Ratios s for PITTCOCK 04 Alias: P-04
72
Water Cut ( % )
0.16
Water / Oil Ratio ( bbl/bbl )
600
0.24
Oil Rate (CD) ( bbl/d )
900
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
PITTCOCK LEASE TEXAS
8
80
240
160
0.8
900
6
60
180
120
0.6
40
120
80
0.4
20
60
40
0.2
8
900
6
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97 98
Date
99 2000 01
02
03
04
05
06
07
08
09
10
11
12
13
Krg_Kro PITTCOCK 04
82
0
PITTCOCK LEASE TEXAS
0
0.0
100
300
200
80
240
160
0.8
60
180
120
0.6
40
120
80
0.4
60
40
0.2
0
0
0.0
600
4
300
2
20
0
0
0
1
5
10
50
Cumulativ e Oil Prod ( Kbbl )
100
500
1000
1.0
PITTCOCK 04
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 45: Field Relative Permeability for PITTCOCK 04 Alias: P-04
73
Wells on Oil Production
1200
81
Krg_Kro PITTCOCK 04
10
0
Krg_Kro
1500
0
Krg_Kro
2
Oil Rate (CD) ( bbl/d ) PITTCOCK 04
300
Oil Rate (CD) ( bbl/d )
4
Krw_Kro PITTCOCK 04
600
Wells on Oil Production PITTCOCK 04
1200
Wells on Oil Production
1.0
Krg_Kro
200
Krg_Kro
300
Oil Rate (CD) ( bbl/d )
100
Krw_Kro
10
Krw_Kro
Water Inj Rate (CD) ( bbl/d )
Cumulative Water Prod : 396.12 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1500
0
Water Inj Rate (CD) ( bbl/d )
Water Inj Rate (CD) ( bbl/d ):Completion: PITTCOCK 11
Cumulative Oil Prod : 132.65 Mbbl
Cumulative Gas Prod : 12.68 MMcf
4.0
80
600
45
3.0
400
30
2.0
200
15
1.0
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
Date
98
99
2000
01
02
03
04
05
06
07
08
09
10
11
12
13
0.0
PITTCOCK LEASE TEXAS
20
0
75
5.0
800
60
4.0
600
45
3.0
400
30
2.0
200
15
1.0
20
0
0
0.0
0
1
5
10
50
Cumulativ e Oil Prod ( Kbbl )
100
500
1000
100
80
60
40
PITTCOCK 04
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 46: Cumulative Rates for PITTCOCK 04 Alias: P-04
74
Oil Rate (CD) ( bbl/d )
82
CV.CUMGASRate ( Mcf/d ) PITTCOCK 04
81
40
CV.CUMGASRate ( Mcf/d )
1000
0
60
Oil Rate (CD) ( bbl/d ) PITTCOCK 04
60
CV.CUMGASRate ( Mcf/d )
800
CV.CUMOILRate ( bbl/d )
100
CV.CUMLIQrate ( bbl/d )
5.0
Oil Rate (CD) ( bbl/d )
Cumulative Water Prod : 396.12 Mbbl
Cumulative Water Inj : * Mbbl
75
0
CV.CUMWINJrate ( bbl/d )
ENERGY RESOURCES CORP.
1000
CV.CUMWATrate ( bbl/d )
CV.CUMWINJrate ( bbl/d ) PITTCOCK 04
CV.CUMWINJrate ( bbl/d )
Cumulative Oil Prod : 132.65 Mbbl
Cumulative Gas Prod : 12.68 MMcf
Cumulative Oil Prod : 132.65 Mbbl
Cumulative Gas Prod : 12.68 MMcf
ENERGY RESOURCES CORP.
Cumulative Water Prod : 396.12 Mbbl
Cumulative Water Inj : * Mbbl
3
10
100
Axis 1 PITTCOCK 04
Water / Oil Ratio ( bbl/bbl )
2
10
CHAN.DPrdWOR
80
CV.WORFIT
1
10
CHAN.dprdworFIT
Axis 2
0
Oil Rate (CD) ( bbl/d ) PITTCOCK 04
10
60
-1
10
40
-2
10
-3
10
20
-4
10
-5
10
0
100
500
1000
CHAN.CumPrdDay s
5000
10000
5000
10000
PITTCOCK LEASE TEXAS
1
10
PITTCOCK 04
Cumulativ e Water/Oil Ratio ( bbl/bbl )
10
0
CHAN.DPrdWORCUM
-1
10
10
-2
-3
10
-4
10
10
-5
-6
10
100
500
1000
CHAN.CumPrdDay s
PITTCOCK 04
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 47: Chan Plots for PITTCOCK 04 Alias: P-04
75
800
0.8
0.30
60
600
0.6
0.20
40
400
0.4
0.10
20
200
0.2
1981
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
Date
2000
01
02
03
04
05
06
07
08
09
10
11
12
13
14
0
15
PITTCOCK LEASE TEXAS
0.0
100
1000
0.40
80
800
0.8
0.30
60
600
0.6
0.20
40
400
0.4
0.10
20
200
0.2
0.00
0
0
0.0
1
5
10
Cumulativ e Oil Prod ( Mbbl )
50
100
1.0
PITTCOCK 06
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 48: Production for PITTCOCK 05 Alias: P-05
76
Wells on Oil Production
0.50
0
Wells on Oil Production PITTCOCK 06
80
Water Rate (CD) ( bbl/d )
0.40
Water Inj Rate (CD) ( bbl/d )
1.0
Oil Rate (CD) ( bbl/d )
1000
Wells on Oil Production
Cumulative Water Prod : 112.33 Mbbl
Cumulative Water Inj : * Mbbl
100
0.00
Gas / Oil Ratio ( Mcf/bbl )
ENERGY RESOURCES CORP.
0.50
Oil Rate (CD) per Well ( bbl/d )
Gas / Oil Ratio ( Mcf/bbl ) PITTCOCK 06
Gas / Oil Ratio ( Mcf/bbl )
Cumulative Oil Prod : 58.27 Mbbl
Cumulative Gas Prod : 6.20 MMcf
0.75
100
1200
0.40
80
0.60
80
60
0.45
40
0.30
0.15
20
0.00
0
900
600
0.30
0.20
Water / Oil Ratio ( bbl/bbl )
100
Oil Rate (CD) ( bbl/d )
0.50
60
40
300
0.10
20
0
0.00
0
1500
0.50
100
0.75
100
1200
0.40
80
0.60
80
60
0.45
40
0.30
0.15
20
0.00
0
1981
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98 99 2000 01
Date
02
03
04
05
06
07
08
09
10
11
12
13
14
15
Water Cut ( % )
Cumulative Water Prod : 112.33 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1500
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
Cumulative Oil Prod : 58.27 Mbbl
Cumulative Gas Prod : 6.20 MMcf
300
0.10
20
0
0.00
0
1
5
10
50
Cumulativ e Water Prod ( Mbbl )
100
500
1000
60
40
PITTCOCK 06
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 49: Fluid Ratios s for PITTCOCK 05 Alias: P-05
77
Water Cut ( % )
0.20
Water / Oil Ratio ( bbl/bbl )
600
0.30
Oil Rate (CD) ( bbl/d )
900
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
PITTCOCK LEASE TEXAS
8
80
240
160
0.8
900
6
60
180
120
0.6
40
120
80
0.4
20
60
40
0.2
8
900
6
84
85
86
87
88
89
90
91
92
93
94
95
96
97 98
Date
99 2000 01
02
03
04
05
06
07
08
09
10
11
12
13
Krg_Kro PITTCOCK 05
83
0
PITTCOCK LEASE TEXAS
0
0.0
100
300
200
80
240
160
0.8
60
180
120
0.6
40
120
80
0.4
60
40
0.2
0
0
0.0
600
4
300
2
20
0
0
0
1
5
10
Cumulativ e Oil Prod ( Kbbl )
50
100
1.0
PITTCOCK 05
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 50: Field Relative Permeability for PITTCOCK 05 Alias: P-05
78
Wells on Oil Production
1200
1981 82
Krg_Kro PITTCOCK 05
10
0
Krg_Kro
1500
0
Krg_Kro
2
Oil Rate (CD) ( bbl/d ) PITTCOCK 05
300
Oil Rate (CD) ( bbl/d )
4
Krw_Kro PITTCOCK 05
600
Wells on Oil Production PITTCOCK 05
1200
Wells on Oil Production
1.0
Krg_Kro
200
Krg_Kro
300
Oil Rate (CD) ( bbl/d )
100
Krw_Kro
10
Krw_Kro
Water Inj Rate (CD) ( bbl/d )
Cumulative Water Prod : 129.05 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1500
0
Water Inj Rate (CD) ( bbl/d )
Water Inj Rate (CD) ( bbl/d ):Completion: PITTCOCK 11
Cumulative Oil Prod : 79.42 Mbbl
Cumulative Gas Prod : 8.33 MMcf
4.0
80
600
30
3.0
400
20
2.0
200
10
1.0
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
Date
98
99
2000
01
02
03
04
05
06
07
08
09
10
11
12
0.0
13
PITTCOCK LEASE TEXAS
20
0
50
5.0
800
40
4.0
600
30
3.0
400
20
2.0
200
10
1.0
20
0
0
0.0
0
1
5
10
Cumulativ e Oil Prod ( Kbbl )
50
100
100
80
60
40
PITTCOCK 05
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 51: Cumulative Rates for PITTCOCK 05 Alias: P-05
79
Oil Rate (CD) ( bbl/d )
82
CV.CUMGASRate ( Mcf/d ) PITTCOCK 05
1981
40
CV.CUMGASRate ( Mcf/d )
1000
0
60
Oil Rate (CD) ( bbl/d ) PITTCOCK 05
40
CV.CUMGASRate ( Mcf/d )
800
CV.CUMOILRate ( bbl/d )
100
CV.CUMLIQrate ( bbl/d )
5.0
Oil Rate (CD) ( bbl/d )
Cumulative Water Prod : 129.05 Mbbl
Cumulative Water Inj : * Mbbl
50
0
CV.CUMWINJrate ( bbl/d )
ENERGY RESOURCES CORP.
1000
CV.CUMWATrate ( bbl/d )
CV.CUMWINJrate ( bbl/d ) PITTCOCK 05
CV.CUMWINJrate ( bbl/d )
Cumulative Oil Prod : 79.42 Mbbl
Cumulative Gas Prod : 8.33 MMcf
Cumulative Oil Prod : 79.42 Mbbl
Cumulative Gas Prod : 8.33 MMcf
ENERGY RESOURCES CORP.
Cumulative Water Prod : 129.05 Mbbl
Cumulative Water Inj : * Mbbl
3
250
10
60
Axis 1 PITTCOCK 05
Water / Oil Ratio ( bbl/bbl )
2
10
200
CHAN.DPrdWOR
CV.WORFIT
1
10
0
Oil Rate (CD) ( bbl/d ) PITTCOCK 05
10
150
45
CHAN.dprdworFIT
Axis 2
-1
10
100
30
-2
10
-3
10
15
50
-4
10
-5
0
10
0
100
500
1000
CHAN.CumPrdDay s
5000
10000
5000
10000
PITTCOCK LEASE TEXAS
1
10
PITTCOCK 05
Cumulativ e Water/Oil Ratio ( bbl/bbl )
10
0
CHAN.DPrdWORCUM
-1
10
10
-2
-3
10
-4
10
10
-5
-6
10
100
500
1000
CHAN.CumPrdDay s
PITTCOCK 05
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 52: Chan Plots for PITTCOCK 05 Alias: P-05
80
0.75
100
1200
0.40
80
0.60
80
60
0.45
40
0.30
0.15
20
0.00
0
900
600
0.30
0.20
Water / Oil Ratio ( bbl/bbl )
100
Oil Rate (CD) ( bbl/d )
0.50
60
40
300
0.10
20
0
0.00
0
1500
0.50
100
0.75
100
1200
0.40
80
0.60
80
60
0.45
40
0.30
0.15
20
0.00
0
1981
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98 99 2000 01
Date
02
03
04
05
06
07
08
09
10
11
12
13
14
15
Water Cut ( % )
Cumulative Water Prod : 112.33 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1500
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
Cumulative Oil Prod : 58.27 Mbbl
Cumulative Gas Prod : 6.20 MMcf
300
0.10
20
0
0.00
0
1
5
10
50
Cumulativ e Water Prod ( Mbbl )
100
500
1000
60
40
PITTCOCK 06
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 53: Production for PITTCOCK 06 Alias: P-06
81
Water Cut ( % )
0.20
Water / Oil Ratio ( bbl/bbl )
600
0.30
Oil Rate (CD) ( bbl/d )
900
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
PITTCOCK LEASE TEXAS
250
100
1200
0.40
80
200
80
60
150
40
100
50
20
0
0
900
600
0.30
0.20
Water / Oil Ratio ( bbl/bbl )
100
Oil Rate (CD) ( bbl/d )
0.50
60
40
300
0.10
20
0
0.00
0
1500
0.50
100
250
100
1200
0.40
80
200
80
60
150
40
100
50
20
0
0
1981
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98 99 2000 01
Date
02
03
04
05
06
07
08
09
10
11
12
13
14
15
Water Cut ( % )
Cumulative Water Prod : 112.33 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1500
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
Cumulative Oil Prod : 58.27 Mbbl
Cumulative Gas Prod : 6.20 MMcf
300
0.10
20
0
0.00
0
10
50
100
Cumulativ e Water Prod ( Mbbl )
500
1000
60
40
PITTCOCK 06
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 54: Fluid Ratios s for PITTCOCK 06 Alias: P-06
82
Water Cut ( % )
0.20
Water / Oil Ratio ( bbl/bbl )
600
0.30
Oil Rate (CD) ( bbl/d )
900
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
PITTCOCK LEASE TEXAS
8
80
240
160
0.8
900
6
60
180
120
0.6
40
120
80
0.4
20
60
40
0.2
8
900
6
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
Date
99 2000 01
02
03
04
05
06
07
08
09
10
11
12
13
Krg_Kro PITTCOCK 06
83
0
PITTCOCK LEASE TEXAS
0
0.0
100
300
200
80
240
160
0.8
60
180
120
0.6
40
120
80
0.4
60
40
0.2
0
0
0.0
600
4
300
2
20
0
0
0
1
5
10
Cumulativ e Oil Prod ( Kbbl )
50
100
1.0
PITTCOCK 06
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 55: Field Relative Permeability for PITTCOCK 06 Alias: P-06
83
Wells on Oil Production
1200
1981 82
Krg_Kro PITTCOCK 06
10
0
Krg_Kro
1500
0
Krg_Kro
2
Oil Rate (CD) ( bbl/d ) PITTCOCK 06
300
Oil Rate (CD) ( bbl/d )
4
Krw_Kro PITTCOCK 06
600
Wells on Oil Production PITTCOCK 06
1200
Wells on Oil Production
1.0
Krg_Kro
200
Krg_Kro
300
Oil Rate (CD) ( bbl/d )
100
Krw_Kro
10
Krw_Kro
Water Inj Rate (CD) ( bbl/d )
Cumulative Water Prod : 112.33 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1500
0
Water Inj Rate (CD) ( bbl/d )
Water Inj Rate (CD) ( bbl/d ):Completion: PITTCOCK 11
Cumulative Oil Prod : 58.27 Mbbl
Cumulative Gas Prod : 6.20 MMcf
4.0
80
600
30
3.0
400
20
2.0
200
10
1.0
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
Date
99
2000
01
02
03
04
05
06
07
08
09
10
11
12
0.0
13
PITTCOCK LEASE TEXAS
20
0
50
5.0
800
40
4.0
600
30
3.0
400
20
2.0
200
10
1.0
20
0
0
0.0
0
1
5
10
Cumulativ e Oil Prod ( Kbbl )
50
100
100
80
60
40
PITTCOCK 06
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 56: Cumulative Rates for PITTCOCK 06 Alias: P-06
84
Oil Rate (CD) ( bbl/d )
83
CV.CUMGASRate ( Mcf/d ) PITTCOCK 06
1981 82
40
CV.CUMGASRate ( Mcf/d )
1000
0
60
Oil Rate (CD) ( bbl/d ) PITTCOCK 06
40
CV.CUMGASRate ( Mcf/d )
800
CV.CUMOILRate ( bbl/d )
100
CV.CUMLIQrate ( bbl/d )
5.0
Oil Rate (CD) ( bbl/d )
Cumulative Water Prod : 112.33 Mbbl
Cumulative Water Inj : * Mbbl
50
0
CV.CUMWINJrate ( bbl/d )
ENERGY RESOURCES CORP.
1000
CV.CUMWATrate ( bbl/d )
CV.CUMWINJrate ( bbl/d ) PITTCOCK 06
CV.CUMWINJrate ( bbl/d )
Cumulative Oil Prod : 58.27 Mbbl
Cumulative Gas Prod : 6.20 MMcf
Cumulative Oil Prod : 58.27 Mbbl
Cumulative Gas Prod : 6.20 MMcf
ENERGY RESOURCES CORP.
Cumulative Water Prod : 112.33 Mbbl
Cumulative Water Inj : * Mbbl
3
250
10
50
Axis 1 PITTCOCK 06
Water / Oil Ratio ( bbl/bbl )
2
10
200
CHAN.DPrdWOR
CHAN.dprdworFIT
Axis 2
0
Oil Rate (CD) ( bbl/d ) PITTCOCK 06
10
150
40
CV.WORFIT
1
10
30
-1
10
100
20
-2
10
-3
10
50
10
-4
10
-5
0
10
0
10
2
10
3
4
10
5
10
CHAN.CumPrdDay s
PITTCOCK LEASE TEXAS
1
10
PITTCOCK 06
Cumulativ e Water/Oil Ratio ( bbl/bbl )
10
0
CHAN.DPrdWORCUM
-1
10
10
-2
-3
10
-4
10
10
-5
-6
10
10
2
3
10
10
4
5
10
CHAN.CumPrdDay s
PITTCOCK 06
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 57: Chan Plots for PITTCOCK 06 Alias: P-06
85
800
1.00
0.09
60
600
0.75
0.06
40
400
0.50
0.03
20
200
0.25
1981
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
Date
99
2000
01
02
03
04
05
06
07
08
09
10
11
12
13
0
14
PITTCOCK LEASE TEXAS
0.00
100
1000
0.12
80
800
1.00
0.09
60
600
0.75
0.06
40
400
0.50
0.03
20
200
0.25
0.00
0
0
0.00
1
5
10
Cumulativ e Oil Prod ( Mbbl )
50
100
1.25
PITTCOCK 07
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 58: Production for PITTCOCK 07 Alias: P-07
86
Wells on Oil Production
0.15
0
Wells on Oil Production PITTCOCK 07
80
Water Rate (CD) ( bbl/d )
0.12
Water Inj Rate (CD) ( bbl/d )
1.25
Oil Rate (CD) ( bbl/d )
1000
Wells on Oil Production
Cumulative Water Prod : 176.22 Mbbl
Cumulative Water Inj : * Mbbl
100
0.00
Gas / Oil Ratio ( Mcf/bbl )
ENERGY RESOURCES CORP.
0.15
Oil Rate (CD) per Well ( bbl/d )
Gas / Oil Ratio ( Mcf/bbl ) PITTCOCK 07
Gas / Oil Ratio ( Mcf/bbl )
Cumulative Oil Prod : 68.20 Mbbl
Cumulative Gas Prod : 6.91 MMcf
0.75
100
1200
0.12
80
0.60
80
60
0.45
40
0.30
0.15
20
0.00
0
900
600
0.09
0.06
Water / Oil Ratio ( bbl/bbl )
100
Oil Rate (CD) ( bbl/d )
0.15
60
40
300
0.03
20
0
0.00
0
1500
0.15
100
0.75
100
1200
0.12
80
0.60
80
60
0.45
40
0.30
0.15
20
0.00
0
1981
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
Date
99 2000 01
02
03
04
05
06
07
08
09
10
11
12
13
14
Water Cut ( % )
Cumulative Water Prod : 176.22 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1500
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
Cumulative Oil Prod : 68.20 Mbbl
Cumulative Gas Prod : 6.91 MMcf
300
0.03
20
0
0.00
0
1
5
10
50
Cumulativ e Water Prod ( Mbbl )
100
500
1000
60
40
PITTCOCK 07
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 59: Fluid Ratios s for PITTCOCK 07 Alias: P-07
87
Water Cut ( % )
0.06
Water / Oil Ratio ( bbl/bbl )
600
0.09
Oil Rate (CD) ( bbl/d )
900
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
PITTCOCK LEASE TEXAS
8
80
240
160
0.8
900
6
60
180
120
0.6
40
120
80
0.4
20
60
40
0.2
8
900
6
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
Date
99 2000 01
02
03
04
05
06
07
08
09
10
11
12
13
Krg_Kro PITTCOCK 07
83
0
PITTCOCK LEASE TEXAS
0
0.0
100
300
200
80
240
160
0.8
60
180
120
0.6
40
120
80
0.4
60
40
0.2
0
0
0.0
600
4
300
2
20
0
0
0
1
5
10
Cumulativ e Oil Prod ( Kbbl )
50
100
1.0
PITTCOCK 07
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 60: Field Relative Permeability for PITTCOCK 07 Alias: P-07
88
Wells on Oil Production
1200
1981 82
Krg_Kro PITTCOCK 07
10
0
Krg_Kro
1500
0
Krg_Kro
2
Oil Rate (CD) ( bbl/d ) PITTCOCK 07
300
Oil Rate (CD) ( bbl/d )
4
Krw_Kro PITTCOCK 07
600
Wells on Oil Production PITTCOCK 07
1200
Wells on Oil Production
1.0
Krg_Kro
200
Krg_Kro
300
Oil Rate (CD) ( bbl/d )
100
Krw_Kro
10
Krw_Kro
Water Inj Rate (CD) ( bbl/d )
Cumulative Water Prod : 176.22 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1500
0
Water Inj Rate (CD) ( bbl/d )
Water Inj Rate (CD) ( bbl/d ):Completion: PITTCOCK 11
Cumulative Oil Prod : 68.20 Mbbl
Cumulative Gas Prod : 6.91 MMcf
4.0
80
600
24
3.0
400
16
2.0
200
8
1.0
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
Date
99
2000
01
02
03
04
05
06
07
08
09
10
11
12
0.0
13
PITTCOCK LEASE TEXAS
20
0
40
5.0
800
32
4.0
600
24
3.0
400
16
2.0
200
8
1.0
20
0
0
0.0
0
1
5
10
Cumulativ e Oil Prod ( Kbbl )
50
100
100
80
60
40
PITTCOCK 07
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 61: Cumulative Rates for PITTCOCK 07 Alias: P-07
89
Oil Rate (CD) ( bbl/d )
83
CV.CUMGASRate ( Mcf/d ) PITTCOCK 07
1981 82
40
CV.CUMGASRate ( Mcf/d )
1000
0
60
Oil Rate (CD) ( bbl/d ) PITTCOCK 07
32
CV.CUMGASRate ( Mcf/d )
800
CV.CUMOILRate ( bbl/d )
100
CV.CUMLIQrate ( bbl/d )
5.0
Oil Rate (CD) ( bbl/d )
Cumulative Water Prod : 176.22 Mbbl
Cumulative Water Inj : * Mbbl
40
0
CV.CUMWINJrate ( bbl/d )
ENERGY RESOURCES CORP.
1000
CV.CUMWATrate ( bbl/d )
CV.CUMWINJrate ( bbl/d ) PITTCOCK 07
CV.CUMWINJrate ( bbl/d )
Cumulative Oil Prod : 68.20 Mbbl
Cumulative Gas Prod : 6.91 MMcf
Cumulative Oil Prod : 68.20 Mbbl
Cumulative Gas Prod : 6.91 MMcf
ENERGY RESOURCES CORP.
Cumulative Water Prod : 176.22 Mbbl
Cumulative Water Inj : * Mbbl
3
250
10
60
Axis 1 PITTCOCK 07
Water / Oil Ratio ( bbl/bbl )
2
10
200
CHAN.DPrdWOR
CV.WORFIT
1
10
0
Oil Rate (CD) ( bbl/d ) PITTCOCK 07
10
150
45
CHAN.dprdworFIT
Axis 2
-1
10
100
30
-2
10
-3
10
15
50
-4
10
-5
0
10
0
100
500
1000
CHAN.CumPrdDay s
5000
10000
5000
10000
PITTCOCK LEASE TEXAS
1
10
PITTCOCK 07
Cumulativ e Water/Oil Ratio ( bbl/bbl )
10
0
CHAN.DPrdWORCUM
-1
10
-2
10
10
-3
-4
10
10
10
-5
-6
-7
10
100
500
1000
CHAN.CumPrdDay s
PITTCOCK 07
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 62: Chan Plots for PITTCOCK 07 Alias: P-07
90
800
0.8
0.24
60
600
0.6
0.16
40
400
0.4
0.08
20
200
0.2
1981
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
Date
2000
01
02
03
04
05
06
07
08
09
10
11
12
13
14
0
15
PITTCOCK LEASE TEXAS
0.0
100
1000
0.32
80
800
0.8
0.24
60
600
0.6
0.16
40
400
0.4
0.08
20
200
0.2
0.00
0
0
0.0
1
5
10
Cumulativ e Oil Prod ( Mbbl )
50
100
1.0
PITTCOCK 08
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 63: Production for PITTCOCK 08 Alias: P-08
91
Wells on Oil Production
0.40
0
Wells on Oil Production PITTCOCK 08
80
Water Rate (CD) ( bbl/d )
0.32
Water Inj Rate (CD) ( bbl/d )
1.0
Oil Rate (CD) ( bbl/d )
1000
Wells on Oil Production
Cumulative Water Prod : 531.39 Mbbl
Cumulative Water Inj : * Mbbl
100
0.00
Gas / Oil Ratio ( Mcf/bbl )
ENERGY RESOURCES CORP.
0.40
Oil Rate (CD) per Well ( bbl/d )
Gas / Oil Ratio ( Mcf/bbl ) PITTCOCK 08
Gas / Oil Ratio ( Mcf/bbl )
Cumulative Oil Prod : 96.14 Mbbl
Cumulative Gas Prod : 9.16 MMcf
0.75
100
1200
0.32
80
0.60
80
60
0.45
40
0.30
0.15
20
0.00
0
900
600
0.24
0.16
Water / Oil Ratio ( bbl/bbl )
100
Oil Rate (CD) ( bbl/d )
0.40
60
40
300
0.08
20
0
0.00
0
1500
0.40
100
0.75
100
1200
0.32
80
0.60
80
60
0.45
40
0.30
0.15
20
0.00
0
1981
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98 99 2000 01
Date
02
03
04
05
06
07
08
09
10
11
12
13
14
15
Water Cut ( % )
Cumulative Water Prod : 531.39 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1500
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
Cumulative Oil Prod : 96.14 Mbbl
Cumulative Gas Prod : 9.16 MMcf
300
0.08
20
0
0.00
0
1
5
10
50
Cumulativ e Water Prod ( Mbbl )
100
500
1000
60
40
PITTCOCK 08
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 64: Fluid Ratios s for PITTCOCK 08 Alias: P-08
92
Water Cut ( % )
0.16
Water / Oil Ratio ( bbl/bbl )
600
0.24
Oil Rate (CD) ( bbl/d )
900
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
PITTCOCK LEASE TEXAS
8
80
240
160
0.8
900
6
60
180
120
0.6
40
120
80
0.4
20
60
40
0.2
8
900
6
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98 99 2000 01
Date
02
03
04
05
06
07
08
09
10
11
12
13
Krg_Kro PITTCOCK 08
83
0
PITTCOCK LEASE TEXAS
0
0.0
100
300
200
80
240
160
0.8
60
180
120
0.6
40
120
80
0.4
60
40
0.2
0
0
0.0
600
4
300
2
20
0
0
0
1
5
10
Cumulativ e Oil Prod ( Kbbl )
50
100
1.0
PITTCOCK 08
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 65: Field Relative Permeability for PITTCOCK 08 Alias: P-08
93
Wells on Oil Production
1200
1981 82
Krg_Kro PITTCOCK 08
10
0
Krg_Kro
1500
0
Krg_Kro
2
Oil Rate (CD) ( bbl/d ) PITTCOCK 08
300
Oil Rate (CD) ( bbl/d )
4
Krw_Kro PITTCOCK 08
600
Wells on Oil Production PITTCOCK 08
1200
Wells on Oil Production
1.0
Krg_Kro
200
Krg_Kro
300
Oil Rate (CD) ( bbl/d )
100
Krw_Kro
10
Krw_Kro
Water Inj Rate (CD) ( bbl/d )
Cumulative Water Prod : 531.39 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1500
0
Water Inj Rate (CD) ( bbl/d )
Water Inj Rate (CD) ( bbl/d ):Completion: PITTCOCK 11
Cumulative Oil Prod : 96.14 Mbbl
Cumulative Gas Prod : 9.16 MMcf
4.0
80
600
45
3.0
400
30
2.0
200
15
1.0
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
Date
99
2000
01
02
03
04
05
06
07
08
09
10
11
12
0.0
13
PITTCOCK LEASE TEXAS
20
0
75
5.0
800
60
4.0
600
45
3.0
400
30
2.0
200
15
1.0
20
0
0
0.0
0
1
5
10
Cumulativ e Oil Prod ( Kbbl )
50
100
100
80
60
40
PITTCOCK 08
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 66: Cumulative Rates for PITTCOCK 08 Alias: P-08
94
Oil Rate (CD) ( bbl/d )
83
CV.CUMGASRate ( Mcf/d ) PITTCOCK 08
1981 82
40
CV.CUMGASRate ( Mcf/d )
1000
0
60
Oil Rate (CD) ( bbl/d ) PITTCOCK 08
60
CV.CUMGASRate ( Mcf/d )
800
CV.CUMOILRate ( bbl/d )
100
CV.CUMLIQrate ( bbl/d )
5.0
Oil Rate (CD) ( bbl/d )
Cumulative Water Prod : 531.39 Mbbl
Cumulative Water Inj : * Mbbl
75
0
CV.CUMWINJrate ( bbl/d )
ENERGY RESOURCES CORP.
1000
CV.CUMWATrate ( bbl/d )
CV.CUMWINJrate ( bbl/d ) PITTCOCK 08
CV.CUMWINJrate ( bbl/d )
Cumulative Oil Prod : 96.14 Mbbl
Cumulative Gas Prod : 9.16 MMcf
Cumulative Oil Prod : 96.14 Mbbl
Cumulative Gas Prod : 9.16 MMcf
ENERGY RESOURCES CORP.
Cumulative Water Prod : 531.39 Mbbl
Cumulative Water Inj : * Mbbl
3
250
10
100
Axis 1 PITTCOCK 08
Water / Oil Ratio ( bbl/bbl )
2
10
200
CHAN.DPrdWOR
CHAN.dprdworFIT
Axis 2
0
Oil Rate (CD) ( bbl/d ) PITTCOCK 08
10
150
80
CV.WORFIT
1
10
60
-1
10
100
40
-2
10
-3
10
50
20
-4
10
-5
0
10
0
10
2
10
3
4
10
5
10
CHAN.CumPrdDay s
PITTCOCK LEASE TEXAS
1
10
PITTCOCK 08
Cumulativ e Water/Oil Ratio ( bbl/bbl )
10
0
CHAN.DPrdWORCUM
-1
10
10
-2
-3
10
-4
10
10
-5
-6
10
10
2
3
10
10
4
5
10
CHAN.CumPrdDay s
PITTCOCK 08
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 67: Chan Plots for PITTCOCK 08 Alias: P-08
95
800
0.8
0.30
60
600
0.6
0.20
40
400
0.4
0.10
20
200
0.2
1982
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99 2000
Date
01
02
03
04
05
06
07
08
09
10
11
12
13
14
0
15
PITTCOCK LEASE TEXAS
0.0
100
1000
0.40
80
800
0.8
0.30
60
600
0.6
0.20
40
400
0.4
0.10
20
200
0.2
0.00
0
0
0.0
1
5
10
Cumulativ e Oil Prod ( Mbbl )
50
100
1.0
PITTCOCK 10
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 68: Production for PITTCOCK 10 Alias: P-10
96
Wells on Oil Production
0.50
0
Wells on Oil Production PITTCOCK 10
80
Water Rate (CD) ( bbl/d )
0.40
Water Inj Rate (CD) ( bbl/d )
1.0
Oil Rate (CD) ( bbl/d )
1000
Wells on Oil Production
Cumulative Water Prod : 174.39 Mbbl
Cumulative Water Inj : * Mbbl
100
0.00
Gas / Oil Ratio ( Mcf/bbl )
ENERGY RESOURCES CORP.
0.50
Oil Rate (CD) per Well ( bbl/d )
Gas / Oil Ratio ( Mcf/bbl ) PITTCOCK 10
Gas / Oil Ratio ( Mcf/bbl )
Cumulative Oil Prod : 35.51 Mbbl
Cumulative Gas Prod : 2.67 MMcf
0.75
100
1200
0.40
80
0.60
80
60
0.45
40
0.30
0.15
20
0.00
0
900
600
0.30
0.20
Water / Oil Ratio ( bbl/bbl )
100
Oil Rate (CD) ( bbl/d )
0.50
60
40
300
0.10
20
0
0.00
0
1500
0.50
100
0.75
100
1200
0.40
80
0.60
80
60
0.45
40
0.30
0.15
20
0.00
0
1982
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99 2000 01
Date
02
03
04
05
06
07
08
09
10
11
12
13
14
15
Water Cut ( % )
Cumulative Water Prod : 174.39 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1500
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
Cumulative Oil Prod : 35.51 Mbbl
Cumulative Gas Prod : 2.67 MMcf
300
0.10
20
0
0.00
0
1
5
10
50
Cumulativ e Water Prod ( Mbbl )
100
500
1000
60
40
PITTCOCK 10
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 69: Fluid Ratios s for PITTCOCK 10 Alias: PITTCOCK 10
97
Water Cut ( % )
0.20
Water / Oil Ratio ( bbl/bbl )
600
0.30
Oil Rate (CD) ( bbl/d )
900
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
PITTCOCK LEASE TEXAS
8
80
240
160
0.8
900
6
60
180
120
0.6
40
120
80
0.4
20
60
40
0.2
8
900
6
85
86
87
88
89
90
91
92
93
94
95
96
97
98 99 2000 01
Date
02
03
04
05
06
07
08
09
10
11
12
13
Krg_Kro PITTCOCK 10
84
0
PITTCOCK LEASE TEXAS
0
0.0
100
300
200
80
240
160
0.8
60
180
120
0.6
40
120
80
0.4
60
40
0.2
0
0
0.0
600
4
300
2
20
0
0
0
1
5
10
Cumulativ e Oil Prod ( Kbbl )
50
100
1.0
PITTCOCK 10
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 70: Field Relative Permeability for PITTCOCK 10 Alias: P-10
98
Wells on Oil Production
1200
83
Krg_Kro PITTCOCK 10
10
0
Krg_Kro
1500
0
Krg_Kro
2
Oil Rate (CD) ( bbl/d ) PITTCOCK 10
300
Oil Rate (CD) ( bbl/d )
4
Krw_Kro PITTCOCK 10
600
Wells on Oil Production PITTCOCK 10
1200
Wells on Oil Production
1.0
Krg_Kro
200
Krg_Kro
300
Oil Rate (CD) ( bbl/d )
100
Krw_Kro
10
Krw_Kro
Water Inj Rate (CD) ( bbl/d )
Cumulative Water Prod : 174.39 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1500
0
Water Inj Rate (CD) ( bbl/d )
Water Inj Rate (CD) ( bbl/d ):Completion: PITTCOCK 11
Cumulative Oil Prod : 35.51 Mbbl
Cumulative Gas Prod : 2.67 MMcf
4.0
80
600
15
3.0
400
10
2.0
200
5
1.0
85
86
87
88
89
90
91
92
93
94
95
96
97
98
Date
99
2000
01
02
03
04
05
06
07
08
09
10
11
12
0.0
13
PITTCOCK LEASE TEXAS
20
0
25
5.0
800
20
4.0
600
15
3.0
400
10
2.0
200
5
1.0
20
0
0
0.0
0
1
5
10
Cumulativ e Oil Prod ( Kbbl )
50
100
100
80
60
40
PITTCOCK 10
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 71: Cumulative Rates for PITTCOCK 10 Alias: P-10
99
Oil Rate (CD) ( bbl/d )
84
CV.CUMGASRate ( Mcf/d ) PITTCOCK 10
83
40
CV.CUMGASRate ( Mcf/d )
1000
0
60
Oil Rate (CD) ( bbl/d ) PITTCOCK 10
20
CV.CUMGASRate ( Mcf/d )
800
CV.CUMOILRate ( bbl/d )
100
CV.CUMLIQrate ( bbl/d )
5.0
Oil Rate (CD) ( bbl/d )
Cumulative Water Prod : 174.39 Mbbl
Cumulative Water Inj : * Mbbl
25
0
CV.CUMWINJrate ( bbl/d )
ENERGY RESOURCES CORP.
1000
CV.CUMWATrate ( bbl/d )
CV.CUMWINJrate ( bbl/d ) PITTCOCK 10
CV.CUMWINJrate ( bbl/d )
Cumulative Oil Prod : 35.51 Mbbl
Cumulative Gas Prod : 2.67 MMcf
Cumulative Oil Prod : 35.51 Mbbl
Cumulative Gas Prod : 2.67 MMcf
ENERGY RESOURCES CORP.
Cumulative Water Prod : 174.39 Mbbl
Cumulative Water Inj : * Mbbl
2
250
10
75
Axis 1 PITTCOCK 10
Water / Oil Ratio ( bbl/bbl )
1
10
CHAN.DPrdWOR
200
60
CV.WORFIT
CHAN.dprdworFIT
0
10
Axis 2
Oil Rate (CD) ( bbl/d ) PITTCOCK 10
150
45
-1
10
-2
10
100
30
-3
10
50
15
-4
10
-5
0
10
0
100
500
1000
CHAN.CumPrdDay s
5000
10000
5000
10000
PITTCOCK LEASE TEXAS
1
10
PITTCOCK 10
Cumulativ e Water/Oil Ratio ( bbl/bbl )
10
0
CHAN.DPrdWORCUM
-1
10
10
-2
-3
10
-4
10
10
-5
-6
10
100
500
1000
CHAN.CumPrdDay s
PITTCOCK 10
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 72: Chan Plots for PITTCOCK 10 Alias: P-10
100
800
1.00
0.09
60
600
0.75
0.06
40
400
0.50
0.03
20
200
0.25
1983
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
2000
Date
01
02
03
04
05
06
07
08
09
10
11
12
13
0
14
PITTCOCK LEASE TEXAS
0.00
100
1000
0.12
80
800
1.00
0.09
60
600
0.75
0.06
40
400
0.50
0.03
20
200
0.25
0.00
0
0
0.00
1
5
10
Cumulativ e Oil Prod ( Mbbl )
50
100
PITTCOCK 11
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 73: Production for PITTCOCK 11 Alias: P-11
101
1.25
Wells on Oil Production
0.15
0
Wells on Oil Production PITTCOCK 11
80
Water Rate (CD) ( bbl/d )
0.12
Water Inj Rate (CD) ( bbl/d )
1.25
Oil Rate (CD) ( bbl/d )
1000
Wells on Oil Production
Cumulative Water Prod : 2.13 Mbbl
Cumulative Water Inj : 2604.76 Mbbl
100
0.00
Gas / Oil Ratio ( Mcf/bbl )
ENERGY RESOURCES CORP.
0.15
Oil Rate (CD) per Well ( bbl/d )
Gas / Oil Ratio ( Mcf/bbl ) PITTCOCK 11
Gas / Oil Ratio ( Mcf/bbl )
Cumulative Oil Prod : 15.16 Mbbl
Cumulative Gas Prod : 1.36 MMcf
Cumulative Water Prod : 2.13 Mbbl
Cumulative Water Inj : 2604.76 Mbbl
0.75
36
1200
0.12
80
0.60
30
60
0.45
40
0.30
0.15
12
0.00
6
900
600
0.09
0.06
Water / Oil Ratio ( bbl/bbl )
100
Oil Rate (CD) ( bbl/d )
0.15
24
18
300
0.03
20
0
0.00
0
1500
0.15
100
0.75
36
1200
0.12
80
0.60
30
60
0.45
40
0.30
0.15
12
0.00
6
1983
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
Date
2000
01
02
03
04
05
06
07
08
09
10
11
12
13
14
Water Cut ( % )
ENERGY RESOURCES CORP.
1500
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
Cumulative Oil Prod : 15.16 Mbbl
Cumulative Gas Prod : 1.36 MMcf
300
0.03
20
0
0.00
0
1
5
10
24
18
Cumulativ e Water Prod ( Mbbl )
PITTCOCK 11
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 74: Fluid Ratios s for PITTCOCK 11 Alias: P-11
102
Water Cut ( % )
0.06
Water / Oil Ratio ( bbl/bbl )
600
0.09
Oil Rate (CD) ( bbl/d )
900
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
PITTCOCK LEASE TEXAS
8
80
240
160
0.8
900
6
60
180
120
0.6
40
120
80
0.4
20
60
40
0.2
8
900
6
86
87
88
89
90
91
92
93
94
95
96
97
98
99 2000 01
Date
02
03
04
05
06
07
08
09
10
11
12
13
Krg_Kro PITTCOCK 11
85
0
PITTCOCK LEASE TEXAS
0
0.0
100
300
200
80
240
160
0.8
60
180
120
0.6
40
120
80
0.4
60
40
0.2
0
0
0.0
600
4
300
2
20
0
0
0
1
5
10
Cumulativ e Oil Prod ( Kbbl )
50
100
PITTCOCK 11
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 75: Field Relative Permeability for PITTCOCK 11 Alias: P-11
103
1.0
Wells on Oil Production
1200
1983 84
Krg_Kro PITTCOCK 11
10
0
Krg_Kro
1500
0
Krg_Kro
2
Oil Rate (CD) ( bbl/d ) PITTCOCK 11
300
Oil Rate (CD) ( bbl/d )
4
Krw_Kro PITTCOCK 11
600
Wells on Oil Production PITTCOCK 11
1200
Wells on Oil Production
1.0
Krg_Kro
200
Krg_Kro
300
Oil Rate (CD) ( bbl/d )
100
Krw_Kro
10
Krw_Kro
Water Inj Rate (CD) ( bbl/d )
Cumulative Water Prod : 2.13 Mbbl
Cumulative Water Inj : 2604.76 Mbbl
ENERGY RESOURCES CORP.
1500
0
Water Inj Rate (CD) ( bbl/d )
Water Inj Rate (CD) ( bbl/d ):Completion: PITTCOCK 11
Cumulative Oil Prod : 15.16 Mbbl
Cumulative Gas Prod : 1.36 MMcf
4.0
80
600
18
3.0
400
12
2.0
200
6
1.0
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
Date
2000
01
02
03
04
05
06
07
08
09
10
11
12
0.0
13
PITTCOCK LEASE TEXAS
20
0
30
5.0
800
24
4.0
600
18
3.0
400
12
2.0
200
6
1.0
20
0
0
0.0
0
1
5
10
Cumulativ e Oil Prod ( Kbbl )
50
100
100
80
60
40
PITTCOCK 11
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 76: Cumulative Rates for PITTCOCK 11 Alias: P-11
104
Oil Rate (CD) ( bbl/d )
84
CV.CUMGASRate ( Mcf/d ) PITTCOCK 11
1983
40
CV.CUMGASRate ( Mcf/d )
1000
0
60
Oil Rate (CD) ( bbl/d ) PITTCOCK 11
24
CV.CUMGASRate ( Mcf/d )
800
CV.CUMOILRate ( bbl/d )
100
CV.CUMLIQrate ( bbl/d )
5.0
Oil Rate (CD) ( bbl/d )
Cumulative Water Prod : 2.13 Mbbl
Cumulative Water Inj : 2604.76 Mbbl
30
0
CV.CUMWINJrate ( bbl/d )
ENERGY RESOURCES CORP.
1000
CV.CUMWATrate ( bbl/d )
CV.CUMWINJrate ( bbl/d ) PITTCOCK 11
CV.CUMWINJrate ( bbl/d )
Cumulative Oil Prod : 15.16 Mbbl
Cumulative Gas Prod : 1.36 MMcf
Cumulative Oil Prod : 15.16 Mbbl
Cumulative Gas Prod : 1.36 MMcf
ENERGY RESOURCES CORP.
Cumulative Water Prod : 2.13 Mbbl
Cumulative Water Inj : 2604.76 Mbbl
0
250
10
30
Axis 1 PITTCOCK 11
Water / Oil Ratio ( bbl/bbl )
CHAN.DPrdWOR
-1
200
10
24
CV.WORFIT
CHAN.dprdworFIT
Axis 2
Oil Rate (CD) ( bbl/d ) PITTCOCK 11
-2
150
10
100
10
50
10
0
10
18
-3
12
-4
6
-5
0
100
500
1000
CHAN.CumPrdDay s
5000
10000
5000
10000
PITTCOCK LEASE TEXAS
0
10
PITTCOCK 11
Cumulativ e Water/Oil Ratio ( bbl/bbl )
CHAN.DPrdWORCUM
-1
10
10
-2
-3
10
10
-4
-5
10
100
500
1000
CHAN.CumPrdDay s
PITTCOCK 11
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 77: Chan Plots for PITTCOCK 11 Alias: P-11
105
800
0.8
0.09
60
600
0.6
0.06
40
400
0.4
0.03
20
200
0.2
1983
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
2000
Date
01
02
03
04
05
06
07
08
09
10
11
12
13
0
14
PITTCOCK LEASE TEXAS
0.0
100
1000
0.12
80
800
0.8
0.09
60
600
0.6
0.06
40
400
0.4
0.03
20
200
0.2
0.00
0
0
0.0
1
5
10
Cumulativ e Oil Prod ( Mbbl )
50
100
PITTCOCK 12
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 78: Production for PITTCOCK 12 Alias: P-12
106
1.0
Wells on Oil Production
0.15
0
Wells on Oil Production PITTCOCK 12
80
Wells on Oil Production
0.12
Water Rate (CD) ( bbl/d )
1.0
Water Inj Rate (CD) ( bbl/d )
1000
Oil Rate (CD) ( bbl/d )
100
0.00
Gas / Oil Ratio ( Mcf/bbl )
Cumulative Water Prod : 3.35 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
0.15
Oil Rate (CD) per Well ( bbl/d )
Gas / Oil Ratio ( Mcf/bbl ) PITTCOCK 12
Gas / Oil Ratio ( Mcf/bbl )
Cumulative Oil Prod : 16.83 Mbbl
Cumulative Gas Prod : 1.53 MMcf
0.75
75
1200
0.12
80
0.60
60
60
0.45
40
0.30
0.15
15
0.00
0
900
600
0.09
0.06
Water / Oil Ratio ( bbl/bbl )
100
Oil Rate (CD) ( bbl/d )
0.15
45
30
300
0.03
20
0
0.00
0
1500
0.15
100
0.75
75
1200
0.12
80
0.60
60
60
0.45
40
0.30
0.15
15
0.00
0
1983
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
Date
2000
01
02
03
04
05
06
07
08
09
10
11
12
13
14
Water Cut ( % )
Cumulative Water Prod : 3.35 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1500
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
Cumulative Oil Prod : 16.83 Mbbl
Cumulative Gas Prod : 1.53 MMcf
300
0.03
20
0
0.00
0
1
5
10
45
30
Cumulativ e Water Prod ( Mbbl )
PITTCOCK 12
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 79: Fluid Ratios s for PITTCOCK 12 Alias: P-12
107
Water Cut ( % )
0.06
Water / Oil Ratio ( bbl/bbl )
600
0.09
Oil Rate (CD) ( bbl/d )
900
Gas / Oil Ratio ( Mcf/bbl )
Water Inj Rate (CD) ( bbl/d )
PITTCOCK LEASE TEXAS
8
80
240
160
0.8
900
6
60
180
120
0.6
40
120
80
0.4
20
60
40
0.2
8
900
6
86
87
88
89
90
91
92
93
94
95
96
97
98
99 2000 01
Date
02
03
04
05
06
07
08
09
10
11
12
13
Krg_Kro PITTCOCK 12
85
0
PITTCOCK LEASE TEXAS
0
0.0
100
300
200
80
240
160
0.8
60
180
120
0.6
40
120
80
0.4
60
40
0.2
0
0
0.0
600
4
300
2
20
0
0
0
1
5
10
Cumulativ e Oil Prod ( Kbbl )
50
100
PITTCOCK 12
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 80: Field Relative Permeability for PITTCOCK 12 Alias: P-12
108
1.0
Wells on Oil Production
1200
1983 84
Krg_Kro PITTCOCK 12
10
0
Krg_Kro
1500
0
Krg_Kro
2
Oil Rate (CD) ( bbl/d ) PITTCOCK 12
300
Oil Rate (CD) ( bbl/d )
4
Krw_Kro PITTCOCK 12
600
Wells on Oil Production PITTCOCK 12
1200
Wells on Oil Production
1.0
Krg_Kro
200
Krg_Kro
300
Oil Rate (CD) ( bbl/d )
100
Krw_Kro
10
Krw_Kro
Water Inj Rate (CD) ( bbl/d )
Cumulative Water Prod : 3.35 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1500
0
Water Inj Rate (CD) ( bbl/d )
Water Inj Rate (CD) ( bbl/d ):Completion: PITTCOCK 11
Cumulative Oil Prod : 16.83 Mbbl
Cumulative Gas Prod : 1.53 MMcf
4.0
80
600
18
3.0
400
12
2.0
200
6
1.0
85
86
87
88
89
90
91
92
93
94
95
96
97
98
Date
99
2000
01
02
03
04
05
06
07
08
09
10
11
12
0.0
13
PITTCOCK LEASE TEXAS
20
0
30
5.0
800
24
4.0
600
18
3.0
400
12
2.0
200
6
1.0
20
0
0
0.0
0
1
5
10
Cumulativ e Oil Prod ( Kbbl )
50
100
100
80
60
40
PITTCOCK 12
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 81: Cumulative Rates for PITTCOCK 12 Alias: P-12
109
Oil Rate (CD) ( bbl/d )
84
CV.CUMGASRate ( Mcf/d ) PITTCOCK 12
1983
40
CV.CUMGASRate ( Mcf/d )
1000
0
60
Oil Rate (CD) ( bbl/d ) PITTCOCK 12
24
Oil Rate (CD) ( bbl/d )
800
CV.CUMGASRate ( Mcf/d )
100
CV.CUMOILRate ( bbl/d )
5.0
CV.CUMLIQrate ( bbl/d )
30
0
CV.CUMWINJrate ( bbl/d )
Cumulative Water Prod : 3.35 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1000
CV.CUMWATrate ( bbl/d )
CV.CUMWINJrate ( bbl/d ) PITTCOCK 12
CV.CUMWINJrate ( bbl/d )
Cumulative Oil Prod : 16.83 Mbbl
Cumulative Gas Prod : 1.53 MMcf
Cumulative Oil Prod : 16.83 Mbbl
Cumulative Gas Prod : 1.53 MMcf
Cumulative Water Prod : 3.35 Mbbl
Cumulative Water Inj : * Mbbl
ENERGY RESOURCES CORP.
1
250
10
30
Axis 1 PITTCOCK 12
Water / Oil Ratio ( bbl/bbl )
0
CHAN.DPrdWOR
10
200
24
CV.WORFIT
CHAN.dprdworFIT
-1
Axis 2
10
Oil Rate (CD) ( bbl/d ) PITTCOCK 12
150
18
-2
10
100
12
-3
10
50
6
-4
10
-5
0
10
0
100
500
1000
CHAN.CumPrdDay s
5000
10000
5000
10000
PITTCOCK LEASE TEXAS
0
10
PITTCOCK 12
Cumulativ e Water/Oil Ratio ( bbl/bbl )
CHAN.DPrdWORCUM
-1
10
10
-2
-3
10
10
-4
-5
10
100
500
1000
CHAN.CumPrdDay s
PITTCOCK 12
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 82: Chan Plots for PITTCOCK 12 Alias: P-12
110
Permex Petroleum’s
PETROPHYSICL EVALUATION SHEET
WELL NAME
ELEVATION: KB
FROMATION
Net thickness
based on the
following cutoffs:
PITTCOCK # 14
TD
3030 ft
Rw
1779 ft SS
EVALUATION SUMMARY
TOP
2957 ft KB
Upper Tannehill
°API< 70
KB
Ø>
0.021 Ω m
15.00
@
Bottom
2962 ft KB
NET
THICKNESS
5
ft
øave
Swavg
19.35
10.42
%
%
FRF(F)
Rt (Ωm)
Sw (%)
Sw <
50.00 %
128 °F
EVALUATION BREAKDOWN
Interval (ft)
ft
2957
2958
1
2958
2959
2960
2961
2959
2960
2961
2962
1
1
1
1
ØD (%) ØN (%) Øavg (%)
17.5
21.0
21.0
17.0
15.0
20.0
18.8
28.4
40.0
12.2
20.5
21.5
20.5
19.5
20.75
21.25
18.75
17.25
23.2
22.1
28.4
33.6
50.0
55.0
60.0
60.0
9.9
9.2
10.0
10.8
Conclusion
(Pay, Wet,
Tight)
Pay
Pay
Pay
Pay
Pay
Table 5: Pittcock # 14 Upper Formation Log Petro-Physical Analysis.
111
Permex Petroleum’s
PETROPHYSICL EVALUATION SHEET
WELL NAME
ELEVATION: KB
FROMATION
Net thickness
based on the
following cutoffs:
PITTCOCK # 14
TD
3030 ft
Rw
1779 ft SS
EVALUATION SUMMARY
TOP
2979 ft KB
Lower Tannehill
°API< 70
KB
Ø>
Ω
m
0.021
15.00
@
Sw <
50.00 %
128 °F
Bottom
2986 ft KB
NET
THICKNESS
8
ft
øave
Swavg
23.59
39.91
%
%
EVALUATION BREAKDOWN
Interval (ft)
ft
2978
2979
1
2979
2980
2981
2982
2983
2984
2985
2980
2981
2982
2983
2984
2985
2986
1
1
1
1
1
1
1
ØD (%) ØN (%)
24.0
27.0
26.5
27.8
26.2
26.5
24.0
20.0
Øavg (%)
FRF(F)
Rt (Ωm)
Sw (%)
24.0
24.0
17.4
3.1
34.6
23.0
21.8
21.8
21.0
21.0
23.0
20.0
25.00
24.13
24.75
23.60
23.75
23.50
20.00
16.0
17.2
16.3
18.0
17.7
18.1
25.0
3.0
2.6
2.5
2.1
2.0
2.0
2.3
33.5
37.3
37.0
42.9
43.1
43.2
47.8
Conclusion
(Pay, Wet,
Tight)
Pay
Pay
Pay
Pay
Pay
Pay
Pay
Pay
Table 6: Pittcock # 14 Lower Formation Log Petro-Physical Analysis.
112
REVISED APPENDIX
113
Figure 83: Revised Cumulative oil production map (Mbbl) for the entire producing pool (19 wells).
114
Figure 84: Revised Cumulative gas production map (MMcf) for the entire pool (19 wells).
115
Figure 85: Revised Cumulative water production map (Mbbl) for the entire pool (19 wells).
116
Figure 86: Revised Cumulative Liquid production map (Mbbl) for the entire pool (19 wells).
117
Figure 87: Revised Cumulative water injected production map (Mbbl) for the entire pool (19 wells).
118
Figure 88: Revised Cumulative water injection and liquid production map (Mbbl) for the entire pool (19 wells).
119
Figure 89: Revised Cumulative oil production rate map (bbl/d) for the entire pool (19 wells).
120
Figure 90: Revised Cumulative gas production rate map (Mcf/d) for the entire pool (19 wells).
121
Figure 91: Revised Cumulative water production rate map (bbl/d) for the entire pool (19 wells).
122
Figure 92: Revised Cumulative liquid production rate map (bbl/d) for the entire pool (19 wells).
123
Figure 93: Revised Calendar day oil production rate map (bbl/d) for the entire pool (19 wells).
124
ENERGY RESOURCES CORP.
PITTCOCK LEASE TEXAS
Gas Rate (CD) ( Mcf/d )
0.00
0.50
1.00
14207B0161731
14207B0163691
14207B0193744A
14207B0163693
Date:6/30/2015
Cumulative Oil Prod : 839.23 Kbbl
Cumulative Gas Prod : 67.62 Mcf
Cumulative Water Prod : 2286.53 Kbbl
14207B0156192/R
14207B0193742
14207B0163694
14207B0163696
Cumulative Water Inj : 3307.85 Kbbl
14207B01636913WS
14207B01636913
14207B01617312
14207B01636912
14207B0163698
14207B0163697
14207B0163695
14207B0193743
14207B01617310
14207B01636910
14207B027675C//3
14207B02790711
14207B0193744
14207B0200343
14207B0180371
14207B0271741
14207B0279071
14207B0180372
14207B0271742
14207B0279072
14207B01617311
14207B01636911
14207B0193423
14207B0199363
14207B0279073
14207B0199366
14207B0219626
14207B0279076
REVISED PLOTS
ZONE: TANNEHILL, TANNEHILL UPPER(36) in Zoomed Area
DL PETROLEUM ENGINEERING AND CONSULTING LIMITED
Figure 94: Revised Calendar day gas production rate map (Mcf/d) for the entire pool (19 wells) – [No gas production
recorded].
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Figure 95: Revised Calendar day water production rate map (bbl/d) for the entire pool (19 wells).
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i
http://dleng.info/oil-gas-well-production-data-analysis/
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