Comprehensive Engineering Study of Columbus Reservoir ... Engineering Study of Columbus Reservoir ...

DISCUSSION

..

JAMES A . LEWIS ENGINEERING, INC. Petroleum Reservoir Anafysts

REPUBLIC NATIONAL BANK BUILDING

DALLAS I , TEXAS

April 26, 1957

Mr. V. O . Sims, Vice President Felmont Oil Corporation P. O. Box 602 Owensboro, Kentucky

Dear Mr. Sims:

...

A detailed engineering study has been made of the Columbus formation, Rodney field, Elgin County, Ontario, Canada, to analyze the future primary field performance and to determine the feasibility and desirability of instituting a field-wide water injection program to increase ultimate oil recovery. The area studied for this report include s the productive acreage of the Rodney field lying north of the center line of Concession VI.

As of March 1, 1957 remaining gross primary oil reserves to be produced from the portion of the Rodney field covered in this study were 2, 303 , 226 barrels to be recovered in 65 years .

Under a field-wide five-spot water injection program, the field gross oil reserves as of March 1, 1957 were calculated to be 5,758,036 barrels to be recovered in 15 years. This represents an increase in oil recovery of 3,454, 810 barrels over that to be anticipated from primary depletion.

Capital investments for injection wells, producing wells, water injection plant and water supply wells are estimated to be $403,883.

It has been a privilege to perform this study for you and we will be pleased to review any part of our work with you as desired.

Very truly yours,

JAMES A. LEWIS ENGINEERING, Inc.

~& James A. Lewis

JAL/mh

· .

TABLE OF CONTENTS

Page No .

INTRODUC TION

, Hi s tor y of Deve lopme nt - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 1

BASIC DATA Production History - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 3 Well Tests -------- -- ------------------------------ 3 Solution Gas Analysis ------------------------------- 4 Produced Water Analyses---------------------------- 4 Water Analysis - Glacial Drift ----------------------- 5 Reservoir Pressure Data ---------------------------- 5 Reservoir Temperature ----------------------------- 6 Core Analyses -------------------------------------- 6 Permeability and Capacity Distribution ---------------- 8 Water Cut - Recovery Relationship -------------------- 8 Interstitial Water Saturation -------------------------- 9 Flood Tests ----------------------------------------- 10 Reservoir Fluid Data -------------------------------- 11

GEOLOGY Ge ne r al - - - - - - - - - - - - - - - - - - - - - - - - - - .- - - - - - - - - - - - - - - - - - 12 Gross Oil Sand Thickness --------.~ -.------------------ 13 Net Oil Sand Thickness ------ -.- ------- - - ... - - ---.- - -- -- - 13 Oil-Water Contact ---------------------------------- 13 Reservoir Dimensions ------ - ------------------------ 14

RESER YES AND PERFORMANCE Primary Depletion - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 Water Injection Program ----------------------------- 15 Anomalous Well Performance ------------------------- 17

WATER INJECTION PLANT AND DISTRIBUTION SYSTEM Plant De sign - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 19 Water Distribution System ---------------------------- 21 Injection and Producing Wells ------------------------- 22

CONCL USIONS - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24

RECOMMENDA TIONS - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 25

· . r ....

'.

INTRODUC TION

The Rodney field is located in the southwestern part of Aldborough Town

ship, Elgin County, Ontario , Canada, approximately three miles north

west of the town of Rodney. The field is about midway between Lake Erie

to the south and the Thames River to the north.

The oil productive area analyzed in this study covers all or part of Lots

4, 5 and 6, Concessions IV, V and VI. One hundred twenty-one producing

oil wells and numerous surrounding dry holes have been drilled and com

pleted as of April 1 , 1957

History of Development The discovery well in the Rodney

field was completed by James Beattie

of Glencoe during 1949 in the Columbus formation at a depth of approximate-

ly 400 feet . Limited developmental drilling proceeded during the next

three year s but it was not until 1953 that the major development phase be

gan . During 1953, forty producing oil wells were completed in the area

being studied. The producing wells completed by lease by operator during

a given year are shown in Table 2 . The rate of development is graphically

presented on Figure 6. The annual field production through 1955 , as con-

-1 -

....

tained in the Second Annual Report of the Ontario Fuel Board (1955), includ

ing both the area analyzed and a somewhat smaller producing area to the

southwest , was as follows :

Year Annual Oil Production, Barrels

1949 1,147

1950 1,546

1951 4 , 050

1952 12,043

1953 126,400

1954 240 , 252

1955 354 , 903

TOTAL 740 , 341

Cumulative oil production from the leases studied for this report is esti

mated to have been 517 , 700 barrels to the end of 1955 .

-2-

.. .. >"

BASIC DATA

Production History Oil production statistics for the

Felmont Oil Corporation leases ln

the Rodney field, and a composite summary, are presented in Table 1 and

graphically presented in Figures 7 through 12 . Cumulative oil production

from the portion of the Rodney field studied for this report is estimated

to have been 880 , 694 barrels as of March 1 , 1957 .

Well Tests Individual well tests were run dur-

ing March 1957 on fifty of the fi£ty

two oil wells operated by the Felmont Oil Corporation. Oil production rates

ranged between 1 . 64 barrels per day and 34 . 20 barrels per day with an

ave rage of 6 . 80 barrels per day per well for those wells tested .

Gas production was measured on nine wells . Gas-oil ratios ranged between

40 and 317 cubic feet per barrel with a weighted average of 93 . 3 cubic feet

per barrel.

Water production in appreciable quantities was measured during only five

-3-

" '" '.

well tests . The water-cuts ranged between zero or a trace to as much as

88. 1 per cent for the Angus Braddon No . 2 well. These well test data are

presented in Table 3.

Solution Gas Analysis Gas sample s , collected from the

Felmont Oil Corporation A . C .

Gillies No. 16 well and the John McMillan No. 17 well, were analyzed

for hydrocarbon composition and gravity. The results of this analysis for

the sample from the A. C . Gillies No . 16 well and the measured specific

gravities for the two samples are contained in Table 17.

Produced Water Analyses Produced water samples from

Felmont Oil Corporation's John

McMillan No.8, John McMillan No. 16 and J . Braddon No . 10 wells have

been collected and analyzed. The results of these laboratory tests are

presented in Table 15. The analyses of the samples from the John

McMillan No . 16 and J. Braddon No . 8 wells showed these two waters to

be practically identical in composition and have been considered as repre

sentative of the reservoir water , whereas the analysis of the sample from

the John McMillan No. 8 well showed a ten-fold greater dissolved solid con

tent, indicating that the water production was coming from a separate

-4-

". J ...

source. The apparent anamolous completion and production history of

this well are discussed elsewhere in this report.

The hydrogen sulfide content in the produced water will create a corrosive

condition during an injection program and consideration should be given to

the use of cement lined pipe to counteract this .

Water Analysis - Glacial Drift During the drilling of the John McMillan

No. 8 well, a water sample from the

glacial drift, at approximately 240 feet subsurface, the most probable water

supply source for water injection, was collected and analyzed. The results

of this analysis are shown in Table 16 . No particular treatment problems

are anticipated in the use of this water for injection.

If this potential water supply source should prove inadequate, either sur

face waters or water from Lake Erie, approximately five miles away,

could be used.

Reservoir Pressure Data A comprehensive field survey, using

an acoustical well sounder , was made

-5-

· . ....

of Felmont Oil Corporation producing wells to determine the current reser-

voir pressure . Based on this survey, the average reservoir pressure is

estimated to be 53 psig at a subsea datum of plus 300 feet . Measured fluid

levels indicated a range of pressures from 9 psig to 126 psig. Pertinent

data from the pressure survey are presented in Table 4.

Original reservoir pressure is estimated to have been 170 psig at a subsea

datum of plus 300 feet, based on a hydrostatic head of 0.434 pounds per

square inch per foot of depth.

Reservoir Temperature

of approximately 400 feet.

Reservoir temperature is estimated

to be 63 0 F at the producing depth

C ore Analyse s Complete core analyses were avail

able on 28 wells operated by Felmont

Oil Corporation and seven wells operated by Dominion Natural Gas , The

porosity , permeability and fluid saturation measurements from these ana

lyses were subjected to statistical analysis. From 532 samples, the

weighted average porosity was calculated to be 19 . 2 per cent, ranging

-6-

· .. . .....

between 33 . 4 and 5 . 2 per cent . Figure 5 is a map showing the areal dis

tribution of weighted average porosities by well and by lease .

The weighted average permeability, using all samples with measured per

meability of five millidarcys or greater was 424 . 3 millidarcys . The range

of permeabilities measured and considered as contributing to oil production

was from 5 . 2 millidarcys to 11 darcys .

The five millidarcy cut-off was selected in consideration that 99 . 88 per cent

of the reservoir capacity is represented by samples having this permeability

or greater . Of the samples analyzed having permeability in excess of one

millidarcy, 86 . 6 per cent have permeabilities greater than five millidarcys .

The relationship between measured permeability and fractional reservoir

capacity is shown on Figure 15 . Figure 16 is a plot of the measured per

rneabil i ty a s a functi o n o f the fractional thickness analyzed with permeability

i n excess of one millidarcy .

Core data are summarized by wells in Table 5 .

-7-

Permeability and Capacity Distribution

· .

Permeability and capacity distribu-

tion relationships were calculated

for the A . C . Gillies lease and for the remainder of the field . After re-

viewing the individual well core analyses, the apparent concentration of

correlative, highly permeable formation in the A . C. Gillies Nos . 13 , 14

and 15 wells, prompted the decision to consider this lease as being suffi-

ciently different to warrant completely independent analysis .

The permeability-capacity distribution relationship for the remainder of

the field was calculated from all samples having permeabilities in excess

of five millidarcys , excluding the three wells enumerated above , while the

relationship for the A . C . Gillies lease incorporates those data as well.

The results of these calculations are presented in Table 11 and graphically

shown as Figures 17 and 18 .

Water Cut-Recovery Relationship Water cut-recovery relationships

were calculated for the A . C . Gillies

lease and the remainder of the field based on the permeability-capacity

distributions, the laboratory derived permeability ratio , Krw/Kro, the oil-

-8-

· .

water viscosity ratio, residual oil saturation after flood, and the estimated

formation volume factor . The results of these calculations are presented

in Tables 12 and 13 and shown on Figures 19 and 20.

Interstitial Water Saturation Volumetrically weighted average inter-

stitial or connate water saturation

has been determined from laboratory studies and oil base core data to be

6. 33 per cent of the pore space.

Production research measurements were made on six samples , ranging in

pe rmeability from 107 to 1070 millidarcys , to determine the relationship

between capillary pressure and water saturation. From these data , incor

porating the relative densities of the crude oil and the interstitial water,

the connate water saturation, as a function of the height above the water

table, was calculated. The results of these tests are presented in Tables

8 a nd 9 and graphically shown on Figures 13 and 14 .

Nineteen wells were either totally or partially cored , using lease crude,

and fluid saturations were measured during laboratory analysis . Average

water saturations in the oil productive sections ranged from 3 , 69 to 10 . 77

-9-

· .

per cent with a weighted average of 6 . 32 per cent . These data are present

ed in Table 10 and have been superimposed on the laboratory derived curve

relating connate water saturation as a function of the height above the water

table , Figure 14 .

Flood Tests Restored state laborator y flood tests

were performed on eleven samples ,

ranging in air permeability from 107 to 2,090 millidarcys . Specific per

meability to water , relative permeability to water at residual oil saturation,

and residual oil saturation after flood were determined.

The residual oil saturation after flood was found to be 23. 2 per cent of pore

space. Relative permeability to water at residual oil saturation was deter

mined to be 37 . 3 per cent of the specific permeability to water .

In addition , flooding tests using natural cores were performed on 18 samples

from the John McMillan No . 17 well and nine samples from the John McMillan

No . 18 well . Average residual oil saturations after flooding were found to

be 26 . 0 and 29 . 4 per cent of the pore space for the John McMillan No . 17

and No . 18 wells , respectively .

-10-

· .

Water flood test data are contained in Tables l4a, 14b and 14c. Figure 21

is a plot of the air permeability as a function of the residual oil saturation

after flooding, while Figure 22 is a comparable plot relating porosity to the

residual oil saturation. While these data are somewhat scattered, an aver

age curve for both graphs indicates a residual oil saturation of approximate

ly 23 per cent for the field-wide average permeability and porosity of 424 . 3

millidarcys and 19 . 2 per cent, re spectively.

Reservoir Fluid Data No reservoir fluid analysis was avail

able for the crude oil produced from

the Rodney field. Based on the reservoir temperature of 630 F, measured

average gas-oil ratio of 93 cubic feet per barrel , and the crude gravity of

380 API, the original formation volume factor is estimated from empirically

derived relationships to have been 1 . 05 . Oil viscosity measurements at

reservoir temperature have ranged between 6 . 1 and an extrapolated value of

7 . 1 centipoise . An average value of 6 . 6 centipoise has been used for calcu

lation purposes .

-11-

· .

GEOLOGY

General The oil productive reservoir in the

Rodney field has been clas sified as

the Columbus formation, Middle Devonian of Upper Onondoga age . This

horizon overlies the Detroit River group disconformably, according to B . V .

Sanford, Geologist with the Geological Survey of Canada, who discussed the

Rodney oil field in the Second Annual Report of the Ontario Fuel Board (1955) .

The productive zone within the Columbus formation is described as consist

ing of medium to coar sely crystalline dolomite with rounded and frosted sand

grains. Laboratory tests of two core samples, using hydrochloric acid ,

showed a loss in weight of 68 and 87 per cent after treatment .

Structurally, the Rodney oil field is an elongated anticline trending es sen

tially north- south in the area studied . Development in the field has indicated

a productive length of 1 . 8 miles and a productive width of 0 . 85 miles . The

structurally highest well in the field, the Felmont Oil Corporation John

McMillan No . 17 well , encountered the top of the Columbus porosity and per

meability at a subsurface depth of 355 feet or 337 feet above sea level. The

structural configuration of the oil producing horizon, contoured on the top and

base of the pay, is shown on Figures 1 and 2 .

-12-

. . !.

Gross Oil Sand Thickness The gross oil sand thickness as deter

mined from core analyses, detailed

sample descriptions , and published reports are tabulated in Table 7 and an

isopachous map is presented as Figure 3 . Gross oil sand thickness ranged

from zero to 30 feet with this maximum of 30 feet being found in the Jim

Beattie N. D. McMillan No. 3 well.

Net Oil Sand Thickness Net oil sand thicknesses were deter-

mined for those wells having complete

core analyses and detailed sample descriptions. The ratio of net thickness

to gross thickness for these wells was calculated to be 0.918 . The assump

tion was made that this same relationship would be applicable to those

wells on which neither core analyses nor detailed sample descriptions were

available .

The net oil sand thicknesses are presented in Table 7 . An isopachous map

of the net oil sand is shown on Figure 4 . The net sand thicknesses ranged

from zero to 28 feet, with a volumetrically weighted average of 13 . 4 feet .

Oil- Water Contact Limited data were available for the

determination of the original oil-

-13-

· .

water contact . Core analyses of the Felmont Oil Corporation A. Braddon

No. 1 and No . 2 wells indicated an oil-water contact, or transition zone, at

plus 275 feet and plus 286 feet, respectively. Well completions in other

parts of the field, however, would indicate the oil-water contact to be some

what lower, with some evidence of a contact at plus 272 feet on the east

side of the field . On the west side of the field the oil-water contact was

placed at plus 270 feet, the base of the pay in the N. D. McMillan No . 3 welL

Reservoir Dimensions The productive area of the portion

of the Rodney field studied, as found

by planimetering Figure 4, covers 1, 020.46 acres . The reservoir volume

underlying this area contains 13,691.75 acre-feet. Original stock tank

oil-in-place is calculated to have been 18,756,020 barrels . Productive

area, reservoir volume, and original oil-in-place by lease are presented

in Table 6.

-14-

:a

RESER YES AND PERFORMANCE

Primary Depletion From the net oil sand isopachous

map the original oil productive re ser

voir volume has been calculated to have been 13, 691 . 75 acre - feet, contain-

ing 18, 756, 020 barrels of stock tank oil.

From lease performance curves and volumetric determinations , the re-

maining total field oil reserves to be recovered after March 1, 1957 have

been estimated to be 2,303,226 barrels. The predicted future field per

formance under primary depletion is presented in Table 18 and shown on

Figure 23 . Ultimate primary oil recovery is calculated to be approximately

17 per cent of the original oil-in-place, or 233 barrels per acre -fooL The

recovery mechanism will be predominantly solution gas drive with limited

edge water encroachment and minor segregation drive.

Under the primary depletion performance analysis the assumption has

been made that no additional wells will be drilled.

Water Injection Program Based on the permeability-capacity

distribution curves and the derived

-15-

water cut - recovery relationships, the future field oil reserves as of

March 1, 1957 to be produced under a five-spot water flood program have

been calculated to be 5,758,036 barrels, recoverable in 15 years . The

assumption has been made that full- scale injection will commence October 1 ,

1957. Ultimate oil recovery after water injection will be 35.4 per cent of

original stock tank oil content or 485 barrels per acre-foot. Field per

formance under a five-spot water injection program has been based on an

initial injection rate of 60 BWPD per injection well , or a total of 4,800

B WPD for the field. This will require approximately 100 psig surface in

jection pressure .

The oil production rate has been maintained constant by increased rates of

water injection and fluid withdrawal until maximum calculated injectivity

of 140 BWPD per injection well with 300 psig surface pressure has been

reached . From this point on the oil rate decline s as the water increase s.

Surface injection pressures of 300 psig are being successfully used on other

neighboring fields with no apparent over-burden lifting .

The predicted field performance under a water injection program is shown

in Table 19 and graphically presented on Figure 24.

-16-

· ,

Anomalous Well Performance During the development of the

Rodney field anomalous completion

and production behaviors were noted for several wells . Perhaps the most

outstanding of these has been the Felmont Oil Corporation John McMillan

No. 8 well which encountered a crevice approximately 1.5 feet below the

main pay and has exhibited a performance which indicates that production

is coming from a separate source . The crude oil viscosity averages

approximately one centipoise greater than the viscosity of the oil produced

from wells with normal behavior. The produced water analysis revealed

a ten-fold difference in the dissolved solids, further substantiating the

supposition that production is from a separate reservoir accumulation .

During the recent well tests the McMillan No. 8 well produced 34 . 2 bar-

rels of oil per day, more than five times the average well and approximately

three times the second most prolific well. No difficulty is anticipated in

shutting off this lower horizon and converting the well to injection for the

proposed water flood program.

Other wells have produced oil and water at high rates but with one known

exception, these wells were initially completed in small productive inter

vals considerably above the main pay. After depleting what performed

as a small oil accumulation in a fractut"ed zone, the wells have been

-17-

t J "

subsequently completed in the main pay as normal wells .

Completion data are not available on wells operated by operators other

than Felmont Oil Corporation but it is considered logical to assume that

the reservoir conditions existing on offset leases will closely approximate

that found underlying Felmont Oil Corporation leases .

During the analyses of the numerous cores from the Felmont Oil Corporation

wells in Rodney, no evidence of any fracturing in the main pay was noted ,

All notations of crevices and fissures from the drillers log place them

sufficiently above the reservoir to be water flooded so that no unusual diffi

culty should be encountered.

-18-

. . ..

• I ••

WATER INJECTION PLANT AND DISTRIBUTION SYSTEM

Plant Design Included in this report as Table 20

is an estimate of development costs

for the water flood program and Figure 26 is a proposed water distribu-

tion system.

The cost estimates are for an injection plant with a capacity of 5,280 bar

rels per day at a discharge pressure of 200 psi. It was assumed that the

water would be handled in a closed system and no costs are included for a

complete treatment system.

Water analysis has been performed on four produced water samples obtain

ed from the wells listed below:

1 . John McMillan No . 16

2 . John Braddon No. 10

3 . John McMillan No. 8

4 . E , J . MacMillan No . 6

Wells No . 1 and 2 above had an average total solids content of 2 , 056 parts

-19-

pe r million and hydrogen sulfide content of 25. 5 parts per million. Theore

tical calculations on the constituents of the se two samples indicated they are

stable when maintained in a completely air free system, and that no plugging

of injection well sand should occur .

The mineral analysis of samples 3 and 4 showed a much higher total mineral

concentration and pattern of individual constituents . Total solids ranged from

24,652 to 32,522 parts per million and hydrogen sulfide from a trace to 444

parts per million. In addition, these samples were very unstable insofar as

their calcium carbonate content is concerned. It is thought that the water

from these two wells was from an extraneous source and is not representa

tive of formation water but this conclusion should be substantiated before

making any definite decision of the type of treating system to be employed .

If this type of water will require handling, complete treatment will be

necessary since it is certain that calcium carbonate precipitation and scal

ing would occur . In this respect there was a considerable quantity of this

precipitate formed in the sampling jars when they were received for analysis

at the laboratory .

In the plant cost estimates, it will be noted that a building of 36' x 40' x 18'

-20-

was included. This size was specified in order to house water storage tanks

as a precaution against freezing in the severe winter weather and also to

allow for a future installation of additional filtering and pumping equipment

in the event that injection rates greater than calculated are possible . With

the added facilities, it would be possible to increase injection rates during

high water cut operating periods with a resulting extension of the economic

limit and ultimate oil recovery from the water flood program .

Water Distribution System The proposed distribution system,

shown as Figure 26 , provides for

13 meter stations in addition to 7 wells being metered directly from the in-

jection plant . This system was utilized in estimating installation costs even

though the pipe and ditching required are more than for a system in which

water meters are located at individual wells . It was thought that from an

operational and field labor cost standpoint, this system would more than

pay for itself over a period of years since the physical limitation involved

in reading 80 water meters at 80 wells as opposed to reading these meters

at 13 locations is apparent.

In addition, the hydrogen sulfide content of produced water dictated the use

-21-

· . ',..

of cement lined pipe for the distribution system. This type of line would be

desirable whether or not the sulfide content is removed from the water

prior to injection since under a complete treatment process an aeriated brine

water would result that is also highly corrosive . Ditching and line laying

costs were estimated at $1. 00 per foot since it will be neces sary to place

them below frost depths. The cost of this operation alone wruld dictate the

use of cement lined pipe since the cost of the pipe is considerably les s than

the cost of placing it in the ground and any replacement during the life of

the flood as a result of corrosion would be expensive . The system as de

signed will supply water to all wells at a very even pressure loss , elevation

losses excluded. The maximum pressure loss calculated to a well head is

25 psi.

The cement lined pipe and fitting costs shown in Table 20 are based on

Jones and Laughlin Steel Company mill prices for this product. As is per

haps known, this company offers this lining service from their mills,

which should be relatively close to these Canadian operations .

Injection and Producing Wells For the same reasons that cement

lined distribution pipe is specified,

-22-

• t I ,

it is recommended that injection into the wells be performed through cement

lined tubing set on packers. New cement lined tubing was included in the

cost estimates for this under Item III of Table 20 .

It will be noted under Item VII of Table 20 that the cost of plugging off pat

tern wells is included in the overall estimates . No consideration has been

given to salvage value of the equipment which will be removed from these

wells , nor has any consideration been given to production tubing which will

be removed from wells converted to injection and replaced by cement lined

tubing . These items , plus any surplus pumping units, will all have a cer

tain salvage value which will deduct from the total cost figure . In the ab

sence of any knowledge of these values , however, they were not considered

in this report .

-23-

.. . .. ' . . ..

CONCLUSIONS

From. this study of the Colum.bus form.ation in the Rodney field, it has been

concluded that:

1 . Ultim.ate oil recovery can be m.easurably increased by water

injection.

2 . Com.plete cooperation am.ong operators or field-wide unitiza

tion will be required before such a program. can be initiated.

3 . Future oil reserves to the field under prim.ary depletion, after

March 1, 1957, are 2, 303, 226 barrels to be recovered in 65 years .

4 . Under a full-scale five-spot water injection program., the

future oil reserves to the field after March 1, 1957 are 5,758,036

barrels to be recovered in 15 years, an increase of 3,454, 810

barrels over that remaining under primary depletion.

5 . Capital investm.ent necessary to develop the water injection

program. is $403 , 883 .

-24-

. . .

6 . Injection wells should be cased and cemented at top of pay.

RECOMMENDATIONS

1 . Initiate field-wide water injection operations in the Columbus

formation after either unitizing the field , which would be highly desirable ,

or securing cooperative agreements among the various operators . Per-

mission to institute this program should be obtained from the Ontario Fuel

Board.

2. During the development of the water-injection program , all

oil wells converted to injection wells and all wells specifically drilled for

this purpose should be cased to the top of the pay and adequately cemented.

This will require supplemental casing strings in some wells .

3 . Accurate records of injection volumes, pressures and production ,

including oil and water, should be maintained .

Respectfully submitted,

_~E/~ Keith D. Sheppard

KDS/mh

-25-

TABLES

Table No .

1 2 3 4 5 6 7 8

9 10 11 12 13

14a 14b 14c 15 16 17 18 19 20

LIST OF TABLES

Title

Production History Tabulation - Felmont Oil Corporation Producing Well Development Rate Well Test Data Reservoir Pressure Data Core Analysis Summary Productive Area and Reservoir Volumes Gross and Net Oil Sand Capillary Pressure - Water Saturation Data Calculated Connate Water Connate Water Saturation from Core Analyses Permeability and Capacity Distribution Water Cut - Recovery Relationship - Fractional Recove ry Water Cut - Recovery Relationship - Barrels Per AcreFoot Water Flood Data - Re stored State Water Flood Data - John McMillan No. 17 Water Flood Data - John McMillan No . 18 Produced Water Analyses Water Analysis - Glacia l Drift Gas Analysis - A . C . Gillies No . 16 Predicted Field Performance - Primary Depletion Predicted Field Performa nce - Water Flood Program Development Cost Estimate - Water Injection System

A. BRADDON LEASE

~ r------o-,-,-----.

U •• 'LO J..:.- ~:::..:":::'::... -l--"-"-"-' --I ! :; *n U :~

I '0 H8 lI8 HE M8

I~ IU

-j-----

I -, -, I-- - l--------HJ.I--+---

-;n -Hl ~- H

IV H 12 _~ .!

I ~4

I-I~-. ,. 5 ,4 6 5. 7 ~.

$i-i IH~ 12 "4

----- - - ---~

-j------

_-=+=m~

-1-=--=r=- -- 1-- - -

A. C. GILLIES L EASE

Table I

PRODUCTION HISTORY TABULATION

F e lmont Oil Corporati on

RODNEY FIELD

Elg i n Count y. Onta rio, Canada

J. D. GRAHAM LEASE

E. J. Ma c MILLAN LEASE

JOHN McMILLAN LEASE

TOTAL

. ,S.l"

f-.---':J~----4~. ~ f-. __ -4l~ ___ 7' 668 mn-... . .

12 4)2

T able 2

PRODUCING WELL DEVELOPMENT RATE

RODNEY FIELD

Elgin County, Ontario , Canada

Produc in~ Wells Drille d Ope rator and Lease 1949 19 50 1951 19 52 1953 1954 1955 19 56 1957 (3 Mos . ) Total

F elmont Oil Corporation

A . Braddon 1 A . C . Gillies 16 Graham 8 Mac Millan 3 9 J. Mc Millan 4 6 18

John Beattie

Sabjan 12

Jim Beatti e

J. Braddon 14 F. Wright 6 Co lthart N. D. Mc Millan

Dom inion Natural Gas Co .

Purce ll 8 Rubi 6

Comfort

Tunks 4

New Bristol

A. McC allum

TOTAL 40 20 24 20 4 121

•

Table 3

WELL TEST DATA

RODNEY FIELD

Elgin County, Ontario, Canada

Oil Production Gas Production Gas-Oil Ratio Water Production Water Cut Operator, Lease and Well No. Barrels Eer Dal: Cubic it. 1Da'i.. Cubic it. / Bbl. Barre ls Eer Da~ Pe r Cent

FELMONT OIL CORPORA TION

A . Braddon No. 100 No. 5.80 43. 1 88.1

A. C. Gillies No. 5.09 No. 7.2 3. 33. No. 4.75 0 0

No. 4 6 . 43 No. 6 . 56 No. 6 . 00 No . 8.40 No. 8 . 00 Tr. No. 5 . 80 0 No.10 2.02 0 No . l1 2.03 644 317 No.12 2.80 N o.13 11.40 456 40 No.14 6.20 No.15 9.93 789 79 No. 16 10.32 1, 115 108 0.58 5.3

J. D . Graham No . Z. 62 No . 4 . 05 Tr . No. 7.52 Tr. No. 4 3.68 10.80 74.6 No. 3.55 No. 3.78 644 170 No . 11.52 0 No. 5.99 .04 0 . 6

E. J . MacMillan No . 2 .20 Tr. No. 4.19 Tr. No. 3 . 50 Tr. No. 4 1. 64 0 No. 3.73 No. 5.00 Tr. No . 6. 16 789 128 0 No. 9.92

J . McMillan No. I 5 . 27 No. 3. 55 No. 3 . 18 No. 4.94 TSTM Nil Tr. No. 1. 69 0 No . 5.45 Tr. No. 6.91 T r . No . 34.20 1 , 582 46 1. 71 4 . 73 No . 8. 18 Tr . No . 10 8 . 54 644 73 Tr . No . II 4 . 37 0 No . 12 8 . 83 Tr. No.13 11.45 Tr. No.14 8.21 0 No.15 5.78 Tr . No . 16 13.57 Tr. No .17 11 .5 2 2,470 214 Tr. No. 18 13 .99 Tr.

Note: T r. denotes trac e of water. TSTM - Too sTnall to measure. Average gas - o il ratio for wells tested - 93.3 cubic feet per bar re l

Table 4

RESER VOIR PRESSURE DATA

Columbus Formation

RODNEY FIELD


FELMONT OIL CORPORATION

Reservoir Pressure @ I 300 Ft . Datum Lease and Well Number PSIG

A . Braddon No . 1 N . T. No . 2 44

A. C. Gillie s No. 1 N . T . No . 2 10 No . 3 126 No . 4 126 No . 5 38 No . 6 29 No . 7 126 No . 8 126 No . 9 60 No . 10 72 No . ·11 27 No . 12 44 No . 13 29 No . 14 29 No. 15 18 No . 16 34

J. D . Graham No . 1 42 No . 2 N . T . No . 3 25 No . 4 49 No . 5 21 No . 6 14 No . 7 41 No . 8 26

Lease and Well Number

E . J . MacMillan No . 1 No . 2 No . 3 No . 4 No. 5 No . 6 No . 7 No . 8 No . 9 No . 10

John McMillan No . 1 No . 2 No . 3 No . 4 No . 5 No . 6 No . 7 No . 8 No . 9 No . 10 No . II No . 12 No . 13 No . 14 No . 15 No . 16 No . 17 No . 18

Arithmetic Average

N . T . - Not Tested Oil gradient - O. 32 psi/ft . Water gradient - 0 . 43 psi/ft.

Table 4

( Continued)

Reservoir Pressure @ I 300 Ft . Datum PSIG

N. T . N. T .

26 74 20

9 9

33 36 60

126 22

106 118

18 124

55 63

107 126

29 37 45 51 18 48 58 29

53

Wells tested during week of April 15 , 1957

Table 5

CORE ANALYSIS SUMMAR Y

Columbus Formation

RODNEY FIELD


Oil Saturat i on, Water Saturation Lease and Well No . Feet Analyzed Permeability , Md. Porosity. Per Cent Per Cent Per Cent

Felmont Oil Coq~oration

Angus Braddon No . 17 263.9 18 . 6 36 . I 23.2 No. 19 296.6 17 . 9 48. 3 I!. 6

Annie C . Gillies No. 13 13 2,046 . 4 26 . 9 57 . I 3. 7 No. 14 12 1,199.0 21. 0 54 . 5 5.8 No. I S 15 915.9 23.6 56 . 5 4 . I No. 16 18 665.9 24 . I 57.3 5.8

J. D . Graham No. 17 78 . 4 15 . I 47.3 8. 3 No . 14 137 . 6 14. 7 35. I 10. 3 No. 19 518 . I 21. 2 35 . 8 19 . I No . 17 357.4 15.9 37 . 4 16.4

E. J. MacMillan No. IS 187. 5 16.9 40.9 9 . 7 No. 4 I I 189.7 16 . 9 63.2 14.9 No. 9 280.4 15.5 54 . 7 b . I No . 13 169.1 14.9 43. I 10. 1 No. 11 173 . 4 lb. 5 41. 3 15.0 No. 8 14 224 . 5 17.8 37.2 10.6 No. 9 17 205.9 18 . 8 38.4 14.6

John A. McMillan No. 8 18 230 . 3 20.6 49.8 6 . 4 No . 9 20 301. 8 23.9 56.7 5. 6 No . 10 23 328 . I 21. 4 49.2 3. 8 No . I I IS 166 . 4 16.8 47. I 8.0 No. 12 15 285.8 18 . 8 51. 0 5. 2 No. 13 19 483.4 15. 1 43 . I 6. 1 No. 14 19 397 . 2 18.6 49.5 10.1 No. 15 19 183.8 18.4 49.5 3. 8 No. 16 20 334.6 20. 3 53.0 7.6 No. 17 20 236.4 17.4 39.6 14 . 2 No. 18 20 285.2 18 . 7 59.5 5.8

D o minion Natural Gas

F. G . Purcell No . 10 483.5 21. 1 No. 12 776 . 7 22.5 No. Z 22. 3 7. 7 No . 15 937.5 19 . 5 No. 11 708. 3 18 . 9

J . Rubi No. 13 477 . 3 2 1. 4 No . 1,056.4 25.4

Ave rage 424 . 3 19.2

Table 6

PRODUCTIVE AREA AND RESERVOIR VOLUMES

RODNEY FIELD


Original Stock Tank Productive Reservoir Volume Oil In Place,

Operator Lease Area-Acres Acre-Feet Barrels

Felmont Oil A. Braddon 25.25 226 . 26 273,840 Corporation

A. C. Gillie s 109 . 45 1,523.60 2,577,470

J. D. Graham 78.91 994.21 1,163,230

E. J . MacMillan 82.47 1,051.23 1,218,170

J. McMillan 151. 86 2,574.65 3,458,S30

Sub-Total 447.94 6,369.95 8,691,240

John Beattie S. Sabjan 54.47 818.41 1,121,140

Jim Beattie J. Braddon 107 . 72 1,852.86 2,538,230

Colthart 36.84 417 . 08 571,360

N. D. McMillan 132. 52 1,825.28 2,500,450

F. Wright 44.99 530.98 727, 390

Sub-Total 322.07 4,626.20 6,337,430

Comfort Tunks 23 . 47 325.93 446,490

Dominion Natural Gas F. G. Purcell 45.22 616.09 837,880

J. Rubi 44.76 284.97 431,130

Sub- Total 89.98 901. 06 1,269,010

New Bristol A. McCallum 82.53 650.20 890,710

TOTAL 1,020.46 13,691.75 18,756,020

F elman! Oil Corporation

Jim Beattie

Leas e and We ll Number

A. Braddon

A. C . Gilli~ a

J. D. Graham

No. No .

No . 1 No. No.3 No . 4 No. No. No. No. No . 9 No . 10 No . 1 1 No. 12 No . 13 No . 14 No . 15 No . 16

No. 1 No.2 No . 3 No .

No . No. No. No.

E. J. Mac Millan No . I No . No. No. No. No . No . No. No.

J . McMillan No.1 No.2 No.3 No . No. No . No. No . No. No. 10 No. 11 No. 12 No. 13 No. 14 No. 15 No. 16 No . 17 No. 18

N. D. 1I.1cMiILan N o. No. No.3 No . 4 No. No . No . No .

T able 7

GROSS AND NET OIL SAND

Columbus F o r matio n

RO DNE Y FIELD

ElgIn County, Ontario, C1tnada

Gross Sand N e t Sand Thic kness· Ft. ThIckness · Ft.

16

IS IS 18 14 14 IZ 14 13 15 15 1 5 16 13 14 14 IS

17 20 15

21 I S 19 18

IS 20 19 15 10 17 II 16 17

I S 25 19 10 16 I S 19 21 22 23 21 22 19 23 20 21 22 21

14 22 30 25 13 18 I S I S

9 16

18 I S

" 14 14 IZ 14 13 15 15 14 14 1 3 II 14 18

17 I S 15

4 17 14 19 17

16 18 15 II

9 1 3 II 14 17

I S 23 17

S 14 16 14 IS 21 23 15 16 19 19 19 21 20 20

13

20 2S 23 IZ 17 17 I "

Jim Beattie (Cont.

John Beattie

New Bristo l

Comfort

Don1ini o n Natural Gas

!'\OIC' Net s<1nd thi c kness based on \ ore analyses, detail ed s:\Inplc des c r iption, o r average rati o of net to ,c:r oss of 91B determined from wells with analyses or des c r ipt ions.

Lease and Well Number

J. Braddon

Co ltbart

F . Wri gh t

S . Sabjan

A. M cC allum

Tunks

Pur ce ll

J. Rubi

No. No . No. No . N o . No . No .

No. No. q No. 10 No. 11 No. I Z No. 13 No. 14

No. No. No . 3 No.4

No.1 No . l No . 3 No .

N o . No .

No.1 No.

No. No. No. No . 6 No. No. No.9 No. 10 No. II No. 12

No.1 No. No. No. No . No. No.7

N o . I No.2 {\;o. 3 No.4

No.1 No. No . No. No . No. No. No.

No . I No . No . No . No. No. No.7

G ro s s Sand Net Sa nd Thickness· F t. T hickness· Ft.

19 19 17 21 20 17 21 IS 19 19

16 21 19

21 19 20

15 IS 16 17 12 12

16 18 16

16 1 3

17 17 16 19 IS 16 19 17 17 17

15

19 17

19 17 IS

14 17 15

16 II II

15 I S

15 13

Table 8

CAPILLARY PRESSURE - SATURATION DATA

Columbus Formation

RODNEY FIELD


Sample No. 2450 2451 2452 2453 2454 2491 Average

Air Perm. , Md . 578 578 635 107 1070 860 638

Pressure PSIG Brine Saturation, Per Cent of Pore Space

0 100 . 0 100 . 0 100 . 0 100.0 100 . 0 100 . 0 100 . 0

0 . 5 97 . 8 98.9 98.0 99 . 0 97 . 0 95 . 6 97 . 7

1 87 . 0 9l. 2 92 . 5 96 . 3 79 . 0 96.0 90 . 3

2 25 . 2 3l. 0 37 . 0 71. 5 31. 4 17 . 3 35 . 6

3 15 . 7 2l. 4 25 . 9 47.5 22 . 0 12 . 5 24 . 2

5 8 . 0 16. 0 15 . 7 25 . 1 13 . 8 8 . 9 14 . 6

7 6 . 0 12.4 10 . 5 15 . 0 9 . 0 7. 3 10 . 0

10 4 . 9 9 . 0 7 . 6 9.8 6.5 6 . 2 7.3

15 3. 8 5 . 6 4.7 6 . 8 4. 1 5 . 0 5 . 0

20 3. 1 3. 9 3. 1 5 . 2 3. 0 4 . 4 3. 8

25 2 . 9 3. 0 2. 6 4 . 5 2. 3 4 . 0 3. 2

30 2 . 7 2 . 5 2 . 4 4 . 1 2. 0 3. 8 2.9

Table 9

CALCULATED CONNATE WATER

Columbus Formation

RODNEY FIELD


Sample No . 2450 2451 2452 2453 2454 2491 Average

Air Perm. , Md 578 578 635 107 1070 860 638

Height Above Water Table Connate Water Saturation, Per Cent of Pore Space

0 57.0 57 . 0 62 . 0 94 . 0 48.0 52 . 0 61. 7

5 22 . 1 28 . 6 33 . 4 65 . 0 28 . 6 19 . 5 32 . 9

10 15 . 2 21. 9 25 . 2 45 . 8 21. 3 12.4 23 . 6

15 11. 0 18.5 20 . 1 34 . 0 17.6 10 . 1 18 . 6

20 8 . 3 26 . 2 16 . 1 26 . 1 14 . 2 9 . 0 16 . 7

30 6 . 1 13. 2 11. 1 15 . 6 9 . 7 7. 7 10 . 6

40 5 . 5 10. 9 9. 1 12 . 0 7 . 7 6 . 8 8 . 7

50 4 . 9 8 . 9 7. 4 9 . 8 6 . 4 6 . 1 7 . 3

60 4 . 4 7. 4 6 . 3 8 . 3 5.4 5 . 9 6 . 3

70 4 . 0 6 . 3 5. 2 7. 3 4 . 7 5. 4 5 . 5

100 3. 2 4 . 1 3. 3 5 . 5 3. 1 4.5 4 . 0

Table 10

CONNA TE WATER SA TURA TION FROM CORE ANALYSES

Columbus Formation

RODNEY FIELD


Fe1mont Oil Corporation

Productive Average Water Well Feet Analyzed Saturation, Per Cent

A . Braddon No. 1 9 9.54 A . Braddon No . 2 15 10 . 26 A. C. Gillie s No . 13 13 3 . 69 A. C . Gillie s No . 14 11 4 . 64 A. C. Gillie s No. 15 14 3 . 78 A . C . Gillies No . 16 18 5 . 82 J. D . Graham No . 5 11 6 . 30 E. J . MacMillan No . 3 16 8 . 87 E. J. MacMillan No . 4 11 10 . 77 E . J . MacMillan No. 5 9 6 . 07 John McMillan No . 8 18 6 . 38 John McMillan No . 9 21 5 . 33 John McMillan No . 10 23 3 . 82 John McMillan No. 11 15 7 . 99 John McMillan No . 13 16 4 . 14 John McMillan No . 14 19 9.03 John McMillan No . 15 18 4 . 34 John McMillan No . 16 17 6 . 41 John McMillan No . 18 20 5. 85

Weighted Average - 6. 32

Table 11

PERMEABILITY AND CAPACITY DISTRIBUTION

Columbus Formation

RODNEY FIELD , Elgin County, Ontario, Canada

A. C . Gillies Lease Remainder of Field Fractional Dimensionless Fractional Dimensionless Fractional Thickness, h Permeability~ R Capacity, C Permeability, R Capacity, C

0 30.8 0 15.5 0

· 01 8. 6 · 13 7.3 · 10 .02 6.9 · 21 5.8 · 17 . 05 4. 3 .35 4. 2 · 31 .07 3 . 5 .43 3. 6 .39 · 10 2. 7 · 51 2 . 9 .48

· 15 1.9 .63 2. 1 . 59 .20 1.4 · 71 1.6 .68 . 25 1. 1 . 78 1.3 .76 .30 .9 . 84 1.0 . 82 .40 .6 .91 .6 .90 . 50 .3 .95 . 3 . 94 .60 . 2 .97 .2 .97 .70 . 1 .986 . 1 . 98 .80 . 08 . 993 .05 .99 .90 .03 .997 . 02 .995

1. 00 0 1. 00 0 1. 00

·.

Table 12

WATER CUT-RECOVERY RELATIONSHIP

Columbus Formation

RODNE Y FIELD


Water Cut Fractional Recovery of Water Flood Reserves Per Cent A. C . Gillie s Lease Remainder of Field

0 .035 . 075

10 . 135 . 170

20 . 206 . 236

30 . 265 .290

40 . 320 . 342

50 . 380 . 403

60 . 450 . 473

70 . 543 . 562

80 . 660 . 678

90 . 840 . 840

95 1. 000 1 . 000

Table 13

WATER CUT-RECOVERY RELATIONSHIP

Columbus Formation

RODNEY FIELD


Water Cut Water Flood Recovery - Barrels per Acre-Foot Per Cent A . C. Gillie s Lease Remainder of Field

0 20 35

10 70 88

20 105 120

30 134 144

40 161 168

50 194 191

60 235 220

70 286 257

80 353 305

90 450 380

9 5 534 462

Table 14a

WATER FLOOD DATA

Columbus Formation

RODNEY FIELD


Specific Permeability Residual Saturations(3) Millidarcys Per cent Pore Space

Sample No. To Air (1) To Brine (2) Oil Water

2450 578 436 20 . 7 79. 3

2451 578 411 24 . 0 76.0

2452 635 490 21. 8 78 . 2

2453 107 53 25.2 74.8

2454 1,070 930 24.4 75.6

2489 1,000 580 22.7 77 . 3

2490 1,410 575 22.9 77. 1

2491 860 450 19 . 5 80.5

2492 1,280 785 25. 0 75 . 0

2493 2,090 960 22 . 7 77 . 3

2494 1,200 650 26 . 2 73.8

Average 983 575 23 . 2 76.8

(1) Corrected for Klinkenberg effect . (2) Brine 5,000 ppm used. (3) After flooding with 50 volumes of water. (4) Permeability to flood water at residual saturations as per cent

of permeability to brine .

Relative Perm. to Water Per cent (4)

30 . 2

21. 9

21. 2

32 . 0

76.6

33 . 1

16.4

77. 1

20 . 2

32. 2

49.2

37 . 3

Table 14b

WATER FLOOD DATA

Columbus Formation

RODNEY FIELD


Residual Saturation - Per Cent Permeability, Porosity of Pore Volume

Sample No. Millidarcys Per Cent Oil Water

12 120. 18.3 20.8 62. 2 12A 118 . 17 . 5 23 . 4 58 . 8 13 125. 18 . 3 25.7 61. 8 14 236. 16 . 8 30 . 4 57. 1 15 424. 19 . 6 22.0 62 . 3 16 449 . 19.6 22 . 5 60 . 8 16A 222 . 16.4 29.8 64.0 18 738. 21. 1 32.6 62.5 20 25. 17 . 3 27.2 57.2 21 287 . 21. 4 22.0 60 . 3 22 249. 21. 4 17.3 65.0 23 89. 16 . 8 23.2 66 . 1 23A 29 . 12.2 32.8 54.0 24 34. 16.0 25. 0 63.2 24A 65. 15 , 7 27.4 55. 5 25 326. 15.5 26.4 65.1 26 28 . 14.9 34.9 51. 6 27 6.5 14 . 6 24. 7 63. 7

Average 198.4 17 . 4 26. 0 60.6

Samples from Felmont Oil Corporation John McMillan No . 17

Table l4c

WATER FLOOD DATA

Columbus Formation

RODNEY FIELD


Residual Saturation - Per Cent Permeability, Porosity of Pore Volume

Sample No. Millidarcys Per Cent Oil Water

7 15. 17. 1 34. 5 58.5

10 87. 16. 1 40.4 51. 5

12 155. 24. 3 37.0 56.0

13 810. 23.8 21. 4 58. 0

14 10 . 15.6 26. 3 64 . 1

16 86. 18. 1 20.4 68 . 6

17 106 . IS. 7 21. 4 55 . 2

20 43. 14.4 27.S 59. 7

22 6.6 15 . 0 35. 3 50.6

Average 146.5 IS. 1 29.4 5S . 0

Samples from Fe1mont Oil Corporation John McMillan No. IS

Constituent

Total Solids Sodium Iron Manganese Barium Calcium Magnesium Chloride Bicarbonate Carbonate Sulfate

Hydrogen Sulfide

Table 15

PRODUCED WATER ANALYSES

Columbus Formation

RODNEY FIELD


Source of Water Samples - Felmont Oil Corporation John McMillan No.8 John McMillan No. 16 J. Braddon No .1 0 Dissolved Solids - ppm

24,652 2,063 2, 049 6,882 574 552

6 6 21 ------ - - - -- - - - --

0 0 0 947 49 56 985 54 52

13 , 829 794 763 909 576 595

0 0 0 1,094 10 10

Dissolved Gases - ppm

444 . 1 27.8 23 . 5

Physical Properties

Specific gravity pH

1. 019 5 . 9

1 . 002 7 . 4

1 , 002 7.4

..

Table 16

WATER ANALYSIS

Glacial Drift

RODNEY FIELD


Constituent

Sodium

Iron

Manganese

Barium

Calcium

Magnesium

Chloride

Bicarbonate

Calcium Carbonate

Sulfate

Silica (Si02)

pH

Dissolved Solids

o

51

27

303

240

40

.28

5

7 . 6

ppm

Table 17

GAS ANAL YSIS

A. C. Gillies No . 16 Well

RODNEY FIELD


Component Mol Per Cent

Nitrogen 23 . 21 Methane 56 . 82 Ethane 10 . 43 Propane 1. 96 Iso-butane 1. 59 N-butane 1. 74 Iso-pentane 1. 02 N-pentane 0 . 48 Hexanes 0 . 33 Heavier O. 64 Carbon Dioxide 1. 78

100 . 00

Experimental Gas Gravity - 0 . 8340 (1)

Orsat Analysis : C02 - 1. 75 Air - 1. 72 H 2S - Nil

G . P. M .

0 . 538 0 . 519 0 . 547 0 . 372 0 . 173 O. 135 O. 295

2 . 579

Calculated gross heating value - 1035 BTU per cubic foot of dry gas at 14 . 7 psia and 60 0 F .

(1) Gas gravity of sample from John McMillan No . 17 Well .

O. 7843

Date

3-1-1957 3-1-1958 3- 1-1959 3-1-1960 3-1-1961 3-1-1962 3-1-1963 3-1-1964 3-1-1965 3-1-1966 3-1-1967 3-1-1968 3-1-1969 3-1-1970 3-1-1971 3-1-1972 3-1-1973 3-1-1974 3-1-1975 3 - 1- 1976 3-1 - 1977 3-1-1982 3-1-1987 3 - 1-1992 3-1-1997 3-1-2002 3-1-2007 3-1-2012 3-1-2017 3 -1-2022

Total

Table 18

PREDIC TED FIELD PERFORMANCE

UNDER PRIMARY DEPLETION

Columbus Formation

RODNEY FIELD


Cumulative Oil Interval Oil Production, Barrels Production Daily Annual Barrels

880,694 657 239,923 1 , 120,617 508 185,463 1,306,080 418 152,470 1 , 458 , 550 356 129 , 940 1,588,490 309 112 , 848 1,701 , 338 276 100,759 1,802 , 097 247 90,220 1 , 892 , 317 226 82 , 596 1 , 974 , 913 207 75 , 375 2 , 050 , 288 191 69 , 873 2 , 120 , 161 176 64,282 2,184,443 164 59,904 2,244,347 155 56,720 2,301 , 067 147 53,579 2,354 , 646 137 50,160 2,404,806 131 47,737 2 , 452 , 543 125 45 , 508 2,498 , 051 119 43 , 254 2 , 541 , 305 112 40 , 938 2 , 582 , 243 107 38 , 906 2 , 621 , 149

92 167 , 923 2 , 789 , 072 68 124, 035 2 , 913 , 107 53 96 , 609 3 , 009 , 716 37 67 , 507 3 , 077,223 25 46 , 290 3 , 123 , 513 14 25 , 352 3 , 148 , 865

9 16 , 554 3 , 165 , 419 6 11 , 501 3,176 , 920 4 7,000 3, 183, 920

2 , 303 , 226

Date

March 1, 1957 March 1, 1958 March 1, 1959 March 1, 1960 March 1, 1961 March 1, 1962 March 1 , 1963 March 1 , 1964 March 1 , 1965 March 1, 1966 March 1, 1967 March 1 , 1968 March 1 , 1969 March 1, 1970 March 1, 1971 March 1, 1972

Total

Table 19

PREDIC TED FIELD PERFORMANCE UNDER FIVE-SPOT WATER FLOOD

Columbus Formation

RODNEY FIELD


Interval Oil Production, Bbls. Cumulative Oil Daily Annual Production, Bbls .

880 , 694 602 219,680 1,100 , 374

2,606 951,020 2,051,394 3,172 1 , 157,700 3,209 , 094 2 , 504 913,900 4,122 , 994 1,756 640,900 4 , 763,894 1 , 264 461 , 200 5 , 225 , 094

869 317,100 5 , 542,194 720 262,800 5,804,994 601 219,200 6 , 024 , 194 504 183,800 6,207 , 994 415 151 , 633 6,359 , 627 361 131,870 6 , 491 , 497 222 80 , 928 6 , 572 , 425 144 52 , 705 6 , 625 , 130

37 13,600 6 , 638 , 730

5 , 758 , 036

Table 20

ESTIMATED WATER FLOOD DEVELOPMENT COSTS

RODNEY FIELD


1. Water Distribution System Pipe Requirements: 9000' of 4" T &: C cement lined pipe @ $123. 89/l 00' -

FOB Mill- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - $ 11, 150 . 10 5300' of 3" T &: C cement lined pipe @ $84 . 12/100' -

FOB Mi 11- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 4, 45 8 . 36 4800' of 2" T &: C cement lined pipe @ $43 . 85 /l 00' -

FOB Mill--------------------------------------------- 2,104 . 80 67, 000' of 1 lIT&: C cement lined pipe @ $23. 61 /l 00' -

FOB Mill--------------------------------------------- 15,818 . 70

Total FOB Mill----------- $ 33,531. 96 Add 10% for freight &: handling charges - - - - - - - -- 3,353 . 19

Total @ Field $ 36 , 885 . 15

II. Connections for Meter Station Headers, Risers, Valves &: Meters

6 - 4" cement lined tees @ $7 . 44 each ------------------- $ 80- 2" cement lined tees @ $2. 28 each -------------------1 - 3" cement lined cross @ $6.38 each ------------------6 - 3" cement lined ell @ $3 , 91 each ---------------------20- 2" cement lined ell @ $1. 91 each ---------------------80- 2" x 1" cement lined swages @ $4 . 52 each ------------5 - 4" x 2" cement lined swages @ $6 . 54 each ------------280 - 1" cement lined ells @ $0.86 each -------------------100 - 2" x 6" cement lined nipples @ $1. 25 each ------------80 - 1" Figure 4455 bronze angle Hancock Flo- Control Valve -

@ $ 1 8. 20 e ac h - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -80 - 1" All bronze 500 psi water me ters @ $30. 00 each - - - --80 - 1" All bronze swing check valve @ $8. 00 each - - - - - - - --80 - 1" All bronze gate valves @ $9 . 00 each ---------------

Total ------------------- $

44.64 182. 40

6. 38 23 . 46 38 . 20

361. 60 32. 70

240 . 80 125 . 00

1,456 . 00 2,400.00

640 . 00 720 , 00

6,271.18

Table 20 ( continued)

DEVELOPMENT COSTS

III. Equipment for Injection Wells 80 - I" All bronze gate valves @ $9. 00 ea. ----------------- $ 80 - I" All bronze check valves @ $8.00 ea. ---------------32000' of 2" cement lined tubing for injection string, based

on 80 wells, 400 feet per well @ $43.85/100 ft. -----------80 - Flood type packers for setting with 2" tubing estimated

at $100. 00 each --------------------------------------Miscellaneous connections for well head at $25 . OO/well - - - --

720 . 00 640.00

14,032.00

8,000 . 00 2,000 . 00

Total $ 25,392 . 00

IV. Installation of Distribution Lines 69,225' of ditching, line laying and backfill of ditch, depth

of approximately 5' to be below frost penetration level, estimated at $1. OO/ft . --------------------------------- $ 69,225 . 00

13 meter stations constructed to include neces sary housing and flooring to prevent freezing during winter at $500 . 00 per s t a ti 0 n - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 6, 5 00 . 0 0

80 Freeze boxes for installations at injection wells, estimated at $50 . 00 per well , insulation included . ----------------- 4 , 000.00

Total $ 79,725 . 00

V . Water Supply Wells Drill and equip three water supply wells to the Glacial Drift

at 285 feet, estimated cost per well , including pumps @ $4 , OOO/well ------------------ - --------------------- $ 12 , 000 . 00

VI. Water Injection Plant To provide 4 , 800 barrels per day @ maximum pressure of 200

psi:

3" X 4" Triplex Plunger pump, nominally rated at 5,280 barrels per day and 570 psi maximum discharge pressure operating at 420 RPM . Under 200 psi pressure rating , horse power requirements would be 20. Unit equipped complete with Vee belt drive and electric motor ----- -- -------------- - ----- $ 5 , 300 . 00

Table 20 (continued)

Water filtration equipment with a capacity of 5 , 500 barrels per day, complete with filter and backwash pumps---- - ------- $ 3 , 850. 00

Surface water storage for filtered and unfiltered water , 2-500 barrel galvanized tanks equipped with necessary gauge boards, ladders and flanges @ $2,500 each -------,---- - ---------- 5 , 000. 00

Electrification of water flood plant, to include necessary automatic protective devices, controls for electric motors , lighting, etc . ----- - - - - - -------------- - --- - ------------ - -- --- - - - 3 , 000 . 00

Building to house water flood plant, size is estimated at 36 i x 40' x 18 ' , building to be insulated and heated to protect against freezing in severe winter weather. Water storage tanks to be housed inside building, cost @ $5 . 75/sq. foot ---------- - --- 8,280 . 00

Concrete and reinforcing for building, 1 , 440 sq. ft. , estimated at $2. 00 per sq. ft . --- - -------- ---- --- - -- -- --- -- -- -- ---- 2 , 880. 00

Labor to make physical hook-up of component parts of water flood plant, estimated -- ---- ---- -~-- - - ---- - - --- - ~,-~, - - ---- 3 , 000 . 00

Miscellaneous valves , fittings and connections required in water flood plant ----- -- - -------- - - ~. -.,, - - -- -- ----------- - ---- - - 1 , 000 . 00

Total $ 32 , 310 . 00

VII. New Producing and Injection Well , and Plugging Cost Drill 13 new producing wells @ $4 , 200/well , producing equip-

ment to be utilized from wells converted to injection - - - - - $ 54 , 600. 00

Drill 28 injection wells @ $4, 200/well ------------------- 117,600 . 00

Convert 52 producing wells to injection, rig time @ $100 . 00 / well ----- - -------------- - - -- ----------- -- - -- ---- - ---- 5 , 200 . 00

Plug and abandon 18 currently producing wells located off pattern, two days rig time @ $15. OO/hour , plus $80 . 00 materials--- 14 , 400 . 00

Total $191 , 800 . 00

Table 20 (continued)

Total - all items ---- ----- - --- -

Add lO per cent contingencies on plant and construction

GRAND TOTAL

$384 , 383 . 00

19 , 500 . 00

$403 , 883 . 00

FIGURES

Figure

1 2 3 4 5 6 7 8 9

10 11 12 13 14 15 16 17

18

19 20 21 22 23 24 25 26

No .

LIST OF FIGURES

Title

Structure Map - Top of Pay Sand Structure Map - Base of Pay Sand Isopachous Map - Gross Oil Sand Isopachous Map - Net Oil Sand Map Showing Average Well and Lease Porosities Producing Well Development Rate Production History - Felmont Oil Corporation Lease s Production History - A . Braddon Lease Production History - A . C . Gillies Lease Production History - J . D. Graham Lease Production History - E . J . MacMillan Lease Production History - John McMillan Lease Capillary Pressure Versus Water Saturation Height Above Water Table Versus Connate Water Saturation Permeability Versus Fractional Reservoir Capacity Permeability Versus Fractional Reservoir Thickness Permeability and Capacity Distribution - A . C . Gillies Lease Permeability and Capacity Distribution - Remainder of Field Water Cut Versus Cumulative Water Flood Recovery Water Cut Versus Fractional Water Flood Recovery Permeability Versus Residual Oil Saturation Porosity Versus Residual Oil Saturation Predicted Field Performance - Primary Depletion Predicted Field Performance - Water Injection Program Proposed Water Injection Pattern Proposed Water Distribution System

. .

. ~

l / /

0 ....

Tu "h

ft l m Onl

LOT 4

; fJJ2~ '. fJ'~ LOT 5

.' + 337

" ." + 329

II La T 6

. .

~; -

f i GURE I

STRUCTURE MAP TOP OF PAY SAND

ICON TOUR INT[RVAL . IQ FEET)

RODNEY POOL ALDBORQUGH TWP ELG I N co

ONTARIO, CANADA

0 • .1 ... " I ~ 111['01 15[0 8'1' O.'f OAT! 4Pf1'1II0'ol[0 81' APPIIOVEO BY OU E

· .

F, l mon l

L O T 4

J RuDI

(

i

~o

'"

,

fiGURE 2

E MAP STRUCTUR SAND OF PAY

BASE RVA L 'OFEE T ) tCONTOUR INTE POOL

ROD~Eiwp ELGIN CO ALDBO~~UTGAR IO, CANA DA

le.~ ( IN H[ T ...

Fr i monl

LOT 4

o

Tunks

fiGURE 3

ISOPACHOUS MAP

GROSS OIL SAND ICONTOUR I NTERVAL 5 FEET)

RODNEY POOL ALOBORQUGH TWP. ELGIN CO

ONTARIO, CANADA

A( VISI!:OBY DATI!: DATI!: , . ...... .... , ..... , .... ~'u

PPItOV 011'1' APPltOVI!:O BY . _ .. _ ._ ._ ••

F'r lmo'" F'rlmo"l

FIGURE 4

S MAP I SOPACHOU

SAND NET 0 1 L L 5 FEET} (CONTOUR I NTERV; 0 OL

RODNEY ELGI N CO ALDBOROUGH

O TW~ANADA

ONT AR I ,

""ll'",U'

o

Tunks

Fe l mDn l

LOT 4

, . 18.6 .' 18.8

LOT

f r lm o'"

.' 18.6

" . ' 58

.'

,"

,

; 17,8

.' 15.5

: , ..

'87 LOT , ..

" 17.4

.' .' 20.3 15./

o' I

I I I , I L_c.,~~J

: ; j I 22.5

j .' I 2U

: : 18.9

TunkS Pur(;, 11

WEIGHTED AVERAGE LEASE POROSITY Felmorlf :

A.8roddon A.C. Gtt hu J.O Graham E,J. Moc M,lIon J.Mc Millon -CON.IV J,foiIc MUlon -CON. V

Dom,nlon : F.G.Purc.11 J . Rubl

Poroslt,% 18.2 24.0

" . 16 .9 18 .2 19 .7

19' 22. .5

~ 18.8

CON

l 165

.• 14.9

CON

.'

I 205

LOT

IV

." 15.9

.' .' 15.1 21,2

: 14]

j LOT

.' V ;

.' , . ~O

.' ;

; ~,

236

, . , . . 2'0

: .' 269 A C 6"l le$

Dom , ",on , j .

21.4

: : 25.4

.'

<! J HUOf

6

6

. .

i

o'

. . ;

:

; A

;

•

MeCal/ llm

F IGURE . !5

MAP SHOWING AVERAGE WELL

AND LEASE POROSITIES

RODNEY POOL ~LDBOROUGH TWP, EL GI N co

DIUW/Ij IIY OATE APItOV[DIIY OUt

ONTAR IO , CANADA

80 160 JAMES A . LEWIS ENGINEERING

INCC""ORATID

P ..... r...m Rt ... .oI, AMI,,,,

70 140

60 120 "0 en Q) ...... ...... ...... ..... Q) .....

'"' ~ 0

50 100 b.O en ~ ...... ..... ...... u Q) ::l ~ "0

0 b.O '"' ~ p.., ..... u 40 80 '+-< ::l 0

"0

'"' 0

'"' Q)

p.., .0

'+-< 8 0 ::l

'"' 30 60 Z

Q) ......

"8 !1l .... 0

::l E-< Z

20 40

10 20

0 ~

w

~ w

~ ~ w

~ w

~ w

~ w

~ w

~ 0

z U ~ z ~ ~ . u ~ z ~

=

z ~ ~ z ~ . ~ ~ z ~ . ~ . ~ ~ ~ ~ ~ ~ ~ ~ 0 ~ ~ 0 ~ 2 ~

1949 1950 1951 1952 1953 1954 1955 1956 1957 1958

Figure 6

PRODUCING WELL DEVELOPMENT RATE

RODNE Y FIELD


· ~ " c u

" "0 0

0: '0 " · .0

~ Z

· "' · · <

"'

60

40

ZO r '

+

12,000

11, 000

6, 000

, 1-, r

:t t -3 ,000

-r :

~

2, 0 00

I-r-~ 1=++= j± :::;

1, 000

R= -+-

~-

- !-j-

--l ±

1-+ ---.

+ -

r---r

1+

++

H-

H- -

T

=t=

~ lit -

'l

500

400

300

ZOO

100

o .~ . "II 1.~ • • t.IIII'1.~ . ~j'i l lll. ~ •• ~.'iji'l ••• ~."jIJl.~ •••• 'ijl' .~.i1.'ijl'!.~ •• ~.'ill'j.~.j1.'illil.~!.1.'ilft .~iO 194 1950 1951 1952 1953 1954 195 5 1956 1957 1958

Figure 7

PRODUCTION HISTORY

F e lrn ont Oil Cor poration

RODNEY FIELD

Elgin Count y , Ontario, Canada

] '" '0 · "0 C · " i! ...

is ,

· ~ U

en :::: 20 <I)

~ be 15 .S I-u ;l

10 "0 0

'"' Po. 5 ....

0

'"' <I) 0 ..0

E ;:l

z ~ f-

.:::1- f-- -- -_.

~ t- t=" ~ I- .-

t- .. .

r:: 1= 1-. ..

I- t-t- .. -. 6 00

f--

f-1- -

....... 1-. i-. 500

..c ....... +-'

~ t-

t- I--

0 400 ::E

'"' <I) -(.J..

en ~

<I)

'"' 300 '"' nl -(!l f-- .. - I-

. <I)

- .. - f--'c<i ex:: 200 .. - - I-

_. --

. ~

0

100

I- i-- .-

~ ~ ;i ti ~ ! ! ! ~ :II ~ ~ C C

o

1955

JAMES A . L.EW IS ENG INEERING

-

I--

-

f-

ri IE

-1- f-.

l-I--

.- l- I -

I-- I-- 1-. --l-

l-.

I-- I-- ..

-

"7

I-f-

i- - /--

- . - .... -t-. -- I- -

II "-1--

--

ff- --

i .- ~ ;i ~ ~ ! ~ ~ ! g ri l ~ :II :II ~ ~ C IE

19 56

Fig ur e 8

P R ODUCTION H IST ORY

Ang u s Braddon Leas e F e l mon t Oi l C o r po r a ti o n

R ODNE Y F IE LD

I-

a ! .

E lg i n Coun ty , Ontario , C anada

I HC O " .. O,,"TIO

p....u.m JWc,uo/. A""" ...

l-. . _ f-

l-/-- I--

t-

I--' -

--!-

.; j ~ I ~ .. ! g j :II . ~ -= ~ :II

195 7

~ ~ r-r-r-

6

5 en ~

<I)

'"' '"' nl (!l

4 .... 0

t- en "0 >:

t- nl en ;:l

3 0

..c E-<

~ .~

t- 0 <I)

2 . ~ +-' nl

- '; E ;:l

u

! o

~ " ~ "" .5 u

" 'tl a ... 0. .., a ... " .D

6 " Z

.c

" a ::E ... " >l. en

" ... ... '" 0:1

" :;; 0::

O

20

15

10

5

0 H-. I

+

3500

3000 +- -

2500

2000

1500 ~ 1

~ I+.~ -+-

1000

500 f-

i-"

. ~ -j

t=

t-

,

. =1;:· I .. ...L

. f-f-

JAM!. A. I..!wrs ENGINEERING I"'C:O"'O""'TIO

Pft'l'O!.tu"'Lt~AKaI,IU

175

150

125

100

75

50

25

o !~~:i~~il~~~~~~~i~~;!~~~!~~ii~~!!g~~!~;iij~!!~i~!~;:i~ ijl~~~!~~:ijil!~i~!~~iij!i!~i~O 1952 1953 1954 1955

Figure 9

PRODUCTION HISTOR Y

A. C. Gillies Lease Felmont Oil Corporation

RODNE Y FIELD

1956

Elgin County, Ontar i o. Canada

1957 1958

is

30 . ; 25

'" c 20 ;:; , " 1 5 0

tl: '0 10

" . .c 6 , z

1400

1200

1000 .c C 0

::E " · 800 '" · · · " • <!l

600 · :< c<

<5 400

200

1949 1950 1951 1952 1953

Figure 10

PRODUCTION HISTORY

John D. Graham Leas e Felmant Oil Corporation

RODNEY FIELD

1954

Elgin County, Ontario . Canada

JAMIS A. L.IWIS t:NQ1NI:I'UNO

1955

70

60

· ~ " • <!l

'0 · " 40 c : , 0 .c f-<

30 <5 · . ~ :< -;

20 6 , U

10

~ 10 .... " o ~ ... 5 " "" '" ~

Su ~ ~ 0 Z'tl

0 ... Il.

900 II

800

700

..c: 600 ;:; 0

::E ... " ~ 500

.")

" ... ... '" tQ

400

" .., c:r::

0 300

200

100

1952 195 3 1954 1955

Figure II

PRODUCTION HISTORY

E . J. Mac Millan Lease Felmant Oil Corporation

RODNEY FIELD

1956


JAMES A. LEWIS ENGINEERINO INCOlOll'OIlATaO

Pmvlnull Re~' A...u,1U

1957 1958

45

40

35

.")

" 30 ... ... '" tQ

.... 0

'" '0 25 <:

'" '" ~ 0

..c: f-<

20 (5

" .?: j " 15 6 " U

10

5

'" <U

~ blJ

5 U

" "" 0 H

P.. ~

0

H <U

.D S " Z

-"

" 0

::E H <U

P,

~ <U H H <tl ~

<U

~ <i

0

20

15 JAMES A. LEWIS ENGINI!EAINQ INCO""OIiATla

Pmol.n4", Rtserwi,AM!,m

10

5

0

8000 400

7000 350

6000 300

5000 250

-+-+---4000 200

I I

. --l

3000 150

2000 100

1000 50

1952 1953 1954 1955

Figure 12

PRODUCTION HISTOR Y

John A . McM illan Lease Felmont Oil Corporation

RODNEY FIELD


1956 1957 1958

'" 0; H H <tl ~ ~ 0

'" "" ~ <tl

'" " 0 ..c: f-<

6 <U ;: :d ;; S " U

OJ)

Ul p..

V .. " Ul Ul Q) ..

p.. >-.. ~

0-m

U

· 20

10

o o 10 20 30 40 50 60 70

Average Connate Water Saturation, Sew, Per Cent

Figure 13

CAPILLAR Y PRESSURE - WATER SA TURA TlON

Columbus Formation

RODNEY FIELD

Elgin County , Ontario, Canada

J A MES A . LEWIS ENG INEER ING ,,,,C. O."OIV.f,O

Pmoltwm ReutOlOl, A,w,a

80 90 100

90

80

70

... Q) Q)

~ 60

Q)

;0

'" f-< ... Q)

;;; 50 ~ Q)

> 0

.0 -< ... ..c: 40 .~ Q)

::c

30

20

10

Laboratory Derived

Core Analyses Derived

10 20 30 40

Connate Water, Per Cent

Figure 14

JAMES A. LEWIS ENGINEERING

50

INCOItP'O""TID

Pmokum Reser""", AMJ,ru

60

CONNATE WATER SATURATION AS FUNCTION OF HEIGHT ABOVE WATER TABLE

Columbus Formation

RODNEY FIELD


70

U)

>-u ... '" "0 --.~

::E

.~ -:0 '" '" E ... '" Po.

100

10

JAMES A. LEWIS ENGINEERING INCOR~ORATID

Pmobm IUsmooif AaaI,ru

10" __ -o .2 .4 .6 . 8 1.0

Frac tional Capacity

Figure 15

RELATIONSHIP BETWEEN AIR PERMEABILITY AND FRACTIONAL RESERVOIR CAPACITY

Columbus Formation

RODNEY FIELD


<fl

>-V H

'" :s .~

::E

.~ -<

II '" '" E H

'" p..

1000

100

IHCO""OIlATIO

Pmoleum RtU'n'Oir AI\tJl,JU

..

1.0 ___ _

o . 2 .4 . 6 .8 1.0

Fr ac ti onal Thi ckne ss Analyzed

Figure 16

RELATIONSHIP BETWEE N AIR PERMEABILIT Y AND FRACTIO NA L RESERVOIR THICKNESS ANA LY ZED

C o lum b us F o rmation

RODNEY F IELD


36. 0

3 2.0

28.0

lit::

.~ 24. 0

.D

'" Q)

E ... Q)

20. 0 P-Vl Vl Q)

"2 .S Vl

" Q) 16.0 E is

12 . 0 ' I

8. 0

4. 0

.- l--

.2 .3 .4 .5 .6 .7

Fractional Th ickn e ss, h

Figur e 17

PERMEABILITY AND CAPAC ITY DISTRIBUTION

Columbus Formation

A . C. Gill ies L ease , F e l mont Oil Corporation

RODNEY FIELD

Elgin C ount y , On ta rio, Canada

JAMES A. LI!!:WIS ENGIN!I!:R INO

.8

11'10::0"'0""'110

PrtTOkum lUu .... ~, A~fU

.9

1.0

.9

.8

. 7

.6

.5

.4

.3

.2

.1

" .S U '" ... ~

U

.~ (J

'" "'-'" U

20. 0

l S.0

16 . 0

14.0

1:<:

.~ 12.0

:c nl

" E ... " p.. 10.0 <Il <Il

" " .S <Il C

" S. O E 6

6 . 0 I-

4 .0

2 . 0

II

, I

00 .1 .2 .3

, , '-I , ...! --

-,- I

I,

J

:-, I

--, --t...,--,;-

.4 . 5 .6 .7

Fractio nal Thickness, h

Figure I S

PERMEABILITY AND CAPAC ITY DISTRIBUTrON

Col unibus F o r mation

Remainde r of Field

RODNEY F IE L D


JAM E S A . LE W IS ENGINEERING

. S

IHCQ"~O"AT'D

Pd.ok"m RtSCTuoir AII<l1,1U

t---'-

"

T

.9

I

1.0

.9

. 8

· 7

.6 " 0 ~

u nl ... ~

· 5 U

::-U nl g. U

. 4

· 3

.2

. 1

0 1.0

90

80

Ren1ainder

70 of Field

:)0

<: " u ... " Po.

50 :; U ... " -;;; ~

40

30

20

100 200

A. C. Gillies Lease

300 400 500 600 700

Cumulative Water Flood Recovery, Barre ls Per Acre Foot

Figure 19

WATER CUT AS FUNCTION OF CUM ULATIVE WATER FLOOD RECOVERY

Colurnbus F o rmation

RODNEY FIELD

El gin County, Ontario, Canada

JAMES A . LEWIS ENGINEERING

800

INCOIl~O"AT[D

Pttl'OUlim ReJn\.(jjr ArtDr"u

900 1000

90

80

70

60

<:: " u ... " p..

'il 50

U ... " ';;j ~

40

30

20 -+--

10

..L

l-j-!-=r:Rf r h- l -i-r ,

°0 .1 .2

A. C. Gillies Lease

TL

t-

~-+

I

E!=l I--I -+-,

I F I-- H , -r- , . -+ t 1 ~tRtf i l-- + _:-- J _ _ :_ +: , ~'-~ L L.L~ _.d±H±~.u..

.3 .4

Rerna inder of Fie ld

+ =H=ff:'t ' ~T~

• 5

I ,

. 6

JAMES A. LEWIS ENGINEERING INCOIIPO",t,TfO

PctToleum Rnl!fllOiy Anal)Jts

i f'1H: ' " ' , -f+ i+

.7 .8

Fractional Recovery of Water Flood Reserves

Figure 20

WATER CUT AS FUNCTION OF FRACTIONAL WATER FLOOD RECOVERY

Columbus Formation

RODNEY FIELD


..Ll

-1 iT H-

.9 1.0

:

, !

20 30

R e s idual Oil Saturation . Sro, Pe r Cent

Figure 21

RESIDUAL OIL SATURATION AS FUNCTION OF POROSITY

Columbu s Formation

RODNEY FIELD

Elg in County, Ontar io , Canada

LEGEND 0 McMillan No . 17

0 M c Millan No. 18 I!J. Branson's

" Branson's McMillan No .

45 50

30

25

20 ..... s:: C1l U !-i C1l

P.. 15

>-..... ...... Ul 0 !-i 0

P.. 10

5

10

JA M ES A . LEWIS ENGINEERING IN COAPO RAT Il O

Pt troltum Rtservoi1' A ftal,ru

20 30 40

Oil Saturation, P e r Cent

Figur e 22

RESIDUAL OIL SATURAT ION AS FUNCTION OF POROSIT Y

C olumbu s Forma t ion

R ODNEY F IELD

Elgin C ou n t y, On ta r io , Canada

50

>-• 0

· 0. · · ~ al

· ;;; a:

<5 · "" ~ · > «

800

700

600

500

200

1 00

o o

Oil Rate

= . .L

:-t

10 15 20

Cumulative Oil

25 30 35 40

Year s After 3 -1 -57

Fig u re 23

PREDICTED FIELD PERFORMANCE

UNDER PRIMARY DEPLETION

Columbus Format ion

RODNEY FIELD

Elgin Co unty , Ontario, Cana da

45 50 55 60

2. 5

1. 5

0.5

o 65

· · " · al

'0 · 0

~ ~

" "B " '8 a: <5 · > ;;; -; E " U

4000

3000

>-'" 0 ... '" 0-

~

'" ... ... '" tx1

'" 2000 ~ p:: ~

<5 '" OIl

'" ... '" > ~

1000

2

Cu mulative Oil

Oil Rate

4 6 8 10

Years After 3-1-57

Figur e 24

PREDICTED FIELD PERFORMANCE

UNDER WATER INJECTION PROGRAM

Columbus Formation

RODNEY FIELD


JAMES A . LEWIS ENGINEERING

12

INCOII" OIlAT[O

PCm)kum Rlunoj, AMI,JtJ

14

6

5

4

3

2

o 16

~

'" ... ... '" tx1

..... 0

'" .: .3 ~

:E a .~ u ::>

"0 0 ...

0..

<5 '" .::: ~ :; E ::>

U

F.lmonl

Tun kS

Ff l monl

Purc~ 1/

LEGEND

rirO' I W'I~Tolnl'Cflon @ PropOS fd Inj'C I ,o n W. II

Prodllc,no 011 W.II

o Proposed P r OGueinO Wi l l

, .. Produc , ,,O Wi l l To Sf A bon don.d

"'~_'/1Nf " 6'1"0 1

~

F I GU RE 25

PROPOSED WATER INJECTION

PATTERN

ROD NEY P OO L 4lDBOROUGH T WP ElGI N co

DII'AWN II Y DAft APPROV[DIIY

ONT ARlO, CANAOA

~

/ F, I,..,on l

'0

L O T 4 LOT 0

.'

~2 . .

LEGEND

® Or! We ll Co n .... e r t e d To In jec t ion - I- PIP' 6 Co nnec t ion s

@ Pr oposed Inject ion Wel l - - -- 2" Pipe a Con nectio ns

o Propos e d Prod uc ing Well

• Pro d uc!nQ Oil Well

- - - 3" P ipe 6 Connec t ions

__ 4- P ipe S Connec l io n s

E3I Woter P lo n l

4 Me hr S t ol lo n

F,lmon'

L OT 6

®

:

fiGUR E 26

PROPOSEO WATER

DISTRIBUTION SYSTEM

R ODNEY POOL A LDBOROUGH TWP ELGI N co

O ItAWN II" OATE Ap"lIo .... roll .. OATC

ON TAR IO, CANA DA

11[ .... 15[0 In OA T [

DISCUSSION

" ..

JAMES A . LEWIS ENGINEERING, INC. Petroleum R eservoir AnalYsts

REPUBLIC NATIONAL BANK BUILDING

DALLAS 1, TEXAS

May 6, 1957

Mr. V. O. Sims, Vice President Felmont Oil Corporation P. O. Box 602 Owensboro, Kentucky

Dear Mr. Sims:

.,

An engineering study has been made of the Columbus reservoir ln the Rodney field and is submitted in two volumes under the title, "Comprehensive Engineering Study, Columbus Reservoir, Rodney Field, Aldborough Township, Elgin County, Ontario, Canada." Volume I contains pertinent information related to the basic data, geology and future field performance under primary depletion and a full- scale water injection program. Volume II contains analyses of individual lease performances and detailed economics for primary depletion and three plans for water injection. Plan I is a modified five - spot pattern with maximum utilization of current wells; Plan II is a staggered line drive with lease line injection; and Plan III is a staggered line drive with lease line injection but a smaller pattern than Plan II.

Comparison of anyone of the three water injection programs with predicted primary performance, either on a field-wide basis or by individual lease, clearly illustrates the conservation and economic benefits to be derived from initiation of a water flood plan in the field as soon as practical.

Field reserves after March I , 1957 can be increased from 2, 303, 226 barrels under primary depletion to 5,758,036 barrels under a water injection program, a gain of 3,454, 810 barrels. Felmont Oil Corporation net oil reserves are I, 022, 191 barrels under primary depletion and 2,447,723 barrels under a water flood program.

Substantial economic gains to the field under a water injection program are demonstrated by the increase in future net income from $3,139,675 under primary depletion to $12, 024, 171 under a secondary recovery program. Felrnont Oil Corporation's share ofthe se values is $1, 644, 988 and $5,828, 023, respectively.

,

Capital investments for producing wells, injection wells, water plant facilities and water supply wells are estimated to range from $403, 883 under Plan I to $1, 102, 514 under Plan III for the total field. Felmont Oil Corporation's share of these capital investments ranges from $209, 713 under Plan I to $471,409 under Plan III.

We appreciate this opportunity to be of service to you and will be pleased to discuss our work with you at your convenience.

Very truly yours,

JAMES A. LEWIS ENGINEERING, Inc .

James A. Lewis

JAL/mh

TABLE OF CONTENTS

Page Number

CONCLUSI0NS- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - i

RECOMMENDA TI0NS - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - v

LEASE PERFORMANCE - - - - - - - - - - - - - - - - - - - - - - - - - - - - - I

WATER INJEC TI0N PROGRAMS Plan I - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 4 Plan 11-------------------------------------- 6 Plan III - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7

ECONOMICS - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 9

CONCLUSIONS

From this study of the Columbus formation in the Rodney field, it has been

concluded that:

(1) Ultimate oil recovery from the Rodney field can be sub-

stantially increased by water injection under either a

cooperative arrangement or after unitization, which would

be highly desirable .

(2) Future oil reserves after March 1, 1957 to be recovered

from the portion of the Rodney field analyzed for this re-

port are :

(a) Primary Depletion - 2, 303, 226 barrels

(b) Water Injection Program - 5,758,036 barrels - Plan I, II or III

(3) Felmont Oil Corporation's net oil reserves are estimated

to be 1 , 022 , 191 barrels under primary depletion and

2,447,723 barrels under water injection, an increase of

1,425,532 barrels over primary production.

-1-

(4) John Beattie net oil reserves are estimated to be 155,462

barrels under primary depletion and 314, 081 barrels un-

der water injection, an increase of 158 , 619 barrels over

primary production.

(5) Jim Beattie net oil reserves are estimated to be 592 , 375

barrels under primary depletion and 1 , 684 , 848 barrels

under water injection, an increase of 1,092, 473 barrels

over primary production.

(6) Future net operating incomes under primary depletion

and a water injection program are estimated to be as

follows :

Primary Water In-Depletion jection Program

Total Field $3,139 , 675 $12,024,171

Felmont Oil Corporation $1 , 644,988 $ 5 , 828 , 023

" John Beattie $ 204 , 696 V $ 747,474 V

Jim Beattie $ 951 , 248 $ 4 , 021 , 074

(7 ) Capital investments necessary to generate the incomes out-

lined above for the water injection program are :

- ii-

Water Flood Program Plan I Plan II Plan III

Total Field $403 , 883 $978,443 $1,102,514

Felmont Oil Corporation $209 , 713 $415 , 597 $ 471 , 409

John Beattie $ 29 , 100 V $ 52 , 107 $ 66,497

Jim Beattie $129 , 320 $277 , 328 $ 368 , 370

(8) Future net profit , expressed as net income less capital invest-

ment, before income tax, and present worth of the future net

profit would be :

Total Field

Felmont Oil

Future Net Profit Primary Depletion

Water Flood Program Plan I Plan II

$3 , 139 , 675 $11,620,288

Plan III

Corporation $1 , 644 , 988 $ 5 , 618,310 $5 , 413,476 $5,356,914

John Beattie $ 204 , 696 $ 718,374 $ 695,367 $ 690 , 936

Jim Beattie

Total Field

Felmont Oil

$ 951 , 248 $ 3 , 891,754 $3 , 744,246 $3 , 653 , 404

Discounted Future Net Profit Pr imary Depletion

Water Flood Program Plan I Plan II

$2 , 259,183 $10 , 088 , 010

Plan III

Corporation $1, 142 , 851 $ 4 , 671, 075 $4 , 565 , 098 $4 , 585, 324

John Beattie $ 154,476 / $ 593,327 ~$ 570 , 596 $ 590 , 235

Jim Beattie $ 694 , 330 $ 3 , 244 , 762 $3 , 079 , 986 $3 , 198 , 945

-111-

Gain Over Primary Depletion Future Discounted Future Net Profit Net Profit

Total Field-Plan I $8 , 480,613 $7,429 , 791

Felmont Oil Corporation

Plan I $3 , 973,322 $3 , 528 , 224

Plan II $3,768,488 $3,422 , 247

Plan III $3,711,926 $3 , 442,473

John Beattie

Plan I $ 513,678 $ 438,851

Plan II $ 490,671 $ 413,120

Plan III $ 486,240 $ 432,759

Jim Beattie

Plan I $2,940,506 $2,550,432

Plan II $2,792,998 $2,385,656

Plan III $2 . 702 , 156 $2 , 504,615

-lV-

RECOMMENDATIONS

1. A water injection program be initiated in the Rodney field , either

after unitization or obtaining cooperative agreements with offset

operators.

2. The modified five-spot injection pattern (Plan I) be utilized, if

feasible .

3. Obtain approval of the Ontario Fuel Board for instituting the

water injection program.

4 . Develop water supply for injection from the glacial drift under

lying the Rodney field .

-v-

LEASE PERFORMANCE

Monthly oil production records were available for all leases analyzed in

the study, except for the New Bristol Oils A. McCallum lease and the A.

Comfort Tunks lease. The assumption was made that these two leases had

performed similarly to the offset leases and cumulative production was es

timated based on the completion dates of the various wells . Production

histories for those leases for which records were available, and summaries

by operator, are presented in Tables 1 through 4 and graphically shown on

Figures 1 through 15.

Development drilling in the field has resulted in increasing or sustained

lease oil production rates but by converting the monthly oil production to

a per well rate , several of the leases exhibited production decline trends

which were extrapolated to the economic limit. The average ultimate re

covery for those lease s amenable to this treatment was 17. 9 per cent and

ranged between 15 . 8 and 23 . 5 per cent with the higher indicated recovery

from the John Beattie Sabjan lease which is more densely drilled and logi

cally should competitively produce more oil with no production regulations

in effect . Volumetric determinations were used for calculating the ultimate

-1-

oil recoveries for the other leases, with minor recognition being given to

edge leases and those less densely developed. The overall recovery under

primary depletion was calculated to be 17 per cent, or 233 barrels per

acre-foot . Table 5 is a tabulation of the lease reserves under primary de

pletion.

Future lease performance under primary production has been predicted

from the production decline trends by converting the rate - cumulative fore

cast to an annual production rate versus time. The field reserves under

primary depletion as of March 1, 1957 are 2 , 303, 226 barrels to be recover

ed in 65 years . However, 75 per cent of these reserves will have been pro

duced within 20 years.

Under a water injection program with additional energy being supplied to

produce the oil , the ultimate oil recovery can be measurably increased

and the peak rate of production will be limited principally by the restrictions

imposed by the operators relative to the water injection rates and the maxi

mum surface injection pressure that can be applied. The ultimate oil re

covery and reserves under a water flood by leases are contained in Table

6 . The field reserves under a water flood program are 5 , 758 , 036 barrels

-2-

as of March 1, 1957. For the three water injection patterns analyzed , the

ultimate oil recovery will be essentially the same with the major difference

being reflected in the capital investments required and the productive life

which ranged from eight years for Plan III to fifteen years for Plan 1.

The oil reserves under a water injection program have been calculated

based on abandonment at a 95 per cent water cut. The distinct possibility

exists that the reserves as herein presented may be conservative if fluid

rates can be kept at a high level and operating costs minimized during the

later stages of depletion to permit lowering the economic limit and produc

ing the field to a higher water cut.

-3-

WATER INJECTION PROGRAMS

Three possible plans for water injection have been investigated and the

future production performances analyzed . The adoption of one of these

plans and the initiation of water injection in the Rodney field will require

either complete cooperation among the various operators or unitization of

the different producing leases . This latter course of action is more de

sirable as it would result in certain operating economies, permit closer

control over the injection program and require minimum capital investment,

However, with complete cooperation, a successful water injection program

can be instituted and carried to completion under anyone of the plans analyze~ .

Plan I The proposed injection pattern under

Plan I is a modified five - spot which

will require the conversion of alternate wells for injection . The approxi-

mate size of the average five - spot is 12 . 8 acres. Under this program ,

complete development will necessitate drilling 13 oil wells and 28 injection

wells. Fifty-four currently producing oil wells are adaptable to this plan,

giving a total of 67 oil wells. Fifty-two wells would be converted to in

jection wells , resulting in a total of 80 input wells and 18 oil wells not

-4-

required or desired for the program would be plugged and abandoned . The

proposed water injection pattern under Plan I is presented on Figure 24.

Performance under this plan has been calculated based on initial water in

jection rates of 60 B WPD per well , or a field total of 4 , 800 B WPD . As the

water cut increases, the injected volumes are increased until calculated

peak injection of 11 , 000 B WPD at 300 psig surface pressure is reached,

thereby maintaining oil production at a relatively constant level. With con

tinued increases in water cut, the total fluid rate remains constant but the

oil rate declines. Pr e dicted perfo r mance under Plan I is presented in

Tables 7 through 10 and graphically shown on Figures 16 through 23 .

The capital investment required for this program is $403 , 883 , which in

cludes the cost to drill producing and injection wells , plug the non-adaptable

wells , install water plant injection facilities and develop an ample water

supply from the glacial drift. A detailed cost estimate for Plan I is con

tained in the report e n titled "Rodne y Field - Volume 1. "

Plan I affords the greatest opportunity for utilization of currently produc

ing wells and require s the minimum capital investment. While the con

version of alternate wells to injection along lease lines is an equitable

-5-

method for protection of correlative rights under a cooperative agreement,

lease line injection as analyzed in the following two plans may constitute

a more obvious and readily acceptable program to operators and royalty

owners.

Plan II Plan II is a staggered line drive with

lease line injection. The majority

of the patterns developed under this progr a m have an approximate size of

13. 3 acres , although lease configuration results in some smaller patterns

containing 6 . 6 acres . This plan will require drilling 58 producing wells

and 102 injection wells . Sixteen producing oil wells are adaptable to this

program, giving a total of 74 producing wells when fully developed . All

injection wells must be drilled . Ninety-nine producing wells improperly

located for either injection or production must be plugged and abandoned.

The proposed pattern under Plan II is presented on Figure 25.

Capital investment for this program is $978,443, an increase of $574, 540

over that required for Plan L Practically the entire additional capital ex

penditure is for injection and producing well development since few of the

current wells can be adapted to this plan .

-6-

Performance under Plan II has been calculated for leases owned by Felmont

Oil Corporation, John Beattie, and Jim Beattie . Initial water injection

rates have been arbitrarily restricted to 60 BWPD, or a field total of 6 , 120

B WPD. Again as in Plan I, fluid injection and withdrawal rates have been

increased as the water cut changes to maintain the oil production rate at a

relatively constant level until peak field injection of 14,000 B WPD at 300

psig surface pressure is reached . From this point on, the oil rate declines

as the water cut continues to increase. Predicted performance under Plan

II for leases owned b y Felmont Oil Corporation, John Beattie and Jim

Beattie is presented i n Tables 8 through 10 and graphically shown on Figures

18 through 23 .

Plan III Plan III is similar to Plan II in be-

ing a staggered line drive injection

pattern with lease line injection wells , but the pattern area has been de

creased to approxima tely 6 . 6 acr es by uti lization of current wells for pro

ducing wells and drilling the required 154 injection wells . Thirty-six pro

ducing wells must be drilled and 93 current wells adapted to the program,

for a total of 129 producing oil wells . Twenty- seven current wells not

suitably located for either injection or production will be plugged and

abandoned . Figur e 26 shows the proposed pattern for Plan III.

-7-

Capital investment for Plan III is estimated to be $1, 102 , 514, an increase

of $698, 631 over that required for Plan I and $124, 071 greater than under

Plan II. Again, this increased capital expenditure results primarily from

the larger number of wells to be drilled to develop the proposed pattern.

Performance of those leases in which Felmont Oil Corporation, John Beattie

and Jim Beattie have working interests has been calculated based on an

initial per well injection rate of 40 BWPD, or a field total of 6, 160 BWPD.

The oil production rate has been maintained by increased fluid injection and

withdrawal rate as the water cut increases until a maximum injection rate

of 14,000 BWPD at 300 psig surface pressure has been reached. There

after, the oil rate declines as the water cut increases . Predicted perfor

mance under Plan III is shown in Tables 8 through 10 and presented on

Figures 18 through 23 .

A summary compari s o n of the development requirements. capital invest

ments and injection rates under Plans I , II and III is contained in Table 11.

-8-

, .

ECONOMICS

Economic analyses of future performance under primary depletion and

water injection have been prepared and are presented in Tables 16 through

57. Individual lease and summary economics under primary depletion and

Plan I water injection have been calculated and summary economics have

been prepared for Felmont Oil Corporation, John Beattie and Jim Beattie

net working interests under Plans II and III. Factors applied in these ana-

lyses have been as follows:

Crude Oil Price

Gross - $3.48 per barrel

Transportation Charge - $0. 35 per barrel

Net - $3. 13 per barrel

Operating Expenses

Primary Depletion - $79 . 00 per well per month

Water Injection Programs - $0.65 per gross barrel water flood oil converted to average annual operating cost.

-9-

•

Interests Evaluated

Felmont Oil Corporation Gross Working Interest In Leases - 1.00 Net Working Interest In Leases - . 868164

Other Operators

Discount Rate

Gross Working Interest In Leases - 1 . 00 Net Working Interest in Lease s - . 875

Five per cent per annum.

Future net operating income to a . 875 net working interest in the field and

to the various operators under primary depletion and a water injection pro-

gram is as follows :

Future Net Operating Income Primary Water Injection Depletion Program

Total Field $3 , 139,675 $12 , 024 , 171

Fe1mont Oil Cor poratlOn $1 , 644 , 988 $ 5,828 , 023

John Beattie $ 204,696 $ 747,474

Jim Beattie $ 951 , 248 $ 4 , 021 , 074

A . Comfort $ 63 , 729 $ 281,422

Dominion Natural Gas $ 163 , 186 $ 720 , 812

New Bristol Oils $ 86 , 638 $ 365 , 038

-10-

Under primary depletion the assumption has been made that no additional

development drilling will be done and, therefore, no additional capital in-

vestment will be required to recover the remaining primary oil reserves.

Under the three water flood programs discus sed elsewhere in this report,

the capital investment required for water injection plant facilities, injection

wells, producing wells and workovers, will be as follows:

Plan I Plan II Plan III

Capital Investment

Injection and Producing Wells $191,800 $751,200 $819,600

Water Injection Plant Facilities 212,083 227,243 282,914

Total $403,883 $978,443 $1,102,514

Felmont Oil Corporation's share of the capital investment for water injection

will be as shown below:

Plan I

Plan II

Plan III

Felmont Oil Corporation Capital Investment

$209,713

$415,597

$471 , 409

-11-

-----------~-- -

The assumption has been made that lease line injection costs under Plans

II and III will be shared proportionately among offset operators and the

water plant facilities cost under the plan adopted will be allocated on the

basis of injection well distribution. Costs for producing wells and injection

wells other than lease line wells will be borne by the operator of the lease

upon which the wells are drilled . The increase in capital investment for

Plans II and III results principally from the additional producing and injection

wells which must be drilled for a staggered line drive with lease line in-

jection.

Future net profit, expressed as net income less capital investment, to

Felmont Oil Corporation under primary depletion and the water injection

program will be as follows :

Primary Depletion

Water Injection Program

Plan I

Plan II

Plan III

Felmont Oil Corporation Future Net Profit

$1,644,988

$5 , 618 , 310

$5 , 413,476

$5 , 356 , 914

-12-

Increase Over Primary Depletion

$3,973,322

$3,768,488

$3,711,926

------------- -- - -

The present net worth of this future net profit to Felmont Oil Corporation,

discounted at five per cent per annum , is as follows:

Primary Depletion


Plan I

Plan II

Plan III

Felmont Oil Corporation Discounted Future Net Profit

$1 , 142, 851

$4,671 , 075

$4,565 , 098

$4,585,324

Increase Over Primary Depletion

$3 , 528 , 224

$3 , 422,247

$3,442 , 473

The allocation of capital investments to John Beattie and Jim Beattie under

the three water injection programs is as follows:

Capital Investment John Beattie Jim Beattie

Plan I $ 29 . 100 $129 , 320

Plan II $52 , 107 $277,328

Plan III $66,497 $368, 370

Future net profit after capital inveshnent and present worth of future net

-13-

---------- ---

..

profit, discounted at five per cent per annum, to the net working interests

owned by John Beattie and Jim Beattie, is as follows:

Future Net Profit John Beattie Jim Beattie

Primary Depletion $204,696 $ 951,248


Plan I $718 , 374 $3,891 , 754

Plan II $695,367 $3,744,246

Plan III $690,936 $3,653,404

Discounted Future Net Profit John Beattie Jim Beattie

Primary Depletion $154,476 $ 694 , 330


Plan I $593,327 $3,244,762

Plan II $570,596 $3,079,986

Plan III $590,235 $3,198,945

Economic comparisons of future performance under primary depletion and

water injection for the field, Felmont Oil Corporation, John Beattie and

-14-

Jim Beattie are presented in Tables 12 through 15 .

This study clearly indicates the economic benefits to accrue to the opera

tors and royalty owners from the application of a water injection program

in the Rodney field and the immediate initiation of such plans is herein

recommended .

Respectfully submitted,

Keith D . Sheppard

KDS/mh

TABLES

LIST OF TABLES

Table No. Title

PRODUCTION HISTORY

1 2 3 4 5 6

Production History Tabulation -Production History Tabulation -Production History Tabulation -Production History Tabulation -Primary Oil Reserves Water Flood Oil Reserves

Felmont Oil Corporation John Beattie V Jim Beattie Dominion Natural Gas

V

PREDIC TED PERFORMANCE

7

8

9

10

11

Predicted Field Performance - Primary Depletion and Water Flood - Plan I Predicted Performance - Primary Depletion and Water Flood Programs - Felmont Oil Corporation Predicted Performance - Primary Depletion and Water V Flood Programs - John Beattie Predicted Performance - Primary Depletion and Water Flood Programs - Jim Beattie

Comparison of Water Injection Programs

ECONOMIC COMPARISON

12

13

14

15

Economic Comparison - Primary Depletion and Plan I Water Flood Program - Rodney Field Economic Comparison - Primary Depletion and Water Flood Program - Felmont Oil Corporation Economic Comparison - Primary Depletion and Water Flood Programs - John Beattie Economic Comparison - Primary Depletion and Water Flood Programs - Jim Beattie

ECONOMIC ANALYSES

Pr imary Depletion 16 Summary - . 875 Net Working Interest - Rodney Field

Table

17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33

34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51

52 53

-'

No .

l

Title

Summary - Felmont Oil Corporation Felmont Oil Corporation - A . Braddon Lease Felmont Oil Corporation - A . C. Gillies Lease Felmont Oil Corporation - J . D . Graham Lease Felmont Oil Corporation - E . J . MacMillan Lease Felmont Oil Corporation - John McMillan Lease. /' John Beattie - Sabjan Lease V

Summary - Jim Beattie Jim Beattie - J. Braddon Lease Jim Beattie - Colthart Lease Jim Beattie - N . D . McMi llan Lease Jim Beattie - F . Wright Lease Comfort - Tunks Lease Summary - Dominion Natural Gas Dominion Natural Gas - F. G . Purcell Lease Dominion Natural Gas - J . Rubi Lease New Bristol Oils - A . McCallum Lease

Plan I - Water Flood Program Summary - .875 Net Working Interest - Rodney Field Summary - Felmont Oil Corporation Felmont Oil Corporation - A . Braddon Lease Felmont Oil Corporation - A . C . Gillies Lease Felmont Oil Corporation - J . D . Graham Lease Felmont Oil Corporation - E . J. MacMillan Lease Felmont Oil Corporation - John McMillan Lease John Beattie - Sabjan Lease Summary - Jim Beattie Jim Beattie - J . Bra ddon Lease Jim Beattie - Colthart Lease Jim Beattie - N . D . McMillan Lease Jim Beattie - F . Wright Lease Comfort - Tunks Le a se Summary - Dominion Natural Gas Dominion Natural Gas - F . G. Purcell Lease Dominion Natural Gas - J . Rubi Lease New Bristol Oils - A . McCallum Lease

Plan II - Water Flood Program Summary - Felmont Oil Corporation John Beattie - Sabjan Lease

Table No.

54

55 56 57

Title

Summary - Jim Beattie

Plan III - Water Flood Program Summary - Felmont Oil Corporation John Beattie - Sabjan Lease Summary - Jim Beattie

•

r -5-1;" qz · . 5 -5-4 , 5. 1 ,-l;" H{-

H Ii 12'" . " qt

5 5

H i · " · " HI!

'~" 1 .. l 5'

• li 5 .. , .. 7 ,. · ,. '1'

~ '-'

A. BRADDON LEASE

------I----------~

---1----- ---r~-

-----, - --,------I __

1 _ __ - -r-------

--'----,--

--,-----L--

J1~--~1l -3ft'" l' -I-!~i~ -- -=If~ - tnl - i~- i:it -- tl ---J: It

- o _ --.J.6 6

I- T:g_-=l -:Jif -- I ~

A. C. GIL LIES LEASE

,. m

I:m 1-1.100

Table I

PRODUCTION HISTORY T AlULA liON

Felmon l Oil C o rpO~i1tiOn

ROONEY FIEL D

Elgin County. O ntario. Canada

J. D. GRAHAM LEASE

E. J. Ma c MILLAN LEASE

0"

• • UUL • I ... U"~L' "OM'"

---+------1

- - ----1----- ---

1------1---

lh II

I~t ;\

!t3 :;.

11 :Yi

Hi :m ,;, :026 __ m :m

=m ]'9810

.:18.

.:n6 . ~t~ '.246

m :m ---iit- .:;82

7.818 ----.. ':789 ,7' m lO:~~

JOHN Mc MILLAN LEASE

..

TOTAL

. 3 ,

"

,., , " .. , :lol

; ::~, " 7

Table 2


JOHN B EA T TIE

Sabjan Lease

RODNEY FIELD


DATE OIL

J: II: I-Z 0(

0 1II

::l: >-

BARRELS CUMULATIVE

PER BARRELS MONTH

~ t~ ~:Z~~ ~~!t ~t:1 i t~ ~:~~~ ~I, i~:: i i~ ~:6~i ~a:~~; ~ I~

i l ~:~ 4 ~~ :i:~~9 ~ .. l~ !:~ ~!

»1, :, I:A~~ ~

tl i:~ ~: ~2 ~i :~~~

} ,« ;9l 4 :~ .!' i 51 :~ ~!Il

! : ». .~ ,: i if ~.

~ 6 :: 9 71': lC r: ~ !~: : .~9 rj ,:' 3]

lb !2 2: ~ (~ : ~* I} ~g ,I ~~~ .• 99 ~t:~~(

-DATE

--,-- -

~B c-. H H t-'

H

~ 1

~ 'f

t ~i 1-1-1-1-1-1-'=='==

-,

J. BRADDON LEASE

O'L

_"'''''''''IEL.' ... CUMULATIVE

MONTH 'AIt"ILI

m m t.tn i:lH , , , , , , , , , • , , , • • • • ·

5:9.9 7 • 67.

~:m : 'm >to, ~ :m

COLTHART LEASE

O'L

.... "JlIL. CUMU ...... TIVI ...

MONTH .... ",,1.1..

1---

1--- -

1-- m m m l:m m ~:m

• , • • • •

Table 3


JIM BEATTlE

RODNEY FIELD

Elgin County, Ontario. Canada

N. D. McMILLAN LEASE

l' 1.'

t' t' t: '

F_ WRIGHT LEASE

O'L

'A'U~r.L' CUMULATIYI . .. . ... IItRI:L.

MO .. TH

.j~ .n m m 4 ,

, • , • ,

t ' , t •

, • , • , , , , , ,

•

1 33 ,mXi • mm • J.:m ,

4~:m , 44m8 , :::H:

TOTAL

O'L

1",'Ut I.LI C UIolU I. ... TIYIE ...

• ... "11111:1. • MONTH

.l~ .91 ~g~ e::

l:j

.:j I:'

~~ • ~~ t ' ~~ t: '

• , 9 , to ,

• ~o • '91

4' :m, ~~ :m. ~'. 8

8m ~:9~ l~ i:X~ i:7 9 II m 9;116 • 15,69

mn u~lli • iZt:2i.a

DATE

x a: .. Z " 0 '" :E >

~ II ~ .~

1~ .~ Hi i~

i: :: i! i~

1 :: H :: l ~~ : ~~ ~ t~ ~ ~~

l~ t~ H i~

~ ~: : ~ ~ 56

l~ ~~ gn

~ U 3 ~H

"

JEAN PURCELL LEASE

OIL

BARRELS CUMULATIVE

PER BARRELS

MONTH

~U U! t~H5 11~~~j t ~~2~ , :, J ~:U~ 1 : :~;

:~Zl ,:l~~ :2~l :l9 ~~Ii • •

1 : : .21 : : !~i • 9.5

: :I: :l:l~

:Ug ~:m . :~~; ~~:m I:: :~ :!:gt H: '4 u:n 1:~i9 U:~;~ l:nr n:n~

• '; g::l;r :1 ~l ~.:~~i :58: g~:~U :~n If:m

l:t~~ :;:~~~ t:;n :::~f6

l.~~~ ,~:g~6 1.013 71.3.3

Table 4


DOMINION NATURAL GAS

RODNEY FIELD


JOHN RUBI LEASE

OIL

BARRELS CUMULATIVE

PER BARRELS MONTH

69 6'

~:! n, ~~j l:tt:

*~~ l:~~ ~~; ~:gi 2H :t tl~ :2: U~ ,~:N~ ~~: :~:~:~

:,~: j:~St ~~" ~~: i ~~ ~' 4 L;:~ ~I : [~ ,:~~: ~J: au ~i~ 9:i~~

~~t ~~:~~i ~f~ H:gu ~~~ ~~: ~~g ~n ~l:iH ~~: ~~:u~ ::6 ~::gH

~H H:~i~ .. tty "".11.10

BARRELS PER

MONTH

TOTAL

a I L

CUMULATIVE

BARRELS

Table 5

PRIMARY OIL RESERVES

Columbus Formation

RODNEY FIELD


Lease

Felmont Oil Corporation A. Braddon

A . C. Gillies

J . D. Graham

E. J. MacMillan

J . McMillan

John Beattie S. Sabjan

Jim Beattie J. Braddon

Colthar t

N. D. McMillan

F . Wright

Comfort Tunks

Dominion Natural Ga s F. G . Pur c ell

J. Rubi

New Bristol A . McCallum

TOTAL

Original Stock Tank Oil In Place, Barrels

l73,840

l,511,470

1. 163,l30

I, l18, 170

3,458,530

8,691,240

1,121,140

2.538,230

571,630

2,500,450

727,390

6,337,430

446,490

837,880

431,130

1,269,010

890,710

18,756, OlD

• Cumulative production as of March I, 1951 estimated.

Ultimate Primar,r Recoverl Per Cent Barrels

16,900

19. I 493,000

17. l 200,000

17 . 9 218,100

18.7 646,000

1,574,000

23 . 5 263,220

15 . 8 402.000

75,000

256,000

17.9 ~ 863,200

17.9 79,900

19 . 9 167, 000

17.9 ~ 227.200

17. 9 159,400

17.0 3, 183,920

t .

Remaining Primary Oil Cumulative Oil Production, Reserves· Ba.rrels Barrels, Mar c h 1, 1957 March 1, 1957

3,972 12,928

148,693 344,307

48,126 151,874

19,113 198, 987

176 , 680 469,320

396,584 1,1 77,416

85,550 • 111 ,6 10 V 107,000· 295,000

10,200 · 64,800

17. 000 • 239,000

52, 000 • ~ 186,200 677,000

28.800 (est. ) 51,100

71.343 95,657

~ ~ 98,960 145,240

84 , 600 * 74,800 V-880,694 2, 303, 226

..

Table 6

OIL RESERVES UNDER FULL SCALE WATER FLOOD

ColUITlbus Formation

RODNEY FIELD


Floodable Reser- Ultimate Recovery Cumulative Oil Remaining Reserve voir Volume under Production - Bbl. Under Water Flood

Operator Lease Acre -Feet Water Flood March 1, 1957 Barrels

Felmant Oil Corporation A. .Braddon 141. 06 62,370 3,972 58 , 398

A . C. Gillie 5 1,486.55 942,510 148,693 793,817

J. D. Graham 846.05 379,780 48,126 331,654

E. J . MacMillan 1,022.00 428,550 19,11 3 409,437

J. McMillan 2 , 570 . 50 1,402,800 176,680 1,226,120

Sub- Total 6 ,066.16 3,216,0 10 396,584 2,819,426

John Beattie S. Sabjan 8 18.41 444,500 85,550 • 358,950

Jim Beattie J. Braddon 1,852.86 965,060 107,000 • 858,060

Colthart 349.86 177,750 10,200' 167,550

N. D. McMiLlan 1,415.10 705,020 17,000 • 688,020

F. Wright 464 .21 263,910 52,000 * 211,910

Sub - Total 4,082.03 2, 111,740 186,200 1,925,540

Comfort Tunks 299.36 163,030 28,800 • 134,230

Dominion Natural Gas F. G. Purcell 557 .32 307,980 71, 343 236,637

J. Rubi 223 . 40 135, 850 27,617 108,233

Sub- Tot a l 780.72 443 ,830 98,960 344,870

New Bristol A. McCallum 426.25 259,620 84,600 • 175,020

TOTAL 12,472.93 6,638,730 880,694 5,758,036

* Cumul a tive production as of March 1, 1957 estimated.

Date

March I, 1957 March I, 1958 March 1, 1959 March I , 1960 March 1 , 1961 March I, 1962 March I, 1963 March I, 1964 March I , 1965 March I , 1966 March 1 , 1967 March I, 1968 March I, 1969 March 1 , 1970 March 1 , 1971 March 1 , 1972 March I , 1973 March I , 1974 March I , 1975 March I , 1976 March 1 , 1977 March I, 1982 March I , 1987 March I, 1992 March I, 1997 March I, 2002 March I, 2007 March 1 , 2014 March I, 2017 March 1 , 2022

Table 7

PREDIC TED FIELD PERFORMANCE

Primary Depletion and Plan I Water Flood Program

RODNEY FIELD


Average Daily Oil Production - Barrels Primary Depletion Plan I - W ate r Flood

657 602 508 2 , 606 418 3,172 356 2,504 309 1,756 276 1,264 247 869 226 720 207 601 191 504 176 415 164 361 155 222 147 144 137 37 131 125 119 112 107

92 68 53 37 25 14

9 6 4

Date

March 1, 1957 March 1, 1958 March 1, 1959 March 1, 1960 March 1, 1961 March 1, 1962 March 1, 1963 March 1, 1964 March 1, 1965 March 1, 1966 March 1, 1967 March 1 , 1968 March 1, 1969 March 1, 1970 March 1, 1971 March 1, 1972 March I , 1973 March 1 , 1974 March 1 , 1975 March 1 , 1976 March 1, 1977 March 1, 1982 March I, 1987 March 1 , 1992 March 1 , 1997 March I , 2002 March I , 2007 March I , 2012 March 1 , 2017

Table 8


Primary Depletion and Water Flood Program

Felmont Oil Corporation Leases

RODNEY FIELD


Average Daily Oil Production - Barrels Primary Water Flood Programs Depletion Plan I Plan II

301 263 251 239 1,279 1,544 198 1 , 524 1,707 171 1,205 1,247 149 868 743 135 621 573 120 413 441 III 350 327 101 299 219

95 254 192 86 207 164 81 187 137 77 142 110 73 102 71 68 60 65 62 59 55 52 48 40 34 30 20

9 4 4

Plan III

330 1,685 1,800 1,625

767 548 397 329 243

Date

March 1, 1957 March 1, 1958 March 1, 1959 March 1, 1960 March 1, 1961 March 1, 1962 March 1, 1963 March 1, 1964 March 1, 1965 March 1, 1966 March 1 , 1967 March 1 , 1968 March 1, 1969 March 1, 1970 March 1, 1971 March 1, 1972 March 1, 1973 March 1, 1974 March 1, 1975 March 1 , 1976 March 1 , 1977 March 1 , 1982 March 1 , 1987 March I , 1992

Table 9



John Beattie

Sabjan Lease

RODNEY FIELD


Average Daily Oil Production - Barrels Primary Water Flood Programs Depletion Plan I Plan II Plan

51 34 34 42 41 130 130 188 35 V 200 200 270 29 178 178 229 26 118 ll8 97 23 82 82 70 21 58 58 55 19 52 52 43 18 44 44 16 33 33 15 27 27 14 22 22 13 17 17 12 12 11 II 10 10

9 8 7 6

III

..

Table 10



Jim Beattie Leases

RODNEY FIELD

Elgin County , Ontario , Canada

Average Daily Oil Production - Barrels Primary Water Flood Pro~rams

Date Depletion Plan I Plan II Plan III

March 1 , 1957 March 1 , 1958 211 212 131 418 March 1 , 1959 155 795 825 1 , 400 March 1 , 1960 125 956 951 1, 400 March I , 1961 104 876 951 844 March 1 , 1962 90 651 647 493 March 1 , 1963 79 441 438 329 March 1 , 1964 70 312 301 260 March 1 , 1965 64 250 252 132 March I , 1966 59 202 214 March 1 , 1967 54 169 164 March 1 , 1968 50 144 137 March 1 , 1969 46 124 123 March 1, 1970 43 63 101 March 1 , 1971 41 50 80 March 1 , 1972 39 32 March I , 1973 37 March 1 , 1974 35 March 1 , 1975 33 March 1 , 1976 31 March 1 , 1977 30 March 1, 1982 26 March 1 , 1987 20 March 1 , 1992 16 March 1 , 1997 7 March 1 , 2002 6 March 1 , 2007 5 March 1 , 2012 5 March 1, 2017 4 March 1 , 20 22 4

Table 11

COMPARISON OF WATER INJECTION PROGRAMS

RODNEY FIELD


Plan I Plan II Plan III Five- Staggered Staggered Spot Line Drive Line Drive

Number of Producing Oil Wells * 67 (13) 74 (58) 129 (36)

Number of Injection Wells * 80 (28) 102 (102) 154 (154)

Wells to be plugged & abandoned 18 99 27

Approximate Pattern Size-Acres 12 . 8 13 . 3 6 . 6

Capital Investments

Injection and Producing Wells $191 , 800 $751,200 $819,600

Water Injection Plant & Facilities $212 , 083 $227 , 243 $282,914

Total $403 , 883 $978 , 443 $1 , 102,514

Initial Injection Rate

Total Field - B WPD 4 , 800 6,120 6,160

Per Well - BWPD 60 60 40

* Figures in parentheses are number of wells to be drilled.

· '

Table 12

ECONOMIC COMPARISON

FUTURE FIELD PERFORMANCE

Primary Depletion and Water Flood Program - Plan I

RODNEY FIELD


Primary Plan I Depletion Water Flood

Future Field Life- Years After March 1, 1957 65 15

Gross Oil Reserves 2,303,226 5,758,036

Net Oil Reserves to . 875 NWI 2,015,323 5,038,281

Gross Income to NWI $6,307,960 $15,769,821

Operating Expenses $3,168,285 $3,745,650

Net Income to NWI $3,139,675 $12,024,171

Capital Investments ---------- $403, 883

Net Profit to NWI $3,139 , 675 $11,620,288

Gain Over Primary ---------- $8,480,613

Discounted Net Income to NWI $2,259, 183 $10,088,010

Discounted Capital Investment ---- - ----- $399,036

Discounted Net Profit to NWI $2 , 259 , 183 $9,688,974

Gain Over Primary ---------- $7,429,791

..

Table 13

ECONOMIC COMPARISON

Primary Depletion and Water Flood Programs

Felmont Oil Corporation Working Interests

RODNEY FIELD


Water Flood Programs Primarl: Depletion Plan I Plan II Plan III

Future Field Life - Years After March 1, 1957 60 15 14 9

Gross Oil Reserves 1,177,416 2,819,426 2,819,406 2,819,406

Net Oil Reserves 1,022,191 2,447,723 2,447,707 2,447,707

Gros s Inc ome to NWI $3,199,458 $7,661,373 $7,661,323 $7,661,323

Operating Expenses $1,554,470 $1 ,833,350 $1,832,250 $1,833,000

Net Income to NWI $1,644,988 $5,828,023 $5,829,073 $5,828,323

Capital Inve s tments ---------- $209,713 $415,597 $471,409

Net Profit to NWI $1,644,988 $5,618,310 $5,413,476 $5 ,356,9 14

Gain Over Primary ---------- $3,973,322 $3,768,488 $3,711,926

Dis counted Net Income to NWI $1,142,851 $4,878,271 $4,975,708 $5,051,076

Dis counted Capital Inve s tments ---------- $207,196 $410,610 $465, 752

Discounted Net Profit to NWI $1,142,851 $4,671,075 $4,5 65, 098 $4,585,324

Gain Over Primary ---------- $3,528,224 $3,422,247 $3,442,47 3

Table 14

ECONOMIC COMPARISON


John Beattie Working Interest

RODNEY FIELD


Water Flood Program Primary Depletion Plan I Plan II Plan III

Future Field Life - Years After March I, 1957 35 13 13 8

Gros sOil Re se rve s 177,670 358,950 358,950 362,550

Net Oil Reserves to . 875 NWI 155,462 V 314,081 314,081 317,231

Gros s Income to NWI $486,596 V $983, 074 $983, 074 $992,933

Operating Expenses $281,900 V $235,600 $235,600 $235,500

Net Income to NWI $204,696 V $747,474 $747,474 $757,433

Capital Investments -------- $29,100 $52,107 $66,497

Net Profit to NWI $204,696 $718,374 $695, 367 $690,936

Gain Over Primary -------- $513,678 $490,671 $486, 240

Discounted Net Income to NWI $157,476 $622,078 $622, 078 $655,934

Discounted Capital Investments -------- $28,751 $51,482 $65,699

Discounted Net Profit to NWI $157,476 $593, 327 $570,596 $590,235

Gain Over Primary -------- $435,851 $413,120 $432, 759

Table 15

ECONOMIC COMPARISON


Jim Beattie Working Interests

RODNEY FIELD


Water Flood Program Primary DeEletion Plan I Plan II Plan III

Future Field Life - Years Afte r March 1, 1957 65 15 14 8

Gross Oil Reserves 677,000 1,925,540 1,925,540 1,925,540

Net Oil Reserves to .875 NWI 592,375 1,684,848 1,684,848 1,684,848

Gross Income to NWI $1,854,133 $5,273,574 $5,273,574 $5,273,574

Operating Expenses $902,885 $1,252,500 $1,252,000 $1,251,800

Net Income to NWI $951,248 $4,021,074 $4,021,574 $4,021,774

Capital Investments ---------- $129,320 $277, 328 $368, 370

Net Profit to NWI $951,248 $3,891,754 $3,744,246 $3,653,404

Gain Over Primary ---------- $2,940,506 $2,792,998 $2,702,156

Discounted Net Income to NWI $694, 330 $3,372,530 $3,353,986 $3,562,895

Discounted Capital Investments ---------- $127,768 $274,000 $363,950

Discounted Net Profit to NWI $694, 330 $3,244,762 $3,079,986 $3,198,945

Gain Over Primary ---------- $2,550,432 $2,385,656 $2 ,504,615

Date

Interva l

Oil Production,

B a rrels

Table 16

SUMMARY

ECONOMIC ANALYSIS OF FUTURE PRIMARY PERFORMANCE

Cumul a tive

Oil Production ,

Barre ls

875 Net Working Interest

All L eases Combi ne d

ROD NEY FIELD

Elgin County, Ontario, Ca nad a

Gross Income Gross Oil Less Sev. Tax,

to NWI.(I) @ $301 300; 2) Ope r a ting Barrels per B arre l Expen ses

Net Income to NWI

C urn ul a ti ve Net Inc o me

t o NWI

Discounted Net Income to NWI @

50/0

Cumulative Disc oun ted Net Inc ome

to NWI

3-1-1957

3-1-1958

880.694

239.923 1.120.617 209.934 $ 657.095 $ 115.810 $ 541.285 $ 541,285 $ 528 ,3 97 $ 528 . 397

3-1-1959

3-1-1960

3-1-1961

3-1-1962

3-1-1963

3-1-1964

3-1-1965

3-1-1966

3-1-1967

3-1-1968

3-1-1969

3-1-1970

3-1-1971

3-1-1972

3-1-1973

3-1-1974

3-1-1975

3-1-1976

3-1-1977

3-1-1982

3-1-1987

3-1-1992

3-1-1997

3-1-2002

3-1-2007

3-1-2012

3-1-2017

3-1-2022

185.463 1.306.080

152,470 1,458,550

129,940 1,588.490

112.848 1,701,3 38

100.759 1,80 2 ,0 97

90.220 1.892.317

82,596 1,974.913

75.375 2 .050,288

69.873 2 .120.161

64,282 2 .184.44 3

59.904 2.244,347

56.720 2,301.067

53.579 2 . 354.646

50,160 2 ,404,806

47.737 2,452.543

45.508 2 ,498.051

43.254 2.541.305

40.938 2 ,582.243

38.906 2 .621,149

167.923 2 .789.072

124.035 2 .913,107

96,609 3 ,00 9 ,716

67.507 3,077.223

46.290 3.123.513

25.352 3,148,865

16.554 3,165,419

11,501 3.176,920

7,000 30183.920

162.281

133 .410

113.700

98 .740

88 .165

78.943

72.270

65. 953

6 1.139

56.246

52.415

49.630

46.882

43.891

41.770

39.820

37.847

35 .822

34.039

146 .936

10 8 . 529

84.534

59.068

40,505

22.182

14.484

10.063

60125

507.938 115.810 392.128 933 ,41 3

4 17.574 115,810 301.764 1,235,177

355.880 11 5 ,810 240 ,070 1,47 5,247

309 .057 115, 810 193,247 1 , 66 8 . 494

275. 956 115 . 810 160.146 1 , 828 .64 0

247.091 115.810 131,281 1 , 959 , 921

226.205 115,810 110, 395 2 , 070 , 316

206.434 1150100 91 . 334 2 . 16 1.65 0

191.365 114.3 90 76 . 9 75 2 . 238 . 625

176.0 50 113,6 80 62 , 370 2 . 300 , 995

164.059 109 , 87 0 54 ,1 89 2 , 355 .1 84

155.342 106,780 4 8 , 562 2 ,4 03 ,746

146.740 103.6 90 43 ,05 0 2 , 446 , 796

137.378 100,635 36,743 2 ,483 , 539

130.741 99.495 31,24 6 2 ,514,78 5

124.637 89.0 80 35,557 2 ,5 50 , 342

118. 4 59 78,665 39,794 2 ,5 90 ,1 36

1120124 68, 25 0 43.874 2 ,6 34 , 010

106.543 57.9 05 48,638 2 ,68 2 ,64 8

45 9 . 90 8 272,050 187, 858 2 ,870,5 06

339 .6 95 223 , 95 0 115 ,74 5 2 . 986,2 51

264 .593 191.890 72 ,70 3 3 . 058 , 954

184.883 145.475 39.408 3 ,098,362

126.780 104.125 22.655 3 .1 2 •• 017

69.430 57.625 11,805 3 .1 32 ,822

45.335 40.325 5.010 3 .137,832

31.497 30,325 1,17 2 3, 13 9, 0 04

190171 18,500 671 3tl39,675

TOTAL 2.303.226 2.015.323 $ 6,307.960 $ 3,168, 2 85 S 3,139,675

(1) NWI - estimated as .875 (2) Crude price $3.48 Ieee $ . ,5 tr&nspor t atiOft charge.

364.565 892.962

267.1 9 1 1,160,153

202 . 442 1 . 362 , 595

155 . 198 1 . 5 17 ,79 3

122 .49 1 1.640 . 28 4

9 5.632 1 , 735 . 9 16

76 .5 89 1, 8 12 . 505

60 . 347 1. 872,852

48.438 1, 921 . 290

3 7.37 9 1, 95 e , 66 9

30 , 929 1. 989 , 598

26,3 96 2 . 0 15 . ,94

22 , 287 2 . 03 8 . 28 1

18.117 2.056. 398

14,672 2.071.07 0

15. 900 2.086. 970

16.949 2.10 3 . 919

17.797 2,121 . 716

18 .789 2.140.5 0 5

62.691 2 . 203 .196

30.267 2 . 233 . 4 6 3

14,894 2.248 , 357

6.325 2.254.682

2.849 2.257.531

1.163 2.25 8 .694

386 2,259.080

71 2.259.151

32 2.2590183

$ 2.2590183

Date

..

Interval

Oil Production,

Barrels

Table 17 SUMMARY


Felmont Oil Corporation Working Interests

Cumulative Oil

Production, Barrels

RODNEY FIELD

Elgin County. Ontario, Canada'


to NWI.(l)@ $3.1300(2) Operating Barrels per Barrel Expenses

" . 396,584 ... "0.'"

Net Income to NWI

Cumulative Net Income

to NWI


5'/0

Cumulative Discounted Net Income

to NWI

3-1-1957

3-1-1958

3-1-1959

109,950 506,534 i ' ''''[ 5'455 $

593'869 ~. ;. 75,821

666, 1141{f f{ 62,721

728.656 54,297

298,774 $ 49,380 $ 249,394 $ 249,394 $ 243,455 $ 243,455

3-1-1960

3-1-1961

3-1-1962

3-1-1963

3-1-1964

3-1-1965

3-1-1966

3-1-1967

3-1-1968

3-1-1969

3-1-1970

3-1-1971

3-1-1972

3-1-1973

3-1-1974

3-1-1975

3-1-1976

3-1-1977

3-1-1982

3,- 1" 1987

3- 1-1992

3-1-1997

3-1-2002

3-1-2007

3-1-2012

3-1-2017

87,335

72,245

62.542

54,341 782.997

49.185 832,182

43,856 876.038

40,569 916,607

36.867 953.474

34.559 988.033

31,462 1,019,495

29.430 1.048.925

28,149 1.077,074

26.710 1.103,784

24,711 1.128.495

23.623 1.152.118

22,604 1.174.722

21.496 1.196.218

20.211 1.216.429

19,142 1,235,571

87,164 1.322.735

72,345 1,395.030

62,451 1,457,531

53.572 1,511,103

35.790 1.546.893

15.852 1.562.745

7.754 1.570,499

3.501 1.574,000

47017&

42,700

38,074

35,221

32,006

30,004

27,314

25,549

24,438

230190

21,453

20,508

19,624

18,662

17,547

16,618

75 , 673

6 2 . 807

5' .. 218

46.511

31,070

13,763

6.732

3,039

237,321 49.380 187,941

196,316 49,380 146.936

1&9.950 49.380 120.570

147,&60 49,380 98.280

133.651 4903 8 0 84.271

119.173 490380 69,793

110.241 490380 60.861

100,177 49,380 50.797

93,914 49.380 44.534

85,493 49,380 36.113

79.9&8 49.260 30.708

76,491 490140 270351

72,584 49.020 23.564

670149 48.905 18,244

640190 48,905 15,285

61,423 42.835 18,588

58.412 36,765 21,647

54.922 30,695 24,227

52.014 24.690 270324

236,857 1130382

196.586 121.675 74,911

169.702 121,075 48,627

145.580 117.750 27,830

97.249 82,800 14.449

43.078 360300 6,778

21.071 19,000 2,071

9.512 9.000 512

TOTAL 1,177,416 1,022,191 $ 3,199,458 $ 1.554,470 $ 1,644,988

(l) NWI - .868164 (2) Crude price $3.48 less $. 35 transportation charge.

437,335 174,731 418018&

584,271 1300101 548,287

704,841 101,672 &49,959

8030121 78,929 728.888

887,392 64,456 793,344

9570185 50,841 844,185

1.018,046 42,224 886,409

1,068,843 33.564 919,973

10113,377 28.023 947,99&

10149.490 21,644 969,640

101800198 17,527 98701&7

1,207,549 14,867 1.002,034

1,231,113 120199 1,014,233

1,249,357 8.995 1.023.228

1,264,642 7,177 1.030,405

1,283,230 8,312 1,038.717

1,304,877 9,219 1,047,936

1,329,104 9,828 1,057,764

1,356,428 10,556 1,068,320

1,469,810 37,836 1.1060156

1,544,721 19,589 1,125,745

1,593,348 9,962 1,135.707

1,6210178 4.468 101400175

1,635,627 1,817 1,1410992

1,642.405 668 1.142,660

1.644,476 160 10142,820

1,644,988 31 1,142,851

$ 1,142,851

Date

Table 18

ECONOMIC ANAL YSIS OF FUTURE PRIMARY PERFORMANCE

Interval Cumulative

Oil Oil Production, Production,

Barrels Barrels

3.912


A. Braddon Lease

RODNEY FIELD


Gross Income Gross Oil Les. Sev. Tax

to NWI,(l)@ $3,1300(2) Operating Barrels per Barrel Expenses

Net Income to NWI


to NWI


5%


to NWI

3-1-1951

3-1-1958 1.150 5.122 1.519 $ 4.754 $ 950 $ 3.804 $ 3.804 $ 3.113 $ 3.113

3-1-1959 1.302 1.024 10131 3.541 950 2.591 6.395 2.409 6.122

3-1-1960 1.059 8.083 919 2.876 950 1.926 8.321 1.705 7.821

3-1-1961 815 8.958 160 2.319 950 1.429 9.150 1.205 9.032

3-1-1962 145 9.103 646 2.022 950 1.012 10.822 861 9.893

3-1-1963 648 10.351 563 1.162 950 812 11.634 621 10.514

3-1-1964 582 10.933 505 1.581 950 631 12.265 460 10.914

3-1-1965 528 11.461 459 1.436 950 486 12.751 337 11.311

3-1-1966 480 11.941 416 1.302 950 352 130103 233 11.544

3-1-1961 437 12.318 380 1.190 950 240 13 .343 151 11.695

3-1-1968 408 12.186 354 10108 950 158 13.501 95 11.790

3-1-1969 383 130169 332 1.039 830 209 13.710 119 11.909

3-1-1910 360 13.529 313 980 110 210 13.980 141 12.056

3-1-1911 341 13. 8 70 296 926 590 336 140316 114 12.230

3-1-1912 318 140188 276 864 475 389 14.705 192 12.422

3-1-1913 294 14.482 255 198 475 323 15.028 152 12.574

3-1-1974 281 14.16 3 244 164 475 289 15.311 129 12.103

3- 1-1975 275 15. 038 239 748 475 213 15. 590 116 12.819

3-1-1 976 263 15.301 228 714 475 239 15.829 91 12.916

3-1-1977 252 15.553 219 685 475 210 16.039 81 12.991

3-1-1982 1.097 16.650 953 2.983 2 .400 583 16.622 195 130192

3-1-1 987 250 16. 9 00 217 619 6eo 19 16.101 13.213

TOTA L 12.928 11.224 $ 35tl31 $ 18.4 30 $ 16.701 $ 13.213

(I) NWI - .868 164 (2 ) Crude pri ce $3.4 8 less $.35 tr ansportation c harge.

Date

Table 19


Interval Cumulative

Oil Oil Production. Production,

Barrels Barrels

148.693


A. C. Gillies Lease

RODNEY FIELD



to NWI.(l)@ 53el30C(2) Operating Barrels per Barrel Expenses

Net Income to NWI


to NWI


50/.


to NWI

3-1-1957

3-1-1958 32.807 181.500 28.482 $ 890149 $ 15.200 $ 73.949 $ 13.949 $ 720188 $ 720188

3-1-1959 26.700 208.200 230180 72.553 15.200 57.353 1310302 53.322 125.510

3-1-1960 22.300 230.500 19.360 60.597 15.200 450391 116.699 400196 165.706

3-1-1961 19.500 250.000 16.929 52.988 15.200 31.788 214.487 31.865 197.571

3-1-1962 16.500 266.500 14.325 44.837 15.200 29.637 2440124 23.802 2210373

3-1-1963 15.000 281.500 13.022 40.159 15.200 25.559 269.683 19.549 240.922

3-1-1964 13.200 294.700 11.460 35.810 15.200 20.670 2900353 255.979

3-1-1965 12.300 307.000 10.678 33.422 15.200 18.222 308.575 12.642 268.621

3-1-1966 11.000 318.00C 9.550 29.891 15.200 14.691 323.266 9.707 278.328

3-1-1967 10.500 328.500 9.116 28.533 15.200 13.333 336.599 8.390 286.718

3-1-1968 9.500 338.000 8.248 25.817 15.200 10.617 341.216 6.363 293.081

3-1-1969 9.000 347.000 7.813 24.454 15.200 9.254 356.410 5.282 2980363

3-1-1970 8.500 355.500 7.379 23.096 15.200 1.896 3640366 4.292 302.655

3-1-1971 8.000 363.500 6.946 21.141 15.200 6.541 310.907 3.386 306.041

3-1-1972 7.500 371.000 6.511 20.380 15.200 5.180 376.087 2.554 308.595

3-1-1973 7.000 378.000 6.077 19.021 15.200 3.821 379.908 1.794 310.389

3-1-1974 6.500 384.500 5.643 17.662 13.300 4.362 384.270 1.951 312.340

3-1-1975 6.500 391.000 5.643 17.663 11.400 6.263 390.533 2.667 315.007

3-1-1976 6.000 397.000 5.209 160304 9.500 6.804 397.337 2.760 317.767

3-1-1977 5 .500 402.500 4.775 14.946 7.600 7.346 404.683 2.838 320.605

3-1-1982 25.500 428.000 22.138 69.292 38.000 31.292 435.975 10.442 331.047

3-1-1987 22.000 450.000 190100 59.783 38.000 21.783 457.758 5.696 336.743

3-1-1992 18.200 468.200 15.800 49.454 38.000 11 .454 469.212 2.347 339.090

3-1-1997 16.300 484.500 140152 44.296 38.000 6.296 475.508 1.011 340.101

3-1-2002 8.500 493.000 7.379 23.096 21.050 2.046 477.554 257 340.358

TOTAL 344.307 298.915 $ 935.604 $ 458.050 $ 471 .554 $ 340.358

(I) NWI - .868164 (2) Crude price $3.48 less $.35 transportation charge.

Date

Table 20

ECONOMIC ANALYSIS OF FUTURE PRIMAR Y PERFORMANCE

Interval Cumulative

Oil Oil Production, Production.

Barrels Barrels

F e lmont Oil Corporation

J. D. Graham Leas e

RODNEY FIELD

Elgin County, Ontario, C anada

Gross Income Gros. Oil Less Sev. Tax,

to NWI~I)@ $3.1300(2) Operating Barrels per Barrel Expenses

Net Income to NWI


to NWI


5%

Cumula tive Discounted Net Income

to NWI

3-1-1557

3-1-1 958 13,80 0

48.1 26

61. 92 6 11.981 $ 37.501 $ 8.530 $ 28.971 $ 28.971 $ 28.281 $ 28.281

3- 1-1 95<; 1 1 03~ 3 73.25 9 9.839 30.796 8.5 30 22.266 51.237 20.701 48.982

3- 1-1 960 9,615 8 2.874 8 .347 260126 8. 5 30 17.596 68.833 15.580 64.562

3-1-1 961 8 ,400 91. 274 7.293 22.827 8.530 14. 297 83.130 12.056 76.618

3-1-1962 7.471 98.745 6.486 20.301 8.530 11.771 94.901 9.453 86.071

3-1-1963 6.737 105.482 5.848 18.304 8.530 9.774 104.675 7.476 93.547

3-1-1964 6.048 111.530 5.251 16,436 8.5 30 7.906 112.581 5.759 99.306

3-1-1 96 5 5.591 117.121 4.854 15.19 3 8.5 30 6.663 119.244 4.623 103.929

3-1-1966 5.125 122. 24 6 4.449 13.925 8.5 30 5.395 124.639 3.565 107.494

3-1-1967 4.731 126. 9 77 4.108 12,858 8.530 40328 128.967 2.723 110.217

3-1-1 968 4.42 9 13 1.40 6 3.845 12.035 8.530 3.505 132.472 2.101 112.318

3-1-1969 4.167 135.573 3.617 11.321 8.530 2.791 135.263 1.593 113.911

3-1-1970 3.935 139.508 3.417 10.696 8.530 2.166 137.429 1.177 115.088

3-1-1971 3.676 143.184 30191 9.987 8.530 1.457 138.886 754 115.842

3-1-1 9 72 3.486 146.670 3.026 9.472 8.530 942 139.828 464 116.306

3-1-1 9 73 3.297 149.967 2.863 8.961 8.530 431 140.259 202 116.508

3-1-1974 30179 1530146 2.760 8.639 7.460 1.179 141.438 527 11 7 .035

3-1-1 975 3.024 156.170 2.625 8.216 6.390 1.826 143.264 778 117.813

3- 1- 1976 2.860 159.0 30 2.483 7.772 5.320 2.452 145.716 995 118.808

3- 1-19 77 2.7 3 3 161.76 3 2.373 7.427 4.265 3.162 148.878 1.222 120.030

3-1-1 9 82 12.275 174.038 10.656 33.354 21.325 12.029 160.907 4.0110 124.044

3-1-1987 10.272 184.310 8.918 27.913 21.325 6.588 167.495 1.723 125.767

3-1-1 992 8.907 193.217 7.733 24.204 21.325 2.879 170.374 590 126.357

3-1-1997 6.783 200.000 5.889 18.433 18.000 433 170.807 70 126.427

TOTAL 151.874 131.852 S 412.697 S 241.890 S 170,807 126.427

(I) NWI - .868164 (2) Crude price $3 . 48 lesB $.35 tranBportation charge .

Date

Interval

Oil Production,

Barrels

Table 21


CutTlulative

Oil Production,

Barrels


E. J . MacMillan Lease

RODNEY FIELD



to NWI.(I) @ 5301300(2) Operating Barrels per Barrel Expenses

Net Income to NWI


to NWI

Discounted Net Income to NWI @ 5'.

Cumula tive Discounted Net Income

to NWI

3-1-1957

3-1-1958 11.273

19.113

300386 9.787 S 30.633 S 7.600 S 23.033 S 23.033 $ 22.485 S 22.485

3-1-1959 10.000 40.386 8.681 27.172 7.600 19.572 42.605 18.196 40.661

3-1-1960 9.071 49.457 7.876 24.652 7.600 17.052 59.657 15.098 55.779

3- 1-1961 8.267 57.724 7.177 22 .464 7.600 14.664 74.521 12.534 680313

3-1-1 962 7.625 65.349 6.619 20.717 7.600 13.117 87.638 10.534 76.647

3-1-1963 7.000 72.349 6.078 19.024 7.600 11.424 99.062 8.738 67.565

3-1-1964 6.526 78.8E 5 .665 17.732 7.600 10.132 109.194 7.381 94.966

3-1-1965 601 5 0 85.02~ 50339 16.711 7 .600 9.111 116.305 6.321 101.267

3-1-1966 5.762 90.787 5 .003 15.659 7.600 8.059 126.364 5.325 106.612

3-1-1967 5. 391 96 ol 78 4.660 14.649 7.600 7.049 133.413 4.436 111.046

3-1-1968 5.125 1010303 4.449 13.925 7.600 6.325 139.738 3.791 114.639

3-1-1969 4. 880 1060183 4.237 13.262 7.600 5.662 145.400 3.232 118.071

3-1-1970 4.654 110.8 3 7 4.040 12.645 7.600 5.04 5 150.44 5 2.742 120.613

3-1-1 9 71 403 93 115.2 30 3 .614 11. 9 38 7.600 154.76 3 2.246 123.059

3-1-1972 4. 207 11 9 .4 3 7 3 . 653 11. 434 7 .600 3 . 83 4 158.617 1.890 124.949

3-1-1973 4.03 2 123.46S 3 .500 10. 9 5 5 7.600 3035 5 161.972 1.575 126.524

3-1-1 974 3. 844 12703 13 3 0337 10 .445 6 .6 50 3 .79 5 165.767 1.697 126. 2 21

? - 1 -1 9 7 ~ 3.69 7 1 3 1. 01 0 3 . 210 10 .047 5 .700 403 47 170.114 1.851 13 0 .072

3- 1-1 976 3 . 58 8 1 3 4, 590 3 .115 9 .750 4.750 5.000 175.114 2.0 26 13 2 01 00

3- 1-1 9 77 ::a,~57 138 .0 5 5 3 .001 9. 393 3 . 300 5. 593 160.707 20161 134. 261

3- 1- 19 8 2 15 .4 92 153 . 547 13 . 450 4 2 .09 8 19 .000 23 . 09 6 203. 8 0 5 7.7 08 141. 9 6 9

:' - 1-1 98 7 1 3 , :! 23 166. 87 0 11 . 566 36. 202 19 .000 17 . 202 221.007 4.496 146. 467

3- 1- 1992 11, 13 4 4 17 8 . 71 4 10. 263 32 . 186 19 .000 13 0166 234 0193 2.701 149.166

3-1- 19n 10,Ll. 89 18 9. 20 ;: 9 .106 28 .5 0 2 19 .0 0 0 9.5 02 243.69 5 1.525 150.693

3 - l - 2 C02 9 . 290 198 .49 , 8 .06 5 19 .00 0 6. 24 3 249.938 765 151.476

3- 1- 200 7 8 . 352 206 , 8 4 5 7. 25 1 22 .6 96 19.000 3 .69 6 253.634 364 151.642

3 - 1- 2 012 7 . 75 4 214. 59 ° 6 .7 32 21.071 19.0 0 0 2 . 07 1 2 55.705 160 15 2 .002

3- l- 2 J l "7 3 , 5 0 ~ 218 01 0 0 3 . 039 9 . 512 9.000 5 12 256.217 3 1 15 2 .033

TOTAL 198 , ~87 172 . 75 3 $ 540 07 17 $ 28 4. 50 0 S; 256. 217 152.033

(I) N WI - ,868 164 (2 ) Crud e pr ice $3. 48 le s s $.35 transpo rtati on c ha r ge .

Date

Table 22


Interval Cumulative


Barrels Barrels


John McMillan Lease

RODNEY FIELD



to NWI.(l)@ $301300(2) Operating Barrels per Barrel Expenses

Net Income to NWI


to NWI


5%


to NWI

3-1-1957

3-1-1958 50.320

176,680

227.000 43.686 $ 136.737 $ 170100 S 119.637 $ 119.637 $ 116.788 $ 116.788

3-1-1959 38,000 265,000 32.990 103.259 170100 860159 205.796 80.103 196.891

3-1-1960 30,200 295,200 26.219 82.065 17.100 64.965 270,761 57.522 254.413

3-1-1961 25,500 320,700 220138 69.292 170100 520192 322,953 44.012 298.425

3-1-1 962 22,000 342,700 190100 59.783 170100 42 ,683 365.636 34.279 332.704

3-1-1963 19,800 362,500 17.189 53.802 170100 36.702 402,338 28.072 360.776

3-1-1964 17,500 380.000 15.193 47,554 170100 30,454 432.792 22.184 382.960

3-1-1965 16,000 396,000 13,891 43.479 17,100 260379 4590171 18.301 401.261

3-1-1966 14,500 410,500 12.588 39.400 170100 220300 481.471 14.734 415.995

3-1-1967 13,500 424.000 11 .720 36.684 17,100 19,584 501,055 12.323 4280318

3-1-196e 12,000 436, 000 10.418 32.608 170100 15,508 516,563 9,294 437.612

3-1-1969 11 ,000 447,000 9 .550 29,892 17.100 12 .792 5290355 7.301 444.913

3-1-1970 10,700 457,700 9 .28 9 29.074 17,100 11,974 5410329 6.509 451.422

3-1-1971 10,30 0 41'>8,000 8.943 27.992 170100 10,892 552,221 5.639 457.061

3-1-1972 9,200 477,200 7,987 24.999 17,100 7.899 5600120 3,895 460.956

3-1-19B 9,000 486,200 7,813 24.455 17.100 7.355 567.475 3.454 464.410

3-1-197" 8,800 495,000 7.1'>40 23.913 14,950 576,438 4,008 468.418

3-1-1975 8,000 503.000 6 .94 5 210738 12.800 8,938 5850376 3.807 472.225

3-:-1976 7,500 510,500 6.512 2003 8 2 10.650 9,732 595010 8 3.948 4760173

3-1-1 9 77 7 ,20 0 517,700 6.250 19.563 8.550 11,013 1'>060121 4,254 480.427

:;-1 -1 g e 2 32,800 550,500 28 .476 89.130 42.750 460380 652,501 15.477 495.904

3- 1-1 987 26 , 5eo 577,000 23.006 72,009 42,750 29,259 681,760 7.651 503.555

3-1-19 92 23,500 1'>00,500 20,402 63.858 42,750 2 1 tloe 702,868 4.3 24 507.879

3-1-1 9 97 20,00D 620,50 ·:J 17.364 54,349 42,750 714,467 1.862 509 .741

3-1- 2002 18,000 638,500 15.626 48.910 42,750 1'>,160 720,627 775 510,516

3-1 - 2007 7,50 C 1'>4 6 , 000 6.512 200382 17 ,300 3 , 092 723,709 304 510 ,82 0

TOTAL 46903 20 407.447 $ 1,275, 3 0 ~ $ 551,600 $ 7230709 510.6~0

(1) NWI - .868164 (2) Crude price $3.48 less $.35 transportation charge

Date

3-1-1957

Table 23


Interval Cumulative

Oil Oil Production. Production,

Barrels Barrels

85.550

John Beattie

Sabjan Lease

RODNEY FIELD


Gross Income Cumulative Gross Oil Less Sev . Tax,

to NWI,(l)@ 5301300(2) Operating Net Income Net Income Barrels per Barrel Expense\! to NWI to NWI


5'.

, ]


to NWI

3-1-1958 18.571 - 104.121 16.250 $ 50.863

, ~? ;,~?:~,LYY,.~ $ 11.400 $ 39.463 S 39.463 S 38.523 $ 38.523

3-1-1959 15.000 - 119.121 13.125

3-1-1960 12.600 131.721 11.025

3-1-1961 10.750 142.471 9.406

3-1-1962 9.538 152.009 8.346

3-1-1963 8.400 160.409 70350

3-1-1964 7.688 168.097 6.727

3-1-1965 6.944 175.041 6 .076

3-1-1966 6.400 181.441 5.600

3-1-1967 5.35 7 187.298 50125

3-1-1968 5.478 192.776 4.793

3-1-1969 197. B5? 4.447

3-1-1970 4.8C8 202 .667 4. 207

3-1-1 9 71 4.519 207 0186 3 . 955

3-1-1 9 72 4.241 211.427 3 . 710

3- 1-1 913 4.067 215.494 3 .5 59

3-1-1 974 3.875 21 9 .369 3 . 391

3 - 1-19 7 5 3.697 223 .066 3.235

3-1-1 976 3 .514 226 .580 3 . 074

3- 1-1 9 77 30351 229 . 93 1 2 . 932

3-1-1 982 14.941 244 . 8 72 13.074

3- 1-1 9 87 12.514 2570386 10.950

3- 1-1 992 5.834 263 .2 20 5 .1 05

TOTAL 177.670 155.462 ~

(I) NWI - estimated as .875 (2) Crude price $3.48 less $.35 transportation cha r ge.

41.081 11.400

34.508 - Jf/tR,I.400

29 .441 - 11 .400

26.123 -3 11.400

23.005 - 3 11.400

21.056 -~ 11.40C

19 .018 -?' 11.400

17.528 - / _ 11.400

16.0 4 1 - ~ 11.400

15.002 - ~ 11.400

13. 9 19 -~ 11.400

13 .168 11.400

12 . 379 11.400

11.612 11.400

11.140 10.2 60

10.614 9.120

10.126 7.98C

9 .6 2 1 6 .840

9 .177 5.700

40.922 28.50C

34. 273 28.500

15.979 14.000

486.596 $ 28 1.9 00 $

29.681 69.144 27.595 66.118

23 0108 v' 92.252 20.461 86.579

18.041 110.293 15.213 101.792

14.723 125.016 11.824 113.616

11.605 136.621 8.876 122.492

9 .656 146.277 7.034 129.526

7.618 153.895 5.285 134.811

6.1 28 160.023 4.049 138.860

4.641 164.664 2.920 141.780

3.602 168.266 20159 143.939

2.519 170.785 1.438 145.377

1.768 172.553 961 146.338

979 173.532 507 146.845

212 173.744 105 146.950

880 174.624 413 147.363

1.494 176.118 668 148.031

2 .146 178.264 914 148.945

2 . 78 1 181.045 1.1 28 150.073

3 .477 184.522 1.343 151.416

12.422 196.944 40145 155.561

5.773 202.717 1.510 157.071

1.979 204.696 405 157.476

204.696 $ 157.476

Date

Interval

Oil Production,

Barrels

Table 24

SUMMARY


Cumulative

Oil Production,

Barrels

Jim Beattie Viorking Interest

RODNEY FIELD



to NWI,(l)@ $3.1300(2) Operating Barrels per Barrel Expenses

Net Income to NWI


to NWI


50/0

Cumula tive Discounted Net Incoroe

to NWI

3-1-1957

3-1-1958 76.867

186.200

263.067 67.260 $ 210.524 $ 31.330 $ 1790194 $ 1790194 $ 174.928 $ 174.928

3-1-1959 56.438 319.505 490383 154.569 31.330 123.239 302.433 114.576 289.504

3-1-1960 45.600 3650105 39.899 124.883 310330 93.553 395.986 82.835 372.339

3-1-1961 37.929 403.034 330189 103.882 31,330 72.552 468.538 61.181 433.520

3-1-1962 32.691 435.725 28.603 89.527 31.330 58.197 526.735 46.738 480.258

3-1-1963 28.711 464.436 250123 78.635 31.330 470305 574.040 36.183 516.441

3-1-1964 25.692 t,90 0128 22.481 70.365 31.330 39.035 613.075 28.435 544.876

3-1-1965 23.333 513.461 20.415 63.900 31.330 32.570 645.645 22.596 567.472

3-1-1966 21.385 534.846 18.712 58.568 31.330 27.238 672. 8 83 17.997 585.469

3-1-1967 19.550 554.396 l7ol07 53.546 31.330 22.216 695.099 13.979 599.448

3-1-1968 180194 572.590 15.919 49.826 31.330 18.496 713.595 11.085 610.533

3-1-1969 16.875 589.465 14.766 46,218 30.620 15.598 7290193 8.902 619.435

3-1-1970 15.803 605.268 13.828 43.282 29.910 130372 742.565 7.268 626.7 03

3-1-1971 14.849 620.117 12.992 40.664 29.200 11.464 754.029 5.934 632.637

3-1-1972 140142 120375 38.734 28.480 10.254 764.283 5.056 637.693

3-1-1973 13.366 647.625 11.695 36.605 28.480 80125 772.408 3.815 641.508

3-1-1974 12.668 660.293 11.094 34.694 25.275 9.419 781.827 4.213 645.721

3-1-1975 12.000 672.293 10.500 32.86 3 22.070 10.793 792.620 4.597 650.318

3-1-1976 11 .438 683.731 10.010 31.332 18.865 12.467 805.087 5.057 655.375

3-1-1977 10.901 694.632 9 .537 29.852 15.665 it .. 187 819.274 5.480 660.855

3-1-1982 470130 741.762 41.240 129.080 77.275 51.805 871.079 17.288 679.143

3-1-1987 35.379 777 0141 30.956 96.892 54.075 32.817 903.896 8.582 686.725

3-1-1992 280324 805.465 240783 77.571 56.815 20.756 924.652 4.252 690.977

3-1-1997 13.935 819.400 120193 380164 27.725 10.439 935.091 1.675 692.652

3-1-2002 10.500 829.900 90188 28.758 210325 7.433 942.524 935 693.587

3-1-2007 9.500 839.400 8.312 26.017 21.325 4.692 947.216 462 694.049

3-1-2012 8.800 848.200 7.700 24.101 21.325 2.776 949.992 214 694.263

3-1-2017 8.000 856.200 7.000 21.910 21 0325 585 950.577 35 694.298

3-1-2022 7.000 863.200 60125 190171 18.500 671 951.248 32 6940330

TOTAL 677.000 592.375 $ 1.854,133 $ 902.885 $ 951.248 $ 6940330

(1) NWI - estimated as .875 (2) Crude price $3. 48 less $. 35 transportation charge.

Date

Table 25


Interval Cumulative

Oil Oil Production, Production.

Barrels Barrels

Jim Beattie

J. Braddon Lease

RODNEY FIELD



to NWI,(I)@ $3.1300(2) Operating Barrels per Barrel Expenses

Net Income to NWI


to NWI


50/.


to NWI

3-1-1957

3-1-1958 44,667

107,000

151,667 39,084 $ 122.333 $ 13,300 $ 109,033 ~ 109,033 $ 106,437 $ 106,437

3-1-1959 29,200 180,867 25,550 79.971 13,300 66,671 175,704 61.985 168.422

3-1-1961 18,42 9 199,296 160126 50,474 13,300 370174 212,878 31,348 199,770

3-1-1962 15,500 214,796 13,562 42,449 13,300 29,149 242,027 23,410 2230180

3-1-1963 13,200 227,996 11 , 550 360152 13,300 22,852 264,879 17.479 240,659

3-1-1964 11,636 239,632 10.182 31,869 13,300 18,569 283.448 13.527 2540186

3-1-1965 10,417 250.049 9.114 28.527 13 .300 15,227 298,675 10,564 264,750

3-1-1966 9,385 259,434 8.212 25.704 13,300 12,404 311,079 8.196 272.946

3-1-1967 8,467 267,901 7.409 230190 13,300 9,890 32 0,969 6.223 2790169

3-1-1968 7,813 275,714 6,836 21,397 13,300 8,097 329,066 4,853 284,022

3-1-1969 7,23 5 282,949 6.331 19,816 13, 300 6,516 335,582 3,719 287,741

3-1-196 0 22,500 305,449 19.687 61,621 13,300 480321 383,903 42.785 330.526

3-1-1970 6,77e 312,227 5,931 18,564 13,300 5,264 3890167 2,861 3330387

3-1-1971 6,250 318,477 5.468 170114 13,300 3,814 392,981 1,974 335.361

3-1-1972 5,90 5 324,382 50167 16 tl 73 13,300 2,873 395,854 1,417 336.778

3-1-1973 5,545 329,927 4,852 15,187 13,300 1,887 397,741 886 337.664

3-1-1974 5,250 335,177 4,594 140379 11 ,640 2,739 400,480 1.225 338.889

3-1-1975 4,960 3400137 4,340 13 ,584 9,980 3,604 404,084 1.535 340.424

3-1-1976 4,731 344,866 4,140 12 ,959 80320 4,639 408,723 1.882 342.306

3-1-1977 349.387 3 .954 12 ,376 6,650 5,726 414,449 2,212 344,518

3-1-1982 19, 825 369, 2 12 17.347 54,296 33,250 21,046 435,495 7,023 351.541

3-1-1987 16,42'1 385 ,641 14.375 44,99 3 33,250 11,743 447,238 3,071 354.612

3-1-1992 13,924 399,565 12.183 380133 33,250 4,883 4520121 1,000 355.612

3-1-1997 2,4 35 402,00 0 2,131 6 , 6 70 6,400 270 452,391 43 355.655

TOTAL 295, 000 25 80125 1 807, 93 1 $ 355 ,540 $ 4520391 $ 355,655

(l) NW1 - estimated as .875 (2) Crude price $3.4 8 less $.35 transportation c harg e.

Date

Interval

Oil Production,

Barrels

Table 26


Cumulative

Oil Production.

Barrels

10.200

Jim Beattie

Colthart Lease

RODNEy FIELD



to NWI~I) @ 53.1300(2) Operating Barrels per Barrel Expens e s

Net Income to NWI


to NWI


5%


to NWI

3-1-1957

3-1-1958 7.200 17.400 6.300 $ 19.719 $ 3.800 $ 15.919 S 15.919 5 15.540 $ 15,540

3-1-1959 6.800 24.200 5.950 18.624 3.800 14.824 30.743 13.782 29.322

3-1-196 0 5.300 29.500 4.638 14.516 3.800 10.716 41.459 9.488 38.810

3-1-1961 4.400 33.900 3.850 12,051 3 . 8 00 8.251 49,710 6,958 45.768

3-1-1962 3.650 37.550 3.193 9.994 3.800 60194 55.904 4.974 50.742

3-1-196 3 3.350 40.900 2.932 9.177 3. 800 50377 61.281 4.113 54.855

3-1-1964 2.850 4 3 .750 2 .493 7.80 3 3 ,8 00 4.003 65.284 2 .916 57,771

3-1-1965 2.500 46.250 2 0188 6.849 3.800 3.049 68.333 20115 59.886

3-1-1966 2.300 48.550 2 .01 2 6.297 3 .800 2,497 70,830 1.650 61.536

3-1-1 967 2.050 50.600 1.794 5 .616 3 .800 1. 8 16 72.646 1.143 62.679

3-1-196 8 1.950 52.550 1 .706 5 .33 9 3 . 800 1.539 740185 922 6 3 .601

3- 1-196 9 1.800 54,350 1.575 4,930 3 .800 1.130 75.315 645 64.246

3-1- 1970 1 , 650 §6.000 1. 44 4 4.520 3 .800 720 76,035 391 64,637

3 - 1-1 971 1 .5 00 57.550 1. 356 4.244 3 , 800 444 76 .479 230 64,867

3- 1-197 2 1.500 59. 050 1. 313 401 10 3.800 3 10 76.78 9 153 65.020

3 - 1- 197 3 1.400 60,4 50 1.225 3,834 3,800 34 76,823 16 6 5 .030

, -1-1 974 1.30 0 61.750 10137 3 . 5 59 3 .3 25 234 77.057 105 650141

3- 1-1 97 5 1,200 6 2 , 95J 1.050 3 .2 86 2.85 0 436 77.493 186 65.327

3- 1-1 976 1 ,1 5:) 1 .007 3.152 2.375 777 78 . 27 0 315 65.642

3- 1- 19 77 1 ,1 00 65, 200 962 3 ,01 1 1. 90 0 1011 1 790381 429 66.071

3-1-1 982 4,850 7 0 . 050 4.244 1 3 . 284 9 . 500 3.784 830165 1.263 67.334

3-1-1 987 4,O ~C 740100 3 .544 11.093 9 . 50 0 1.5 93 84.758 417 67.751

3-1-1 99 2 900 75.000 787 2 .46 3 2 . 240 223 84 .981 46 67.797

TOTAL 64,8 00 56 ,100 ~ 177.471 $ 9 2 . 4 9 0 $ 84 . 98 1 $ 67.797

(1) NWI - est im ate d as .875 (2) Crude price $ 3.48 less $ .35 transportation charg e.

Date

Table 27


Interval Cumulative Oil Oil

Production, Production, Barrels Barrels

Jim Beattie

N. D. McMillan Lease

RODNEY FIELD



to NWI,(I)@ 53.1300(2) Operating Barrels per Barrel Expenses

Net Income to NWI


to NWI


5%


to NWI

3-1-1957

3-1-1958 13.500

17.000

30.500 11.813 $ 36.975 5 8.530 S 28.445 S 28.445 S 27.768 $ 27.768

3-1-1959 12.000 42.500 10.500 32.865 8.530 24.335 52.780 22.624 50.392

3-1-1960 11 .100 53.600 9.712 30.398 8.530 21.868 74.648 19.363 69.755

3-1-1961 9,600 63.200 8.400 26.292 8,530 17.762 92.410 14.978 84.733

3-1-1962 8,800 72.000 7.700 24.101 8.530 15.571 107.981 12.505 97.238

3-1-1963 8.000 80,000 7.000 21.910 8.530 13,380 121.361 10.234 107.472

3-1-1964 7,500 87.500 6.563 20.542 8.530 12,012 1330373 8.750 116.222

3-1-1965 7,100 94,600 6.212 19,444 8.530 10.914 144.287 7.572 123.794

3-1-1966 6,700 1011300 5.863 189351 8.530 9.821 1540108 6.489 130.283

3-1-1967 6,300 10 7 ,600 5.512 17,253 8.530 8.723 162.831 5.489 135.772

3-1-1968 5,900 113,500 5,163 16,160 8.530 7,630 170,461 4.573 140.345

3-1-196 9 5,500 119.000 4.812 15,062 8.530 6,532 176,993 3.728 144.073

3-1-1970 5,200 124,200 4.550 14.241 8.530 5.711 182,704 3.104 147.177

3-1-1 971 5,000 129,200 4,375 13.694 8.530 5.164 187.868 2.673 149.850

3- 1-19 72 4, 800 134,000 4,200 13 ,146 8.530 4.616 192,484 2.276 1520126

3-1-197 3 4,600 138.600 4.025 12.598 8.530 4.068 196,552 1.910 154.036

3- 1-1974 4,400 143,000 3.850 12,051 7.460 4.591 201 tl43 2.053 156.089

3- 1-1975 4, 200 147,200 3.675 11,502 6.390 5,112 206.255 2.177 158.266

3-1-1 9 76 4, 000 151,200 3.500 10,955 5.320 5,635 211,890 2.286 160.552

3- 1-1 9 77 3 , 600 155,000 3.325 10,408 4.265 6,143 218.033 2,373 162.925

3-1-1 9 fl 2 17 ')CO 172 dCO 15tl38 471381 21 .325 26,056 244,089 8.695 171.620

3 - 1- 198 7 14 , , 00 187,200 13.037 40,806 21.325 19,481 263,570 5.094 176.714

3-1-19 92 13 ,50 0 200,700 11.813 36.975 21.325 15,650 279,220 3.206 179.920

3- 1-19 97 11 , 500 212,200 10.062 31,494 210325 100169 289,389 1.632 181.552

3-1- 2002 10 ,50 0 222 , 700 9 tl88 28.758 21.325 7.433 296.822 935 182.487

3- 1- 200 7 9 ,50C 232,200 8.312 26,017 21.325 4,692 301.514 462 182.949

3-1-20 12 8 ,800 241, 000 7.70C 240101 21.325 2,776 304,290 214 183 tl63

3-1-20 1 7 8 , COO 24 9 ,000 7.000 21,910 21.325 585 304,875 35 183.198

3- 1- 2022 7, 000 2 56,000 6,125 19 0171 18.500 671 305,546 32 183.230

TOTA L 2 39,CO O 2090125 ~ 65 4 ,561 $ 349.015 $ 305,546 183.230

(1) NWI - estimate d as .875 (2) Crude pric e $3. ,. 8 less $,35 transportation charge.

Table 28

ECONOMIC AN ALYSIS OF F UTURE PRIMARY PERF ORMANCE

Jim B eattie

F. Wright Lease

RODNEY F IELD

E l gin County, Ontari o, Canada

Inte r va l Cum ul a tiv e Gross Income Discounted C umulative Oil Oil G ros s Oil L e s s Sev. Tax, Cumulative Net Income Discounted

P roduction , P roduction , to NWI. (I) @ $3 . 1300 (2 ) Operating Net Income Net Income to NWI @ Ne t IncoITle Date Bar r e l s Barrels B arrels per Bar r el E XEe nses to NWI to NWI 5"/0 to NWI

3- 1- 1957 52 . 000

3- 1-1958 11.500 63 . 500 10,063 $ 31 , 497 $ 5.700 $ 25,797 $ 25 . 79 7 $ 2501 83 $ 25 . 183

3-1 -1 959 8 . 438 7 1. 938 7 , 383 230109 5 .7 00 17,409 43 , 206 16018 5 4 1 03 68

3 - 1- 1960 6 . 700 78 , 638 5 , 862 18 , 348 5 , 700 12 ,6 48 55 . 85 4 1101 99 52 , 56 7

3- 1- 196 1 5 . 500 84 01 38 4 , 8 1 3 15 , 065 5 .7 00 9 . 365 65 . 219 7,897 60,464

3- 1- 1962 4,741 88 , 879 4 01 48 12 , 983 5 . 700 7.283 72.502 5.849 66 .3 13

3-1 -1 963 4 .1 61 93 . 040 3 , 641 11.396 5 .700 5 . 696 780198 4,35 7 70 ,670

3- 1-1964 3,70 6 96 . 746 3 , 243 10.151 5 . 700 4 . 451 82 . 649 3 , 242 73,912

3-1-1965 3,316 100,0 6 2 2 . 901 9 . 080 5 , 700 3 . 38 0 86 . 029 2 ,345 76, 2 57

3- 1-1966 3 . 000 lC3,062 2 , 625 8,216 5 . 700 2 . 5 16 88 . 5 4 5 1,662 77, 9 19

3- 1- 1967 2 . 733 lC5 . 795 2 , 392 7 . 487 5.700 1.187 90.332 1 , 124 19, 0 43

3 - 1- 1968 2.531 lC80326 2 . 214 6 . 930 5.700 1 .230 91 . 56 2 737 1 9.18 0

3-1-196S 2 . 340 110 . 6 6 6 2 , 048 6 . 410 4.990 1. 420 92 . 98 2 81 0 80 , 5 9 0

3- 1-1970 2.175 112.84\ 1 . 903 5 . 957 4.280 1 . 677 94 .65 9 9 12 81 , 502

3- 1-1 971 2 . 049 114 . 890 1 , 793 5.612 3.570 2.042 96. 70 1 1, 05 1 82, 559

3-1-1 972 1 . ,,37 1 16 . 827 1 , 695 5.305 2.850 2 . 455 99 01 56 1.210 8 3 .769

3- 1-197: I . 821 11 8 . 648 1 , 593 4 . 986 2.850 2 tl 36 101 ,292 1,003 84 ,112

3-1-1974 1 . 7 1 8 1209366 1, 503 4 ,705 2 , 850 1 . 855 103 tl47 8 30 85,60 2

3- 1-1975 1 . 640 122.006 1 , 435 4 . 49 1 2 . 850 1 . 64 1 104 . 788 699 86, 301

3- 1-1976 1 . 557 123 . 563 1 , 363 4 , 266 2 . 850 1 . 416 106 ,204 574 86, 815

3- 1-1977 1 , 482 125 . 043 1 , 296 4 ,0 57 2,850 1 , 20 7 10 7 , 4 11 466 81,341

3- 1- 198 2 5 01 55 130 . 20 0 4, 511 14 011 9 13 . 20 0 919 108. 33 0 30 7 87,648

TOTAL 78 . 200 68 , 425 $ 214 tl 70 $ 105 . 840 $ 10 80330 $ 8 7,648

(1) N WI - estimated as .815 (2) Crude price $3. 48 less $.35 transpor tation c harge.

Date

Table 29


Interval Cumulative


Barrels Barrels

A. Comfort

Tunks Lease

RODNEY FIELD



to NWI.(l) @ $301300(2) Operating Barrels per Barrel Expens e s

Net Income to NWI


to NWI


5%


to NWI

3-1-1957

3-1-1958 6.213

28.800

35.013 5.489 $ 110181 $ 3.800 $ 13 .~ 8J $ 130381 $ 1 3 .062 $ 13.06 2

3-1-1959 4.815 39.888 4.213 13. 186 3.800 9.386 22 .767 8 .726 21.78 8

3-1-1960 4.000 43.888 3.500 10.955 3.800 70155 29 . 922 6033 5 2 B.12?

3-1-1961 3.421 47.309 2.993 90368 3.8OC 5.568 32.818

3-1-1962 2.930 50.239 2.564 8.026 3.800 4.226 39 .716 3 .394 36 .21 2

3-1-1963 2.592 52.831 2.268 1.099 3 .800 3 .299 43.015 2.523 36 .135

3-1-1964 2.327 550158 2.036 60312 3 .600 2 .572 45.5 8 7 1.874 <' 0 .6 09

3-1-1965 2.098 51.256 1.836 5.141 3 .800 1.947 47.5 34 1.351 ~ 1 . 96C

3-1-1966 1.922 59.118 1.682 5.265 3.aoo 1.465 48.999 968 42.92 0

3-1-1967 1.183 60.961 1.560 4.882 3 .800 1.082 50.081 681 .. 3.6 09

3-1-1968 1.640 62.601 1.435 4.492 1 .800 692 50.713 415 4':".024

3-1-1969 1.519 64.120 1.329 4.160 3 .3 20 840 51.613 <'79 4".5C3

3-1-1970 1.425 65.545 1.241 3.903 2.840 1.063 52.676 578 :. 5 . 081

3-1-1971 1.348 66.89 3 1.119 2 .360 10330 54 .006 689 ~ 5 ,77 'J

3-1-1972 1.263 680156 1.106 3 .46 2 1. 90 0 1.562 55 . 568 710 46.540

3-1-1973 10192 69.348 1.043 3 .264 1.90C ,.364 56.932 640 470180

3-1-1974 1.136 10.484 994 3.112 1.900 1.212 58 .14" 542 41.722

3-1-1975 1.07 8 71.562 943 2.951 1. 900 1 .0 51 59 .1 95 480110

3-1-1976 1.033 72.595 904 2.830 1.900 930 600125 3 71 48.541

3-1-1911 983 13.518 860 2.692 1.900 792 60.917 3G6 ,+8.853

3-1-1982 4.309 77.881 3.710 11.800 9.500 2.300 63.211 768 49.621

3-1-1981 2.013 79.900 1.761 5.512 5.000 512 63.729 134 49.155

TOTAL 51.100 44.712 $ 139 . 949 $ 76.220 $ 63.129 $ 49.755

(I) NWI - estimated as .875 (2) Crude price $3.48 les s $. 35 transportation charge.

Date

3-1-1957

Table 3 0

SUMMARY


Interval Cumulative


Barrels B a rrels

98.960

Dominion Natur a l Gas Working Interests

RODNEY FIELD

Elgin County , Ontario , Canad a

Gross Income Gross Oil Less Se v . Tax,

to NWI,(l)@ $3 .1300(2) Operating Barr els per Barrel Expenses

Net Income to NWI

Cumulative N et Income

to NWI

D iscounted Net Income to NWI @

5%


to NWI

3-1-1958 17,976 116,936 15,72 9 49 . 232 13,300 $ 35, 932 $ 35,932 $ 35,076 $ 35 . 0 76

3-1-1959 14tll0 131,046 12,346 38,643 13,3 00 25,343 61,275 23 , 56 2 58,638

3-1-1960 11,692 14 2 , 738 10,231 3 2 , 022 13,300 18 ,722 79,997 16, 577 75,215

3-1-1961 9 , 978 152 ,716 8 ,7 3 1 27 , 329 1 3 .300 14,029 94 ,0 26 11,830 87.045

3-1-1 9 6 2 8,777 161.49 3 7,679 24 ,0 35 1 3 , 300 10,735 104 ,761 8 ,6 2 1 95 .666

3-1-1963 7,840 169.333 6 , 860 21,472 13 , 300 8 ,17 2 112,93 3 6 , 251 101 , 917

3-1-1964 7 , 057 17 6.390 6 , 176 19 . 3 3 1 13, 300 6.031 118,964 4 , 393 106 , 3 10

3-1-1965 6 ,421 182.811 5 , 6 18 17,584 13 , 3 00 4 , 284 123,248 2 ,973 10 9 ,283

3-1-1966 5,872 188.68 3 5 tl37 16,079 12 , 590 3 ,489 126,737' 2.305 111,588

3-1-1967 5,407 194 ,090 4,732 14,811 11,8 80 2 , 9 3 1 129,668 1 , 84 5 113,433

3-1-1968 5,008 199,098 4,382 13 ,71 5 11,170 2 ,54 5 132 . 213 1 ,525 114,95 8

3-1-196 9 4,657 203, 75 5 4.075 12.756 9 , 50 0 3,256 13 5 , 46 9 1 . 859 116,817

3- 1-1970 4, 36 0 208tl15 3 ,814 11,9 37 8 , 550 3 , 387 138 , 856 1.841 11 8 ,65 6

3-1-1 97 1 4,104 2 12 .219 3 , 592 11 , 243 7 ,6 0 0 3 ,64 3 142,49 9 1,886 120.544

3-1-1972 3 , 866 216 ,085 3 . 382 10,586 ~ , 650 3 ,936 146, 43 5 1, 940 122,484

3- 1-1973 3,668 2 19 ,75 3 3 . 2 10 10 ,048 6 , 6 50 3 , 398 149 ,8 33 1 .5 96 12 4 . 08 0

3-1-1974 3,48 2 223 ,235 3 .047 9,536 6,650 2 , 886 152,71 9 1,290 125.370

3-1 -1975 3 , 334 226 ,569 2 , 9 17 9,130 6 ,6 50 2 ,48 0 155tl99 1 .056 126,426

3-1-1976 3 .17 8 229 ,747 2 ,781 8 ,70 5 6,650 2 ,05 5 157.254 834 127,260

3-1-1977 3,029 232 .776 2 . 650 8 . 294 6 ,6 50 1,644 158.898 635 127,895

3-1-1982 9 ,640 242 ,416 8,435 26,402 22 , 300 4 tl0 2 163,000 1,369 129,2 64

3-1-1987 1,784 24 4,200 1,561 4,886 4,700 186 163tl86 49 12 9, 313

TOTAL 145,240 127.085 $ 397,776 $ 234 , 590 $ 163 ,186 $ 129 ,313

(l) NWI - estimated as . 875 (2) Crude price $ 3. 48 l e ss $.35 transportation charge .

Date

Table 31


Interval Cumulative


Barrels Barrels

Dominion Natural Gas

F. G. Purcell Le ase

RODNEY FIELD


Gross Income Gross Oil Less Sev . Tax,

to NWI ,(1) @ $3.1300(2) Operating Barrels per Barrel Expens e s

Net Income to NWI


to NWI


5%

Cumulative Di scounte d Net Income

to NWI

3-1-1 957

3-1-1958 12.000

71.343

83.343 10.500 $ 32.865 $ 7.600 $ 25.265 $ 25.265 $ 24.663 $ 24.663

3-1-1959 9 .28 6 92.629 80125 25.431 7.600 17.8 31 43.096 16.578 41.241

3-1-1 960 7.588 100 .217 6.640 20.783 7.600 13tl83 56.279 11.673 52.914

3-1-1961 6.450 106.667 5.644 17.666 7.600 10.066 66.345 8.488 61.402

3-1-1962 5.609 112.276 4.907 15.359 7.600 7.759 74.104 6.231 67.633

3-1-1963 4.960 117.236 4.340 13.584 7.600 5.984 80.088 4.577 72. 2 10

3-1-1964 4.429 121.665 3 . 876 12 0132 7.600 4.532 84.620 3.301 75.511

3-1-1965 4.031 125.696 3 .5 27 11.040 7.600 3.44C 88.060 2.387 77.898

3-1-1966 3 .676 129.372 3 . 216 10.066 7 .600 2 .466 90.526 1.629 79.527

3-1-1 967 3.405 132.777 2 . 980 90327 7.600 1.727 92.253 1.087 80.614

3-1-1 9(1) 30150 135. 92 7 2 .756 8 .626 7.600 1.026 93.279 615 81.229

3-1-1 96 9 2.929 138.856 2 .563 8 .023 6.650 1.373 94.652 784 82.013

3-1-1970 2.733 141.589 2 . 391 7.483 5.700 1.783 96.435 969 82.982

3- 1- 19 71 2 .56 3 1440152 2 . 243 7 .021 4.750 2.27 1 98.706 1.176 84.158

3- 1-1 9 7 2 2.41 2 146.564 2 .1 10 6.604 3.800 2 . 804 101.510 1.382 85.540

3- 1-197 3 2.278 14 8 . 842 1. 994 6 .242 3.800 2.442 103.952 10147 86.687

3- 1-1 9 74 20158 15 1.000 1 . 888 5 .909 3.800 2.109 106.061 943 87.630

3-1- 19 75 2.067 15 3 . 067 1. 80 9 5 .66 2 3 . 800 1.862 107.923 793 88.423

3-1-1 9 76 1 . 968 15 5 . 0 35 1 .722 5 .39C 3.80C 1.5 90 109.51 3 645 89.068

3-1-1 9 77 1.877 156.<;12 1.642 5.139 3 . 80C 1. 339 110.852 517 89.585

3-1- 19 82 8 . 3C4 165. 2 16 7.266 22 .74:! 19.000 3 ,743 114.595 1.249 90.834

3-1 - 198 7 1 . 7e4 167.000 1.561 4.886 4.700 186 114.781 49 90 .883

TOTAL 95 .6 57 8 3. 7CO $ 261.961 $ 147 . 20 0 $ 114.781 $ 90.883

(1) NWI - estimated as .875 (2) Crude price $3.48 l e ss $.35 transportation charge

Table 32



J. Rubi L ease

RODNE Y FIELD

Elgin County. Ontario, Canada

Interval Cumulative Gross Income Discounted Cumulative Oil Oil Gross Oil Less Sev. Tax, Cumulative Net Income Discounted

Production, Production, to NWI.(l)@ $3.1300(2) Operating Net Income Net Income to NWI @ Net Income Date Barrels Barrels Barrels per Barrel Ex;eenses to NWI to NWI 5"/. to NWI

3-1-1957 27.617

3-1-1 958 5.976 33.593 5.229 160367 $ 5.700 $ 10.667 '" 10.667 $ 10.413 $ 10.413

3-1-19 59 4.824 38.4 17 4.221 13.2 12 5.700 7.512 18 017 9 6.984 170397

3- 1-196 0 4.104 42,5 21 3 .591 11.239 5.700 5.539 23 .718 4.904 220301

3- 1-1 96 1 3 .5 28 46.C49 3 . 087 9.663 5 . 700 3 .96 3 27 .6 81 3 .342 25 .64 3

3-1-1 962 30168 49.217 2 .772 8 .676 5.700 2.976 30 .65 7 2 . 390 2~ . 033

3-1-196 3 2 .8 80 52.097 2 . 520 7.888 5 .700 2 .18 8 32.845 1.67 .. 29 .707

3-1-1 964 2 .62 8 540725 2 . 300 7,199 5,700 1,499 340344 1 , 0,2 30.799

3-1-1965 2 . 390 570115 2.091 6,544 5 .7 00 844 350188 586 31.385

3-1-1966 2 ,196 590311 1.921 6,013 < , 990 1,023 36 , 211 676 32,061

3-1-1967 2.002 610313 1,752 5 ,48 4 10 , 280 1,204 37,4 1 5 758 ~2 , 819

3-1 -196 8 1,858 63.171 1,626 5 . 089 3,570 1.519 38 .934 910 B,729

3-1-196 9 1.728 64.899 1.512 4.733 2,850 1,883 40,8 17 1.075 34 . 804

3-1-1970 1.627 66.526 1,42 3 4,454 2,850 1.604 42,421 872 ::15.676

3 - 1-1971 1.541 68,067 1,349 4 , 222 2 , 850 1 d72 43 , 793 710 36.386

3-1 -1972 1,454 69,521 1,272 3 , 982 2.850 1.132 44 . 925 558 36.944

3-1-1973 1.390 70.911 1. 216 3,806 2,850 956 45 , 881 449 370393

3-1-1974 1 . 324 72,235 1,159 3 ,6 27 2.850 777 46,65 8 347 37 .74 0

3-1-1975 1,267 73,502 1.108 3.468 2 , 850 618 47.276 263 38.00 3

3-1-1976 1.210 74.712 1.059 30315 2,850 465 47,741 189 38 019 2

3-1-1977 1 015 2 75.864 1.008 3. 155 2,850 305 48,046 118 3803 10

3-1-1982 1.336 77.200 1.169 3 ,65 9 3.300 359 48,405 120 38.430

TOTAL 49.583 43.385 i 135.795 $ 87.390 $ 48.405 $ 38,430

(l)NWI- estimated as . 875 (2) Crude price $3.48 less $. 35 transportation charge.

Table 33


New Bristol Oils

A. McCallum L ease

RODNEY FIELD


Interval Cumulative Gross Income Discounted Cumulative Oil Oil Gross Oil Less Sev . Tax, Cumulative Net Income Discounted

Production, Production. to NWI.(l)@ 53.1300(2) Operating Net Income Net Income to NWI @ Net Income Date Barrels Barrels Barrels per Barrel to NWI to NWI 5', to NWI

3 -1-19~7 84.600

3-1-1958 10.286 94.886 9.000 S 6.600 S 21t 5 70 S 21.570 $ 21.056 $ 21.056

3- 1-195 9 7.765 102.651 6.795 21.268 6.600 14.668 36.238 13 .637 34.693

3-1-1960 60333 108.984 5.541 17.344 - ';2.ff( 6 .600 10.744 \.I 46.982 9.513 44.206

3-1-191>1 50320 114.304 4.1>55 14.570 -~ 1>.1>00 7.970 54.952 6.721 50.927

3-1-191>2 4.571 118.875 4.000 12.5 20 - - .5~ 6.1>00 5.920 60.872 4.754 55.681

3 -1 -1963 4.031 122.906 3.527 11.03 9 ~ 1 6.600 4,439 650311 3.395 59,076

3-1-196" 3,600 126 ,50 1> 3.150 9,81>0 - 1 6,600 3,260 68,571 2,375 61.451

3-1- 1965 3.231 129,737 2,827 8 , 848 1>,600 2,248 70,819 1.560 63,011

3-1 - 191>6 2 . 929 132,1>1>6 2 . 563 8.023 - 6.1>00 1,423 72. 2 42 940 1>3.951

3-1-1967 2.717 135.383 2.377 7,440 6,600 840 73.082 529 64.480

3-1-190 e 2.:00 137,e83 2 .188 0,848 6.000 248 730330 149 04,029

3-1-1969 20340 140.223 2 .047 6,407 5,770 637 73.967 364 64.993

3-1-197C 2 , 175 142.3 98 1.903 5.956 4,940 1,016 74,983 552 65.545

:' - 1- 1971 2 ,()1~9 1"4,"47 10193 5.613 4.110 1,503 76.486 778 66,323

3-2-197 2 1,937 146 . 38 t. ] .695 5,305 3,300 2,005 78,491 989 67. 3 12

3- 1-1973 1.821 148,205 1.593 4,986 30300 1,686 80t! 77 792 68.104

3-1-197" 1. 7£..:3 1/19. 94P 1 .5 26 ".776 3 . 300 1 , 476 81,653 660 6 8 .764

3 - 1-1 975 1 • ~"9 151,59 7 1, ''' 2 4. , 5 1 £. 30300 1.21 4 82 .867 517 69.281

3 - 1-1976 1 , 564 153']61 1 . 36 9 ", 285 3 0300 985 83.852 400 ,,9 .6 81

3-1-1 977 1.500 154.661 1 . 31? ".106 3.'300 806 84.658 311 69.992

3- 1-1 982 4,73 9 ~59,40 0 4 , 147 12.980 11,000 1.9RC 86 ,638 661 7 ') .653

T OTA L 74,800 65. /~SC $ 20 4 , F. :- B 11 8 , 220 $ 8","38 70, 653

(l) NW1- es timated as .875 (2) Cr ude pri ce $3.48 less $.35 tr ansportation char ge .

Table 34

SUMMARY

Plan I

ECONOMIC ANALYSIS OF WATER FLOOD PERFORMANCE

Date

3-1 -1 957

3- 1-1958

3- 1-1 959

3-) -196 0

3- 1-1 961

3- 1-196 2

3-1-1963

3- 1-1 964

3 - 1- 1965

3- 1-1 966

3- 1-19 67

3- 1-1 968

3-1-1 969

3- 1-1 970

3-1 -1 97 1

3- 1-1972

TO TAL

Interval

Oil Production,

Barrels

2 1101 8 0

S2 7.620

1 0138.500

93 2 . 000

655.400

463.700

321.200

2650100

221 .300

184.800

152.633

132.270

81 .22 8

55.495

15.610

5 .7 58 . 036

Capital Investment for

Cumulative

Oil Pro duction,

Barrels

880 .694

1. 091.874

2 . 019 .494

3 tI57 .994

4.089.994

4.745.394

5.209 . 094

5 . 530.294

5.7950394

6.016 . 69£0

6 . 201 .494

6.3540127

6.486.397

6 . 567 . 625

6 . 623.120

6 . 638 .7 30

8 75 Net Working Inte rest

All Leases Combined

RODNEY FIELD



to NWI,(I) @ $3 .1 300(2) Operating Barrels per Barrel Expenses

184.784 $ 578 . 376 $ 145.750

811. 669 2.540 .5 24 294.300

99601 8 7 3 .118.065 296 .7 00

815 . 50 1 2 . 552 .51 6 296.700

573 .474 1 .794. 9 75 296.700

405.738 1.269 . 957 296 . 700

281 . 05C 879 . 688 296 . 700

231.96; 726.047 296 .7 00

193.6 38 606.086 296.700

161.699 506.115 296.700

133.554 418.027 294 .600

115.736 362 . 25 4 2820300

71.073 222.457 178.800

48.557 151.984 135.000

13.658 42.750 410300

5 . 038.281 $ 1 5.769.821 $ 30745.650

Wells and Water Injection Facilities

Net Income to NWI

$ 432.626

2 .246. 224

2 . 821 . 365

2 .255. 816

1.498 . 275

973 . 257

582 . 988

429.347

309.386

209.4 15

12 3 .427

79.954

43.657

16. 984

1.450

$12.024 .171

403,883

Net Profit to NWI $ 11 ,620,288

(I) NWI - estimated as .875 (2) Crude price $3. 48 less $.35 t ransportation charge .


to NWI

$ 432.626

2 .678. 850

5 .500. 215

7.756.031

9 . 254.3C5

10.227.563

10 .810. 55 1

11 .239.898

11.549.284

11.758. 699

11.8820126

11.962.080

12 .005.7 37

12.022.721

12.024 01 71


5%

$ 4220326

2 .0 89 . 046

2 . 50 1.529

1.907 .723

1.206.491

745.955

425.896

298 .6 34

204 . 944

132.095

74 tI91

45.767

23.829

8 .864

720

$10.088.010

399,036

$ 9,688,974


t o NWI

$ 4220326

2.511.372

5.012.901

6.920.624

80127.115

8.873.0 70

9.298.966

9.597.600

9.802.544

9.934.639

10.008.830

10.054.597

10.078.426

10.087.290

10.088.01 0

Table 35

Plan I

SUMMARY


Felmant Oil Corporation Working Inte rest

RODNEY FIELD



Production, Production. to NWI,(I) @ $301300(2) Operating Net Income Net Income to NWI @ Net Income Date Barrels Barrels Barrels per Barrel EXEenses to NWI to NWI 5% to NWI

3-1-1957 396.584

3-1-1958 95.980 492.564 83.326 $ 260.810 $ 65.250 $ 195.560 $ 195.560 $ 190.904 $ 190.904

3-1-195 9 466.700 959.264 405tl72 1.2680188 140.500 It127.688 103 2 3.248 1.048.422 1.2390326

3-1-1960 556 tlOO 1.515.364 482.786 1.511tl21 140.500 1.370.621 2.693.869 1.213.587 2.452.913

3-1-1961 439.900 1.955.264 381.905 It195.363 140.500 1.054.863 3 .748.732 889.534 3.342.447

3-1-1962 316.900 2.2720164 275.122 861tl32 140.500 720.632 4.469 . 364 578.747 3.921tl94

3-1-1963 226.700 2.498.864 196.812 616.021 140.500 475.521 4,944,885 363.712 4.284.906

3-1-1964 150.900 2.6490764 131.007 410.052 140.500 269.552 5.214.437 196.355 4.481.261

3-1-1965 127.700 2.777.464 110.864 347.004 140.500 206.504 5.420.941 143.264 4./124.525

3-1-1966 109.200 2.886.664 94. 804 296.737 140.500 156.237 5.577tl78 103.229 4.727.754

3-1-1967 92. 8 00 2.979.464 80.567 252tl74 140.500 111.674 5./188.852 70.271 4.798.025

3-1-1968 75.400 3 .054.864 65.458 204.884 140.500 640384 5.753.236 38.585 4.836./110

3-1-1969 68.300 3 0123tl64 59.296 185.5 9 7 140.500 45.097 5.7980333 25.740 4.862.350

3-1-1970 51. 8 71 3 tl75 .0 35 45.03 2 140.950 119.500 21.450 5.819.783 11.661 4.874.011

3-1-1971 37tl95 3 .212.2 :', 0 32.291 101.071 93tlOO 7.971 5.827.754 40127 4.878 tl38

3-1-1972 3. ?eO 3 .216.010 3.281 10.269 10.000 269 5.828.023 133 4.878.271

TOTAL 2.819.426 2.447.723 $ 7.6610373 $ 1.833.350 $ 5.828.023 $ 4.878.271

Capital Investment for Wells and Water Injection Facilities 209,713 207,196

Net Profit to NWI $ 5,618,310 $ 4,671,075

(1) NWI - .868164 (2) Crude price $3.48 less $.35 transportation charge.

Table 36

Plan I


Interval

Oil Production,

Date Barrels

3-1 -1 957

3-1-1958 2.700

3- 1-1 959 14.600

3-1-196 0 11 0100

3-1 -1961 6.900

3- 1- 1962 4.900

3- 1-1 9 6 3 3 . 700

3- 1-1 964 2 . 900

3- 1-1965 2 . 700

3- 1- 19 66 2 . 20 0

3- 1-1967 1. 800

3- 1-1 968 1 . 40 0

3- 1-1 969 10300

3- 1- 1970 1 . 200

3 - 1- 1971 99 3

TOPL 58 . 39 0


Net Profit to NWI

( I ) NWI - .868 164

Cumulative


A. Braddon L ease

RODNEY FIELD


Gross Income Oil Gross Oil Less Sev. Tax,

Production. to NWI ,(I)@ $3.1300(2) Operating Barrels Barrels per Barrel EXEenses

3.972

6 .672 2.344 $ 70337 $ 1.250

210272 12.675 39.672 2.900

32. 372 9 .637 300164 2.900

39 . 272 5.990 18.749 2 . 900

440172 4.254 130315 2 . 900

47.87 2 3.212 10.054 2.900

50 . 772 2 . 518 7. 881 2 . 900

53 .47 2 2 . 344 703 37 2 . 900

55 . 672 1. 9 10 5 . 978 2 . 900

57.47 2 1.563 4 . 892 2 . 90 0

58 .872 1.215 3.803 2 . 900

60 . 172 1.129 3 . 53 4 2 . 900

610372 1 . 042 3 . 261 2 . 90 0

620370 366 2 . 71 1 2 . 50 0

50 . 699 5 158 . 688 $ 3 8 t 550

We lls and Water Inj ec tion F ac i lities

(2) C r ude price $ 3.48 less $ .35 tr ansportation c ha r ge .

Cumulative Net Income Net Income

to NWI to NWI

$ 6.087 $ 6.087

36.772 42.85 9

27.264 7001 23

15.849 85 . 972

10.41 5 960387

70154 103.541

4.981 108.52 2

4.437 112.95 9

3 .078 116. 037

1.99 2 118.02 9

903 118 . 932

6 34 119. 566

361 119 . 927

211 1200138

$ 1200138

2 , 750

$ lJ 7,38 8

Discounted Cumulative Net Income Discounte d to NWI @ Net Income

5,. to NWI

$ 5.942 $ 5.942

340187 400129

240140 64.269

13.365 77.634

8 .364 8 5 .998

5.472 91.470

3.628 95.09 8

3 . 078 98.176

2 .0 34 100. 2 10

1.253 101.463

541 102.004

362 1020366

196 10 2 . 5 6 2

109 10 2 .671

$ 102 . 671

2,717

$ 99,954

Table 37

Plan I

ECONOMIC ANALYSIS OF WATER FLOOD P E RFORMAN CE

Fe lmont Oil Corpor ation

A . C . G i llie s L eas e

RODNE Y FIEL D

Elg i n C ounty, O n ta rio, Cana da

In terval Cumulative Gros s Inc o m e Oil Oil Gros s Oil Le s s Sev. Tax ,

P r oduction , Production, to NWI ,(l) @ $3 01 300 (2 ) Ope r a ting Ne t Inc ome Date Bar rels Bar rels B a rre ls per B a rrel EXEe ns ea to NWI

3- 1- 19 57 148. 693

3- 1- 19 58 22 . 520 171 . 213 19 . 55 1 $ 61 t1 95 $ 18 .00 0 $ 43 01 95

3- 1-1 959 129 tlO O 300. 3 13 11 2 . 08 0 350 . 8 10 38. 8 0 0 312 . 0 10

3- 1- 1960 165.00 0 46503 13 143 . 24 7 448.3 6 3 38 . 800 409 . 563

3- 1-1 961 1 17. 000 582 . 3 13 101 . 57 5 317. 93 0 38 . 800 279 01 30

3- 1- 196 2 84 . 000 66 603 13 72 . 92 6 228 . 258 38·. 8 00 189 . 458

3- 1- 1963 60 . 000 726 . 3 13 52 . 090 163 . 042 38 . 800 124 . 242

3 - 1- 1964 45 . 000 7710313 39 . 067 122 . 280 38 . 800 83 . 480

3-1-1 965 38 . 0 0 0 809 . 313 32 . 991 103 . 262 38 . 800 64.462

3-1- 1966 32 . 00 0 84 1 0313 2 7 . 781 86 . 954 38 . 800 48 . 154

3- 1-1 967 29 . 000 8700313 25 t177 78.804 38 . 80 0 40 . 004

3- 1- 1968 22 . 000 8920313 19 . 099 59.780 38 . 800 20 . 98 0

3- 1-1969 21.00 0 9130313 18. 232 57 . 066 38 . 800 18.266

3- 1-1 970 17 . 000 9300313 14 . 758 46 . 19 3 38 . 800 70393

3- 1- 19 7 1 1201 97 942 . 510 10 . 589 3:?143 32 . 000 1 .14 3

TOTA L 793 . 8 17 689 . 16 3 S 2 . 157 . 080 $ 515 . 600 $ 1 . 641 . 480

Capital Investment for We ll s and Water Injection Faci lities

Net P rofit to NWI

(1 ) NWI - .868 164 (2) Crude price $3.48 less $ . 35 transportat ion charge.

38, 860

$ 1,602,620

Cumul a tive Net Inc om e

t o NWI

$ 43 t1 9 5

35 5. 205

764 .768

1 . 043 . 898

1 . 23303 56

1 . 35 7. 598

1 . 441 . 078

1 . 505 . 540

1.553 . 694

1. 593 . 698

1 . 614 . 678

1 . 632.944

1 . 6 4 0 . 337

1 . 64 1. 480

D iscounted Ne t Inc o me to NW I @

5')'.

$ 42 .167

29 0.079

362 . 639

235 . 382

152 t1 56

95 . 029

6 0 . 811

44 . 721

31 . 8 16

25t173

12 . 573

10 . 426

4 . 019

592

$ 1.367 . 583

38, 394

$ 1,329 , 189

Cumulative D iscounted Net Income

to N WI

$ 42 .167

3 32 . 2 46

6 94.8 85

930 . 26 7

1. 082 .423

It177 . 4 5 2

1. 2 38 . 26 3

1 . 28 2 . 984

1 . 3 14 . 800

1 . 339 . 9 7 3

1. 352 . 546

1 0362 . 972

1 . 366 . 991

1 03 67. 583

Interval Oil

Production, Date Barrels

3-1-1 9 57

3-1 -1 958 10,520

3-1-1 959 63.500

3-1-1 960 78,000

3- 1- 1961 50.000

3- 1-1 962 32 .00 0

3- 1- 1963 22.000

3- 1-1964 ,7 . 000

3- 1-1 965 14, 000

3- 1- 1966 12,000

3- 1-1 967 10,000

3 - 1 - 196 ~ 9 , 000

3 - 1-1 96 9 8 , 000

3- 1- 1970 5 , 634

TOTAL 331 , 654

Capita l Investment for

Net Profit to NWl

(I) NWl - .868164

Table 38

Plan I



J. D. Graham Lease

RODNEY FIELD


Cumulative Gross Income Oil Gross Oil Less Sev. Tax,

Production. to NWI ,(1) @ $3 01 300(2 ) Operating Net Income Barrels Barrels per Barrel EXEenses to NWl

4 8 ,126

58,646 9 ,1 33 $ 28,586 $ 12.000 $ 16,586

122tl46 55 ,1 28 172.551 17 . 300 155 . 251

200,146 67 ,71 7 211.954 17. 300 194 . 654

2 5 0 tl46 43.408 135 . 867 170300 118.567

282 .1 46 27 . 782 86.958 170300 69 . 658

30 4tl46 19 ,099 590780 17 t3 00 42,480

321.146 14.759 46.195 17 t3 00 28 . 895

335 tl4& 12 tl54 38.042 1703 00 200742

3 47.146 10.418 32 . 609 170300 15 . 309

35 7tl4f, 8 . 682 27 tl 74 170300 9,974

; 660146 7 . 8 1" 24 , 458 170300 7,1 58

3 74 , 146 6 . 9 '-5 21 ,7 33 17, 300 4, 438

37 0 ,730 4 . 39 1 15 .30 9 14,000 1 . 309

287 , 930 , 90 1,2 21 $ 2160300 f 684 , 921

Wells and Water Inj ection Facilities 46,460

$ 638,461


to NWI

$ 16.586

171.837

366.491

485.058

554.716

597tl96

626,091

646.833

662tl42

672.016

6790174

683.612

684,921

(2) Crude price $3 . 48 less $.35 transportation charge.

Discounted Cumulative Net Income Discounted to NWI @ Net Income

5"/0 to NWl

$ 16tl91 $ 16tl91

144,338 160,529

172,352 332 . 88 1

99 . 984 432 . 865

55 . 943 488.808

32 ,492 521 , 300

21 .049 542,349

14.390 556 .7 39

10,115 566.854

6.213 573.067

4 . 290 5 77. 357

2.533 579 . 890

712 580.602

~ 580 ,602

45,902

$ 534, 700

Table 39

Plan I



E . J. MacMillan Lease

RODNEY FIELD


Interval Cumulative Gross Inc ome Oil Oil Gross Oil Less Sev. Tax, Cumulative

Production, Production, to NWI,(l)@ $301300(2) Operating Net Income Net Income Date Barrels Barrels Barrels per Barrel EXEenses to NWI to NWI

3- 1- 1957 190113

3-1-1958 18.300 37.413 15.887 $ 49.726 $ 9 .000 $ 40.726 $ 40.726

3-1 -1959 890100 126.513 77.354 242 .11 8 22 .900 219 . 218 259 . 944

3-1-1960 92.000 218.513 79.871 249 . 997 «''700 227.097 487.041

3-1-1961 56 . 000 274.513 48.617 1520171 22 .900 129 .271 6160312

3- 1-1962 36.000 310.513 31.254 97 . 825 22 .900 74.925 691 . 23 7

3-1 -1 963 31 .00 0 341.513 26 . 9 13 84 .2 37 22.900 61d37 752.574

3-1 - 1964 21 .000 362 . 513 18.232 57.067 22.900 340167 786.741

3- 1-1965 16.000 378 . 513 13 . 890 43 . 475 22.900 20 . 575 807 . 316

3- 1-1966 15.000 393 . 513 13.023 40.762 22.900 17.862 8250178

3- 1-1967 12.000 405.513 10.418 32.609 22.900 9.709 834 .887

3 - 1-1968 11.000 416 .5 13 9 .549 29 . 888 22 . 900 6 . 988 84 1.875

3- 1-1969 10.000 426.513 8 .682 27 . 175 22.900 4 . 275 846.150

3-1-1 970 2 . 037 428 . 550 1 . 768 5 . 534 5.200 33 4 846 .4 84

TOTAL 409.437 355 .458 $ 1.112.584 $ 266 tl 00 $ 846.484

Capital Inves tment for Wells and Water Inj ection Facilities 46, 360

Net Profit to NWI $ 800,124

(1) NWI - .868164 (2) Crude price $3.48 le ss $.35 transportation charge.


50/0 to NWI

$ 39.756 $ 39.756

203.809 243 . 565

201.078 444.&43

109.010 553.653

600173 613.826

46.915 660.741

24 .8 89 685.630

14.274 699.904

11.802 711.706

60109 717.815

40188 722. 003

2.440 724.443

182 724.625

$ 724.625

45,804

$ 678,821

Table 40

Plan I

ECONOMIC ANAL YSIS OF WATE R FLOOD PERFORMANCE

Interval

Oil P roduction ,

Date Barre l s

3- 1- 1957

:> - 1- 1958 41 . 940

3- 1-1959 170 . 40()

3- 1- 1960 210.000

3-1 - 1961 210 . 000

3- 1- 1962 160 . 000

3- 1- 1963 110 . 000

3- 1- 1961, 65 . 000

3- 1- 196 5 57 . 000

3- 1- 196 ;;' 48 . 000

3- 1- 1967 40 . 000

3- 1-1960 32 . 000

3- 1- 196 9 28 .00 0

3- 1- 1970 26.000

3 - 1-1971 24 . 000

3- 1- 1972 3.780

TOTAL 1 . 2260120


Net Profit to NWI

( I ) NWI - . 868164

Cumulative

Oil Production ,

Barrel s

17 6 . 680

21'::; , 620

389 . 020

599 . 020

809 . 020

969 . 020

1 . 079 . 020

1 . 144.020

1 . 201 . 02·0

1 . <49 . 0 20

1 . 289 . 020

10321 . 020

1 ,~49 , O20

1 , 375. . 020

1 . 39 9.020

l , .u02 ,80C


John McMillan Lease

RODNEY F IE LD

Elgin County, Ontar io, Canada

G ros s Income Gross Oil Less Sev . Tax ,

to NWI ,(I) @ $3 . 130<:(2 ) Operating

~~ per B arrel EXEen ses

36 . 411 $ 1 13 . 966 $ 25 . 000

147 . 935 463 . 037 58 . 600

182031 4 570. 643 58.600

182 . 315 570 . 646 58 . 600

138 . 905 434 . 776 58 . 600

9 5.498 298 . 908 58.600

56.431 176 . 629 58 . 60 0

49 . 485 154 . 888 58.600

41 . 672 130 . 434 58 . 600

340727 100 . 695 58 . 600

27.781 86 . 955 58.600

24 . 30 9 76 . 084 58 . 600

22 . 57 3 70 . 653 58.6 00

20 . 8 36 65 . 217 58 . 600

3 . 281 10 . 269 10.000

1.064 . 473 $ 3 0331. 8 00 $ 796.800

Wells and Water Injection F acilities

(2) Crude price $3.48 less $.35 transportation charge.

Cumul ative Net Income Net Income

to NW I t o NW I

$ 88 . 966 $ 88 . 966

404.437 493.403

512 . 043 1 . 005 . 446

5 12 . 046 1 . 517.492

3760176 1 . 89 3 . 668

240030 8 20133 . 976

118.029 2 . 252 . 005

96 . 288 2 . 348.293

71 . 834 2 . 42001 2 7

50.095 2 . 4 70.222

280355 2 . 498 . 57 7

17.484 2 .516 . 061

12.053 2.528 .11 4

6.617 2 . 534 . 731

269 2 . 535 . 000

5 2 . 535 . 000

75 , 283

$ 2,459 , 717

D iscounted Cumulative Ne t Income Discounted to NWI @ Net Income

50/0 to NWI

$ 86 . 848 $ 86.848

376 . 009 46 2 . 857

453 . 378 9 16 . 235

431.793 1 0348 . 028

302 01 11 1. 650 01 39

18 3.804 1 . 833.943

85.978 1 . 9 19 . 921

66.801 1 . 986 . 722

47 . 462 2 . 034 01 84

31 . 523 2 . 0 6 5 . 707

16. 993 2 . 082 . 700

9 . 979 2 . 092 . 67 9

6.552 2.099 . 231

3.426 2 .1 02. 65 7

133 2 tl 02 . 790

$ 2 . 102 . 790

74,380

$ 2,028 , 410

, ,

Table 41

Plan I


Interval Cumulative


Date Barrels Barrels

3-1-1957 85.550

3-1-1 9 58 12,400 97.950

3-1-1959 47.600 145.550

3-1-196 0 73.000 218.550

3-1-1961 65.000 283,550

3-1-1962 43.000 326,550

3-1-1963 30,000 356,550

3-1-1964 21.000 377.550

3-1-1965 19.000 396.550

3-1 -1966 16.000 412.550

3-1-1967 12,000 424.550

3- 1-196 E 10.000 "34.55 ·0

3-1-196 9 e.,OOO 442 .55 0

3-1-1970 1,950 444.500

TOTAL ;58 . 95C

Gross Oil

John Beattie

Sabjan Lease

RODNEY FIELD


Gross Income Less Sev. Tax,

to NWI,(I)@ $301300(2) Operating Barrels per Barrel EXEenses

10.850 $ 33.961 $ 15.000

41.650 130.364 19.600

63.875 199.929 19.600

56,875 178,019 19,600

37.625 117,766 19,600

26,250 820162 19.600

180375 57.514 19.600

16,625 52.036 19.600

14.000 43.820 19.600

10 .500 32.865 19.600

8.750 270388 19.600

7.000 21.910 19 .600

1.706 5.340 5.000

314 . 081 $ 983 .074 $ 235 .600

Capital Investment for Wells and Water Injection Facilities

Net Profit to NWI

(1) NWI - estimated as .875 (2) Crude price $3.48 less $.35 transportation charge.

" Cumulative Net Income Net Income

to NWI to NWI

$ 18.961 $ 18.961

110.764 129.725

1800329 310.054

158,419 468.473

98,166 566.639

.62 .562 629.201

37.914 667.115

32.436 699.551

24.220 723.771

13.265 737.036

7.788 744.824

20310 747.134

340 747.474

£ 747,474

29,100

$ 718,374


5% to NWI

$ 18.510 $ 18.510

102.978 121.488

159.669 281.157

133,590 414,747

78,838 493,585

47.852 541,437

27,618 569,055

22.503 591,558

16.003 607.561

8,347 615.908

4.667 620.575

1.318 621.893

185 622.078

$ 622.078

28,751

$ 593 ,327

, ,

Table 42

Plan I

SUMMARY


Jim Beattie Working Interest

RODNEY FIELD


Interval Cumulative Gross Income Ii Oil Oil Gross Oil Less Sev. Tax, Cumulative Production, Production. to NWI,(I)@ $3.1300(2) Operating Net Income Net Income

Date Barrels Barrels Barrels !;!er Barrel EXEenses to NWI to NWI

3-1-1957 186,200

3-1-1958 77,200 263,400 67,550 $ 211,432 $ 35,500 $ 175,932 $ 175,932

3-1-1959 290,000 553,400 253,751 794,241 98,400 695,841 871,773

3-1-1960 348,900 902,300 305.287 955,548 100,800 854,748 lt726,521

3-1-1961 319,600 1,221,900 279,651 875 >307 100,800 774,507 2,501,028

3-1-1962 237,500 1,459,400 207,812 650,452 100,800 549,652 3,050,680

3-1-191>3 161,000 1,1>20.400 140,875 440,937 100,800 340.137 30390,817

3-1-191>4 114,000 1,734,400 99,750 312.218 100.800 211.418 3.1>02,235

3-1-191>5 91,400 1,825.800 79,975 250.323 100.800 149.523 3,751,758

3-1-1966 73,600 1,899,400 1>4,400 201,572 100,800 100,772 3.852,530

3-1-1967 61,500 1.960,900 53,812 168,431 100,800 67,631 3,920tl61

3-1-1968 52.500 2.013,400 45,938 143,786 100.800 42,986 3,963tl47

3-1-1969 45,250 2 ,058,650 39,593 123,921> 95,400 28,526 3,991,673

3-1-1970 22.960 2.081,1>10 20,091 62.885 42.800 20,085 4,011.758

3-1-1971 18,300 2 .099,910 16,012 50,117 41,900 8,217 4.019,975

3- 1-1 972 11. 830 2.1 11,740 10,351 32.399 31.300 1.099 4.021.074

TOTAL 1,925.540 1.684,848 $ 5.273.574 $ 1.252.500 $ 4.021.074

Capital Investment for Wells and Water Injection Facilities 129, 320

Net Profit to NWI $ 3,891,754

(1) NWI - estimated as .875 (2) Crude price $3.48 less $.35 transportation charge.

Discounted Cumulative Net Income Discounted to NWI@ Net Income 5,.. to NWI

S 171,743 $ 171,743

647,640 819,383

760,228 1.579.611

658,580 2,238.191

444,643 2,682,834

261,700 2.944,534

155,225 3,099,759

104,503 3,204,262

67tl07 3,271,369

42,876 3.314,245

25,983 3,340.228

16,415 3.356.643

11.015 3,367,658

4,325 3,371,983

547 3,372,530

$ 3.372.530

127,768

$ 3,244, 762

Table 43

Plan I


Jim Beattie

J. Braddon Lease

RODNEY FIELD


Interval Cumulative Gross Income Oil Oil Gross Oil Less Sev. Tax, Cumulative

Production, Production, to NWI,(l)@ $3.1300(2) Operating Net Income Net Income Date Barrels Barrels Barrels ~er Barrel EXEenses to NWI to NWI

3-1-1957 107.000

3-1-1958 39.200 1,.6.200 34.300 $ 1070359 $ 18.000 $ 89.359 $ 890359

3-1-1959 151.500 297.700 132.563 414.922 49.000 365.922 455.281

3-1-1960 180.000 477.700 157.500 492.975 49.000 443.975 899.256

3-1-1961 134.000 611.700 117.250 366.993 49.000 317.993 1.217.249

3-1-1962 96.000 707.700 84.000 202.920 49.000 213.920 1.4310109

3-1-1963 65.000 7720700 56.875 178.018 49.000 129.018 1.5600187

3-1-1964 50.000 822.700 43.750 136.938 49.000 87.938 1.648.125

3-1-1905 38.000 800.700 33.250 104.072 49.000 55.072 1.7030197

3-1-1906 33.000 893.700 28.875 900379 49.000 41.379 1.744.576

3-1-1967 28.000 921.700 24.500 76.685 49.000 27.085 1.772.201

3-1-1908 23.000 944.700 200125 02.991 49.000 13.991 1.780.252

3-1-1969 20.000 96".700 17.500 54.775 49.000 5.775 1.792.027

3-1-1970 36e 905.000 315 980 900 86 1.792.113

TOTAL 358.060 750.803 $ 2.350.013 $ 557.900 $ 1.792.113

Capital Investment for Wells and Water Injection Facilities 41,260

Net Profit to NWI $ 1,750,853

(l) NWI - estimated as .875 (2) Crude price $3.48 less $.35 transportation charge.


5% to NWI

$ 87.231 $ 87.231

340.2Ul 427.432

393.109 820.541

2080154 1.088.695

171.801 1.200.496

98.082 1.3590178

64.058 1.423.236

38.207 1.4010443

27.340 1.488.783

17.421 1.500.204

80385 1.514.589

3.290 1.517.885

47 1.517.932

$ 1.517.932

40, 765

$ 1,477,167

Table 44

Plan I


Interval Cumulative



3 - 1-1 9 57 10. 200

3- 1-1 958 10, 300 21.000

3-1-1 9 59 36.000 57.000

3- ] -1 960 35 .000 92 . 000

3- 1-1961 26 . 500 11 8 .500

3-1-1 962 16, 000 13 5.000

3- 1-1 963 11. 000 14 6 . 000

3-1- 1964 8 . 000 154 . 00 0

3-1-1 965 7.000 11>1. 000

3-1-191>6 6.000 167.000

3-1-1 9 67 5 . 000 172.000

3-1-1 968 4 . 000 176 . 000

3- 1- 1909 1 . 750 177,750

TOTA L 167 . 550

Jim Beattie

Colthart Lease

RODNEY FIELD


Gross Income Gross Oil Less Sev. Tax.

to NWI.(l) @ $301300(2) Operating Barrels per Barrel EXE,enses

9 , 450 $ 29 . 579 $ 5 ,500

31.500 98 .595 9,900

30 .625 9 5.856 9 ,900

23 .18 8 72.578 9 . 900

14.437 450188 9 ,9 00

9 .62 5 30.126 9.900

7.000 2 1.910 9 . 90 0

60125 19 017 2 9 . 90 0

5.250 16 .4 32 9 . 900

40375 1 3 .6 94 9 , 900

3 .500 10.955 9 . 900

1 , 531 4 ,7 92 4 . 500

146 .606 $ 45 8 . 677 $ 109 .000

Capital Investment for We lls and Water Injection Facilities

Net Profit to NWI

(1) NWI - estimated as .875 (2 ) Crude price $3.48 less $ .35 transportation charge.

Cumulative Net Incomt: Net Income

to NWI to NWI

$ 24,07 9 $ 24,079

88.69 5 112.774

85.956 198.730

62.678 261.408

35.288 29 6,696

20.226 316 . 922

12 .010 328.932

9.272 33 8.2 04

1>,532 344.736

3 .794 348,530

1,055 349,585

292 349,677

$ 349.877

19.200

$ 330.677

Discounted Cumulative Net Income Discounted to NWI@ Net Income

5% to NWI

$ 23.501> $ ~ 3.501>

82.41>1 105.967

760108 182,075

52.854 234.929

28.340 263.269

15,470 278.739

8.749 287.488

6.433 293.921

4.311> 298.237

2.387 300.624

1>32 301,256

11>7 301.423

$ 301 .423

18.970

$ 282,453

Table 4 5

Plan I


Jim Beattie


RODNEY FIELD


Interval Cumulative Gross Income Oil Oil Gross Oil Less Sev. Tax. Cumulative

Production, Production, to NWI,(I)@ $301300(2) Operating Net Income Net Income Date Barrels Barrels Barrels per Barrel EXEenses to NWI to NWI

3-1-1 957 17.000

3-1-1 9 58 27. 20 0 44. 200 23.800 $ 74.494 $ 12.000 $ 62.494 $ 62.494

3-1-1 9 59 94.000 138.200 82.250 257.443 31.500 225.943 288.437

3-1- 1960 102.000 240.200 89.250 279.352 31.500 247.852 536.28 9

3- 1-1 961 108.000 348.200 94.500 295.785 31 .500 264.285 800.574

3- 1-1962 92.000 440.200 80.500 251. 9 65 31.500 220.465 1.021.039

3-1-1963 66.500 506.700 58.188 18 2 d28 31.500 150.628 I tl71.667

3-1-1964 40.000 546.100 35.000 109.550 31.500 78.050 1.249.717

3-1-1965 34.500 581.200 30d87 94.486 31.500 62.986 1.312.703

3- 1-1 960 25.000 606.20 0 21.875 68.469 31.500 36.969 1.349.672

3-1-1 967 21.000 627.200 180375 57.513 31.500 26.013 1.375.685

3-1-196 8 19 .000 646. 20 0 16. 6 25 52.037 31.500 20.537 1.396.222

3-1-1969 18 . 00 0 664.200 15.750 49. 297 31.500 17.797 1.414.019

3-1-1 970 17.50 0 681.700 15.313 47.930 31.500 16.430 1.4 30. 4 49

3-1-1 9 71 13.500 6 9 5. 20 0 11.812 36.971 31.500 5.471 1.435.920

3-1-1 9 7 2 9 .8 20 705.0 20 8.593 26.896 26.000 896 1.436.816

TOTAL 6 88.0 20 602. 0 18 $ 10884.316 $ 447.500 $ 1.431>. 8 16

Capital Investment for Wells and Water Injection Facilities 53.760

Net Profit t o NWI $ 1,383,056

(1) NWI - e stimated a s .875 (2 ) Crude price $3. 48 less $ . 35 transportation charge.


5% to NWI

$ 61.001> $ I> 1. 00 6

210.061 271.01>7

2l9.456 490.523

222.864 713.387

177.058 890.445

115.211 1.005.,,56

51>.856 1.062.512

43.697 l.101>.209

24.426 10130.635

11>.369 1.147.004

12.308 1.159.312

100158 1 tl1>9.470

8.931 1.178.401

2.832 10181.233

442 1.181.1>75

$ 1.181.675

53,115

$ 1,128,560

Table 46

Plan I


Jim Beattie

F. Wright Lease

RODNEY FIELD



Production, Production, to NWI,(l)@ $3.1300(2) Operating Net Income Net Income to NWI @ Net Income Date Barrels Barrels Barrels per Barrel EXEenses to NWI to NWI 5% to NWI

3-1-1957 52.000

3-1-1959 8.500 60.500 7.438 $ 23.281 $ 8.000 $ 15.281 $ 15.281 $ 14.917 $ 14.917

3-1-1960 31.9CO 92.400 27.912 87.365 10.400 76.965 92.246 71.555 86.472

3-1-1961 510100 143.500 44.713 139.951 10.400 129.551 221.797 114.708 201.180

3-1-1962 33.000 176.500 28.875 90.379 10.400 79.979 301.776 67.444 268.624

3-1-1963 18.500 195.000 16tl87 50.665 10.400 40.265 342.041 32.337 300.961

3-1-1964 16.000 211.000 14.000 43.820 10.400 33.420 375.461 25.562 326.523

3-1-1965 11.900 222.900 10.413 32.593 10.400 22.193 397.654 160166 342.689

3- 1-1 966 9 .600 232.500 8.400 26.292 10.400 15.892 413.546 11 .025 353.714

3-1 -1 967 7.500 240.000 6.562 20.539 10.400 100139 423.685 6.699 360.413

3-1-1 968 6.500 246.500 5.688 17.803 10.400 7.403 431.088 4.658 365.071

3-1-1969 5.500 252.000 4 . 812 15.062 10.400 4.662 435.750 2.794 367.865

3-1-1970 5.100 2570100 4.463 13.969 10.400 3.569 439.319 2.037 369.902

3-1-1 9 71 4.800 261.900 4.208 13.146 10.400 2.746 442.065 1.493 371.395

3-1-1972 2.010 263. 9 10 1.758 5.503 5.300 203 442.268 105 371.500

TOTAL 211.910 185.421 $ 580.368 $ 1380100 5 442.268 $ 371.500

Capital Investment for Wells and Water Injection Facilities 15, lOa 14,919

Net Profit to NWI $ 427,168 $ 356,581

(I) NWI - estimated as . 875 (2) Crude price $3.48 less $.35 transportation charge.

Table 47

Plan I


Interval Cumulative



3-1-1957 28.800

3-1 -195 8 4.800 33.600

3-1-1959 250120 58.720

3-1-1 960 33.000 91.720

3- 1-1961 20.000 111.720

3-1-1962 12.000 123.720

3-1-1963 10.00C 133.720

;-1-1964 7,300 141.02 0

3- 1-1965 6.000 147.020

3-1 -1 966 5.000 152.020

3-1-1967 3.500 155.520

:: - 1-196 8 3.000 158.520

] -1-196 9 2.500 161.0 20

3-1-1 9 70 2 . 01 0 163. 0J O

TOTAL 134.23 0

Gross Oil

A. Comfort

Tunks Lease

RODNEY FIELD


Gross Income Less Sev. Tax,

to NWI,(l)@ $3.1300(2) Operating

Barrels per Barrel EXEenses

4.200 $ 130146 $ 5.000

21.980 68.797 7.000

28.875 90.379 7.000

17,500 54.775 7.000

10 .500 32 .865 7.000

8.750 27.388 7.000

6.388 19.994 7.000

5,250 16.433 7.000

40375 13.693 7.000

3 .062 9.584 7.000

2 .625 8 , 217 7.000

2 .1 88 6,848 6.000

1,758 5,50 3 5.200

117.451 $ 367.6 22 $ 86. 200

Capi tal Inv e stment for We lls and Water Injection Facilities

Ne t Profit to NWI

(I) NWI - estimated as .875 (2) Crude price $3.48 less $.35 tr a nsportation charge .

Net Income to NWI

$ 8.146

61.797

83.379

47.775

25.865

200388

12.994

9.433

6.693

2.584

1.217

848

30J

$ 281.422

5,500

$ 275,922

Discounted Cumulative Cumulative Net Income Discounted Net Income to NWI@ Net Income

to NWI 5% to NWI

$ 8.146 $ 7.952 $ 7.952

69.943 57.453 65.405

153. 322 73,826 139.231

201.097 40.287 179.518

226 .96 2 20.772 200.290

247 . 350 15.594 215.884

2600344 9 ,46 5 225.349

269. 777 6.544 23 1.89 3

276.470 4.422 2360315

279.054 1.626 237.941

280.271 729 238.670

281.119 484 2390154

281.42 2 165 239 . 3 19

$ 239.319

5,434

$ 233,885

Table 48

SUMMARY

Plan I


Dominion Natural Gas Working Interests

RODNEY FIELD


Interval Cumulative Gross Income Oil Oil Gross Oil Less Sev. Tax,

Production, Production, to NWI,(I)@ $3.130(2) Operating Net Income Date Barrels Barrels Barrels Eer Barrel EXEenses to NWI

3-1-1957 98.960

3-1-1958 13.000 111.960 110375 $ 35.604 $ 16.000 $ 19.604

3-1-1959 68.200 180tl60 59.675 186.783 19 tl 00 167.683

3-1-1960 87.500 267.660 76.563 239.642 19 tl 00 220.542

3-1-1961 52.500 320.160 45.937 143.782 19 tl 00 124.682

3-1-1962 30.000 350 tloO 26.250 82 fl6} 19 tl 00 03.003

3-1-196 3 24 . 000 374.160 21 .000 05.730 19 tl 00 46.630

3-1-1964 19.000 3930160 10.625 52 .0 36 190100 32.936

3-1-196 5 14.0CO 4070160 12.25C 38.343 19.100 19.243

3-1-1966 11.500 418.660 10.063 31.497 19.100 12.397

3-1-1967 10.000 428.660 8.750 27.387 19 tl CO 8.287

3-1-196 G 7.733 4360393 6.766 21.179 17.000 4.179

3- 1-19S 9 5.000 441.3?3 4.375 13.693 12.50·) 1.193

3 - ~ -1 9 70 2.437 443. 830 ;:,132 6.673 00300 373

TOTAL 344.87C 301,101 S 944.512 $ 22 3 .700 :I 720. 812

Capital Investment for We lls and Water Injection Fac ilities

Net Profit to NWI

(1) NWI - estimated as .875 (2) Crude price $3.48 less $.35 tr a nsportation charge.

$

22,000

698,812


to NWI

$ 19.604

187.287

407.829

532.511

595.574

642.204

675.140

694.383

706.780

715.067

719.246

720.439

720.812


$

$

5%

19.137

155.896

195.275

105.140

50.646

35.666

23.993

13.350

8 fl91

5.215

2.504

681

203

615.897

21,736

';94,161


to NWI

$ 19.137

175.033

370.308

475.448

520.094

561.700

585.753

599.103

607.294

612.509

615.013

615.694

615.897

Table 49

Plan I



F. G . Pur ce ll Lease

RODNEY FIELD


Interval Cumulative Gross Income Oil Oil Gross Oil Less Sev . Tax,

Production, Production. to NWI,(I) @ $3 . 130CX2) Ope rating Net Income Date Barrels Barrels Barrels per Barrel EX,Eenses to NWI

3- 1-1 9 57 71034 3

3-1 - 1958 9 . 000 RO 034 3 7, 8 75 $ 24,649 $ 10,000 $ 14,649

3 - 1-1 9,9 39 , 200 11 9 ,54 3 34,300 1070359 12 ,500 94,859

3- 1- 1960 61.000 180,543 5303 75 167,064 12, 500 154,51>4

3-1-1 961 37 . 000 2 17, 54 3 32037, 101,333 1 2 . 500 88.833

3- 1-1 962 21. 000 238 , 543 180375 57 , 514 12. 500 45.014

3-1-1 963 17. 000 25 5 , 543 1'., 8 75 46.559 12 . 500 34, 059

3- 1- 1964 14. 000 269 .54 3 12 , 250 38 .34 2 12 . 500 25,84 2

3-1-1 965 10.000 2 79 . 543 8 .7 50 27 0386 12 .5 00 14 , 888

3-1-1965 8.0CO 287, 543 7 . 0 00 2 1. 9 10 12 .5 00 9 .410

3-1-1 967 7.000 29 4.54 3 6 .1 25' 1 Q 0171 12.500 6.671

3-1-1 968 6 . 00 0 300 . 543 5 , 250 16.4 3?· 12 . 500 3 . 9 33

3-1-1 969 5 . 00 0 305 . ,43 4 , 375 13 . b93 12 . 500 10193

3-1-1 970 2 .437 307 . 980 2 01 32 6 . 1> 73 6 . 300 3 7 3

TO TAL 236 . 637 '207 . 05 7 5 648 . 088 $ 153 , 800 5 494.288

C apital Investment fo r Wells a nd Wa ter Injection Facilitie s

Ne t Pro fit to NWI

(l) NWI - estimated a s .875 (2) Crude price $3.48 less $.35 transportation c harge.

$

11,000

483,288

Discounted Cumulative Cumulative Net Income Discounted Net Income to NWI @ Net Income

to NWI 5"1. to NWI

$ 14.649 $ 140300 $ 140300

10 9,508 880191 102,491

264,07 2 136.856 239,34 7

352,905 74,910 314, 2 57

397,919 360151 350,408

431.978 26 ,051 376,459

457.820 18,825 395,284

472,708 10.329 405 .613

482.lIS 6,217 411,830

4 8 8.78 S' 4,198 416,028

492.722 20357 4180385

493.915 681 419,066

494 . 288 203 419.269

$ 419 . 269

10,868

$ 408,40)

Table 50

Plan I



J. Rubi Lease

RODNEY FIELD



Production. Production. to NWI,(l) @ $301300(2) Operating Net Income Net Income to NWI@ Net Income Date Barrels Barre ls Barrels per Barrel EXEenses to NWI to NWI 50/0 to NWI

3- 1-1 9 57 27.617

3-1-1958 4.000 31.617 3.500 $ 10.955 $ 6.000 $ 4.955 $ 4.955 $ 4.837 $ 4.837

3-1-195 9 29.000 60.617 25. 375 79.424 6.600 72.824 77.779 67.705 72.542

3- 1-1 960 26.500 87.117 23 0188 72.578 6.600 65.978 143.757 58.419 130.961

3-1-1961 15.500 102.617 13.562 42.449 6.600 35.849 179.606 30.230 1610191

3-1-1 962 9.000 111.617 7 .875 24.649 6.600 18.049 197.655 14.495 175.686

3-1-1 9 6 3 7.000 118.617 60125 190171 6.600 12.571 210.226 9.615 185.301

3-1-1964 5.000 123.617 4.375 13 .694 6.600 7.094 2170320 5.168 190.469

3-1-1965 4.000 127.617 3.500 10.955 6.600 4.355 221.675 3.021 193.490

3-1-1966 3.500 131.117 3.063 9.587 6.600 2.987 224.662 1.974 195.464

3-1-1 967 3.000 134.117 2.625 8.216 6.600 1.616 226.278 1.017 196.481

3-1-1968 1.733 135.850 1.516 4.746 4.500 246 226.524 147 196.628

TOT AL 108.233 94.704 $ 296.424 $ 69.900 $ 226.524 $ 196.628

Capital Investment for Wells and Water Injection Facilities ll. 000 10,868

Net Profit to NWI $ 215,524 $ 185,760

( 1) NWI - e sti m a ted a s .8 75 (2 ) Crude price $3 . 4 8 le ss $ .35 transpo r ta ti o n c har ge.

Table 51

Plan I


New Bristol Oils

A. McCallum Lease

RODNEY FIELD


Interval Cumulative Gross Income Oil Oil Gross Oil Less Seve Tax,

Production, Production, to NWI,(I)@ $3 . 1300(2) Operating Net Income Date Barrels Barrels Barrels per Barrel EXEenses to NWI

3-1-1 957 84.600

3-1-l ? 58 7.800 92.400 6 . 825 $ 21.362 $ 9 .000 $ 12.362

3-1-1959 30.000 122.400 26.250 820163 9.700 72.463

3-1-1960 40,000 162.400 35 .000 109.550 9.700 99.850

3- 1-1961 35,000 197.4CO 30.625 95 . 856 9.700 86.156

3- 1-1962 16,000 213.',00 14.00 0 43.820 9 .7 00 340120

3-1-196 3 12 ,000 225 . 4C·0 10.500 32.865 9.700 23.165

3 - 1-1 964 9 .00 0 234.400 7.875 24.649 9.700 14.949

3-1-196 5 7,000 241 .40 0 6.125 190171 9.700 9.471

3-1-1966 6.000 247.'-00 5 .250 16.433 9,700 60733

3-1-1 967 5.000 252.400 40375 13.693 9.700 3,993

3- 1-1966 4,000 256,400 3.500 10.955 9,700 1,255

3- 1-1969 3,2 2 C 259.620 2 . 818 8.821 8030C 521

TOTAL 175,020 153.143 $ 479,338 $ 1140300 $ 365.038

Capital Investment for Wells and Water Injection Facilities

Net Profit to NWI

(1) NWI - estimated as . 875 (2) Crude price $348 less $.35 transportation charge.

$

8,250

356,788


to NWI

$ 120362

84.825

184.675

270,831

304,951

328.116

343.065

352.536

359.269

363.262

364,517

365,038


$

$

$

5'/0

12. 068

67.370

88.410

72.653

27,402

17.718

10.890

6.571

4.449

2.513

752

297

311 .093

8,151

302,942

Curnulative Discounted Net Incorne

to NWI

$ 12.068

79.438

167.848

240.501

267.903

285.621

296.511

303.08 2

307.53.

310.044

310.796

311.093

Table 52

SUMMARY

Plan II


Felmont Oil Corpor a tion Wo r king Inte rest

RODNEY FIELD



Production, Production. to NWI.(I)@ $3.1300(2) Operating Net Income Date Barrels Barrels Barrels per Barrel EX,Eenses to NWI

3-1-1957 396,584

3-1-1958 91,&00 488 ol84 79,524 $ 248,910 $ 65,250 $ 183.660

3-1-1959 563,400 1,051,584 489tl23 1,530,955 147,600 103830355

3-1-1960 b23,OOO 1,674,584 540,867 l.b92,914 147,bOC 1,5450314

3-1-19bl 455,000 2,129,58~ 395,014 1.2360394 147.bOO 1,088,794

3-1-19b2 271,000 2,400,584 235,273 736,404 147,600 588,804

3-1-1963 209,000 2,609,584 181,446 567,926 147.600 4200326

3-1-1964 161,000 2,770,584 139,774 437.493 147,600 289.893

3-1-1965 119,500 2,890.084 103,746 324,725 147,600 171d25

3-1-1966 80,000 2.970,084 69,453 217,388 147,600 69.788

3-1-1967 70.000 3.040.084 60,772 190.216 147.60U 4 2 .616

3-1-1968 60.000 30100.084 52,089 163,039 147.600 15.439

3-1-1969 50.000 3,150.084 43,409 135.870 124.000 11.870

3-1-1970 40,000 3,190.084 34,726 108.692 99.000 9.692

3-1-1971 25.906 3.215.990 22.491 70.397 68.000 20397

TOTA~ 2,819.406 2,447,707 $ 7,661.323 $ 1.832.250 $ 5.829.073

Capital Investment for Wells and Water Injection Facilities 415,597

$ 5,413,476 Net Profit to NWI

(1) NWI - .868164. (2) Crude price $3.48 less $.35 transportation charge.


to NWI

$ 183,660

1,567,015

3 01120329

4,2010123

4.789,927

5 .210.253

5,5000146

5,677,271

5.747,059

') .789.675

5 . 8 050114

5.816.984

5,826.676

5.829.073


50/0

$ 179.287

l,286tl19

It3b8,267

9l8d47

472 ,874

321,495

211tl73

122,882

460110

26.817

9 ,253

6,775

5,268

1,241

$ 4.975.708

410,610

$ 4,565,098

Cumulative Discounted Net lncorne

to NWI

$ 179,287

1,465,406

2,833,b73

3,751,820

4.224,694

4,546,189

4,757,362

4,880,244

4,9260354

4.9530171

4.962.424

4,9690199

40974.467

4.975,7 0 8

,

Table 53

Pla n I I


John Beattie

Sabjan Lease

RODNEY FIELD


INTERVAL CUMULATIVE GROSS OIL GROSS INCOME DISCOUNTED CUMULATIVE

OIL OIL LESS SEV. TAX OPERATING NET INCOME CUMULATIVE NET INCOME DISCOUNTED DATE TO NWI .(I) PRODUCTION PRODUCTION @ $3.1300(2) EXPENSES TO NWI NET INCOME TO NWI NET INCOME

BARRELS BARRELS BARRELS

PER BARREL TO NWI (/ 50/0 I ANNUM TO NWI

3- J - 19 57 85.550

3- 1- 1958 12.400 97.950 10 , 850 $ 33.961 $ 15,000 $ 18,961 S 18,961 $ 18,510 S 18,510

3-1 - 19 59 47,600 145.550 41.650 1300364 19,600 110,764 129,725 102,978 121,488

3-1-1 960 73,000 218,550 63 , 875 199,929 19,600 1800329 310,054 159,669 281,157

3-1-1 9 6 1 65.000 283. 550 56 . 875 178,019 19.600 158,419 468.473 133,590 414.747

3- 1-1 96 2 43,000 3 26,550 37,625 117 , 766 19.600 98.166 566.639 78,838 493,585

3-1-1963 30,000 356 , 550 26 , 250 82.162 19,600 62,562 629,201 47,852 541,437

3- 1-1 9 64 21.000 37 7.55::> 180375 57.514 19 . 600 3 7,914 6670115 27,618 569.055

3- 1- 1965 19.000 ~ 96,5 5C 16,1>25 52 ,0 36 19 . 600 32,4 36 69 9.551 22,503 591,55 8

3-1-1966 16,000 412.550 14.000 43, 82 0 19.600 24,2 2 0 723.771 16,003 607,561

3-1-196 7 12.000 424 . 55C 10.500 32 . 865 19,600 13, 265 737,036 80347 615 . 908

3 - 1- 1968 10.000 4 34 . 550 8 .750 27 . 388 19,6 00 7,788 744.824 4,667 620 . 575

3-J- 1969 8. 000 44 ;> , 550 7 .000 21. 9 10 19.600 20310 7470134 10318 621,893

3- J -1 9 70 1. 950 444.50 0 1,706 5 .340 5,000 340 747.474 185 622.078

TO TAL 35 8 . 95 0 314 , 081 $ 98 3 ,074 $ 235.600 $ 747.474 $ 622,078

C a p i tal Inves tITle n t fo r We ll s a nd Wate r Injec ti o n Fac ilities $ 52, 107 $ 51,48 2 Ne t Profit to NWI $ 695 , 36 7 $ 570,596

(I) N WI - e s ti m ate d as . 8 7 5 (2) C r ude price $3.48 less $. 35 t rans por t a t ion charge.

Table 54

SUMMARY

Plan II



RODNEY FIELD



Production, Production, to NWI,(l)@ $3.1300(2) Operating Net Income Date Barrels Barrels Barrels per Barrel EXEenses to NWI

3-1-1957 186.200

3-1-1958 47.900 234.100 41.913 $ 131.188 $ 35.500 $ 95.688

3-1-1959 301.000 535.100 2630375 824.363 98.500 725.863

3-1-1960 347.000 0820100 303.625 950.347 98.500 851.847

3-1-1961 347.000 1.229.100 303.625 950.346 98.500 851.846

3-1-1962 236.000 1.465.100 206.500 646.345 98.500 547.845

3-1-1963 160.000 1.6250100 140.000 438.200 98.500 339.700

3-1-1964 110.000 1.7350100 96.250 301.262 98.500 202.762

3-1-1965 92 .000 1.827.100 80.500 251.965 98.500 153.465

3-1-1966 78.000 1.9050100 68.250 213.623 98.500 1150123

3-1-1967 60.000 1.9650100 52.500 1640325 98.500 65.825

3-1-1968 50.000 2.0150100 43.750 136.937 98.500 38.437

3-1-1969 45.000 2.0600100 39.375 123.244 98.500 24.744

3-1-1970 37.000 2.0970100 32.375 1010334 95.000 6.334

3-1-1971 14.640 2.111.740 12.810 40.095 38.000 2.095

TOTAl. 1.925.540 1 .684.848 $ 5.273.574 $ 1.252.000 $ 4.021.574

Capital Inv estment for Wells and Water Inj ec tion Facilities

Ne t Profit to NWI

(l) NWI - e stimated. 875 (2) Crude price $ 3 .48 less $. 35 transportation c harge.

$ 277,328

$ 3,744,246


to NWI

$ 95.688

821.551

1.6730398

2.525.244

3.073.089

3 .412.789

3 .615.551

3.769.016

3.8840139

3 .949.964

3 .988.401

4.0130145

4.019.479

4.021.574

Discounted Net Income to NWI@

50/.

$ 93.410

674.842

754.251

718.336

439.980

259.826

147.702

106.468

70.064

41.421

23.035

14.123

3.443

1.085

$ 30353.986

$ 274, 000

$ 3,079,986


to NWI

$ 93.410

768.252

1.522.503

2.240.839

2.680.819

2.940.645

3.088.347

3.194.815

3.270.879

3.312.300

3.335.335

3.349.458

3.352.901

3.353.986

Interval

Oil Production,

Date Barrels

3-1-1957

3-1-1958 120.600

3-1-1959 615.000

3-1-1960 657.000

3-1-1961 593.000

3-1-1962 280.000

3-1-1963 200.000

3-1-1964 145.000

3-1-1965 120.000

3-1-1966 88.806

TOTA~ 2.819.406


Net Profit to NWI

(1) NWI - 868164

Table 55

SUMMARY

Plan III


Felmont Oil Corporation Working Interest

RODNEY FIELD


Cumulative Gross Income Oil Gross Oil Less Sev. Tax, Cumulative

Production, to NWI,(I)@ $301300(2) Operating Net Income Net Income Barrels Barrels per Barrel EXEenses to NWI to NWI

396.584

5170184 104.701 $ 327.714 $ 85.000 $ 242.71" $ 242 .714

101320184 533.920 1.671.170 218.500 1.452.670 1.6950384

1.789ol84 570.384 1.7850302 218.500 1.566.802 1.2620186

2.3820184 514.821 1 .611.389 218.500 1039 2 .88 9 4.655.075

2.662.184 243.086 760.860 218.500 5420360 S tl97.435

2 .862 ol84 173.633 543.471 218.500 324,971 S .522.406

3.007.184 125.884 394 .017 218.500 175.517 , .697.923

3.1270184 104 ol80 326.083 2l8.500 107.583 5 .8 0S.506

3.215.990 77.098 2410317 218.S00 22.817 5 .8280323

2.447.707 $ 7.66103 23 $ 1.833.000 $ 5.8280323

Wells and Water Injection Facilities $ 471,409

$ 5,356,914

(2) Crude price $3.48 less $.35 transportation charge.

•

Discounted Cumulative Net Income Discounted to NWI @ Net Incorne

5"/. to NWI

$ 236.935 $ 2360935

10350.562 1.587.497

1.3 6 7 .2 9 3 2.974.790

Itl74.5 82 4tl49.372

435.575 4, 58 4,947

248 .561 4.83 3 . S0e

12 7.855 4,9610363

74.637 5.036.000

15.076 5.051.076

$ 5.051.076

$ 465,752

$ 4 ,585 ,324

•

Table 56

SUMMARY

Plan III


John Beattie Working Interes t

RODNEY FIELD

Elg in County, Ontario, Canada


Production, Production, to NWI,(I)@ $301300(2) Operating Net Income Date Barrels Barrels Barr e ls per Barrel

3-1 -1957 85.550

3-1-1958 15.500 101.050 13 .563 $ 42.452 $

3-1 -1959 68.500 169.550 59.937 187.603

3-1-1960 98.500 268.050 86.188 269 .768

3-1-1961 83.500 351.550 73 .062 228.685

3-1-1962 35.500 387 .05 0 31.063 97.227

3-1-196 3 25.500 412.550 2203 12 69.836

3-1-1964 20.000 432.550 17.500 54.775

3-1-1965 15.550 44 8 .100 13 . 606 42.587

TOTAL 362 .550 317.231 $ 992,933 $

Capital Investment for We lls and Water Injecti on Fac ilities

Ne t Pr o fit t o NW I

(I) NWI - e stimated as .875 (2 ) Crude pri ce $3.48 Ie •• $. 35 transportati on c harge .

EXEenses

15.000 $

31.500

31 . 500

31 . 500

31 . 500

31.500

31.500

31 .5 00

235,500 $

$

to NWI

27.452

156.103

238.268

1970185

65.727

38.336

23.275

11.087

757,433

66,497

69 0,936


to NWI

$ 27.452

183.555

421.823

619.008

684.735

723.071

746.346

757.433

...


, ".10 to NWI

$ 26.798 $ 26.798

1450131 171.929

210.970 382.899

166.280 549.179

52.786 &01.965

29 .322 631.287

16.955 648.242

7.092 &55.934

$ 655,934

65,699

$ 590,235

...

Table 57

SUMMARY

Plan III



RODNEY FIELD


Interval Cumulative Gross Income Discounted Cumulative Oil Oil Gross Oil Less Sev . Tax, Cumulative Net Income Discounted

Production, Production, to NWI,(l) @ $3.1300(2) Operating Net Income Net Income to NWI @ Net Income Date Barrels Barre ls Barrels per Barrel EXEenses to NWI to NWI 5"/0 to N WI

3-1-1957 186. 200

3-1-1958 152.400 338 ,600 133 , 350 $ 4170386 $ 48.000 $ 36 9 03 8 6 $ 36 9 , 386 $ 360 . 59 1 $ 36 0 . '>9 1

3-1-1959 511.000 849.600 447.125 1.399.501 17 9 . 800 1.21 9 , 701 1 ,5 8 9 ,087 101 3 3 . 96 3 1,1.9 /,. , 5 59

3-1-1960 511.000 1.360.600 447.125 1 . 399 . 501 179. 800 1 , 2190101 2 . 808 ,7 8 8 1 , 0 7 <,> . 96 0 2 . 5 7l., ~ 1 ~

3-1-1961 308.000 1.668.600 269 , 500 843 .5 35 179,800 66 3 01 3 5 3 .4 72,523 5 5 9 01 08 3013 ,+ , 227

3-1-1962 180.000 1.848.600 157 . 500 492.975 179 . 8 00 31 3 017 : , ,7 8 5 , 698 2 51 . 51 4 303g :; .74 1

3-1-1963 120,000 1.968.600 105 .000 328.650 1 79 . 8 00 148 , 850 3 , 934 . 548 113 . 851 3 ,499 . 5 92

3-1-1964 95.000 2.063.600 830125 260.181 179.800 800381 '.,0 14 , 92 9 58 , 554 3 , 55 o ol4 ~

3-1-1965 48.140 2 .111.740 42.123 131.845 125 , 000 6 . 845 4 . 021 ,77 4 4 , 74 9 3,562 , 09 "

TOTAL 1.925.540 1, 684 . 848 $ 5 ,2 73 . 574 1 ,2 51 . 80 0 $ 4 . 0210174 $ ] , 5 6 2 , 89 5

Capital Investment for Wells and Water Inje c tion Facilities $ 368,370 $ 363,950

Net Profit to N WI $ 3,653 , 404 $ 3, 198,945

(1) NWI - estimated . 875 (Z) Crude price $3.48 less $ . 35 transportation charge.

FIGURES

LIST OF FIGURES

Figure No . Title

PRODUCTION HISTORY

1 Production History - Felmont Oil Corporation Lease s 2 Production History - A. Braddon Lease 3 Production History - A . C . Gillies Lease 4 Production History - J . D. Graham Lease 5 Production History - E . J . MacMillan Lease 6 Production History - John McMillan Lease 7 Production History - John Beattie - Sabjan Lease 8 Production History - Jim Beattie 9 Production History - J . Braddon Lease

10 Production History - Colthart Lease 11 Production History - N . D . McMillan Lease 12 Production History - F. Wright Lease 13 Production History - Dominion Natural Gas 14 Production History - F . G. Purcell Lease 15 Production History - J . Rubi Lease


16 17 18 19 20 21 22 23

Primary Depletion - Total Field Plan I Water Flood - Total Field Primary Depletion - Felmont Oil Corporation Water Flood Programs - Felmont Oil Corporation Primary Depletion - John Beattie Water Flood Programs - John Beattie Primary Depletion - Jim Beattie Water Flood Programs - Jim Beattie

WATER INJECTION PATTERN

24 25 26

Proposed Water Injection Pattern - Plan I Proposed Water Injection Pattern - Plan II Proposed Water Injection Pattern - Plan III

..

,- 1+

Fig ure 1

PRODUCTION HISTORY


RODNEY FIELD

Elgin Counl y , Ontario , Canada

~~-t+i=R= - -Jl=~l~ _-t, '

-=1: ~!::

·-W~' 1=

r. 60G

~:=t= 500

-H- 1+.L1±~ -,

400

+

x' _=t'

300

200

100

•

oo ::::: 20

<1J

;3:: 00 15 C

. ~

u ::l 10 "0 0 H

0.. 5 ....

0 H -<1J .0 0 S ::l Z

-- -I - - - - - i-- 1--

1= t-t-

I-- I-- L _

6 00 I

I-- -~- -

I-- I--

500 1--

..c: ~ 0

400 t--~ H <1J

I-'-< oo ...... <1J H 3 00 H ro -~ . <1J .... ro ~ 200

<5

100

195 5

-- - -1--

\-- f-

- 1-- -- r-

t--r - ' · t--,

j-- t-f--

---r-

\-\- --

1956

Figure 2

PRODUCTION HISTORY

Angus Braddon Lease F e lrnont O i l Corporat ion

RODNEY FIELD

JAMES A . LEW I S ENG INEERING INC O I'tP' O I't AT IO

Pnrokum Rtu"I'","r AMl,JU

I- -

- f-- t--f--

---I-f- - 1--l-

1--

-r- r--

I

1957

E l g in County, Ontario, Canada

= = = -

e-

6

5 oo ...... <1J H H ro ~ ...... 4 0

oo "0 C ro oo ::l 0 3 ..c:

E-<

......

<5 <1J

2 . ~ .... ~ ::l S ::l l)

•

Ul 20

Q)

~ 15 bl)

5 U

" 10 ." 0 , .. r-+ P.. 5 ... ,=t + + --+ 0

... 0 - <--I

Q)

~i ,

.D ::r - -,-

E f-+ ~~=R=R=+ " z H - ~1=J~ ,

r- ,- f-;'-+R !, I

:j f± -

TI t-3500 :

R=, 3000 , :

.c

" 0

~ 2500 .. Q)

P.. (/l

r-r-Q) +: ... 2000 ... '" "" Q)

~ -1 ~ 1500

<5 --c

1000 -,

500

---1---

1952 1953

r+-..J

-1-=-1=

1954

, '- ! l L_ ± I .r-

=8- $-l +- +:-

=1-

H--r

1955

Figure 3

PRODUCTION HISTOR Y

A. C. Gillies Lease


RODNEY FIELD

1956


JAM!. A. LEWIS INGINI!!RING IHC:O"POIIATIlD

Pmol.tvm RutnlOi'r AlI4l,ru

H-

~- --+-=-,--

200

175

150 ~ Q) ... ... '" "" ...

125 0

Ul "0 c

'" "' " 100 0 .c E-<

<5 Q)

75 -~ ~ " E " U

50

25

1957 1958

. ;; "" .: u , " o 0': (;

" . .D r: , z

25

2 0 f-7+1

~ 1-.-+- n--

600 r-r+ t-

..

:-+-'''+ f-L":i=l..j..C: " - .

T ,

I-r L:.j:"f't 1-1- ri- . + -- -+~ :+ r+- -+ -

r'

f-l -h'

.b

H:"r:j::::j:=j= 1-= ..1

+H-H·

~f!~

L p:: ·+I~ .

"':":..c. -:-;:f:j:-.. :t.., ~. ~. =+

Figure 4

PRODUC TION HISTOR Y

John D. Graham L e ase Felmont O il Co rpor atio n

RODNEY FIELD

=l=\.

Elg in County. O ntcl.rio, Canad a

.rt-H- ' 70

_ ... C

r+- "

60

40

+h- 30

~ .... OJ o ~ ~

OJ 00 .0 " Eu " " Z"" 0

OJ k ~

nl ttl

o

~

Po.

10

5

0

900

800

700

600

500

400

300

200

i=t-

100

R-jl

, , .-1 --r

':'1-

1-1-

- + 11 --+-

-I

I-

--+-1-1-+H-

-t-

+ _ r -

_OJ;, '_ f

+ 1-++

±-=1--r ' 1--

H +

H~rl _

JAME. A. . LEWIS INGIHEIAINO lNCO",.O" .. 'UI

Pnovkwm RUlYloOIt AII4!,IU

40

35

30

25

20

15

10

5

o ~~;iill;£~~~~~Jii~l;!~l~~~~iijli18~~~~~~i!~il~~~~~~~i~]i18j~~~~:illi!8~~!!i:ij~t18!~O 1952 1953 19 54 1955

Fig ure 5

PROD UCTION HIST ORY

E. J - MacMillan L ease F e Lm ont Oil C orpo rati on

RODNEY FIELD

1956

Elgin C o unt y, Ontario , Canada

1957 1958

o OJ ,t oj

'3 E " u

"' '" ~ CD

.S u

" ." 0 ~

0.. .... 0

~

'" .D

S " z

.<: '2 0

::E ~

'" P..

~

" ~ ~

'" Iil

'" :;; ~

0

20

15

10

5

a i---I--~

8000 r-I

7000

6000

5000

rr

4000

3 000

f-> .-t-

2 000 H--i-+-,r i=t=j:+-t

i-H-++-

1000 1+tt=l=t+-

1-1-r,-L

--++ , H·

+

: :

-1 I ,-, .. ,L

I--+--j-

,~

, -,

;

, H-=1-.

f+

1 +;-

-1--:+-

.-1.

+ -

+

JAMES A . LEWIS ENGINEERING IN(;QII"OIlATIO

P'lroW"'" Rurr,*, .... "a/,JlJ

350

300

250

200

150

100

50

a .ii:i"~~"~1i~~~.ii:i';~"~"~~~.ii:i'~~"~"ti~i.';:i.:~~"li"tl~i.';:i.::~"""~~i.'; :i.:: ~"li"~"C1i; ·~li""i"Ji.¥O ~~~<~~~<~~~c~~~<~~~<~~~c~~~<~~~<~ozc~~~<~~~<~ o zo~~~<~~~~~~zo~~s<~~~<~8.d~~a12 __ ~~d.c 19 52 1953 1954 195 5

Figure 6

P RODU C TION HIS TOR Y

John A. M c Millan Lease Felrnont Oil Corporation

RODNEY FIELD

Elgin County, O n ta.rio , Canada

1956 19 57 1958

o '" .~ .,. ;; S " u

..

til 20 ...... ...... Q)

~ 0.0 ~ ... u 10 :;l '0 0

'"' 0.. ..... f-0 f-- - - f-

'"' 0 f- --. -

Q)

.D E

f- f---f- - f- I-f- ·-f - ._-

:;l z 1- - -_. +- -- _.-f- - _. -1- - 1---I-- f-- . --I-- f--

r- --- -.

f- f-- f-

f- f--

f- --

f-- f-

5 000

..c: ..... -~ 0 4 000 ::E '"' -Q)

0.-til ...... Q) -_.

'"' '"' 3000

ro j:Q

. 1/ .... -Q)

..... ro ~ 200 0 ...... ... 0

--

1000 Ii ! i f I I t i ! 8 .Ii

19 55

.. -

J J

--

-

~

- _.1.. _ i- -f-- ,---

/

If

I/'

/ ~-

- f-

..

f- 1--

-

_.

- - t-- 1---- f-.. I-- t--- -

- t-

---

,; ! j t I I f j i s j ~ • 1956

Figur e 7

PRODUC TION HIS TOR Y

Sabjan L ease

John B eattie

RODNEY FIELD

JAMES A. LEWIS ENGINEERING IN C ORPOAATID

PCh'Oleum R£s~wiT ArtaZ,.fu

f-I-

-_.

- . -- ,- - - .. - - f-

t-- -- . _- t-r--

-l-t----

- -

j ! j I ~ 1 t Il i j J :II

19 57

E l gin County, Ontar i o, Canada

90

80 til ...... Q)

'"' '"' !II

j:Q .....

70 0 til '0 ~ ro til :;l 0

..c: 60 E-<

~ 0 ... ..... u :;l

50 '0 0

'"' 0.. ...... ... 0

40 Q)

> ... ..... !II ...... :;l

E :;l

30 U

20

.. 40

'" ~ 5" 30 u

" '0 o ... 20

0..

'0 ... '" E " z

... '" p.

10

o

10

8

6

4

2

1953

f- -

1954

~~ "- -

1955

Fig ur e 8

PRODUCTION HISTORY

Jim B e attie

RODNEY FIELD

1-

Elgin County, Ontari o, Ca nada

=I=r --i

1956

JAMES A . LEWIS INGINIIAINO

.... 140 0

" '0 = <d

120 ~ o

..c: E-<

100 ~ u

" '0

80 ~ 0..

(5 i-r- r:- 60 '" .::

1957

~ " 40 E

20

" u

30 III -..... ..... Q)

~ tlI) .:: .... 20 u ;;J

"C 0 !-< P. "" -0 10 !-< Q)

..a S ;;J

z I-- -I--~ -- --I- --I-- - f- - -

0 I-- -- --

--I-- e- I-I--i-t--

I--f- f- - -I-- i-t--

--I--I-- t- - -- 1-- f---

--f-e-- -f-- -f--- ---I--

1= f-

1--1--I--f- -

8000

..<: ..... .:: 0

6000 ~ !-< Q)

0-III ..... Q)

!-< 4000 !-<

'" ill

0) .....

'" ~ 2000 ..... 6

0 i ! j i i J filii

1954

- -" JAMES A . LEWIS ENG INEERING

--

i .i •

r- -

-

. f-I-f-- -- -

-- f- --,

--1--- --f---

--- -

- -

.i ! j iii f j 11 I .i i! 1955

Figur e 9

PRODUC TlON HIS TOR Y

J . Braddon Lease

Jim Beattie

RODNEY FIELD

Elg i n County, Ontario, Canada

INC O 'U"Q IIII ATIO

Pttroltum JUmvoir ANlbltS

-

-- -f- --

- f--

-- --

I i I ! ftlll 1956

100

90

80

III ..... Q)

!-< 70 !-<

'" ill

"" 0

III "C

60 .:: '" III ;;J 0

..<: E-<

50 ~ 0 .... ..... u ;;J

"C 0 !-< P.

4 0 -<

6 Q)

. ~ .....

'" ..... 30 ;;J

S ;;J

U

20

10

o J

III --4)

~ bO ~ ... u ;1

'tI 0 k

p.. .... 0

k 4)

,!l

S ;l Z

k 4)

20

10

0

2500

2000

p,. 1500

'" ...... 4)

k k nl

f- -I-

f-1-- -

f-t- - -

(!l f-t-_ 1000

QJ

~ ~

f-_ .

500 f- - -

f- -

o

- f-

. -1--

1955

f -

- f-

-- -

1- - . - t-f- -

I- t--t-I -f-

JAMES A. LEWIS ENOINU"INO

r-t--

IMCO"~O.AT'D

P_ .. ~AMbta

. _- f- .

i·- r-

I - t-t

i-t-t

t-f-

;=

9

8

7

6

5

3

f-t-f - t-I-- ··-t-t·-f-t- -

. -" -t - f- t·_ · t- ,,- 1"-1-- t-t-- +- f-t- 1-

- t-t- 2 f- f- t--t--t- - I- i-

f- - f- t-. . ._-

"--1--

.- r-e-'

1956 19 5 7

F ig u r e 10

PRODUCTION HISTORY

C o lthart L ease

J im B e a t ti e

ROD NE Y FIELD

Elgin C o u nty , Ontario , C a nada

...... o

QJ > ..... ~ ...... ;1

S ;1 u

CD 20 ..... ..... JANE. A . LEWI. ENGINURING Q)

~ INCO .. ~ •• T.D , ..... __ Aoor.bta

00 d .... u 10 =' '1:l 0 ~

~ ..... 0 ~ 0 14 Q)

.Ll E ;l z

12 CD ..... Q)

r- .. ~ ~ <II ~

2500 10 ..... 0

CD I- '1:l

d <II

1-1-. III

=' 2000

.c:

- -1- 0 8 .c:

E-< .... -- --d 0 ci" ~ 0 ....

-- .... ~ Q)

1500 P-III ..... Q)

f-- t- - -

.t- .

u 6 ;l

-g ~

~ ~ ~ ~ ~

0) 1000

.... <II ~

- - - 1--- f - -1= -- I- l-I--I-1- .- - r-._- 1-- -- .

_.

1-· , .. - t---

l-I- t- t-- I- I-

..... 0

4 Q)

> . ... .... <II ..... =' ..... ....

0 500

- .- - .----I- E

;l

2 U

- I--t-I-- - - ~- I-

i ! j ! ~ ! Ii i ~ i ! .; ! Ii !i It i j i ~ I ! i ! I !iJ i j i ~ j J a IE a .i o o

1955 1956 1957

Figure 11

PRODUCTION HISTORY


Jim Beattie

RODNEY FIELD


<II 30

'" ~ b/) 20 .5 u

" "" 0 .. 10 ~ ... 0 .. '" 0 .D E " z

..c: 'i: o 4000

::E .. '" ; 3000

'" .. .. nl ~ 2000

'" :il ~ 1000

<5

I-I-f--

50 JAM!.. A . LEWIS ENGINEIJUNO

IHCOIIP'O""T'O

1- :-r ___ ~~

1-=1 45

40

35

30

25

1-1- --20

I-r-- 15

._- -

10

f--F _

5

- 1-1-1-0 ' . . . . . 0

~ ~ ~ l i 1 ~ 1 ! ~ l l ~ ~ ~ : i j ~ i 1 ~ ~ ~ ~ ~ i : i j ~ 1 a ~ ~ ~ ! ~ ~ : i ] i i 1 g l ~ ! ! ~ l i ] ~ i 1 ~ j ~ 1953 1954 1955 1956 1957

Fig ure 12

PRODUCTION HISTORY

F. Wright Le as e

Jim Beattie

RODNEY FIELD


~

'" .. .. nl ~ .... 0

<II

"" ~ nI <II

" 0 ..c: E-<

ci' ·3 u

" "" 0 .. ~

<5 '" -:: :il ;; E " U

(II 15 100

" ~ "" 10 90 <: '0 JAMR. A . LEW IS ING1NlEilAINO

::l IH COIt'OIlllATID

!! '0 PmoWu'" R.NnIOfr A""'" 0 " ... 5 80 ... 0- ...

III

"" 0 CIl ... "" " 0 70 0

,J:l (II

E '0

::l C

Z III (II

3000 60 ::l 0 .c f-<

Ii' .c 2500 50 0

i:: ~

u 0 ::l

::E '0 0

... 2000 40 ... " 0-C>.

~ <5 " 1500 30 " ... ... ,~ nS ~ CIl ..,; " 1000 20 E ~ F--- · F = ".1. ... ::l

0:: = ': .01= W= 1- U

<5 I=- c.~= ; =-r=.: ~ ...

50 f- -~-~F 10

l-=±-c: f--T- =i=l--:

1953 1954 1955 1956 1957

Figure 13

PRODUC TlON HISTORY


RODNEY FIELD

Elgin County , Ontar i o, Canada

'" " ~ OIl

.5 u

" '0 0 ..

p,. ... 0 .. " ,D

E " Z

..c: C 0

~ .. " 0-

~

" ... .. '" ~ " ';d ~

0

15~

=. ~ =C" -- .

10

=--t=1 iJ=

5

0

3000

2500

2000

1500

1000

500

= I-'-i""

I-

i r r--:

-f 1-=+=

-- I=~ '=

-+-

-+--

~ ---i- ._> ,

:t='. -1 . - i~ '=t

,~ .

H - _J

1-

=+-~- --. :~-.

,==1 =- -:' ---j-

JAMIES A. I.,.EWI5 INGINI!EAING '''C:O.''OIl .. ,IO

PftO'DIN", IWorrlolOh A..."..

:t::::!=i=+= :~ =-i=;... I- I- % 1-i;,,;;;:t::--l=I==i= =t:t: I=: 1=

t~1=1= ~ 1-1- 80

70 '0

60

1-1-_ 50

40

30

20

10

'" '0

" '" '" " o ..c: f-<

" .~ u

" '0 o ..

p,.

o " .:: 3 " E " u

19 5 3 l S54 1955 1956 1957

Figure 14

PRODUCTION HISTORY

F. G. Purcell Lease


RODNEY FIELD


.,

" ~ bO <= U " "0 0 ~

Po. ... 0 .. " .J:J e " z

.c 0: 0

::\ ~

" 0-

~

" .. ... '" ~ " ~ ~

0

15 5 0 J AIo4Ea A. L EWIS INGIHE!RINO

'''CO'U' OJl ATlO

p~", Jteuwob A-I, ..

10 45

5 40

0 35

30

1000 - - 25

800 20

600 15

,-400 10

r-C--

200 ~

__ I- f= t-- --- -5

1-'----_-

o !~~: i ~li!~!~!~~:iilE!8f~~~;:i~~i£~!i!~~~ii~ilg!~A ! ilijii!~!~O 1953 1954 1955

Figure 15

PRODUCTION HISTORY

John Rubi Le ase


RODNEY FIELD


1956 1957

~

" ~ ~

'" ~ ... 0

'" "0 <=

'" ., " 0 .c f-<

c: ·3 u

" "0 0 ~

Po. ~

0 " .:: ~ S e " u

BOO

±

700

" 600

>. · Cl

" · 0-

· " t · III

· .. .:

i5 I · " ~ 0 > t- -, <:

0 0 10 15 20

-h

f

i+

r ~

/-

+ '1- t -t -,- ~--H+

25 30 35 40

Years After 3-1-57

Figure 16

PREl)JCTED FIELD PERFORMANCE

UNDER PRIMAR Y DEPLETION

Columbus Formation

RODNEY FIELD


L

J ...... &. A . L.I[WI5 lNGINll.lUNG

1'<fI'Ol." ............. AowJ,tu

· · " 2.5 " · III

'0 · C

~ l

" 'B , '0

1. 5 0

a: i5 · . ~ .. -;; E " u

0. 5

+-0

45 50 55 60 65

-

4 000

I

3000

* 1

>-'" 0 H-... " p.

~

" H-... ... f++- ~ -I '

'" , , ill !-i t+- L

" 2000 ';;j 0:: rl -<5 t±!= " oil

'" ... " > ..:

I -I

1 000 H

-i -I-L.

H-tJ I

4'

rf

t-r ,- I

H+b 2

I

=F I -- +--,

:~~* --

i+1=l= I I

- I . T 1 -,-, f-l:::t -- H - -- J AM ES A . L EWIS ENG I N EER I N G '

1-' -INCOIt,.O,. ... T(O I I

P~tf'olnu" Rewn'Oir AruaJ,ru

- - i

I --

- --

-

I I I I.

I

-

I

I I I --

I , -I- -

6

+1 -t 1 -- --- -•. , J --" 1--

t+=' --, f-tt H - -I ' --r- Cum ulativ e Oi l -- ,r . r I I -

I b} 1 ;

+ I+H+ ~ =;= J .- r++ I , ++ -.

Oil Rate +' -j -I

I I

5

-,r -f ,-- !

It I

I I -- I I

I ! I r I I

I '~ 1 1 ~~=- it _. . 1-'- I - -f _ I q=n 1 ~ $clIJ .-

-I itr!-$~T I T: I

~$ti 1 - -,-

S L l' __ 1\ -L+ t " -t t IT t .. J.. I

- :t~ '=H~H~~i ' . I I I

4

3

t ,i1~ --\- -I..Lr ~~- l--l ~~ f I

-t- l- H-i-r . I, I

-I + I

+ - -

i

4

- -I-I I -I I

I I . -

~ ~ t*~ .~ 1 -. , ~i. -' -LLL _.

j LLLiJ-I _I i-I ! I

i-rr I I -j I I

-1 + 1-+-1 d: I R1- 1 I

I -I-+-

i

6 8 1 0

Years After 3-1-57

Figure 1 7

PRE DICTED FIELD PERFORMANCE

UNDER WATER INJECTION PROGRAM P l an I

Columbus Fo r mation

R ODNEY FIELD

Elgin County , O ntario, Canada

1 2 14

2

a 16

~

" ... ... '" ill

4-0 0

<Il 0:: 0

~ C

.S u

" "d 0 ... 0.

<5 " ;: ';;j '3 E " u

>-• Cl

" ~ 0. ~

~ " • '" ~ ..

0::

(5 ~

"" ~ · > -<

100

10 zo 30

Years After Mar c h 1, 1957

Figure 18

PREDICTED PRIMARY PERFORMANCE

Felmont Oil Corporation Leases

RODNEY FIELD


' .

JAhnS A. l.IlW.S I:N01NIIIIIIINO

40 50

1Z00

1000 !; ~ " • '" '0

· 800 "0 C

~ " o "' f-<

600 .! , "" o , ~

400 6

· .~ .. :; E ,

zoo u

o 60

2000

1500

>-oj

Q ,.. ~ 0-C/l ..... ~ ,.. ,.. oj

(Q

0) 1000 ... oj

~ ..... <5

Q)

OIl oj ,..

" ~

> ...1 ' ~

If

500

Plan II Plan III

:::l

5 10

Years After Mar c h 1, 1957

Figur e 19

Plan I

+ JAMES A . LEWIS ENGINEERING

15

INCOilll l"O" "TID

Pt'trof,.um Rt'Ut'wif AMI,ru

r

PREDICTED WATER FLOOD PERFORMANCE

Pla ns I, II and III

F e lrnont Oil Corpor a tion Leases

RODNEY FIELD

Elg in County , Ontario , Canada

3000 C/l ..... ~ ,.. ,.. oj

(Q .... 0

C/l 'U ~ oj C/l ~ 0 .c f-<

a 2000 .~ u ~

'U 0 ,..

Po. ..... <5 ~

. ~ ... oj

;; S

1000 ~ u

· · 0.

· · · · '"

·

80

70

60

~ )0

· ~

+-

T

'-+-1

,-I-

L - I-

10

.J

-1 ..!

,. J: l-

f-;

'1:::-, -I

+ 'I

15 20

Ye a rs After Ma rch I, 1957

Figu t't! 20


Sabjan Le a s e

John Beattie

ROD NE Y FIEL D

El gin County , Ontario. Canada

150 · · · '" c;

· -0

~ " 1 ...

100 .;

'B " -0 0

.t i5 · .~ -;

H E 50 " U

25 30

... (l)

0.

'" ...... (l) ... ... oj

~

......

<5 (l)

OIl

'" ... (l)

~

JAMES A. LEWIS ENGINEERING INCO"~O"ATID

P,rrolnlm RutTtIOif Anm,ru

400~~~~~400

200

H+ T

H+ ~ +-1

++ 1

1

H-'

100

o o 5

, 1 Plans I & II

, ,

-1- -

1 G

Years Afte r March I, 1957

Figure 21


Plans I, II, and III

Sabjan L ease

John B eattie


15 o

4-< o

250

.. .."..

-!. 200

T

700

;:- I.: , Q

-· " 600 0-

~ · · - + · - -· -co · -, 500 CO · '0 :;; ~I' · 0: ·r ' T

'" c 0 ~ · " 0

'" 400 .<:

~ f-< _l.. -'

> -r C < 'B " '" 300 0

-j 0'::

0 ~ T · .~

" 200 :;; -; E " U

100

t-I

T

0 ' , 0 0 10 15 20 25 30 35 40 45 50 55 60 65

Years After March I, 19 57

Figure 22


Jim Beattie Leases

RODNEY FIELD

Elgin Count y, Ontario, Canada

I

>. oS 0 ..

<I)

Po

'" ..... <I) .. .. oS ~

ai ..... oS ~ ..... .... 0

<I)

bO oS .. <I)

> <

1600

1400

1200

1000

800

600

400

200

o o

-

JAMi!:B A. L!WIS I!NGIN!ERING INCOIIII"OltAT,D

Pmokum Rt~, AMl,su

2000

Plan III Plan I

Plan II 1500 '" ..... <I) .. .. oS ~ .... 0

'" 'tl ~ oS

'" ::s , 0

..r::: - I I E-<

a 1000 0 .... .....

u ::s 'tl 0 ..

p.. ..... 0

<I)

.~ ..... oS ..... ::s 8

- ::s , 500 U

I

I -

I

I

o 5 10 15

Years After March 1, 1957

Figure 23


Plans I, II and III

Jim Beattie Leases

RODNEY FIELD


F, l lnO"! 1', 1",, 011' ", Im o n t

LOT 4 LOT 6

I I I I I

--L __ __ A_.'~ ==~~~~~;t!:=:=:::~~~~=;3~7')::::----_~..0==== _ _ ,= 7 N twS"SIO I

I-~ I ~

I I I I I I I I I I I

_ ..L_

~-r;

I

I

, .. " l _CD'~ ~j 'un', I PII ,.~ , II

LE GEN D

® ad W. II'Con ... .. "d To I"llct lon

o Propos. d Prod UCI ng Wi l l

, " Produc i ng WIll To at Abo"don,d

J Rub,

II

FIGU RE 24

PLAN

PROPOSED WATER INJECTION PATTERN

MODIFIED FIVE SPOT

RODNEY POOL AlDBORQUGH rwp ELG I N CO

iltOVED 11' CArIE

ONTAR IO, CANAOA

iIt(Y'$(O l Y CATE APPtlO V[ OI" DAff '

o

I

I I I

F.lmonl

LOT 4

F.lmonf

LO

1' . l monf

.. k

J

.;

'0

.3

CON

J

1

, k

I ~ .... 'J /I 2 £ J MacMlllolI

IV

J

.; 0

I', l monf

LOT

.J

6

. k

JO. Grah a m

I ____ A_B"~~dd~'~"='ilE==,JE~J ~~~'~~'~'~"~'~~~~===3IF=~=~~~ -L- " • "'''----./~7Ne'''B,, !>rO I ---r --.-,~" " F l l mon'.:. e mon _'. '---./.,,:

I " ... :·l'· ... ' -I i

I J ~ ... ' LOT 4 I

" 0

o OT.s 5

. '" 0

LEGEND

®" Ojl W." Convlrf.d To In j lct i on

@ Pro pos.d I",j.ctlon W.II

Pr oducln o all W.II

o PropOlld Producl no W.II

, • ProduclnO w ... To 8. Abondo ... . d

, '"

LOT

.;

.:

,;

~'

.. k

J Rue,

6 ...

;

~

.:

.;

:

.. A ItI Co llu'"

FIGUR E 25

PLAN II

PROPOSED WATER INJECTION PATTERN

STAGGERED LINE DRIVE

RODNEY POOL .o.LDBOROU GH TWP ELGIN CO

O.lf • ltov[oeV

O NTARI O, CANADA

OAT! . PPiltDvEO 8f

D

Felmo n l Feimoni

~o

LOT 4 LOT !5 LO T 6

®---+-CO/'l~v-----<o

• 6 • Fe mo,, 1

I .' .' :

I I ~, " · , . · I

}

I .' .' .' ,I/on j E J ~a M,I/on

j ~ __ __ A_ 8,OdtJ(M J "',

I--~ Beo I,t F e lm o"~

" .' . I .F 0 , .' J

. . 6 0

~ [or , I

.J " ) . CON V

J

...Lo ., .'

• 0 ." J

~o

.' I

I ; ; / J O~," B1o lI ' :

J

. 0 · . 4 i .

I -< ~ 1 ; .'

I .' .. .' t

1 I ~

.' f : ;

I .' ;,.0 . -~

NO M( M, 'en J 8 , ,JJo n 5 , ,on

71 f ell,. Cemlo,1 0, ''''0'' .. .' 4 .' .' .

J

. .' .' .' .. . .' . · J f : .' :

J

4 4 : F ~~ J .

l_ T unts Cou"o" runtJ Pu ~ ell ~- --- 0

LEGEND

<i Oil W,II COn Wf"fd To Inj'ctlon

@ Propos,d Inj ectio n W,I I

Prod"clnO 011 W'II

o Propoud Produc inO W,II

, .. Prod"C ln; '1'1, 11 To B, Abondon,d

;

.' • 0 :

.;

.J 0 G, hOm

F" ~Nt!"'B"5fOI

.' 0

LOT 6 ,.' .;

" . · .

~O

.' ;

~ .6 .'

" .' · : .' A C 6'/I, e5

.'

:

.'

,; .J Rub '

i

------.,0

.'

-------"0

4 . ~o

.' -:

.. A "

.'

C<JII~m

FI GURE 26

PLAN m PROPOSED WATER INJECTION PATTERN

STAGGERED LINE DRIVE

D'''''''fllllly DaTE

RODNEY POOL ALD80ROUGH r wp E L G I N CO

ONTARIO, CA N ADA

Comprehensive Engineering Study of Columbus Reservoir ... Engineering Study of Columbus Reservoir ...

Documents