ZA

RSW

>
ts
5 R4W.
Ie
5 KEY
215
8le
° z —I50— CONTOURS ON
5]o TOP OF HOING SAND,
Sie ELEVATIONS IN
z/7 FEET ABOVE SEA
zi LEVEL
WA. RUGGLES 4 g
4 of o
og og ~ oO _500 1000
y¥¥ Slo sf
4 pt 2 \6 SCALE:FEET
— 20
3 PETER HAMM ~~ [-~_} > 1d
LYON HEIRS R. sata
_——
1
/
CHAS. ALESHIRE — o~ \_J 17 / M.c. SMITH
\5> Cc” D
STODGE
Hw ip
%

FIGURE 9.- Structure map of Plymouth oil field, Hancock and McDonough Counties, I11.


R.I. 3783

Shale breaks from 10 to 40 feet in thickness separate the lenses, and one
to three mica and shale streaks, 1 to 6 inches thick, frequently are found
in the two lenses containing oil, further subdividing the sand.

Porosity, permeability, and oil-saturation profiles shown in figure 2
constitute the available core-analysis data. The average porosity of the
cores was 17.9 percent, The permeability of the core samples averaged 123
millidercys and ranged as high as 729 millidarcys. The average oil satu-
ration of the sand varied widely but probably did not exceed 35 percent of
the average pore volume,

Development,

°

A surface map indicating the extent of development.of the eight leases
comprising the Henry project on July 31, 1943, is shown in figure 3. Air-
and gas-injection wells on adjacent leases north and south of the: project
also are shown because they affect the operation. Thelhocation of closely
spaced wells along lease lines with inside areas left undrilled are: features
common to many areas in the Robinson field, as are the numerous dry: holes
and early abondonments.

Development of the Henry project was begun in September 1932 and pro-
ceeded slowly with the experimental injection of air into the Robinson sand
through an old oil well - Henry No..9.. The oil well was converted to an
injection well by cleaning out the shot hole and setting a tubing packer
ebove the top of the sand. Oil production from 2 of the 11 wells, on, the
Drake lease increased 400 percent for the remainder of 1932 as a result of
the injection of air.. Injection through Henry well No. 9 was discontinued
early in 1933, and in June 1933 Drake well No. 2 was selected as an’ input
well for further experimentation, The number of wells affected by this in-
jection is not known, but production from the Drake lease in 1933 was double
that of the previous year. At least one well on the T. Randolph ease also
benefited by the injection. Neithor injection well was used again for over
@ year. H

For the purpose of this report development of the Henry project is con-
sidered to have started in May 1934 with the injection of air into Stifle
well No, 8. By the end of 1934 eight injection wells, affecting an area
estimated at 130 acres, were in operation. Subsequent development to
August’ 1, 1943, is shown in table 3. On that date there were 21 active in-
jection wells, which had affected 555 acres or 79 percent of the total
productive area of the leases included in this project.

Well-Completion Methods

All but three oil wells on the Henry project were drilled about 35
years ago and shot with 2 to 4 quarts of nitroglycerin per foot of sand.
Ten-inch ‘drive pipe usually was: set at 90 feet, 8-1/k-inch casing was set
at approximately 400 feet, and an oil string of 6-1/4-inch casing was set
about 25 feet above the first Robinson lens (the gas sand) at 875 feet. No
change was made in the casing program for oil wells when gas injection was
begun., All of the oil wells are pumped through 2-inch tubing by three ~
central powers, and a vacuum on the send is pulled through the casing of

_most oil’ wélls by the same ‘compressors ‘that supply the air-gas mixture under
pressure t6. the injection wells,

239 - al -




R.I. 3783

TABLE 16. - Volumes of air - injectead/ and oil produced by months on
The Ohio Oil Co. Plymouth project

(Pressure base, 1}.4 1b. per sq. in. abs.; temperature base, 60° F.)
1934 1935 1936 i 1937 1938,
Air | oil ; Air Oil Air {| Oil Air | Oil Air Oil
injected, | produced, | injected, produced, | injected, !produced,| injected, |produced, |} injected, jproduced,
Mcu. ft. | bbl. | Mou. ft. bbl. |Mocu. ft.| bbl. [M cu. ft.| bbl. |Mcu. ft,! bbl.
January... i iPressure Plant; 2,475 ») | 2,478 ) 12,594 ) 2,450
February. | 1 1390, 1,759 {Shut Down i 2,549 ) 1,203 )2/15,000' 2,352 iP | 2,542
March... !) | 22438 112-14-3h to 2,048 )2/22,000| 3,089 1 3,336 | )2/27,500! 3,142
oe) 2 508 15-1-35 1,400 3,035 473k) 3,474 ) | 2,khe
wt) | 3 3485 | 6,307 | 2082 6, 75! 37115 | 26h. |) | 2° 286
D) ) 3,316 | 7,035 | 3,393 5,658| 3,511 | )2/15,000! 23088 | 5,45 | 2,896
2/106, 400) 37696 1) | 3,567 5,143) 2,979 ) | 2,935!) 1 2,560
4,257 1) 3,233 6,067, 2,692 5,273, 3,591 |) | 2,638
September ) i 3,827 |) 3,066 2/5? 500! 3,158 | 2/5;500| 3,399 | )2/33,000} 2,607
October... 1) | 3,951 | )8/39,000 3,608 Wort) 3,062 |. 5,614) 2,586 |) aria
November. ') | 3,527 \ 2, Bhb. 5 3,134h }) | 3,031 ) | 2,518
December. )-_ | 23529 +) 12,832 _1)2/11,000| 3,324 _| )2/10,000! 2,270 |) | 22 hkS
Total. | 107, 750135,353 | 52,302 1335257 66 , 288 [5k 798 60,621 134, 297 05, 945 30,269
i/ Volumes of air computed from occasional tests. é/ Estimated.
239 - kh -


R.I. 3783

The Ohio Oil Co. Colmar Project

The Colmar project, in secs. 9, 10, 14, 15, and 16, T. 4 NL, Rw 4 We,
McDonough County, I1l., encloses a productive area of 1,420 acres, Oil is
produced from the Hoing sand on the northeastern flank of an anticline about
1-1/2 miles from the crest of the structure. Wells encbuntered the top of
the sand et an average depth of 463 feet in the Colmar oil field, an average
of 335 feet deeper than those drilled in the Plymouth oil field, before pene-
trating the sand. The top of the sand, however, is 60 to 70 feet lower on
the sturcture in the Colmar field. The Hoing sand in the Colmar oil field
averages 12.4 feet in thickness. .

History

Most of the wells in the Colmar field were drilled in 1914 and 1915.
The wells originally produced from less than 1 to 150 barrels of oil daily
and averaged 20 barrels daily, The daily oil-producing rate of wells in
the Colmar field, as in the Plymouth field, declined to a fraction of a
barrel per well by 1925. Vacuum was applied to the Hoing sand in May 1926,
and the average d-ily oil production per well increased from 0.41 barrel in
1925 to 0,54 barrel in 1926, An average daily oil-producing rate of 0.61
barrel per well was maintained until January 1931, when Illinois oil produc-
tion was prorated, Vacuum operations were suspended until oil-producing
restrictions were remowwd in November 1931 and then were discontinued after
air injection was begun in July 1935.

A slow encroachment of water was reported in the north and northwestern
part of the field, but as the water drive was ineffective in the Hoing sand
and too little energy was provided by the small volume of gas initially
associated with the oil, a low recovery of oil was achieved by primary
methods.

Characteristics of Qil Sand

Wells drilled during 1943 for a pilot water-flooding project on the
Hendricks and McFadden leases provided mush of the available information on
the reservoir. Analyses of core samples from these wells, supported by
drillers’ logs of other wells in the field, reveal that the Hoing sand is
7 to 26 feet thick, The average thickness of the sand is 12.4 feet.

The average porosity of the cores taken from nine wells in the water-
flooding area wes 18.3 percent. The average permeability of the core samples
was a littlemore than 1 darcy, The sand in six of the wells was cored using
an oil-base drilling fluid. The average oil content of these cores was 52.5
percent of the average pore volume of the cores, whereas the average oil
saturation of the sand cored in three other wells, using a water-base drill-
ing fluid, was 26.8 percent of the average pore volume. The average water
saturation was 22.8 percent of the pore volume of sand cored with oil and
51.9 percent of the pore volume of sand cored with water. The oil-satura-
tion figures cited above do not include values for the lower 2 or 3 feet of
sand, which have a water content of approximately 70 percent. A core log

239 - 50 -


RL. ST8S

TABLE 2. = Aotive gascinjeotion operations in I1inots

July 32, 1965,

Location Compaay Lease or pre: Wember O11 wally Injection medium aatty of] production, bbl, Initial
= toasty Togal dosortptioa eerie Taly, TS atr-gas
Section Tom Range area, mated —tnjooe number af injection
up Mere are th footed
fectes walle
acres
AMlendale fhe
Died 1d 28 Mth a . D, Tomar Litherland 0955 2 2 2 Ate B wl” 5 12 1999
tate _
Totals 5. 2 2 2 wy 8 oa we
Bridgeport field
Betageport 925 WO lawrence 52 Lm. 12%, The Obto O11 Co, Johnson KO 2501 2 TB MMe teres = BT
tomier Mo OO Ean) = 06m 137
Cavin stole
sz Yese 2,000 25 0 mite 8 LS. 1k, Momndon Driti- oad 15 1 mn 6 te 30s tw 98/ ae
con
‘Bethel 2,690 2 do. 7 LS. bm ae Branlett J bo 1 wz 6 oe 380 so 220 to. 165 ade
Profaction Cos
Faint creek 2,655 1h)
Bethel ER fo, Sani7 As. um we. coutter ko ne ed am a, %& slg
ux Vases 2,610 16)
Maint creek 2,670 12) to. 7 us wm ts. to yo 2 bo tee 380 TO 505 to, 5S
‘Bethel bat 1) . —_— - _ — — — —
160 re is = 37 eT 36
Cavey fheld
Casey go 25 Clarke 6 10% Dinsmcor O11 Co, Mumford LO 35. 2 B w oF 100 A aly 2B Bw sen
‘Totale: wo 2 B 10 / (10l/ B B
Colmer field
Boing M5 12 Hanoook La. Wm. Tae Chto O11 co, Colmar — 1,800 1,100 on Im ot ee ls mH we Pr 1985
Tole 1,800 1,100 bh 77ST Tm ug 38 226
Hoodvitle field
Bethel 2,950 20. Manilten 3 68. 6B, Te Texe Co., Hoodville 19 88. yom 8 ts 80 Wh 1,2501/ Mo imorease = 1,193 193.
tax Tass 3.050 2 The Ohio O11 Gow, 260 2
to Tide Meer
re
rue GS BOF Zz 3 @ Tay ar}

=




RoI. 3783
~- Results

The cumulative oil production, before the initial injection of air in
May 1934 » has been estimated at 125 barrels per acre-foot. From May 1934
through July 1943 the total recovery of oil was 20 barrels per acre-foot,.
By assuming that none of the eight leases forming this project would have
exceeded its economic limit of operation by the end of July 1943, the oil
gained by air and gas injection amounted to 12 barrels per acre-foot. The
oil gained each year for a calculated normal decline in the production rate
of 4.85 percent per year is given in table 7. The decline rate was calculated
for the period of settled oil production between the years 1923 and 1932
(see fig. 4).

TABLE 7. ~ Oil-production statistics - Henry project

Year Qil production, bbl. ! Estimated oil

Normal decline | Actual gained, bbl.
19snI 7... | 12,129 ; 17,935 5,806
1935.06 | 17,311 | 33,307 15,996
1956 .0004 j 16,471 ' 35,015 18, 54h
19BTseeee | 15,672 \ 50,325 34 653
1938. .006 14,912 | 45,115 30 ,203
1939. .008 14,189 i 33,368 19,179
1940, .006 13,501 | 35,402 21,901
1941.0... 12,846 i 36,270 23 hol
1D seve | 12,223 j 36,614 2h 391
19h32/.0. 3 6.78% : 212682 | 14898

r 136,038, 345,033 | 208,995
17 Last 8 months. 2/7 First 7 months.

Oil production by leases is illustrated graphically in figure 5. The
degree to which the leases responded to gir and gas injection generally
appears to have been in the order of their past productivities. The Henry
lease was the most prolific and had the greatest. increase in oil recovery,
The T. Randolph lease showed the greatest improvement, moving in rank from
eighth in primary recovery .of oil to fourth in percentage recovery during air

and gas injection.

Between May 1934 and August 1943 approximately 1,115,500,000 cubic feet
of air and gas were injected into the Robinson sand at a differential pressure
of about 50 pounds per square. inch between injection and oil wells. During
this period 3,230 cubic feet of air and gas were injected for each barrel of
oil produced, .or 5,340 cubic feet for each barrel of oil gained by the injec-
tion, The driving medium was injected at an average daily rate of 650 cubic
feet per vertical foot of sand, per injection well. The volume of oil gained
by the air and gas drive was 299 barrels per acre.. An estimate of the oil
recovery indicated that 65 percent or more of the original oil content of
the sand, measured at stock-tank conditions, had not been recovered on

August 1, 1943.

239 : - 28 -


R.I. 3783
TABLE 25, - Oil-production statistics - Colmar project

Oil production, bbl. Estimated oil

Year l-percent decline ; Actual | gained, bbl.
Sr rrrrrrrrr rrr rie 22,379 21,782 | Minus 697
oe 42,967 118,307 75,340
| 41,248 H 115,564 74, 316
o 39,598 | 93,152 | 53,554
we | 38,014 | 96,178 | 58,164
36,493 | 93,479 56,986
vel 35,033 88,219 | 53,186
Wen | tegen | ao guy
Total sees 300,198 | Y 767,422 | 159, 22h

1/7 Last 6 months, 2@/ First 7 months.

From July 1935 to August 1943 approximately 1,524,000, 000 cubic feet of
air were injected into the Hoing sand at an averege pressure of 32 pounds per
square inch. About 2,000 cubic feet of air were injected for each barrel of
oil produced or 3,320 cubic feet of air for each barrel estimated tc have been
gained by August 1, 1943, The driving medium was injected at an avsrage daily
rate of approximately 800 cubic feet per vertical foot of sand exposed in each
well. The estimated volume of oil gained by the injection of air into the
Hoing sand was 323 barrels per acre. The cumulative oil production (on
August 1, 1943) was 1,345 barrels per acre.

The Ohio Oil Co, reported that the development cost for the Colmar and
Plymouth projects was approximately $55,000, or about $30.00 per acre. The
low cost may be attributed chiefly to the absence of extensive drilling pro-
grams, but two other contributing factors were the inexpensive method of con-
verting old oil wells to injection wells and the utilization of the vacuum
pipe-line systems in air injection, Labor and material costs prevailing in
1943 would increase the capital requirements for the same development.

239 - 59 -


R.I. 3783

Tide Water Associated Oil Co. reported that the development cost for
the Henry project was about $50.00 per acre. Absence of an extensive drill-
ing program and the saving realized by using salvaged and second-hand materi-
als are reflected in the low cost, The same development would require more
capital if it were attempted with the advanced cost of labor and material
that prevailed in 1943,

The Ohio O11 Co. Warnock Project

The Ohio Oil Co. Warnock gas-injection project in the Robinson oil
field, Crawford County, Ill., encloses an oil-productive area of 630 acres.
The Robinson sand is at an average depth of 8935 feet, and is 13 to 50 feet
thick,

History

The leases comprising the Warnock project were originally developed be-
tween 1906 and 1916. Of 118 wells drilled during the original development
of these leases, 29 wells cither were nonproductive when drilled or were
abandoned as noncommercial oil producers within a few years after they were
drilled. Completed wells flowed at an initial daily rate of 1 to 200 barrels
of oil and averaged approximately 40 barrels. It was necessary to pump most
of the oil wells within 1 month after completion which indicated that the
original reservoir pressure was low. By 1925 the daily oil production had
decreased to an average of 0.63 barrel per well. The Robinson sand was sub-
jected to vacuum the following year (1926), and although a small increase in
the oil-producing rate was observed the more important immediate benefit was
the increase in production of "wet" gas. Vacuum operations were maintained
after gas injection was begun in 1936, and in July, 1943, approximately half
of the oil wells still were on vacuun.

Characteristics of Oil Sand

No wells were drilled on the leases included in the Warnock project after
1916 , therefore core~analysis information was not available. Consistent re-
sults of the analyses of core samples of the reservoir in other parts of the
field indicate that the Robinson sand will average 25 feet in thickness. The
porosity of the sandstone ranged from 17 to 19 percent. The permeability of
the samples ranged from 0 to 2 darcys and averaged over 100 millidarcys.

Development

A map giving the location of producing and injection wells on the leases
included in the Warnock project on July 31, 19h3, is shown as figure 6. The
undrilled areas, the large number of abandoned wells, and the lack of uniform
spacing of oil wells prevented the development of repeating spacing patterns

when gas injection was begun.

Air first was injected into the Robinson sand through Warnock fee well
No. 4, an old oil well, on May 16, 1936. The injection affected offset pro-
ducing wells within 1 month. Other oil wells were converted to injection

239 - 30 -




300e=

280
OIL PRODUCED BY GAS INJECTION FROM
MAY. 1, 1934 TO AUGUST |, 1943
2. OIL PRODUCED BY PRIMARY AND VACUUM
OPERATIONS UNTIL MAY 1, 1934
220)
2007
°
°
rs
.
@
2
&
2 160
a”
a
w
4
< 140
o
’
8
; iz
Ja
3 100)

60 ZL

60 Z

z=
z «|
«so Aiwa.
3 tw
a z a
ww! wl 4 a ~ 3 <
z Pa x z 3 r=) ta 8 |
z = < gz a z & z 4
20 Fw | « 4 4 < < <
| z a r=) é Ea EV Ed « J
z| ) a ai] a a 3 # <

:

°

FIGURE 5.- Comparative oil production by leases before and after
injection, Henry project, Crawford County, III.



R.I. 3783
Well-Completion Methods

All wells included in this project were drilled in 1915 and 1916 and
shot with 2 to 4 quarts of nitroglycerin per foot of sand. The casing
usually consisted of a surface string of 8-1/%-inch drive pipe set at a
depth of approximately 30 feet and 6-1/4-inch pipe set about 240 feet above
the top of the Hoing sand at an average depth of 190 feet, During develop-
ment of the Plymouth project no additional ‘explosives were used in the oil
wells, and the wells are still cased in the same manner, 011 wells are
equipped with 2-inch tubing set on bottom and pumped by central power.

All of the air-injection wells are old oil wells. Oil wells were con-
verted to injection wells by cleaning out the shot hole and setting on
bottom tubing with a perforated anchor and an anchor packer, The perforated
section of tubing, about 4 feet in length, was placed opposite the sand, and
the anchor packer was set in the lower part of the 6-1/l-inch casing, Ordi-
narily the 6-1/4-inch casing was pulled during conversion, and damaged joints
were replaced with good pipe. This method of completing injection wells is
both rapid and simple and is applicable particularly to the Plymouth field,
where the shot holes must be cleaned out frequently.

Operating Practice

A compressor plant on the east line of the Peter Hamm lease in the
center of the Plymouth field is composed essentially of two horizontal two-
stage compressors and their prime movers. One compressor is a Worthington
Feather Valve (10-1/2- by 4-3/h- by 12-inch) and the other an Ingersoll-Rand
Imperial (8-1/2- by 4-1/2- by 10-inch). Both compressors discharge into a
common header at an average pressure of 50 pounds per square inch. Water
accumilation is removed from the header by means of a valve at the end of
the header. Each compressor is belt-driven by a 30-horsepower oil engine.

A part of the old vacuum pipe-line system was converted to a distri-
bution system for the injection medium. The main pressure line - 3-inch
pipe approximately 1 mile in length - extends east-west through the center
of the field, and @-inch lateral lines tie into the 3-inch trunk line to
conduct air to the injection wells. Traps for removing water ‘are located
at low points in the system.

Measurements to determine the rate of flow of the air injected into
the Hoing sand are made at a meter run at each input well, The meter runs
consist of 20 feet of 2-inch pipe and tapped flanges containing 1/8-inch
orifice plates. All meter runs are elevated’ about 2-1/2 feet above the
surface of the ground to minimize the accumulation of water near the orifice
and to facilitate the measurement*of.flow rates, Flow measurements are made
monthly with a portable manometer and pressure gage , and the individual in-
jection rates are computed. A record of the air injected and oil produced
monthly is given in table 16. :

239 - 43 -




R.I. 3783

fn Ingersoll-Rand two-stage compressor (8-1/2- by 4-1/2- by 10-inch),
belt-driven by a 35-horsepower gas engine, provides compressed air for the
project at a discharge pressure of approximately 160 pounds per square inch.
The compressed air is inter- and after-cooled by discharging the air through
water-cooled coils of 2-inch pipe, and water condensed from the air is re-
moved in two stages by passing the cooled air through traps originally used
in the extraction of gasoline from the produced gas. Compressed air is dis-
tributed from the high-pressure trap to the injection wells at approximately
atmospheric temperature,

Since air first was introduced into the Robinson sand in May 1936 the
injection pressure has averaged 106 pounds. per square-inch, At this pressure
each injection well has affected an area of about 40 acres of sand, or ap-
proximately twice the area affected by injection wells on those projects in
the Robinson field where injection pressures range from 25 to 40 pounds per
square inch. Core analyses of the oil sand under the Warnock project are not
available, but analyses of core samples from other parts of the field indi-
cate that the permeability of the sand probably will average 125 millidercys.
In such a permeable sand, therefore, the high injection pressures used on the
Warnock project have caused channeling of the injection medium to several of
the producing wells, and it has been necessary to disconnect these wells from
the vacuum system, Control over channeling has been made possible, to some
extent, by reducing the injection rates of injection wells responsible for
the channeling,

Six injection wells have 18-foot meter runs of 2-inch pipe, and two
wells are equipped with 2l-foot meter runs... The-21-foot meter runs are pro-
vided with 6-1/k-inch traps to collect water present inthe injection. medium
and are located below the meter runs which are elevated about 2-1/2-Peet
above the surface of the ground. A 1/4-inch bypass around a stop on the up-
stream side of each meter run includes a gate valve to tegulate the rate of
flow of injection medium. Flanges, flange taps, and either 1/8- or 1/4-inch
orifice plates are part of the meter runs. Flow measurements are made
monthly with a portable manometer and pressure gage, and the rate of inJjec-
tion is computed, Volumes of gas injected and oil produced monthly are given
for the gas-injection period in table 10, Gas-injection figures are estima-
tions based on recommendations of the operators' personnel, or they are
interpolations of available data.

The use of air as an injection medium does not seem to have increased
the rate of corrosion of subsurface and surface equipment. Corrosion of
equipment before air injection was caused by water and small quantities of
hydrogen sulfide associated with the oil and gas in the reservoir,

239 - 33 -


ZhoH

J OINNIE FIGURES ON ISOPACHOUS LINES ARE

SAND THICKNESSES IN FEET.

1000

4$
rs. ddaax | WM. CONN JM WEAR
/
\ Q a)
(. /
Is 10 4
0 «
$ 0
S
5
Co] JMOMYERS ACI 4 WoW. CULP

FIGURE 17.- Isopachous map of Hoing sand, Colmar oil field, McDonough County, 111.





Figs
9.

io.

11.

17.

19.

20.

239

R.I.

ILLUSTRATIONS ~ (Cont'd. )

3783

Pollowing

Structure map of Plymouth oil field, Hancock and McDonough
Counties, T1l. sesscseccecceceereceecercucceseecseesececs
Isopachous map of Hoing sand, Plymouth oil field, Hancock
and McDonough Counties, Ill. wccessccccescccccvccccccccee
Northwest-southeast cross section A-A' of Hoing sand,
Plymouth field, Hancock and McDonough Counties, Ill. ....
Production-decline curve, The Ohio Oil Co. Plymouth project,
Hancock and McDonough Counties, Ill. cecsecesecercesseeee
Comparative oil production by leases before and after air
injection, Plymouth project, Hancock and McDonough
Counties, Tll. sesecccsceececccececcsccscscsscescesceeese
Analysis. of..Hoing-sand core from well in sec. 15, T. 4.N.,
Re WW. } McDonough County, T1l. .esccscecsssnccevceseeees

Map of The“ Ohio’ Oil ‘Co. Colmar air-injection projéct,

~ McDonough ‘County, TIl., July 31, 1943 ......

“Structure map of Colmar oil field, McDonough County, IIl...

Isopachous map of Hoing sand, Colmar oil field, McDonough
County, Ill. sesveseseeee
Northwest-southeast, southwest-northeast, and north-south
cross sections B-B', Ct-C, and D-D' of Hoing sand, Colmar
oil field, McDonough County, Ill. sevsseeesceee oe
Production-decline curve, The Ohio Oil Co. Colmar project,
McDonough County, Ill. seccccceccccccccnscvesccseccsecves
Comparative oil production by leases: before and after air
injection, Colmar project, McDonough County, Tll. .......

Page
ite)

Lo
ho
ug




‘SYMBOLS
5: A- NEW WELLS ACQUIRED
B- VACUUM OPERATIONS STARTED
4 - PRODUCTION PRORATED-1! MONTHS
7 [ D- AIR INJECTION STARTED
q g. E- GAIN DUE TO AIR INJECTION
é
a | F - ESTIMATED NATURAL DECLINE
«
2 40r
°
4
= x
Pa
Fs 9
6 3
3
z E
$s 28)
8
°
2
- —— F, —
3 8 c :
¥ \
8
Fa
z {
'
2
3 yw \ |
V
8
4
ol
1910 1915 1920 1925 1930 1935, 1940 945

YEAR

FIGURE 12.- Production-decline-curve, The Ohio Oi! Co., Plymouth project, Hancock and McDonough
Counties, 111.




R. I. 3783 Novemser 1944

UNITED STATES
DEPARTMENT OF THE INTERIOR
Harovp L. Ickes, SECRETARY
BUREAU OF MINES
R. R. Sayers, Director

REPORT OF INVESTIGATIONS

AIR AND GAS INJECTION IN THE OIL FIELDS OF ILLINOIS

BY

Cc. M. KEITHLY AND THOMAS JENNINGS




R.I. 3783
‘TABLES (Cont'd.)

Page
9. Development of The Ohio Oil Co. Warnock project ..ssecececee’s 32
10. Volumes of gas injected and oil produced by months - The Ohio
Oil Co. Warnock project .
11. Orsat analyses~-of ‘gas produced. from oil wells-in Robinson
field --Warnock project . bee ececestevees 36
12. Chemical and-physical properties of crudé oil produced on.-The
Ohio Oil Co. Warnock project. from-Robinson sand ...seeeee 37

sdecevecevseceeces 3

13. Oil-production statistics - Warnock project ceecsceesccvenece 38
14, Summary of operations for The Ohio Oil Co. Warnock project . 39
15. Development of The Ohio Oil Co. Plymouth project ..secceseees he
16. Volumes of gas injected and oil produced by months - The Ohio

Oil Co. Plymouth project .. be ee ee eeeceees yy
17. Orsat analyses of gas produced from oil wells in Plymouth .

field - Plymouth project .c.seae sevecccccecceccessces 46
18. Chemical and physical properties . of. crude oil prdduced on -The

Ohio Oil Co, ‘Plymouth project. f: joing sand :....4 47
19. Oil-produétion statistics -. Plymouth, project’ .iscesesece ug

20. Summary’ of” operations: for The. Ohio Oil Co. Plymouth project . 4g

el. 52
22.
55

23. | wells in Colmar
2h. Chemical ‘arid physical properties of crude ‘oil °

Ohio Of1 Co. ‘Colmar project from the Hoing sand ... 56
25. Oil-production statistics.+.Colmgr Project ssecesssovceee 59
26. Summary of’ operations for.The.Qhio Oil Co. Colmar project ... 60

ILLUSTRATIONS
Following

Fi Page
I. Map of crawford County, Ill. showing location of gas-

njection projects in Robinson field, July 31, aa seeee 8

T.'7 N., Ro 13 W., Crawford County, TLL. seceeecceeceeeee 20
3. Map of Tide Water Associated Oil Co, Henry gas-injection

project; ‘Crawford County I1l., July 31,1943 .....eeeee0. 20
4, Production-decline curve, Tide Water..Associated Oil Co.

Henry project; Crawford. County, [1]. sssccsecceeseceteree 28
5. Comparative oil production by leases, fore and after gas

injection, Henry project, Crawford County, Tll. ..ve..- 28
6. Map of The’ Ohio’ Oil: Co. Warnock gas- injection project,

Crawford County, T1l., July 31,° 1943"... 30
7. Production-decline curve, The Ohio dil Co. Warnock project,

Crawford ‘County; -Ells -sceeaeseene . 38

8, “Map of The Ohio.0il Co. Plymouth aiz injecti
Hanéock’ and ueDonough: Counties, The, 3 July 31,-1945 «+. 4o

239 ° -2-


R.I. 3783

The rate at which air or air-gas mixture is injected into each well is
controlled by a globe or gate valve in a 1/4-inch bypass around a stop on
the upstream side of the meter run at each well. Meter runs consist of 2-
inch pipe, flange taps, and flanges containing either 3/8- or 1/2-inch ori-
fice plates. The static pressure and pressure differential across the ori-
fice plate in each meter run are measured about once each month with a pres-
sure gage and a manometer, aid the rate of injection is computed. Recently
flow measurements ha. 2 been made weekly to permit closer control of the
injection rate,

Minor corrosion problems, common to this area, have not been aggravated
perceptibly by the injection of air, Well records indicate that the casing
and tubing in several wells have been replaced once or twice before air-gas
injection was begun. The corrosion resulting in those replacements was
caused by small amounts of hydrogen sulfide in the presence of water.

Orsat analyses of air-gas mixtures produced by six oil wells nearest
the injection wells on the J. Randolph lease were made October 22, 1943,
These analyses show that the gas contained unusually large amounts of carbon
dioxide (see table 5). Although some oxidation of the oil may have occurred ,
the operator reported that no trouble has been experienced with the plugging
of sand faces in the producing wells by the precipitation of insoluble
residues.

TABLE 5. - Orsat_ansalyses of gas produced from oil wells in the
Robinson field - Henry project, J. Randolph lease

Percent by volume of sample
analyzed.
- Well No, 5 i C02
3. 10.6 7.6
Ds 10.8 7.0
6 wee se eeeeeees +2 | 8.0
le, see eceeeees 3.7 { 13.7
Ly seaeee eteeeees 2.8 | 4.8
LD ceeseeessseeessner es 5.3 | 8.4

The air-gas mixtures tested were produced from oil wells selected be-
cause of their proximity to the injection wells being supplied air on the
Henry project. The operator considered none of the mixtures explosive, and
these mixtures, as well as produced by 16 other wells, were being compressed
for injection. An analysis of the air-gas mixture on the discharge side of
the compressor revealed that 5.2 percent of the sample was oxygen and 7.7
percent carbon dioxide. The percentage of excess nitrogen in this sample
was not determined, but the proportion of natural gas in the injection medium
probably was 50 percent or less.

The general characteristics and distillation analysis of a crude-oil
sample taken from a run tank on the Henry lease are shown in table 6. The
gravity of the oil is 35.2° A.P.I., and the viscosity at a formation tempera-
ture (measured in June 1943) of 84° F, is 52 geconds Saybolt Universal, or
6.8 centipoises. vt

239 - 26-


wow 2 ovy saan es

Com 2200 sear

vom 3970 sunanr

110m maoavs om 4

NW-SE CROSS SECTION B-#

! OW m300VS Om 1

© om Suotowan ">

1 on erowenae a

2 om suoimanan 3

Lom vane

con avoe'y

VOM mosmieow'y

“0m nosmeow'y

60m wosmeou'y

4334 ‘T3A77 V38 3A08V NOWLVATT

orem waa ce

10m wpeavs om “4

91-0m mpegs 30°

SW-NE CROSS SECTION CLC

exotwena 3

oon camsn's

orem anoo “na

o1-on avis

o1-om wavi0 -w

(L334 ‘72771 V38 3A08V NOILVATI

Ome

1 ee eves

Aen neve

N-% CROSS SECTION D-0'

{em suvre “ew

"on exemenne “2
“or suewenpe “3
"o8 cxeeense “3
rom muave a
e-em auave ss
ere paave “i
0 vom paava a
orem suave “a

270m pave"

a a

£324°T0A31 V38 2A08V NOLLVATTD

FIGURE 18.- Cross sections B-B', C'-C, and D-D' of Hoing sand, Colmar oi! field, McDonough

County.




R.I. 3783

gas were being produced when @i¥ first was injected, the air introduced into
oil sands forced largé volumes of natural gas to. producing wells. During
the first year or. two. of operation tlany projects, produced enough gas to es-
tablish a cycle,.and air was introduced (or injected) thereafter only once
or twice yearly for 30- to 60-day periods to replace the liquids removed
from the reservoir ani the gas used as fuel. The air-injection periods in-
creased in succeeding’ years,’ and as the percentage of natural gas in the
produced air-gas mixtures decreased the extraction of gasoline from the gas
became unprofitable and entire air-wet-gas mixtures were recycled, In 1943,
recycled air-gas mixtures were being supplemented with air continuously on
neanly half of the gas-injection projects. On the remainder of the projects
only, air was being injected;. and the produced air-gas mixtures, because of
low fuel value, were being discharged into the atmosphere.

Explosion Hazards

“hen air or air-gdis mixtures are compressed an oxplosién hazard is
present; however if the -fundaméntal laws governing combustion are recognized
and precautionary measures are taken explosions on air-gas injection projects
can be avoided. A complete discussion of explosive limits of air-gas mix-
tures is not within the scope of this report, but the subject has been evalu-
ated comprehensively by Jones and associates.12/, 13, 1 Experience has
shown that ordinarily months. or years elapse after initiation of air-injec-
tion projects before the produced air-gas mixture comes within the explosive
range (unless excessive bypassing or channeling is occurring in the reservoir).

Air-gas mixtures containing 10 percent oxygen or less will not burn or
explode, therefore compression is relatively safe if the oxygen content of
the produced air-gas mixture is kept below 10 percent. Some operators in
Illinois have successfully compressed and injected into oil sands air-gas
mixtures containing as much as 16 percent oxygen (approximately 76 percent
air). Mixtures containing 16 percent oxygen or less can be explosive, how-
ever, depending mainly upon the kind and proportion of inert gases present
(nitrogen in excess of that in air and ‘carbon dioxide) and to some extent
upon the composition of the natural gas portion of the air-gas mixture.. Ex-
plosive limits of air-gas, mixtures are not altered much by temperatures or
pressures encountered in compressors ordinarily used on air-gas injection
projects in the older oil fields of Illinois.

Tests should be made periodically te determine the explosibility of
air-gas mixtures produced on air-injection projects. Some operators make
oxygen and carbon dioxide tests on composite samples of the air-gas mixtures
semi-monthly or monthly with an Orsat analyzer. Ordinarily when the com*~
posite samples contain 10 percent or more oxygen the gas produced by each

127 Coward, H. F., and Jones, G. W., Limits.of Inflammability of Gases and
Vapors: Bureau of Mines Bull. 279, 1939, 146 pp.

13/ Jones, G. W., and Kennedy, R. E., Limits of Inflanmmability of Natural
Gases Containing High Percentages of Carbon Dioxide and Nitrogen:
Bureau of Mines Rept. of Investigations 3216, 1933, 23 pp.

14/ Jones, G. W., Inflammability of Mixed Gases: Bureau of Mines Tech.
Paper 450, 1929, 38 pp.

239 - le -






BARRELS PER ACRE-FOOT

OIL PRODUCED -

300

28 OIL PRODUCED BY AIR INJECTION FROM
FEBRUARY 1,1934 TO AUGUST |, 1943

26 OIL PRODUCED BY PRIMARY AND VACUUM
OPERATIONS UNTIL FEBRUARY |, 1934

24 a

22

200 _

180

140]

120

100

60

60

40

_

x
°o
y
STOOGELL

LYON HEIRS
PETER HAMM
W.A. RUGGLES
CHAS. ALESHIRE
ALL LEASES

R. SMITH
M.C. SMITH

LZ

FIGURE 13.- Comparative oil production by leases before and after
air injection, Plymouth project, Hancock. and McDonough Counties,
Wt.

IN





RoI. 3783

The injection of air into the Robinson sand.has caused some oxidation
of the oil, but no study was made to determine the extent of oxidation.
Soon after the initial injection! of air in 1936, the injection medium chan-
neled to Mewmaw well No. 3 and an analysis of the produced, gas showed the
carbon dioxide content to be 14.2 percent by volume. The well was not pro-
duced after December 1936 but has not been plugeed. Analyses of samples of
the gas produced by a1 oil wells in 1937 showed a maximum. carbon dioxide:
content of 3.4 percent. Recent Orsat analyses of the produced gas indicated
that the amount of carbon dioxide present in a composite sample had increased
to 4.9 percent. Analyses’ cf the gas produced by individual wells supplying
part of the composite sample in November 1943 are given in table ll.

TABLE 11. - Orsat_ analyses of gas produced from oil wells in the
Robinson field - Warnock project

| Percent by volume of sample analyzed

Lease Well No. | Oo COs

d. MN. Barnes ...... 6 13.4 6.6
Do. a 3.9 11.9
Do. 26 12.0 1.6
Do. i 29 13.6 1.8
Do. 31 22 am
Do. 32 9.2 7.0
Do. 36 3 6

Te CULD veeeeeeeeee | 1 5.6 3.6
M. McClain, fee... | 25 1i.o 14
DO. soveceeveees 28 8.9 Tod
DO. -eeeeaee 29 10.8 6.
E. Mowmaw .. 7 2.0 7.8
Dow wsseeeeee 1d «0 Lk
Schwenke 1 i 2:8 1.6
Wm. Warnock, fee .. | 3 { 6.4 6.8
DO. seseereeeees | 1 77 10.0:

When the tests were made, none of the oil wells listed in table 11 were
producing mixtures of air and gas that are considered explosive by the oper-
ator. The mixtures were not recycled, however, because the: volume produced
was inadequate for both fuel and injection. An analysis of a composite sample
of air-gas mixture taken from the discharge side of a vacuum pump showed that
5.0 percent of the sample was. oxygen and 4.9 percent carbon dioxide.

The general characteristics and distillation analysis of a sample of

crude oil from a run tank on the J. N. Barnes leas¢ ere given in table le.
The gravity of the oil is 33.8° A.P.I., and the viscosity at a formation

temperature (measured in June 1953) of 84° PF. is.59 seconds.Saybolt Universal,
or 8.5 centipoises.

239 - 36 -


R.I. 3783
TABLE 14. - Summary of operations for The Ohio Oil Co. Yarnock project, Crawford County, Ill.

j Average in- | i 1 T [Ratio of gas [Ratio of gas [Horsepower of
i Ges '§Jection pres-lInjection- ! Oil-well i 3stimated H Cumulative Cumulative jinjected to oil jinjected to oiljcompressor and
injected, L ! 1b. tell spacing, + spacing, area arfected,| oil production, coil gained, j/produced, cu. | gained, cu. |vacuum pump
Year jM cu. ft. jper su. inch acr:3 yer well bcresper well ecres ibbl. per acre ibbl. per acre ,ft. per bbl. lft. per bbl. | srime movers
193627! 6,857 80 r 105.0 T 7.6 ' ai) i 11.7 1.8 Tt" 1,200 i 8,500 / 105
1937 | 13,982 | 99 | 99.0 j 7.7 | 280 Hl 3365 9-7 | 1,020 | 2,799 | 105
1938 , 18,414  ) 103 : 78.8 | 7-8 | 300 ' 56.4 : 19.7 | 1,280 I 3,050 i 105
1939 ' agiszo ! lel ‘78.8 { 7.6 | 300 | 72.2 | 23.6 | 1,870 ; 10,270 | 105
1940 | 18,100 | 119 i 78.8 ‘ 7-8 { 300 ! 90.0 | 30.4 H 1,610 \ 5,430 i 105
1941 | 22,572 | 113 70.0 ' 7.9 ‘ 300 ! 111.2 Uae H 1,690 | 3,970 | 105
19h2 i 23,696 | 104 i 78.3 i 7-8 309 i 133.0 \ 53.6 | 1,730 3,850 105
19433/ +17, /36__ 1108 | 78.8 i 7.8 300 i 145.3 60.8 | 2,300 : 5,210 ! 105
voteL "181,867 | | ' : TE5.3 60.8 ! i H
L106 l | i i i 1,550 i 4, 330 i

ij ct ced from occesion2l tests.
2/ Lest * months of 1936.
3/ First 7 months of 1943.

239 . - 39 -


R.I. 3783

TABLE 12, - Chemical and physical properties of crude oil produced on
The Ohio Oil Co. Warnock project from Robinson sand

GENERAL CHARACTERISTICS

Sulfur, percent, 0.17 Specific gravity, 0.856
Saybolt Universal viscosity at 100°F., 53 sec, A.P.I. gravity, 33,8°
Saybolt Universal viscosity at 840F,, 59 sec. Color, greenish black

DISTILLATION, BUREAU OF MINES -HEMPEL METHOD

Distillation at atmospheric pressure, 753 mm, First drop, 31°C. (88°r.)

Fraction Cut at- Per: Sum, Sp. gr., CA.P.I., C.I. S.U. Cloud.
No. oC. (OF. cent . per- 60/60°F, 60°F, visc., test,
+ cent 100°F, OF.

1 50 122 0.5 0.5 )

2 75-1677 2.2 2.7.) 0.675 78.1 -

3. -100. 212° 2.9. 5.6 +723 64,2 23

4 125 257 5.1 10.7 +740 59.7 22

5 150 302 5.4 16.1 «757 55.4 22

6 175 347 5.5 . 21.6 +775 51.1 2)

7 200 492 5.0 26.6 - 192 47,2 26

8 225 437 5.3 31.9 «808 43.6 28

9 250 482 5.8 37.7 821 40.9 29

10 275 5eT 7.0 4b.7 835 38.0 31
Distillation continued at 40 mm,

11 200. 392 2.7 ky. 0.849 35.2 33 am 15
12 225 437 5.9 53.3 856 33.8 3546 30
13 250 482 6.5 59.6 869 31.3 36 59 50
wy 275 527 5.3 64.9 881 29.1 38 (93 65
15 300 572 6.9 71.8 890 27.5 39-165 85
Residuum “28.0 99.8 2955 16.7

Carbon residue of residuum, 8,0 percent; carbon residue of crude, 2.2 percent.
Base of crude: Intermediate -

APPROXIMATE SUMMARY

Percent Sp. gr. °A.P.I. Viscosity

Light gasoline 5.6 0.700 70.6

Total gasoline and naphtha 26.6 0.752 56.7°

Kerosine distillate 1.1 815 42,1

Gas oil 14.6 8li5 36.0

Noviscous lubricating distillate 10.6 ~860-.882 33,0-28.9 50-100
Medium lubricating distillate 8.4 .882-,894.. 28.9-26.8 100-200
Viscous lubricating distillate oo) ~894-.895 -26,8-26.6 Abeve 200
Residuum 28.0 2955 16.7
Distillation loss 22

239 - 37 -






R.I. 3785

wells, and by the end of 1936 six injection wells, spaced 105 acres per
well, were in operation. The yearly status of the development of the
project is given in table 9, On August 1, 1943, air was being injected
through eight wells, spaced 78.8 acres per well, end had affected an area
estimated to be 300 acres, or 48 percent of the productive area of the
properties included in the Warnock project.

Well-Completion Methods

No wells have been drilled on the leases comprising the Warnock project
since 1916, and oil wells are cased as they were originally - 10-inch drive
pipe set at an average depth of 77 feet, 8-1/%-inch pipe set at an average
depth of 386 feet, and 6-1/l-inch pipe set approximately 35 feet above the
top of the Robinson sand at an average depth of 858 feet. The producing
wells are equipped with 2-inch tubing and pumped by central powers.
Bighty-one oil wells, spaced 7.8 acres per well, were active'on July 31,
1943.

Injection wells are converted oll wells with no change in the casing
program except to replace corroded pipe with new pipe. The oil sand in
converted wells originally was shot with 2 to 4 quarts of nitroglycerin per
foot of sand, but no additional explosives were used because shot holes had
become enlarged by caving over a period of 20 to 30 years. During conversion
shot holes were cleaned out, and a 2- by 10- by 6-1/4-inch anchor packer was
run in the hole on @-inch tubing. The packer was set in the lower part of
the 6-i/4-inch casing, and a perforated anchor on the tubing (set on bottom)
was placed opposite the sand face. Perforated anchors in injection wells
are approximately 4 feet in length.

Operating Practice

A vacuum pump and compressor plant is located on the Warnock lease,
and a second vacuum pump is housed on the Barnes lease. Both vacuum pumps
(22- by 8-inch) are belt-driven by 35 horsepower gas engines. The pumps
pull a vacuum ranging from 25 to 27 inches of mercury on about half of the
oil wells on the project and discharge into a fuel line at a pressure of
1 to 2 pounds per square inch. A trap to remove scale and water is on the
intake side of each pump. During the first 5 years of gas injection the
quantity of air-gas mixture produced was adequate for fuel and reinjection,
although it was necessary to supplement the mixture with air several months
each year. Since 1941 the oil wells on vacuum have produced only enough
gas to provide fuel for central-power, compressor, and vacuum-pump engines,
and air has been used exclusively as the injection medium. The air-gas
mixtures produced by the other oil wells are deficient in gas and are
vented to the atmosphere,

239 -31-


R.I. 3783,
November 1944.

REPORT OF INVESTIGATIONS

UNITED STATES DEPARTMENT OF THE INTERIOR - BUREAU OF MINES

SS =F —

AIR AND GAS INJECTION IN THE OIL FIELDS OF quitnorsi/

By C. M. Keithly2/ and Thomas Jennings3/

CONTENTS

&
:

Introduction ...eee
Acknowledgments .
History of gas injection ....
Gas- injection projec sin tllinois:
Location, of gas-injection projects .
Features, of reservoirs being exploited
Source of gas for injection ..
Development practices 4...
Use of air-gas mixtures

ur gas injection projects in Illinois ...s....0655 20

WPAN NATE

O11 Co. Henry project .... 20
farnock ‘project’. 30
The Ohio Oil Co. Plymouth project ..... ho
The Ohio Oil Co. Colmar Project secescecssvececcecccvccevenes 50
TABLES
Page
1,-, Maximum percentage of water Vapor in GAS cecoveseceseseseceves aL
2. Active gas-injection operations in IT1linois .o..cecceeseseeces 15

3. Development of Tide Water Associated ‘Oil Co. Henry project ... 22
4, Volumes of gas ‘injected and oil produced by nonths - Tide

au
5s
26
6.
Sand sececvcee Leeeeceteccscegeeses We ew econ senceee 27
7. Oil-production statistics - Henry project svecessccccevesesees 28
8. Summary of operations for Tide Water” Associated Oil Co. Henry
Project SAAR RRR Rn Ra ae 29

1/7 The Bureau of Mines WiLL welcome‘ reprinting of this paper, provided the
following footnote acknowledgment is used: "Reprinted from Bureau of
Mines Rept. of Investigations 3783." .

2/ Assistant petroleum engineer, Bureau of Mines, Bartiesville, Okla,’

3/ Assistant petroleum engineer, Bureau of Mines, Franklin, Pa.

239




R.I. 3783

TABLE 15. - Development of The Ohio Oil Co. Plymouth project

Active air-injection wells Active oil wells Compressors |
Spacing, 1/ T Spacing, 1) in
Date Number acres per well j; Number, acres per well | operation | Remarks
May 1, 19352/ 16 25.6 k6 8.9 2 [6 oil wells were converted
i i to injection wells in 1934,
Jan. 1, 1936 19 21,6 43 9.5 2 D oil wells were converted
| to injection wells in 1935.
Jan. 1, 1937 | 18 22.8 db 9.3 2 ‘1 injection well was con-
| | verted to an oil well in
| | | 1936.
gan. 1, 1938 | 18 22.8 db 9.3 | 2
Jan. 1, 1939 18 22,8 4h 9.3 | 2 i
Jan. 1, 1940 19 21.6 ho 9.8 2 fL oil well was abandoned
i j and 1 oil well converted
i i to an injection well in
| | 1939.
Jan. 1, 1941 | 119 21.6 ke 9.8 2 i
Jan. 1, 1942 19 21.6 he 9.8 2 i
Jan. 1) 1983 19 21.6 ho 9.8 2 |
Aug. 1, 1945 19 H 21.6 he 9.8 2 |

i/ Computed for a productive area of 410 acres.
2/ Compressor plant not in operation from December 14, 19

Bw

239

- ho -

to May 1, 1955.




TABLE 23. - Orsat analyses of gas produced from oil

wells in the Colmar field

RI. 3783

Percent by volume of sample analyzed

Lease Well No. | 02 COn

T, Binnie veseeseceeees 10 : 9.8 4.8
D0. sesesecessccenee | 230 | 13.2 3,4
Wm. Conn H 5 : 51 7.8
DO. sececeseeveceeee | 8 | 16.5 2.5
We He Culp sessceceeeee | 1 17.9 20
E. H. Hendricks ....qe. | 18 15.4 2.4
1 8 18.0 8

| 31 11.8 4.0

H 35 | 18.5 3

i 1 17.1 1h

i 6 + 42 11.0

j 12: i 11.9 4.8

T. M. McFadden . ah. i 18.2 38
DOs sesceveeee . 29° | 14.8 a8
J. M. Myers a/c l. ! 2: ! 18.1 .
ue gers ofe 2 a re) 2.8
J.M. Myers afc 2aceee | 1 | U2 2.8
DO. seveecaves 2 9. 15.4 | 2.4
T. C. Payne .. a | 1 | 16.6 | 1.4
R. D. Robinson .. . 1 ; 5.4 j Tob
CG. F. Valentine sseseee 6 : 9.4 5.4
DOs secccveece . 9. i 16.3 2.3
A. N. Wear . ' a, | 17.2 1.6
Do. oe vl 12 i 14,2 3.0
Do. i 16, Ok 5.2
Do. .- . a | 11.2 Ah
M. D. Wear ceeoeee . 3 : 18.7 “7
DO. soeveecece . Te 14.6 2.2
DOs sevcesececeveres 9 i 19.0 oh

239

-57-


R.I. 3783

TABLE 3. - Development of the Tide Water Associated Oil Co. Henry project

|Affected|Active gas-injection wells | Active oil wells Compressors]
area, Spacing,i/ | | Spacing,Z in i
Date acres |Number acres per well |Number | acres per wellloperation | Remarks
Jan. 1, 1935} 130 87.5 103° | 6.8 | 2 ;@ oil wells were converted
| | ! , i | to injection wells prior
{ | | to 1935.
Jan. 1, 1936} 190. j; .20 70.0 lol. 6.9 2 ; 2 oil wells were converted
' | to injection wells in 1935.
Jan. 1, 1937; 305 |2/15-1/2 45,2 96 7.3 3 [5 oll wells were converted
7 H to injection wells (1 in
| | 1937) and 1 oil well was
: | drilled in 1936.
gan. 1, 1938; 420 2/i7 41.2 98 7.1 3 j2 oil well was converted to
; an injection well and 2
| oil wells were drilled in
. 1937.
Jan. 1, 1939] 460 18 38.9 97 7.2 3 1 oil well wes converted to
, | an injection well in 1938,
Jan. 1, 1940] 465 18 38.9 97 | 7.2 3. i
Jan. 1, 1941! 465 18 38.9 a7 7.2 a
Jan. 1, 1942] 505 18 38.9 9 7.5 3 | 3 oil wells were. converted
i to injection wells, 1 in-
i H jection well was converted
i | | to an oil well, and 2 ofl
| | wells and 2 injection wells
were abandoned in 1941.
Jen. 1, 1943 | 535 18 38.9 93 7.5 3
Aug. 1, 1943) 555 eal 33.3 90 7.8 3 *% oil wells were converted
* i i fl | to injectién wells in.1943,

1/7 ‘Computed for a productive area of 700 acres.
2/ Offset operations added 1/2 injection well in both 1936 amd 1937.

239

- 22 -




R.I. 3783

TABLE 26. - Summary of operations for The Ohio Oil Co. Colmar project, McDonough County, Ill.

| average in- | ] 3stimated Ratio of air Ratio of air |
air j jection pres-| Injection- | Oil-well |Repressured | Cumulative cumulative injected to injected to | Zorsepower of
injected, L/i sure, 1b. per!well spacing, spacing, i area, foil production, oil gained, | oil produced, oil gained, compressor
Yegr jm cu. ft. | sq. in. tgeres por welllacres per well | acres {bol. per acre |bvbl. per acreicu. ft. per bbl.| cu. ft. per bbl.|prime movers
193527 60, 000 | a5 | 30.9 H 8. 1 1,420 i 15.3 0.0 2,710 - 90
1936 124,568 33 | 30.2 | 8.2 | ajyeo | 98.6 52.6 | 1,050 1,650 | 90
1937 108,057 | 39 i 30.2 | 8.2 ' 1,420 171.0 | 104.8 glo : 1,450 90
1938 180,000 ! 33 : 29.0 | 8.3 ! 1,420 i 245.6 1 142.6 i 1,930 | 3,360 | 90
1939 | 193,146 28 H 29.0 | 8.3 F420 | 313.3 | 183.6 | 2,010 | 3,320 90
1gho | 206,809 | eT ! 29.6 i 8.2 | 1,420 i 379-1 | 223.7 | 2,210 i 3,630 90
1941 220,730 | 26 ' 29.6 | 8.2 » 1,420 4u1.3 ! 261.2 | 2,500 ! 4,150 | 125
1942 | 286,075 . 27 i 29.6 | 8.2 » 1,keo | 506. : 302.6 i 3,090 | 4, 860 | 125
19433/ | 538 | au i 32.3 ' 6.0 1420; 54o.4 i 323.4 i 2,990 | 4, 890 | 125
Total 1,523,923 ° i | : i SOG : 323.4 j | |
averegg 32 i | i i : ! 1,990 H 3,320 |

1/ Computed from occasionsl tests.
2/ Last 6 months of 1935.
3/ First 7 nonths of 1943.

239 -~ 60 -








R.I. 3783

TABLE 4, - Volumes of gas injecteal/ and oil produced by months - Tide Water Associated Oil Co. Henry Project
(Pressure base, 14.4 1b. per sq. in. abs.; temperature base, 60°F.)

| L93y q 1935 i 1936 | 1937 j 1938
1 Gas Oil | Gas Oil | Gas i Oil ; Gas | oil Gas Oil
| injected, tproduced,; injected, | produced,| injected, produced, ‘injected, produced, injected, } produced,
[Mcu. ft. ! bbl. |Mocu, ft.| bbl. |M cv. Ft Le bol. {M cu. ft. bbl. |M.cu. ft. bbl.
H . 9,765 {| 2,615. 10,757 i 25209 T 12,916 2 016 9,639 5,652
i i 8} 700 i 2) 6h7 | 107108 / 1,811 | 12,29k | 4010 11,109 3,337
' 10,058 | 3,213 | 1h, 546 | 2,236 | we oh | 4&6 12,901 | 3,407
: | 7,162 | 3,098 , 14,031 ; 2,590 13161 ; 4,486 | 12,914 + hy okd
| 2,770) 1,732 ; 6,648 2,960 | 17,097 | 3,117 ! 15,223 | 4,581 12,660 | 4 eke
+ 8,160 1,665 ! 5,906 | 2,906 | 17,150 | 3,358 | 12,480 4 3h5 12,748 3,877
) ; 2,095 | 5,420 | 2,865 | 17,528 | 3,548 ! 12,946 | 3,999 13,565 4,068
August... 1) | 2,503 | 5,455 | 2,692 | 14,912 | 3,360 , 13,304 | 4530 13,276 ; 3,945
September! )2 2/56, 488; 2,555 | 8,188 | 2,539 | 15,032 | 2,948 | 1h,552 | 4,055 | 11,880 |; 3,670
October... ) 2,535 | 7,905 1 2,665 | 13,742 ; 3,135 | 15,2he | 4,162 | 12,400 | 3,709
November.; ) ! 1 7,725 +: 2,588 | 12,676 | 3,20k | 14,995 | 3,822 | 10,315 3,675
December. ) i 8,959 | 2,519 | 12 7369 | 3,496 | 20,915 | 3,698 1 20,279 | 3,483
1

Total. 2/67, m8. GL,SGL 1 33 TESS FET + 35,015 _1168,519 50,325 143,686 {| 45,115
I/7 Volumes of gas computed from occasional tests.

2/ Estimated.

239 - ah -


R.I. 3783

The rate of air injection is determined in the same manner as was de-
scribed for the Plymouth project. A record of the air injected and oil pro-
duced for the Colmar project is given in table 22. The values for the
volumes of air injected are estimates based on monthly flow tests, end
several of the air-injection figures either are interpolations of the
available data or were recommended by production men in the field.

As in the Plymouth oil field, water and the small quantities of hydrogen
sulfide associated with the oil in the reservoir caused most of the corrosion
of subsurface and surface equipment .before air-injection operations were
begun. The rate of corrosion of equipment has not been affected perceptibly
during air injection,

Orsat analyses of gas produced from 30 of the 177 oil wells on this pro-
ject were made October 25 and 26, 1943. Results of the tests, which are
given in table 23, are not considered conclusive proof that oxidetion of
the oil has occurred. The operator reported that no evidence of sand
plugging with solid oxidation products has been found.

The general characteristics and distillation analysis of 2 sample of
erude oil taken from the oil and gas separator on the Hendricks lease are
shown in table 24, The gravity of the oil is 35.8° A.P.I., and the viscosity
at a formation temperature (measured in June 1943) of 68° F. is 60 seconds
Saybolt Universal, or 8.6 centipoises.

Results

The estimated cumulative oil production for the Colmar project before
the initial injection of air in July 1935 was 65.4 barrels per acre-foot,
and the cumulative oil production during air injection to August 1, 1943?
was 43,9 barrels per acre-foot. An estimate of the oil gained fora 4-per-
cent decline in the rate of oil production during vacuum operetions is given
in table 25. Because of the difficulty of extrapolating a decline curve for
this project (see fig. 19), the 4-percent decline rate was adopted on the
recommendation of engineers familiar with operations in this field.

All except two of the leases comprising the Colmar project have pro-
duced more oil during secondary-recovery than during primary operations.
Such unusual results are misleading, however, unless it is recognized that
the initial energy-in the reservoir was very limited. The original oil con-
tent of the Hoing sand was over 500 barrels per acre-foot, and the total
primary recovery of oil from the send in the Colmar field was approximately
41 barrels per .acre-foot; therefore less than 10 percent of the oil origi-
nally present was produced during the primary-recovery period between 1914
and 1926. The proportion of oil recovered from each lesse in the project
during primary-~ and sec¢ondary-recovery operations is given in figure 20.
“Generally leeses responded to secondsry-recovery operations in.a manner in-
dicated by their past productivity; that is, a lease with high oil recovery
during primary production usually realized a correspondingly high oil re-
covery during secondary-recovery operations. One notable exception is the
Myers a/c 2 lease which had a higher oil recovery during air injection than
during both primary and vacuum operations.

239 - 54 -


RI, 3783

It is split into two or three persistent lenses that show average
depths of about 850, 900 and 940 feet. with an average interval between
the, tops of the sands of about 50 feet... The thickness of the sand
lenses varies between 2 and 50 feet with an average of about 25 feet,
The wells in which one or two lenses are absent are too numerous to
mention, There are additional lenses. of sand both above and below
the zone which includes the three persistent lenses, One above is
known as the "gas" or "stray" sand, It is usually from 6 to 20 feet
thick and about 20 to 50 feet above the top-most lens of the Robinson
sand, The sand lens lower than the oil zone may belong to the»
Robinson sand as a fourth lens, so closely is it related to the upper
lenses, There are other minor streaks of sand even in the producing
zone that add further confusion to the correlation,

Source-of Gas for Injection

The supply of natural gas in the old oil fields of Illinois usually
has been inadequate for gas injection, ‘In the Colmar and Plymouth oil fields
of western Illinois, where the volume of natural gas produced is inadequate
to supply fuel for central-power engines, air is injected into the oil sand,
Operators in the Robinson oil field in the southeastern part of the State
have been more fortunate. After air has been injected into the reservoir
for several months, enough gas is produced to provide fuel for engines on
most of the projects, and part of the produced air-gas mixture is reinjected.
‘Within the last 5 years, however, only air has been used as.an injection
medium on several projects because the air-gas mixtures produced by the oil
wells have become deficient in gas.

Natural gas is produced in some of the newer oil fields in quantities
exceeding their requirements for ‘gas injection and fuel. It is unfortunate
that gas from these fields (all of which are less than 70 miles from the
Robinson oil field) has not been used to replenish the diminishing supply
of gas in the older oil ficlds in that part of the State,

Development Practices

Ordinarily most operators of gas-injection projects.in the stripper
fields of Illinois have converted 01d oil wells to injection wells and have
drilled no new wells. On a few, large, well-organized projects one or more
wells have been drilled to obtain information on the reservoir, Absence of
extensive drilling programs has resulted in a material saving in the cost
of developing’ many projects, but the scarcity of core samples from the oil-
producing sands has made it difficult to design systematic gas-injection
projects, Thus, projects have been developed slowly, usually by experimental
injection, and it is common practice for an oil well to be converted to an
injection well and reconverted to a producing well within 1 year.

With few exceptions, the 12 oil-producing companies operating gas-
injection projects in the old oil fields have utilized second-hand equip-
ment in the development of their projects, In the southeastern oil fields
gas pumps and compressors, utilized in vacuum operations and the

239 -9-


RI. 3783

TABLE 20. - Summary of opceretions for The Ohio Oil Co. Plymouth project, Hancock and McDonough Counties, I1l.

; | Average in- i] | I { Estimated | Ratio of air Ratio of air |
Hl Air ‘jection pres~ | Injection- Oil-well ' Repressured! Cumulative oil! cumulative injected to injoeted to |Eorsenower of
linjected,4/! sure, lb. per; well specing,! spacing, i area, | production, |oil gaincd, ‘oil produced, | oil gained, ; compressor
Year iMcu. ft. | sq. in. lacres per well acres per well acres bbl. ner ecre {bbl. per acre icu.ft. per bbl.jcu. ft. per bbl.| prime movers
193427 } 107,750, ay 7 25.6 1! 8.9 10 i 86.2 ' 35.5 if 3, 050 7,399 { 60
193 1 52,362 | 36 i 21.6 ! 9.5 410 » 167.4 i 83-7 H 1,270 4, 540 | 60
193) | 66,228 | 27 f 22.8 i 9.3 410 i 252.3 i 97. o 1,900 | 4,760 i 60
1937 60,621 | 26 | 22.8 9.3 410 | 336.0 1 132.3 | 1,770 | 4,260 i 60
1938 | 65,945 | 24 i 22.8 ! 9.3 410 »  4o9.8 1159.1 H 2,180 \ 5,990 | 60
1939 ; 65,600 | 22 i 21,6 i 2.8 410 1 479.5 | 183.7 | 2,300 ! 6,510 i 60
1940 ' 75,662 ' 25 i 21.6 : 5.8 , 410 ; 549.2 » 210.1 | 2,650 : 6,990 | 60
1941 + 78,000 ol 21.6 i 9.8 410 > 61L4.5 i 233.9 2,910 ‘ 8,000 \ 60
igk2,, ; 78,026 | 23 ' 21.6 i 9.8 410 676.7 | 256.2 | 3,650 ! 8,540 i 60
19433/ 1, 42,323 eu 21.6 i 9.8 10 i 710.7 267.9 i 3,360 i 8, 850 | 60
Total ' 692,517 T i | | 710.7 T 267.9 ; H ;
Average i 2g ! i i H | | 2,380 | 6,310 |
i/ Computed from occesional tests.
2/ Last 11 months of 1934,
3/ First 7 months of 1943.

vo

239 ~ 4


R4W.

5000

4000

SCALE: FEET

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FIGURE 1!5.- Map of The Ohio Oi! Co. Colmar air-injection project, McDonough County, 111.



RI. 3783

In addition to gas injection in the stripper oil fields of Illinois,
extensively developed projects are located in some of the oil fields dis-
covered since 1937, The largest project is that of the Carter Oil Co, in
the Louden field, Fayette County; two others of comparable size are the
Salem project of The Texas Co. in Marion County and the New Harmony project
jointly operated by Superior Oil Co,, Tide Water Associated Oil Co., and
Sun Oil Co, The joint project included most of the New Harmony oil field,
in White County, I1l., and Posey County, Ind. A smaller project includes
parts of the Hocdville and Walpole oil fields in Hamilton County, where
residue gas and some of the liquid products from a gasoline-extraction
plant are injected into two sandstones.

Features of Reservoirs Being Exploited

Gas is being injected into oil sands occurring at depths ranging from
400 feet in the Siggins field to 3,075 feet in the Walpole field. The sands
are of Pennsylvanian, Mississippian, and Devonian age; most old oil fields
in southeastern Illinois produce from Pennyslvanian and Upper Mississippian
formations. The important newer fields in which gas-injection operations
are active produce oil from sands of Mississippian age. Gas is injected
into three oil sands in the Louden field, two sands in the Salem field,
and seven sands in the New Harmony field,

The porosity of most oil-producing sandstones in Illinois ranges from
17 to 20 percent and averages 18 percent. 10 Measurements of the permea-
bility of the sandstones range from 0 to 2,530 millidarcys, averaging over
100 millidarcys, The high average permeability characteristic of many of
the oil sands permits the use of low injection pressures.

The oil-producing formation of greatest areal extent in the older oil
fields of the State is the Robinson sand of Pennsylvanian age. Most wells
in the Robinson field were drilled before the value of information concern-
ing the characteristics of an oil sand was appreciated, and few core analy-
ses of the sand are available, Results of a few analyses indicate that the
porosity of the Robinson sand ranges from 17 to 19 percent and its permea-
bility is as high as 2 darcys, averaging about 125 millidarcys. Oil- and-
water-saturation values fluctuate so widgly that no general statement
regarding them can be made, BlatchleyLL/ has described the Robinson sand
as follows:

The Crawford County pools are distinctive for possessing one
general. oil-producing zone mown as the Robinson sand. This sand is so
broken and lenticular that it offers little opportunity for structural
study, In fact the sand shows innumerable streaks, tongues and de-
tached portions and so prohibits correlation and contouring, In some
portions of the field, however, the sand is regular in its distribution.

10/ Bell, Alfred H., Squires, Frederick, end Cohee, George V., Secondary

Recovery of Oil in Illinois: Illinois Petroleum No. 43, Press

Bulletin Series, Illinois State Geol, Survey, Jan. 20, 1943, 14 pp.

11/ Blatchley, Raymond S,, Oil in Crawford and Lawrence Counties; Illinois
State Geol. Survoy Bull, 22, 1913, pp. 97, g8, and 99.

269 -7-


fe T
Race PERMEABILITY, MILLIDARCYS POROSITY, PERCENT SATURATION, PERCENT OF PORE SPACE

‘SURFACE, oS
FEET 200_400__600_800 1000 1200 _1400_1600_1800 510 18 20 1020 30 40 $0 60 70 80 90
T 306070 6 50403020 10
| | I | | | | ]water
[- 484
|_—° i
[485 }—
| 71
[- 486 oa | |
——t—}-—}
TT
L- 487 2830 —| t
i

k

L—- 493 a :

—- 494 Lb

}— 488

— 489 WN

L- 490

L- 491 -

[— 492 t F

r— 495 cS

|
|

f— 496 to

— 497 ta — TI 1
CORE OBTAINED voip

}— 498 MARCH 1943

!

FIGURE !4.- Analysis of Hoing-sand core from well in sec. 15, T.4 Ne, Re 4 We, McDonough County, I11.




RoI. 3783

TABLE 21. - Development of The Ohio Oil Co. Colmar project

Active air-injection wells Active oil wells | Compressors
‘ Spacing,4/ Spacing, 1/ in |
Date lmusber | jacres per well Number | acres per well, operntion | Remarks
gan. 1, 1936 i 50.9 ; 13 | Bl | 3 46 oil wells were converted to
| | H : injection wells and 1 oil well
| f | ! | was drilled in 1935.
Jan. 1, 1937 ! u7 30.2 ‘173 | 8.2 : 3 fp oil well was converted to an
| j | injection well and 1 oil well
I | i i was drilled in 1936,
Jan, 1, 1938 | 47 | 30.2 | ath | 8.2 | 3 (1 oil well was drilled in 1937.
Jon. 1, 1939, 49 | 29.0 | 17a} 8.3 | 4 5 oil wells were converted to
' | ! | | injection wells, and 1 injec-
| ' i H | tion well was converted to an
1 | : l oil well in 1938.
Jan. 1, 19h0 | 49 | 29.0 172 | 8.30 | 3 [1 of well was converted to an
! : | | injection well and 1 injection
i ij | well to an oil well in 1939.
Jan. 1, 1941 | 48} 29.6 173 | 6.2 | 5 |2 oil wells were converted to
| | | i i injection wells and 3 injec-
| \ ' tion wells to oil wells in
| | : 19h0.
Jan. 1, 1942 | 48 | 29.6 173 | 8.2 4 |
Jan. 1, 1943 | 48 | 29.6 173 8.2 4 |
Aug, 1, 1943 Ay | 32.3 i 177 | 8.0 4 ik injection wells were con-
i I | L_verted to oil wells in 1943.
i7 Computed for a productive area of 1, 126 acres.
239 - 52 -






3185

TUILE 2. - Astive gascinjostion operations in 1i1inots (cont'd)

July 32, 1985
Sand Location Company Leet Mumber —_Of1 wolle Jeotion medium Average daily of1 produstion, bbl, Initial
= verege Toate Togal desortption Tame of Total” Wenbor verages average ofere desi slg, TSG atevese
thal Seotion Tom- Range umber af- Anjection volume air-gas injeotin
fest” nese, onip Footed Injection

bzd cd Crasfora — 16,19,30 as Arnold 165 n ST 16 160 lo a 6 oe ike
bcd 0 doe 15,16,21 and 22 7%. mary 15 7 oa wy 60 5 a cy 5 ida
5 p do. ca. ‘Wilkin 30 bea 5 7 6 Lo J 8 3 3 1s
5 eo dow Toms ca ‘Eawarde 325-100 7 ba 6 150 & ww Z Es 3a

95 ed do. ca Wood Rel Lo 2 is 7 bo 10 »o bs 4s
3 lf a: Baie ix Rive = 90 a8 os 8 OB 2 i apse
ms fl 35,Bbs ana 35 ix 7 a a a) wm BR is 38 g38
@ 8 a im mo i 5 0 ok Ot 2 OB & (SST
IP a do. 6 sh Hille 200 6 2 a 5 cy a Cs a 1937

Stents
bod oS dow 33 ant 3h on Woodworth 1460 » 1 wv 3 80 Bb 32 wo 37 1932,
FR 2 do. n an ‘Culver 30 20 1 3 2 C7 uy 2 6 5 1937
5 3 doy oy 7”. ‘J.Randolph 190 70 2 B & air 125 ” 6 wy 6 1936
a cd C7 do. nD Th Rutherma = 30. 2 1 Ss 2 te, 6 9 4 6 1936
to. aa) om TM wey Ka. rr 6 b 1936
to. = ok én Pireh Cr) 1 108 ee 30 6 ° ” uy 1936
doe 5 0 do. 6 6m. Good 80 15 1 B 2 to, 2 15 10 18 9 1936
dow 915 30 do. Ww on Murphy 6 7 a 9 1 to. lo 10 3 " 3 19%
ao. m5} @ on TM Bra 0k 9 3 mw » © 2 101955
do. oS 2 do. 9 end 10 mm! Nettle 120100 3 n 10 to. 7 ” 5 a3 1935,
9

to. 40085 de. 9 and 10 TM Finwoigh 000-6) = 1 mek 1 hs
do. 9 ” to. 10 and 15 7%. ‘Tkonire 120 80 3 wy 8 to, 20 lp 6 a wv 193k
do. 915 2 do. 10 a ‘EB. Stifle 100 100 6 wy .s to. 20 5 a ur 25 1934
do. 5 7 do. iz ms Drake 6 25 a 6 2 ate 6 ws 3 7 5 95h
do. 5 7 to. 10 7s P. Drake J 6 2 9 9 Ces 20 8 6 . 1933
to. ms «0 TM > 6 b&b w 6 © 5 5 % uss
ao m5 8 TM %& & 2 a ee) “6 au (Re
do. 0 Ed doy oF Ts. 160 80 6 wo 9 air 125 6 8 Ww 6 1952
doe ‘95 2 do. ‘21 and 28 mh 210 B 2 B 6 ue 6 » 12 32 wz 19@9
a, m= # 6 TM we 5 2 2 we oe Y 2 sr
toe 5 20 do. 2 en rR u 15 8 to. ed 100 oy 7 7 13T
do. 900, 30 tow 2 Th 100 to L nu & Cas 0 a 9 20 n 1937
on 050 3 TM wo we Cr ee 5 5 (Be
ae. 1,000 20 wo 2 2 2 Hf 0 wy 2 D 2 1928
doe 1,000 5 id 25 2 7 3 te.” 100 & 6 1ge9
a m3 8 mw 8 & © 3 ° 3 a noe
to. 5 30 TH. 0 6 3 % 6 ate J 19 a 28 a 1929



R.I. 3783

TABLE 10. - Volumes of gas injectea2/ and oil produced by months - The Ohio Oil Co.
_ , . Warnock project (Cont'd. ) ;
(Pressure base, 14.4 Ib. per sq. in. abs.; temperature base, 60° F.)

1940 ighi 1gke 1943
Gas i Oil Gas P Oal Gas Oil Gas oil
injected, | produced, injected, | produced, | injected, | produced, injected, | produced,
Mou. ft. | bbl. | M cu. ft. bbl. | Mou. ft. bbl. Mou. ft. bbl.
January... |) | 756 T) 959 ~«T *) 1,269 2,077 1,012
February.. |) | 113 ) 984 | )2/5,640 1,032 ; 2,372 1,008
March..... ;) | 967 )2/7,500 1,286 ) 1,038 i 2,362 1,301
April..... |) | 772 ) 15054 2,102 iok7 | 2,658 1,055
May... ) 849 1,975, 1,293. - 1,905 1,313 ; 2,772 1,031
June...... | )2/18,100 1,164 2,104 {| 1,037 1,478 1,053 ; 1,931 1,273
July....6. |) i 921 2,060 j{ 1,038 1,813 1,046 1 2,765 1,043
August.... |) | 1,128 2,000 1,302 1,630 1,314
September. |) i 908 1,44 1,049 1,446 1,032
October... |) ! guh 1,649 1,052 2,409 1,268
November.. |) | 1,145 1,680 1,310 2,668 1,016
December.. |) - { 935 1,760 1,045 2,605 1,281
Total.. [2/18,100 111,232 22,572 | 15,389 1 23,696 13,709 17,736 i 7,723

1/ Volumes of gas. computed from occasional tests.
2/ Estimated.

239 > 35 -


OIL PRODUCED - THOUSANDS OF BARRELS PER YEAR

. F
aot \
ae
\ SYMBOLS:

‘A = GAS INJECTION STARTED

1B = GAIN DUE TO GAS INJECTION
aa C = ESTIMATED NATURAL DECLINE
a
aa A

BARRELS OF OIL PRODUCED
ad b— BO hTERe I
1908 To 1916

APPROXIMATELY 450,000

5.

1920 25 1930 1935 1940 145

FIGURE 7.- Production-decline curve, The Ohio Oit Co., Warnock project, Crawford County, III.




R.I. 3783

oil well is analyzed, and wells producing mixtures having the highest
oxygen content are withdrawn from the gathering. system, Either back pres-
sure is applied to the sand in oil wells with high air:gas ratios or the
gas-injection rate of the nearest injection well is reduced, Oil wells with
persistently high ratios are removed permanently from the gathering system,

The results of periodic tests that indicate the injection medium is
not explosive are reliable only at the time of the test. In southeastern
Illinois Orsat analyses of air-gas mixtures once or twice each month have
proved adequate; but, in addition, operators observe closely those operating
conditions that are apt to dlter the composition of the mixtures. Three
operations having important bearing on the alteration of air-gas mixture
compositions are the unexpected channeling of the injection medivm through
the reservoir from injection to producing wells, the withdrawal of produc-
ing wells from the gathering system for reconditioning, and the rise and
fall of fluid levels in cil wells. These conditions can be controlled,
resulting in an air-gas mixture of more uniform composition.

Oxidation of Crude Oil

The use of air, or air and gas, as the injection medium in air-injec-
tion projects probably has resulted in some oxidation of the oil in the
reservoirs, The time allotted for this investigation did not permit a
study to determine the degree of oxidation, but analyses of air-gas mix-
tures from 62 oil wells show that tlie percentage of carbon dioxide in the
mixture produced by. many of these wells was higher than would be expected
ordinarily, which indicates that oxidation of the oil may have occurred,
The results of these analyses are given in tables 5, 11, 17, and 23, High
concentrations of carbon dioxide in some of the mixtures produced on the
Henry and Warnock projects probably were due to the cumlative effects of
recycling air: and gas mixtures containing the inert gas.

Taylor and Smith reporteala/ that the resistance to oxidation of crude
oils studied by them decreased in the following order: Paraffin base,
intermediate base, and naphthene base. In the laboratory they also found
that when the crude oils were oxidized severely asphaltic materials and
gums insoluble in the oil were formed; and-in the presence of water, .the
oil emulsified more readily because. of.a decrease in interfacial tension
between the oil and water, Field studies 526/ however, indicate: that
oxidation of oil under field conditions is not severe.

Physical properties of the intermediate-base oils produced in the old
oil fields of Illinois may be altered over a long period of air injection,
but no evidence was obtained during this study which indicated that
oxidation of the oil has affected the oil-recovery rate.

i5/ Taylor, Sam S., and Smith, H. M., Summary of Experimental Data on
Laboratory Oxidation of Crude Oils, With Particular Reference to Air-
Repressuring: . Bureau of Mines Rept. of Investigations 3238, 1934,
11 pp. .

16/ Johnson, T. W,, and Taylor, S. S., A Study of Oxidation of the Oil in
Two Air and Air-gas Repressuring Projects: Bureau of Mines Rept.
of Investigations 3325, 1937, 2h pp.

239 -1-


R.I. 3783

The Ohio Oil Co. Plymouth Project

The Ohio Oil Co. is injecting air into the Hoing sand in the Colmar and
Plymouth oil fields of Hancock and McDonough Covnuies in west-central Illi+
nois. The Hoing sand is at an average depth of feet in the Colmar field
and averages 12 fect in thickness. One and one-ha!f miles southwest, in the
Plymouth field, the sand occurs at an average depth of 430 feet and averages
11 feet in thickness,

The Hoing sand in each field was subjected to vacuum in 1926, before
air-injection operations were begun, and a substantial increase in the rate
of oil production was obtained. Air injection, which was begun in the
Plymouth field in 1934 and in the Colmar field the following year, resulted
in still greater rates of oil recovery. Oil production from each field has
declined for the last few years at a rate exceeding the decline rate for the
period preceding vacuum operations; the production rate in 1943, however,
almost doubled that in 1925.

The distance between fields has made desirable the maintenance of sepa-
rate compressor plants, centrally located with respect to each field. The
old vacuum pipe-line systems were used, wherever feasible, for distribution
of air to the various injection wells. Although secondary-recovery practices
are identical, the available historical and operating data for each field
will be presented separately. All but 200 acres of the Colmar oil field,
with a productive area of approximately 1,600 acres, and the Plymouth oil
field, with a productive area of 410 acres, are included in the two projects.

The Plymouth project lies in secs, 19 and 20, T. 4 N., RJ 4 wW.,
McDonough County, I11., and sec. 24, T. 4 N., R. 5 W., Hancock County, Ill.,
and encloses a productive area of 410 acres. Oil wells are produced from the
southern and southeastern flank, near the crest of an anticlinal struc-
ture.17/ The structure also is productive on the northeastern flank in the
Colmar field, but Flooal8/ reported that the sand probably is not connected
between the two fields, A map giving the location of producing and injection
wells is shown as figure 8, There is no spacing relationship for oil wells
and injection wells, but oil wells generally are 440 feet apart.

History

Original development of the Plymouth oil field was begun in 1915, when
Peter Hamm well No. 1 was completed in the Hoing sand and flowed at a daily
vate of 280 barrels of oil. By the end of 1916 the field was developed com-
pletely. Initially the wells produced 2 to 280 barrels of oil daily and
averaged 35 barrels, but by 1925 the average daily oil production had de-
clined to approximately 0.7 barrel per well. In May 1926 vacuum wes applied
to the Hoing sand, and almost immediately the average daily oil production

17/7 Hinds, Henry, Oil and Gas in Colchéster and Macomb Quadrangles:
Illinois State Geol, Survey, Bull. No. 23, 1917, pp. 45-50.
18/ Flood, Millard H., petroleum engineer, The Ohio Oil Co., Robinson, Ill.

239 - ho -


R.I. 3783
INTRODUCTION

This report is one of a seriest,5,6/ concerned with presenting histori-
cal, development, » and operating data on secondary-recovery projects in vari-
ous States to stimulate interest in sound secondary-recovery programs. Pre-
ceding reports in this series have dealt éxclusively with descriptions of and
results obtained by water flooding in-three States, but no recent publication
of comparable purpose describes gas-injection!, practices. The authors in-
tend to present material relevant to the development and operation of gas-
injection projects in Illinois, with particular emphasis on those producing
from oil-bearing horizons that had been depleted to a point near the economic
limit of operation by past oil-recovery methods.

Most operators realize.that.the energy expended on the movement of
fluids, through gas-expansion- or gas-cap-type oil reservoirs to producing
wells must’ be’ supplemented. to. attain maximum recovery of the oil present.
Under, favorable conditions, many operators choose to maintain oil-propulsive

forces at or near their original magnitude by injecting extraneous fluids
into a reseryoir or recycling produced fluids early in the life of a field.

ing States during the last 40 years, but other old oil fields, and oil proper-
ties within those fields. which were partly exploited by secondary-recovery
methods, also may offer favorable opportunity for further development. To
encourage and aid operators in the development of gas-injection. projects in
the old oil fields of the United States, four projects have been described

in detail “in this report.
ACKNOWLEDGMENTS

This report was prepared under the general supervision of R. A. Cattell,
chief engineer, Petroleum and Natural Gas Division, Bureau of Mines,
Washington, D. C.,and N. A. C. Smith, supervising engineer, Petroleum Experi-
ment Station, Bureau of Mines, Bartlesville, Okla., and under the direct
supervision of Ludwig Schmidt, senior petroleum engineer, Bureau of Mines,
Bartlesville, Okla., and C. J. Wilhelm, supervising engineer, Bureau of Mines,
Franklin, Pa.

4/7 Taliaferro, D. B., and Logan, David, History of Water Flooding of Oil
Sands in Oklahoma: Bureau of Mines Rept. of Investigations 3728,
1943, 182 pp.

5/ Grandone, Peter, History of Water Flooding of Oil Sands in Kansas:
Bureau of Mines Rept. of Investigations 3761, 1944, 146 pp.

6/ Taliaferro, D. B., Keithly, C. M., and Jennings, Thos., Water Flooding
of Oil Sands in Illinois: Bureau of Mines Rept. of Investigations
3778, 194k, 23 pp.

u The term "gas injection” is used connotatively throughout this report

unless emphasis is to be placed on the type of medium injected.

239 -he


R.I. 3783 °
Results

The estimated cumulative oil production for the Plymouth project be-
fore the initial injection of air in February 1934 was 84.5 barrels per «
acre-foot, and the cumulative oll production during air-injection operations
to August 1, 1943,.was.65.9 barrels per acre*foot. An estimate of the oil
gained for a 4-percent decline in the rate of oil production.under vacuum
operations is given in table 19. Because of the difficulty of extrapolating
a decline curve for this project (sce fig. 12), the 4-percent decline rate
was adopted on the recommendation of engineers familiar with operations in
this field.

TABLE 19. - Qil-production statistics - Plymouth project

Qil production, bbl. =; Estimated oil
Year 4-percent decline Actual; gained, bbl.

ig3hly ee. | 20, 780 35,353! 145575
1935 oe . 213767 33,297! 11,530
1936 .. 20,896 3,738, 13,902
1937 6. i 20,060 | 34,097; 1h 237
1938 .. i 19,258 (| 50. 269) 11,011
1939 H 18,488 =| 28,56), 10,076
19ho i 17,748 | 287579 | 10,831
1941 | 17,038 =| 26 s792! 9,754
1942 16,356 | 25, ugle| 9,138
94327! 92260 | _1329h01 i,’ 780

Total .esececoese 181,551 2513651 109, 832
17 Last 11 months. 2/ First seven months.

Oil production by leases is illustrated graphically in figure 13. In-
sufficient evidence was available to explain the relatively poor response of
the Lyon Heirs and Hamm leases to air injection. Four of the first six in-
jection wells placed in operation early in 1934 were on Lyon Heirs and Hamm
leases. The initial injection rates were relatively high, ranging from
3,500 to 7,000 cubic feet of air per foot of sand dsily. Oil production
from the five. other leases during air injection exceeded that for the period
of primary vacuum operations.

From February 1934 to August 1943 approximately 692,500,000 cubic feet
of air were injected into the Haing sand at an average pressure of 28 pounds
per square inch. A Volume of 2,380 cubic feet of air was injected for each
barrel of oil produced, or 6,510 cubic feet of air for each barrel of oil
estimated to have been gained by August 1,°1943. The driving medium was in-
jected at an average daily rate of approximately 1,040 cubic feet per verti-
cal foot of sand exposed in each well, The estimated volume of oil gained
by the injection of air was 268 barrels por acre. The cumulative oil pro-
duction (on August 1, 1943) for all of the leases comprising this project
was about 1,600 barrels per acre. -

239 - 48 -


R.I. 3783

All gas-injection wells are old oil wells. In the early stages of the
project's development, the conversion from an oil well to!an injection well
was accomplished by cleaning out the shot hole and setting a burlep packer
(on 2-inch tubing) below the 6-1/4-inch casing seat and above the top
Robinson lens. This method seldom was. successful because the walls of the
old oil wells caved and prevented a tight seating of the packer, Only 4 of
the injection wells ere completed in this manner at the present time. The
tubing and oil strings were removed from 5 other wells, the oil strings re-
set without packers, and air and gas injected through the casing. The re-
mainder of the injection wells (12 wells) were “completed with 2-inch tubing
cemented in place, A normal completion of this kind included setting on
bottom a string of 2-inch tubing, which had the lower 10 to 20 feet perfo-
rated, and filling the shot hole with gravel to a point above the top perfo-
rations. A l- to 2-foot clay bridge was added and the tubing cemented with
6 to 8 sacks of cement.

Operating Practice

Three Ingersoll-Rand, horizontal compressors furnish compressed air and
gas for the Henry project. Two of the compressors have been converted from
two-stage to low-stage compression and compress only the return.air-gas mix-
tures from oil wells. The third compressor has two stages (11- by 5-1/2- py16-
inch); the smaller cylinder is used to supply air to injection wells on the
Jd. Randolph lease, and the low-pressure cylinder is used to compress air-gas
mixtures produced by part of the oil wells. A vacuum of about 18 inches of
mercury is pulled on the oil sand in most of the oil wells by the. low-pressure
cylinders at the three compressor plants, and the air-gas. mixture is dis-
charged to the pressure system at 60 to 70 pounds per square inch. Traps to
collect scale and water have been installed in the vacuum’ lines at the three
plants in addition to the customary water-trap installations on the discharge
lines of the compressors.

Initial injection of sir into the Robinson sand was begun in May 1934,
but the produced gas was not recycled until 9 months later, when the operator
determined that the air-gas mixture produced hy the oi1 wells was not explo-
sive. Since 1935 the volume of. air-gas mixture produced on the Henry project
has not been sufficient to supply all of the injection wells, therefore only
air has becn introduced into the oil send under the J. Randolph lease. Fuel
requirements of central power and compressor engines and losses in the reser-
voir have made it necessary to supplement the recycled mixture with air for 2
or 3 months each year.

The low injection pressures on this project have not caused excessive
channeling of the. injection medium thraugh the sand. One well on the J.
Randolph lease, where injection pressures are higher, has been disconnected
from the vacuum system because channeling could not be controlled.

239 - 23-


R.I. 3783

Excessive channeling of air through the more permeable sections of the
sand has occurred several times; but two corrective measures have been
applied successfully, and serious channeling of air to producing wells has
been overcome, One consisted of raising fluid levels in the oil wells as
high as 100 feet above the top of the sand, ‘Although the back pressure on
the sand obtained by controlling fluid levels was adequate for redycing
channeling, the operating practice required close supervision and was aban-
doned in favor of the method now in use. Under the new procedure back
pressure is maintained in the casing and on the sand face by installing 1/h-
inch brass petcocks in the 8-1/4-inch casing through which air-gas mixtures
entering the well bores are exhausted to the atmosphere. ‘The small-diameter
petcocks, which remain open, effect a back pressure by maintaining a maximum
or critical velocity of the air-gas mixtures that escape through then,

The operator reported that the use of air as an injection medium has
not affected noticeably the rate of corrosion of surface and subsurface
equipment. Before the injection of air into the Hoing sand, corrosion of
equipment was caused by hydrogen sulfide and water produced with the oil.

Orsat analyses of the air-gas mixtures produced to the atmosphere by
8 of the 42 oil wells were made on October 26, 1943. The tests were con-
ducted on the mixtures produced from wells located near injection wells.
Results of the tests are presented in table 17.

TABLE 17. - Orsat_ analyses of gas produced from oil
wells in the Plymouth field

i Percent by volume of sample
| analyzed

Lease | Well No. Oo j CO,
C. S, Aleshire .. eee I 5 16.8 i 1.0
W. A. Ruggles ... see | 6 18.7 a
Peter Ha eesecescseesceeceee | 2 17.4 8
DOe seveccvcvccrvvscveceenes | 8 17.0 i 1.0
Dow eee eeeees 4h 18.4 | ot
Do. seevee se ebeeeees | 17 16.1 | Led
Lyon Heirs sescccceccccccceeee | 6 18.9 i 3
Doe seceverseereerssesesses | w|i ! 1.0

General characteristics and the results of a distillation analysis of
a sample of crude oil taken from the oil and water separator on the Hamm
lease are given in table 18, The gravity of the oil is 35.4° A.P.I., and
the viscosity of the oil at a formation temperature (measured in June 1943)
of 68° F, is 63 seconds, Saybolt Universal, or 9.3 centipoises.

239 ~ 6 -


160
150
l40
30
120

[ DAAAUAAAA) IABALBAAD) ADAALIALAS LAARIRAAAS

S$ ‘ON 17390018 ‘W

v ON 173900158 "H

9-ON SUIZH NOAT

fI'ON SUIZH NOAT

21 ‘ON SUIZH NOAT

6 ‘ON WWVH ‘d

CI'ON WVHA

(ON WAH ‘d

22 ‘ON WAVH ‘d

9 ‘ON WAH ‘d

1-°ON 3UIHS3ITV—O

SON 3MIHS3TV ‘OD

g [oy ° °
2 2 i) N

4334 ‘13437 v3s 3A0ev NOILWA3713

40

2000

1000

$00

FIGURE I!.- Northwest-southeast cross section A-A' of Hoing sand, Plymouth oil field, Hancock and McDonough

HORIZONTAL SCALE, FEET

Counties, 111.


R.I. 3783

that of adjacent properties. A high oil recovery by primary methods of
production usually is indicative of a high oil recovery by secondary-
recovery methods.

DESCRIPTION OF FOUR GAS-INJECTION PRCJECTS IN ILLINOIS

Tide Water Associated Oil Co. Henry Project

Tide Water Associated Oil Co. has developed an air and gas drive on
700 productive acres in the north-central part of the Robinson field,
Crawford County, Ill. The oil-producing member is the Robinson sand, which
occurs at an average depth of 975 feet. The sand averages 25 feet in
thickness.

History

Most of the oil wells on the leases included in the Henry project were
drilled in 1907 and 1908. The wells produced initially at rates ranging
from 5 to 300 barrels of oil daily and averaging 75 barrels. The absence
of an active water drive in the Robinson sand and of large quantities of
gas associated with the oil accounted for a reduced daily oil-producing
rate of 4 barrels per well in 1911, The normal decline in the rate of oil
production was interrupted in 1919 by the application of vacuum (15 to 25
inches of mercury), and although it did not cause a substantial increase in
the oil-recovery rate the operation resulted in an increased yield of
natural gasoline from the solution gas and light hydrocarbon fractions that
were released from the crude oil. Vacuum was maintained on the sand after
gas injection was begun in May 1934.

As the chief propulsive force originally in the oil sand was supplied
by the expansion of gas liberated from solution, the rapid decline in indi-
vidual well-production rates indicates that the reservoir pressure was low
or that the oil was greatly undersaturated. High primary recovery of the
oil contained in the sand could not be expected, therefore, and less than
25 percent of the original oil in place was recovered before vacuum
operations were begun.

Characteristics of Oil Sand

Most of the oil wells on the Henry project were drilled before the
practice of taking cores had been developed and before the importance of
accurate information regarding the reservoir was recognized. Drillers' logs
and the analyses of cores from two wells drilled in recent years reveal that
two lenses are present in most wells and that a lenticular gas sand was
penetrated by half of the wells. The gas sand, when present, is above the
oil sand and is at an average depth of 900 feet. The gas sand is 2 to 12
fect in thickness. As the gas in the lenticular gas sand has been exhausted
and as the casing in all oil wells is set above the top of that sand, it has
been difficult to isolate it from the lower oil-productive lenses before
secondary-recovery methods are applied. The second and third lenses are at
depths of 945 and 975 feet, and their combined thickness averages 25 feet.

239 - 20 -


RI. 3783

TABLE 8. - Summary of operatfons for the Tide Water Associated Oil Co. Henry project, Crawford County, Ill.

average | | 1 | 1
injection @stimated | (Estimated iRatio of gas i Ratio of gas | Horsepower of
Gas pressure, | Average vecuun |Ratio of oil 1 area Cumulative oil jcumlative linjected to injected to | compressor
injected! lb. per | on oil wells, [wells to in- effected, , production, joil gained, foil produced, oil gained, priae
Year wicu. ft. | sq. in. | lb. ver sq. in.! jection wells | acres bbl. per acre jbol. per acrelcu. ft. per dbl. cu.ft.ner bbL movers
193he7 67,418 | qe] 8 1 “12.9 ' 130 | 25.6 l 8.3 ; 3, 760 TY 21,610 | 1h0
1935 91,891 | 35°C 8 | 10.1 190 i 73.2 1 31.1 | 2,760 5, 740 | 140
1936 169,747 | ug 8 | 6.2 305 ! 123.2 | 57-6 \ 4, 850 9,150 230
1937 ; 168,519 H hoo! 8g H 5.8 420 | 195.1 ' 107.1 i 3,350 4,860 | 230
1938 i 143,686 | uy & | 5.4 » 460 i 259.6 150.3 ' 3,180 4, 760 i 230
1939 ' 105,150 | yo: 8 | 5.4 i 465 : 307.2 | 177-7 ! 3,150 5,480 ! 230
1940 | 97,002 | 9) g i 5. 1 465 357.8 | 209.0 1 2, 7ho 4430 i 230
1941 i 100,299 | et 8 i 5.2 ; 505 409.6 i 2he.y i 2,770 4,280 : 230
1942 99,605 ; 330 OO! 8 5.2 ; 6350! 461.9 | 277.3 i 2,720 1,080 : 230
19433/ 72,162 | 35 § 43 +555 | 4g2.9 1298.6 3,330 4, sho : 230
Total + {2,115,479 ' 1 | | t92.9 "298.6 |
Average. | ho | g i i | 3,230 L 5,340 I
1/ Computed from occasional tests. 2/7 Last 3 months of 1934 3/ First 7 months of 1943.

239 - 29 -


Zao

R5W. i
l: R4W.
iz SYMBOLS
as
Sie & @ OL WELL
fo rs NOTE: ALL FARM LINES ARE
jo ©. NOT SHOWN FoR THE |g ABANDONED OIL WELL
g ig CHAS. ALESHIRE ANO
q o WA RUGGLES FARMS. + ORY HOLE
i é
4 INJECTION WELL.
gs Ly + & INJECTION WELL
4 fara CONVERTED TO
warucces S| * 8 OIL WELL
os £9 tls, 78
4 3 “3 19 20
t $ 2 44 +
8 4 2 S| 4 Lyon Hes Ae
£ 4 s 4 e 4 4
% » nm S/S g 8
44 2 PETER HAMM R SMITH
CHAS. ALESHIRE, s a & ¢
7 4
% ds & ' 5 Ro oole + Fy
2 e e
+ HS 8 1% & ste $s ste gs
H. STODGELL
Moc. SMITH
eye & 31/4 3 8
tie ff g13 8
9 500 1000 2000 3000 4000 5000
SCALE: FEET

FIGURE 8.- Map of The Ohio Oi! Co. Plymouth air-injection project, Hancock and McDonough Counties. III.,
duly 31, 1943.


RI3W.

ARKANSAS FUEL OIL ca
ee .
A 8 2 $ 9 ¢
. e ele e¢ 2
&s s8 & 2 3/2? 2 S13 ¢
a #8 4
J. DRAKE eo #6 8 A oop 4+ — E. BIRCH
(Geno OF. CO. €. STIFLE = @ e e e 2
o 2 3 8
8
° e 4129 £2 @8 2% ¢ HP DRAKE 7
9 lo =
¢ 8 3 8 ¢)4 9 $718 4 :
a a’
a el 4
Pa) 8} 4 Bea &
T RANDOLPH P ORAKE H. HENRY
e e e e a e
$4 $ Ce ad #}/2 9 2 3 3 ¢
°
#%8 2 8 rN $ t]2@ 2 £8 & 4 S$
a
a rN
J. WATTLEWORTH o 8 o]8 8a ry
8 . IKEMIRE
iJ & 5 4 2 3s t]2 4 3
ry e|/?% fe ¢ & &
10 6 u 9 7 e 3 5 ‘e
T % symBots
7 ° |
be 3/2 © om wet
N. gf ABANDONED OIL WELL
ae a . g DRY HOLE
20 s ' 2 & INJECTION WELL
5.. s& ABANDONED INJECTION WELL.
£ 3 (CENTRAL PUMPING POWER
J. Hie @ COMPRESSOR PLANT
Ae onto on. co
o%
& ¢
16 15
we
a 8
. ° 500 1000 2000
:
SCALE: FEET
+ 4% $

FIGURE 3.- Map of Tide Water Associated Oi! Co. Henry gas-injection project,
Crawford County, I}1., July 31, 1943.




R.I. 3783

TABLE 9. - Development of The Ohio Oil Co. Wernock project

Estimated | Active gas-injection wells: Active oil wells, i i
area of- | i Spacing ,2/ H Spacing, 1/ | Compressors!
fected, | | acres per ecres per in * |
Date acres Number i well Number” well operation Remarks
Jan. 1, 1937} 20 6 | 2105.0 83 | 7.6 1 8 oil wells were converted
: | | | | to injection wells and 2
+ | H injection wells converted
| to oil wells in 1936,
Jan. 1, 1938; 280 7 90.0 82 7.7 1 11 oil well was converted
| | to an injection well in
| i 1937.
Jan. 1, 1939| 300 8 } 78.8 81 7.8 | 1 1-oil well was converted
| | to an injection well in
| | 1938.
Jan. 1, 1940: 300 8 | 78.8 81! 7.8 | 1
Jan. 1, 19k1/ 300 8 78.8 8 | (7.8 | 1
Jan. 1, 1942| 300 9 | 70.9 80 | 7.9 1 1 oil well was converted
i : | to an injection well in
| | igh.
Jen. 1, 1943 300 & | 78.8 81 | 7.8 1 j1 injeetion well was con-
| i H verted to.en oil well in
; Igke.
Aug. 1, 1943 300 j_ 8 78.8 { 81 | 7.8 1

1/7 Computed for a productive crea of 630 ccres.

259


ZhaA

4 BINNIE

TC PAYNE

90
> eee 01 lf

}—85,
~

+85

90 —T
C4

on

=>

AC. WEAR

\v

M.D.WEAR

KEY

—90— CONTOURS ON TOP OF HOING SAND,
IN FEET ABOVE

ELEVATIONS
LEVEL

\
SCALE: FEET

7 =

2
&

U

4
a
ve
Ro CLARK
16
wm CONN
J JARVIS S| SS
oT

EH. HENDRICKS

ml
SA

D\ expe

2

}—5-

C.F VALENTINE

88
TM. MC FADDEN

9°

~~ 85

JMMYERS A/C 1

M.MYERS A/C
x MEY

JM. WEAR,

=

WwW. CULP

FIGURE I6.- Structure map of Colmer oil field, McDonough County, 111.







RoI, 3783

TABLE 6. - Qhemical and physical properties of crude oil produced on Tide
Water Associated Oil Co. Henry project from Robinson sand

GENERAL CHARACTERISTICS

Specific gravity, 0.849
A.P.I. gravity, 35,2°
Color, greenish black

Sulfur, percent, 0.19
Saybolt Universal viscosity at 100°F., 47 sec,
Saybolt Universal viscosity at Sh°F,, 52 sec.

DISTILLATION, BUREAU OF MINES HEMPEL METHOD

Distillation at atmospheric pressure, 752 mm. First drop, 26°C. (79°F.)

Fraction Cut at- Per- Sun, Sp. er., CAP.I., CsI. SU. Cloud
No, °c, “°F, cent per- 60/60°F, 60°F, visc., test,
cent 100°F, OF.
1 50 122 18 1.8)
2 7 167 2.3 4.1) 0.659 83.2 -
3 100 «212 5.4 9.5 -715 66.4 19
4 125 257 6.1 15.6 +739 60.0 al
5 150 302 5.1 20.7 +758 55.2 23
6 175-347 4,9 25.6 “TTT 50.6 25
T 200 392 04,7 50.3 “195 46.5 27
8 225 437 4,8 45,1 812 42.8 30
9 250 482 5,8 ho.9 826 39,8 31
10 275 «4527 6.4 47.5 839 37.2 32
Distillation continued at 40 m,
1 200 392 2.8 50.1 0.852 34.6 35 ia 15
12 225 a7 5.6 55.7 .860 33.0 35 47 35
13 250 482 5.3 61.0 871 31.0 37 60 50
14 275 587 5k 66,4 883 28.8 39 95 65
15 300 572 5.9 72.3 895 26.6 he 180 90
Residuun 27.6 99.9 0.954 16.8

Carbon residue of residuum, 7.5 percent; carbon residue of crude, 2,1 percent.
Base of crude: Intermediate

APPROXIMATE SUMMARY

Percent Sp, gr. °,.P.I. Viscosity
Light gasoline 9.5. 0.691 13-3
Total gasoline and naphtha 30.3 0.742 59.2
Kerosine distillate . 10.6 «820 Wi .2
Gas oil 13.3 848 35.4
Nonviscous lubricating distillate 9.9 .862-,88h 32.7-28.6 50-100
Medium lubricating distillate 6.6 .88h4-.898 28.6-28.1 100-200
Viscous lubricating distillate 1.6 .898-,901 26,1-25.6 Above 200
Residuum 27.6 954 16.8
Distillation loss ol

239 - 27 -


45) G7) GD 61) G3 65) 6? C9 E) 63 5 69 69 @) (3D)

0 eeeeveseeeeee ge
On ¥} I /)
ENG (My

ONY \ |
© ‘ i"

@) VS .
52 ay f ay

(5) SS { J :
(6)
85 Ss f° |, ~
a) mas N \
Boa

R.14WI RI2W. RIIW. ‘

ee r —
9o— SN 6
CS —— N
eo
ee i
ea | — — T
Q2—+ 5

e+ a

FIGURE 1.- Map of Crawford County, I11., showing location of gas-injection projects
in the Robinson field, July 31, 1943.


R.I. 3783

TABLE 10. - Volumes of gas injecteal/ and oil produced_by months - The Ohio Oil Co.

Warnock project
(Pressure base, 14.4 lb. per sq. in. abs.; temperature base, 60° F.)

l 1936 | 1937 i 1938 1939
Gas i Oil! Gas [oily Gas Oil Gas Oil
injected, produced, | injected, | produced, | injected, produced , injected, produced,
Mou. ft. bbl. | Mov. ft. | bbl. | Meou. ft. bbl. Micu. ft. | bbl.
January... | | 1,872 I 1,144 i 725 1,330 2,201 | 873
February... i {  1,69h | 952 770 1,031 2,005 | 799
March..... H | 1,931 | 99h | 992 1,030 2,378 | 770
Aprile... | 645 | 1,0kk | 1, 52h | 1,288 | 2,292 |  gho
May.eresee 125 1,023 | 961 | 1,358 i 2,102 1 1,081 1,279 749
JUNC. sees 195 82h | 789 | 1,106 | 2,076 | 1,085 14g 757
July...... | 1,093 | 833 | 1,237 | 1,380 | 2,108 1,359 1,345 | 957
August.... | 1,595 {| 1,038 | 1,111 =| 1,094 1 1,767 ' 1,117 1,311 ! 756
September. | 1,387 | 832 1,124 | 1,096 | 1,872 | 1,212 {1,261 951
October... 1,739 1,078 | 1,107 1,365 : 1,479 | 1,414 | 689 ; 75h
November... 1,677 e820} “8L5 1,088 =| vor | 1,176 | 1,235 | 757
December... 1,026 80 666 | (1,097 (1,922 11,396 1,185 | 952
Total.. [ 8,337 7390 i 13,982 {15,718 18,414 (a Sr 18,520 9,925
See footnotes on page 35. y
239 - 3h -


+ 3183,

AIR-GAS-INJECTION OPERATIONS, CRAWFORD COUNTY, ILL.

Shown in Figure 1

REFERENCE MAP NO. COMPANY LEASE OR PROJSCT. EYERRNCE MAP NO, COMPANY LEASE OR PROJECT
1. Brenneman & McDonnel ‘Kirtland 39 Tide Water Associated 011 Co. Due No. 1
2 Mabutska 011 Co. 4o do. Due No. 2
3 ‘Te Onto O11 Co. ry doe Mann Ko. 1
y Miagara 011 Corporation Stifle ye Bell Bros. Maxwell
5 Mae Vator Associated O11 Co, J. Randolph 43 do. Daron Hotre
6 Kewanee O11 Co. Headley - Chalon ny Gheuvront & Brown Oil Co. Robinson
1 Brenneman & KeDonnel Wokensan 45 Kovanee 011 Cor Headley
8 Tide Water Associated O11 Co, stifle Ho. 1 46 Dinenoor O41 Cor Grogan-ifonry-Randolph
9 The Obto O11 Cor Bavarde Mw Tae Ohio O11 Cor Drake
10 Mahutska Clark 4s ‘Mde Water Associated O11 Co. Wattleworth - T. Randolph
un Dinanoor 011 Co. 4g Dinemoor 011 Cor 8. Wilks
12 Tae Oho O11 Cor 50 Mde Vater Associated O11 Co,  Tkenire
3 Mae Vator Associated O11 Cor a dow B. stifle
aw do. 52 Axeaneas uel O11 Cor Tkentre
15 dow Clark 53 Mahutska O11 Co. Shire
16 Te Ohio O11 Cor witein ” Mde Water Associated O11 Go, P. Drake
q do. Arnold 5 do. Henry
as Mabutska 012 Co. Price 56 Arkansas Tuel 011 Coy Drake
19 Tide Water Associated O11 Co. a7 ‘The Ohio O11 Co. Hill - Stents
20 Kewanee 011 Co. 58 Arkansas Puel O11 Co. McClain
a ‘The Ohio O12 Co, 59 ‘Tide Water Associated O11 Co, Culver
Ed Wabuteka O11 Cor 60 Bell Bros. mn
3 American O11 Development Co, Wall ~ Short a Tovanee 011 Cor Curtis
au Me Ohio O11 Woodvorta 62 Belt Bros. Jonason
25 don Wood 6 Tide Vater Associated O11 Co. Howard
26 Kewanee O11 Co. Shilte oe American 011 Development Co. Wood
eT Tide Water Associated 011 Co. Birch 5 dow Athey
28 dow Murphy 66 ‘The Ohio O11 Co. Lewis - Fawley
29 do. Good 67 ‘Tide Water Associated 011 Co. Tracey
30 ‘The Ohio O12 Co. Siler 68 dow Barrick No. 3
Be fo. Prior 6 Tue Obie O11 Cor Witeon
32 dow Shire TO ‘Tide Water Associated O11 Co, Horning McCane
3B Kewanee 011 Co. Hooker n dow Meserve
” dow Martin rr do. Conrad
35 J. D, Toomey Retate ‘Highsmith - Kills B do. Wewlin
36 Manateka 011 Co. Cariton TM to.” doatin
7 Kewanee 011 Co. Wetght 6 do. Sankey
38 ‘Mde Water Associated 011 Co, Dennis 76 dow Correll
--

239




RAL. 3185

TABLE 2, = Aotive gus-injootion operations tn Tiiinots (cont'd.)

Suly 32, 1985
Sand Location Company Tease or orofect Number Ol well Tnjaotion nedion davorage daily of
Tame ‘Tverage Iverage  Tomnty” Legal desoription of Total Number Type Average Average fore a
depth, thiol Seotion Tom Bange tnjoo- umber af- injection volume after
feat” oss, ap ‘ton Fectee
feet wile
Robinson field
Robinson, 950 30 Crawford = 29 7h wm ‘Tide Water Asso = Horning- 7 30 2 7 3 Air 6 U5 7 16 7 1936
Gated O11 Co, Movane
De. 90 do. 18 Th 1am to. Rrvicx 10010 a dbo Arana LS 2 8 9 1 1936
Yor oe
a ae) ® on em te. Correll 12035 a 6 3 hr 110 9 5 B 6 A926
De, 95030 to. 10 wm * Newlin 5 2 1 2 2 190 2 & 8 2 1926
>. ced 9 wn Weserre 350100 ‘6 0 160 = 19 » we 1906
De. 90 50 fo. Gand 10 ran a. Conrad = 10020 3 wo S 160 2 10 us 8 1926
De. 0 50 fe, 10 ran fo. Avetin 40-70 2 9 6 160 5 n 38 8 1926
Doe 950 ~” doe 0 wn de. ‘Sankey lo 15 a 5 2 to, 125 20 5 Ba 3 1926
totale: 10,0 5,901 I Ts Loy Bee Te Ter Tas
selen field
Bete 75 US in The Texas Co. Salen 6,355 3,912 Wdt/ 50 t/a 30000 7,580 y Y 199
aur Vases 1,800 15 am WAR/ 10 al/ Y ¥
Totals: th iss . aay 7,580
casey 19025 Cumberland 15 108. 10K Bal Brees queen ® 6 5 bh L we 2 y ww 1se8
Totaler 8 5 5 ah 7 2 18
Malpole field
du Vases 3,075 20S amtlton 27 and 5h, 63. 68, ‘Tae Toxas Co, Warple 320. & a 00 158 680M Anorease, re
puis 320 é 3 OS 158 60 56
2/ Rotimted, Q/ Information not available
O11 production for the affected wells only. Estimated reservoir volumes produotive:
x 7 x Walters renft.
Y/ 3 tape soaee, Syprese
Weiler
I 2 Aapat nenes, Beet
dex Vases =
5/ Estimated reservoir volunes affected: Omer
er = 176,800 aorenfte Yeclody
Paint creck = "62,150 acrecfts 765.900 eore-fe
tae = _UBLS0 eorentt,
Total 265,100 aore-fee 10/00 tops snes.

270 Anpat ones,

‘720 protactng sone.
-19-

xe


R.I. 3783
Sumnery

Information regarding all gas-injection projects active in Illinois on
July 31, 1943, is summarized in table 2, which includes information on the
Dinsmoor Oil Co. Mumford project, which was developed in 1921 and was the
first successful gas-injection operation in the State. Complete data were
not available for the two lergest projects, in the Louden and Salem oil

ilelds.

Gas-injection projects in the old oil fields comprise 13,788 acres; 42
percent (5,832 acres) have been affected by air and air-gas mixtures intro-
duced into the oil sands through 279 injection wells. By July 1943 these
projects had been in operation for an average of approximately 9 years and
were producing oi] at an average rate of 1.4 times the average rate for the
period immediately preceding gas-injection operations. A maximum rate
usually was obtained 1 to 18 months after initial gas injection on a fully
developed project; depending on the injection rate and the degree of control
over excessive channaling through the oil sands of the medium injected. The
maximum oil-producing rate after air and gas injection was begun averaged
1.8 times the average rate for the period immediately preceding gas injec-
tion. Approximately 2,400 cubic feet of air and gas were injected into oil
sands for each barrel of oil produced in the old fields; and about 8,000
cubic feet of air and gas were injected for each barrel of oil estimated to

have been gained by August 1, 1943.

More systematic gas-injection projects in the stripper fiélds have been
developed in the Robinson, Bridgeport, Colmar, and Plymouth oil fields. The
quantity of oil gained in these fiélds by projects that have been operating
9 or 10 years is not spectacular when compared to results obtained by
successful water-flooding operations. Development costs for gas-injection
projects in the old oil fields of Illinois have been so low, however, that
profitable operation has been assured over a longer period than the life
expectancy of an average water-flooding project. Development expenditures
for well-organized projects in the old oil fields of Illinois did not ex-
ceed $50.00 per acre before the present. World War, but in 1943 material and
labor costs would increase the investment for the development of similar
projects. The low development costs are attributed chiefly to the absence
of extensive drilling programs which ordinarily are necessary for the proper
development of water-flooding projects,

Oil-producing companies usually agree that because of lack of uniform
permeability and the irregular distribution of oil sands, and the unusual
local variations in the oil saturetion of the sands, the general application
of secondary-recovery methods in the old southeastern Illinois oil fields
would not result in a profitable recovery of mors oil. A complete study
rarely can be made of the applicability of gas injection to an oil property
in en old oil field. A proper evaluation would include consideration of the
analyses of core samples of the oil sand, and these seldom are available.
Wehn the results of core analyses of the sand are not available assumptions
may be made regarding the probable success or failure of secondary-recovery
operations by comparing the oil productivity of the property in the past with

239 - 1 -


R.I. 3783

The authors are greatly indebted to the companies and individuals
conducting gas-injection operations in the State of Illinois for their
active cooperation in supplying information on which this report is based.
Special recognition for helpful information and assistance is due to Ivan
G. Burrell and Millard H. Flood, The Ohio Oil Co., Marshall, Ill., and to
R. A. Wilson, Tide Water Associated O11 Co., Mount Carmel, Ill.

Special thanks are given to D. B. Taliaferro, petroleum engineer,
Bureau of Mines, Bartlesville, Okla., who was responsible for preliminary
organization of the work involved in this study.

The writers gratefully acknowledge the assistance of the following
members of the Bureau of Mines for review and constructive criticism of
the manuscript: C. B. Carpenter, Dallas, Tex.; D. B. Taliaferro, Bartles-
ville, Okla.; and Sam Ss. Taylor, Franklin, Pa.

J. R. Eaves and W. 0. Smith of. the Bureau of Mines, Bartlesville,

Okla., assisted materially in compiling and preparing most of the data
presented,

HISTORY OF GAS INJECTION

Records indicate that the injection of a gaseous medium into an oil
reservoir to stimulate the oil-recovery rate first occurred in 1903 in the
Macksburg field near Marietta, Ohio.. I. L. Dunn introduced gas through a
well completed in the Macksburg 500-foot sand for a 10-day period at a pres-
sure of 45 pounds per square inch. When the gas was released from the sand
the well pumped much oil. The method was demonstrated commercially by Dunn
in 1911 on the Wood farm near Chesterhill, Ohio, where air was injected
trhough a well (completed in the First Cow-Run sand) at a rate of 150,000
cubic feet per day and at a pressure of 40 pounds per square inch. Within
a@ week the oil-producing rate of surrounding wells had increased. The use
of compressed air as an injection-medium was extended to other parts of the
property, almost doubling the oil-producing rate 2-1/2 years after the air
drive was begun. The air- and gas-drive method developed by I. L. Dunn and
two associates, 0. C. Dunn and H. E. Smith, sometimes is referred to as the
"Smith-Dunn" or "Marietta" process.

The initial success of the gas-injection process on the Woog farm led
to its use in other oil fields in Ohio and West Virginia. tewis8/ reported
that by 1917 approximately 4,000 oil wells had been affected by the injec-
tion of air and gas. The method was extended to Pennsylvania, Illinois, and
the Mid-Continent area during the years immediately following the First
World War.

87 Lewis, J. 0., Methods for Measuring the Recovery from Oil Sands:
Bureau of Mines Bull. 148, 1917, 128 pp.

239 -5-


R.I. 3783

TABLE 16. - Volumes of air injecteal/ and oil produced by months on.
The Ohio Oil Co. Plymouth project (Cont'd.)
(Pressure base, 14.4 lb. per sq. in. abs.; temperature base, 60° F.)

1939 19ho 19k1 i ighe i 19h3
Air Oil Air Oil Air} Oal Air Oil; Air Oil
injected, iproduced, , injected, produced, injected, iproducea, jinjected, produced, | injected, Iproduced,

Meu. ft.; bbl. | Mou, ft. | bbl, IM ou. ft.! boi, IM cu, ft.! bel. ‘Mou. ft.| ddl.

January. 5,100 i 2,029 No, . 1,825 y ' 2,313 ~«!) 2,415 26,000 1,719

February. |) | 2,103 ) 25157 ) i 2) Uh 1), | 2,031 5,561 1 * hy

March... i) | 2,565 — |)2/57,800 2,598 |) | 2,293 )2/26 000} 1,920 6,727 | 2,390

April...) | pace I) 2,482 |) | 249i |) | 933 6,408 | 13939

Mays eeeee ') | 2,755 |) | 2,673 j) 2,418 6,526] 2,512 | 5,641. | 1,907

gune.....})2/60,500 | 2,417 p 2,260 2/78, 000; 2,438 ) 1,833 | 6,279 | 2,406

July... |) | 2,360 6,362 2,466 ) ' e160 (|) 1 2,075 . 5,707 | 1,835
August... |) 7; 2,586 |) | 2,613 1) fem |) | 2,543
September |) 230 |) i 2372 1) 1 13993 | )2/45,500} 2,485
October.. } “2,509 |)2/31,500 | 2,550 1) 1 2,238 (|) 1,954
November. 2,463 |) | 2,230 |) 1; 1,94k |) 1,656
December. |) 2,125 |) 2,353 I). | ei2kg i) [2,139

Total. 65,600 [20,504 | 75,662 28,579 78,000 26,792 | 78,026 125, ho4 G2 ,323 113,940

1/7 Volunes of air computed from occasional tests. 2/ Estimated.

239 - 45 -




R.I. 3783

extraction of gasoline from the natural gas produced with the oil, have
been included in compressor plants to supply either air or gas under pressure
for injection into the oil sands.

Air- and gas-distribution systems usually include pipe and fittings
salvaged from the normal accumulation of used equipment in old oil fields.
Low injection pressures, ranging from 20 to 190 pounds per square inch,
make this practice possible. A few operators have reduced development costs
by changing gathering-line -systems , used in vacuum operations, to distri-
bution lines for the injection medium. The saving realized is not large,
but steel is conserved. Most air- and gas-distribution lines consist of
2-inch pipe and fittings, but larger projects, such as those in the Colmar
and Plymouth oil fields, are equipped with trunk lines of 3-inch pipe laid
through the center of the project, and air or gas is delivered to injection
wells through 2-inch lateral lines connected to the trunk lines.

. Compressed air or air-gas mixtures are used as the injection medium on
most projects in the old oil fields, and some provision is made to reduce
the moisture content of the gas after compression. The presence of moisture
in the injection medium not only stimulates the rate of corrosion of pipe
and fittings but forms an emulsion with oil that has leaked by compressor
rings end may plug the sand face in injection wells over a long operating
period. In the winter, when atmospheric temperatures below freezing are
common, the accumulation of water in distribution lines may cause much
difficulty; therefore a nipple and valve usually are installed at low points
in the lines, and the water is blown périodically to the atmosphere. On
most projects the provision made for condensing and removing moisture im-
mediately after compression of the gas consists of a 2-inch riser pipe 10
or 15 feet long on the discharge lines of the compressor. Moisture con-
densed by a reduction in temperature between the compressor cylinder and
the vertical pipe is trapped and discharged from the line. Radiation of
heat alone seldom reduces the temperature enough to cause appreciable con-
densation at the compressor plant, and additional traps at points more
distant from the plant frequently are necessary. The temperature of the
compressed gas can be reduced more satisfactorily by passing the gas through
water-cooled coils, This method of cooling is being employed with. good
results by The Ohio Oil Co, on the Warnock project in the north central part
of the Robinson field, :

The calculated maximum percentages of water vapor that can exist in gas
at various temperatures and pressures are shown.in table 1. The celcula-
tions were based on the following formyla:,

Ww
S=100P.,

where S = water vapor existing in the gas, percent;

P,=-vapor pressure of water at the temperature of the compressed gas,
pounds per square inch;

Pm= pressure of the gas and water-vapor mixture, pounds per square
inch absolute.

239 - 10 -


R.I.. 3783
TABLE 4. - Volumes of gas injectea=/ ana. oil. produced by months - Tide Water Associated Oil Co. Henry Project

(Pressure base, 14.4 1b. per sq, in. abs.; temperature base, 60°F.) (Cont'd. )
[ 1939 I 1940 I __19h1 i 1ghe 1943,
Gas oil Gas | (G1 | Gas .;} O11 Gas “Oil Gas Oil
injected, |produced, | injected, [produced ,! injected, | proaucea, | injected, |produced,| injected, | produced,
M cu. ft. bbl, iM.cu. ft.: bbl. i{M cu. ft. bbl. Mon. ft. bbl. Mcu. ft. bbl.
January. | 648s 12,735 «TY 2,77, 8,029; 3,110] ) 3,007 9,037 3, 3eL
February.| 7,940 | 2,520 | )2/2h,300| 2,457 i 7,282! 2,663 |:)e/25,980| 2,852 8,900 2,848
March....| 8,800 2,777 | ) 12,761 | 8,129) 3,104 i y 3,068 10,013 3,213
April....{ 8,471 2,805 8,022| 2,711 7,759; 2,868 | 8,597| 2,782 9,679 | 3,02
Moy.eeees, 8,852 ©] 3,017 |) | 2,996!) | 3,048 |) 2,938 10,075 | 3,143
June... 9,620 | 2,726 ) 3,003 |i) ! 2,777 |) 2,851 11,160 | 3,009
duly.. 9,570 2,836 ) | 3,236. N i 3,025 |) 3,029 13,298 3,124
August...| 8,933 | 2,793 ‘| )2/64,680) 3,180 |) '2/69,100/ 3,003 )2/65,028| 3,016
September| 8,820 | 2,934 |) | 3,004 ) | 3,023 |) 3,180
October..| 8,885 3,027 ) | 3,196 i i 3,255 |) 3,319. |
former | Ss Lose ee he te tl else
December, A A | 207: | 3s A
Total. [105,150 133,300 . | 2/97,002'35,402 | 2/100,299 | 36,278 2/99 605 |36, 614 72,162 | 21,682

1/7 Volumes of gas computed from occasional tests.
2/ iBstimated,

239 - 25 -




R.I. 3783

prepared from the results of analyses of samples cored with oil in! the
McFadden well No. Q-10 is shown in figure’l4. It is believed that similar
sand characteristics exist for the Hoing sand in the Plymouth oil field.

Development

A surface map.of the Colmar project (sée fig. 15) shows the locations
of producing and air-injection wells on.duly 31, 1943. Figures 16 to 18
give maps and cross. sections of the Colmar field. Air-injection patterns
seldom are complete, and never are repeating because the leases comprising
this project were not fully developed by drilling. The complete pattern,
when it occurs, ‘is an inverted five-spot, with the injection well in the
center of four oil wells, The injection well is 440 feet from each producing
well in the pattern.

Development, of the Colmar project was begun more than a year after the
first injection of air into the Hoing sand in the Plymouth oil field, and the
operator's experience with high injection rates and their detrimental effects
on the sand in that field resulted in the use of lower initial injection
rates in the Colmar field. Hendricks well No. 32, an old oil well, was
chosen as the first injection well, and air was introduced into the Hoing
sand through it.on July 2, 1935, at a daily rate of 14,000 cubic feet. By
the end of the year 46- injection welis, spaced: 30.9 acres per well, were in
operation, Annual development of the Colmar project to August 1, 1943, when
the number of injection wells was reduced to uy, with a spacing of 32.3 acres
per well, is summarized in table 21. .

Well-Completion :Methods

Most of the oil- wells in the Colmar project were drilled in 1914. and
1915, and the completion practices were similar to those described under the
Plymouth project. Three wells were drilled after 1935, in addition to those
drilled during 1943, in an area of approximately 70 acres for the pilot
water flood begin in June 1943.

All of the air-injection wells are old oil wells that were converted
to injection wells, in the same,manner as for the Plymouth project.

239 - 51 -


RI. 3783

TABLE 1. - Maximum percentage of water vapor in gas
(Pressure base, 14. Ib. per sq.in.abs.)

Gage pressure, | Temperature, OF.
lb. per sq..in. [ 32 [50 | 600.1 70 | 60 | 90 i 100 % ted | 1hO | 160 | 180
0 VO.6L [L.A 1. 78/2.52 [5.55 4.86]6.60 11.8 [20.1 153.0 [52.2
10 36 | 73 /1.05/1.49 [2.08 |2.87/3.90 | 6.95 11.9 119.4 {30.8
20 +26! .52] «7511.06 |1.48 12,0312.76 | 4.93 | 8.41/13.8 [21.8
30 220} 640] .58) .82 1.24 1.57)2.14 | 3.82] 6.51)10.7 [16.9
ko 016| .33} .47]-.67] .93|2.29|1.75 | 3.12 | 5.32] 8.72/13.8
50 1b} 628] 40] 656] .79]2.0911.48 | 2.63] 4.49] 7.357)/11.7
60 212] .2h} 34! .49] .68| .oh!1.28 | 2.28 | 3.89] 6.38]10.1
70 o11] .21] .30) 643] .60] .83}1.13 | 2.01 | 3.43] 5.62} 8.90
80 209} 619] 627] 639] .54) .74/1.00 | 1.80] 3.07] 5.03] 7.86
90 09! 617] .251 235] .49! 667] .91 | 1.62] 2.77] 4.55]. 7.20
100 : 208} 616} .22] 632] 4b] 62} .83 | 1.48] 2.53] 4.15] 6.56
150 a 605) 612} 616] .22] 31) 243] .58 | 1.03} 1.76] 2.89] 4.57
200 «04 | .08 | .12! 17 “i | «33| 4h | ..79 | 2.35; 2.22] 3.50
Well Spacing

No’ spacing relationship exists for oil and injection wells in the old
oil fields. Densities of injection wells on systematic projects. range from
20 to 35.acres per well. In the Robinson field old’oil wells usually are
spaced 40 feet apart along the boundaries of leases, the interior. of which
is undeveloped by drilling. These undrilled areas and the arrangement of
oil.wells in irregular lines preclude the. development of repeating well
patterns, vote .

Well-Completion Methods

The conversion of. an oil well to an injection well includes the replace-
ment of corroded casing with good pipe, cleaning out the shot hole, and either
cementing 2-inch tubing above the oil sand or setting it with a tubing packer
in the lower part of the casing, The tubing, extending to the bottom of the
well, contains a perforated section } to 20 feet in length and opposite the
sand face, The oil sand in injection wells is not shot. A few operators
have converted old oil wells to injection wells by cleaning out the shot
hole, running a burlap packer on 2-inch tubing into the well, and setting
the packer. in the open hole below the casing. ‘This practice usually is not
satisfactory in Illinois because well bores in the old oil wells have caved,
making it difficult to isolate the oil-producing zone with a packer in the
open hole,

Use of Air-Gas Mixtures

Vacuum has been. maintained on tiost of the oil sands in southeastern
Illinois for over 30 years, and large quantities of natural gas obtained
by its use were sold or wasted before operators considered installation of
gas-injection projects. advisable. In general, air injection.was adopted
in conjunction with vacuum operations, and although only small volumes of

239 -h-


OIL PRODUCED - BARRELS PER ACAE- FOOT

2001
v0} OIL PRODUCED BY AIR INJECTION FROM
JULY 2 1935 TO AUGUST | 1943
Z OIL PRODUCED BY PRIMARY AND VACUUM
LA OPERATIONS UNTIL JULY 2 1038
“ 7
—
u
‘ —
20)
Cc) ZZ
r 8 Yt
z| q| |
Z| 7
40 g < 3 I al Fy z 7
a 7” «| 3 4] 4 q| z By a

a 9 ¥ 4] z « <q S| S| «| < a Fr q q z

SEEGER CECE CECECECECECECECECECECE
zof-3| 3 z Fy Ze: 4 Fy 5 Fy q $ a z 5 8 4

x 3 oY) z r) S| z 5 x Zz 3 5 re 4 6 J q Zz

FS VA 4 WA V4 2 WA WA IW WA WA WW dV V4 VW VA
°

FIGURE 20.- Comparative

oil production by leases

before and after air injection, Colmar project, McDonough County, Il.



RoI. 3783

TABLE 21. - Chemical and physical properties of crude oil produced.
on The Ohio Oii Co, Colmar project from Hoing sand

GENERAL CHARACTERISTICS

Sulfur, percent, 0.25 Specific gravity, 0.846
Saybolt Universal viscosity at 100°F., 48 sec. A.P.I. gravity, -35.8°
Saybolt Universal viscosity at 68°F,, 60 sec. Color," greenish blaek

DISTILLATION, BUREAU OF MINES HEMPEL METHOD
Distillation at atmospheric pressure, 752 mm. First drop, 27°C. (81°R. )

Fraction. Cut at- Per- Sum, Sp. gr., OA.P.I., C.I. SU. . Clont

No. °c. OF, cent per- 60/60°F., 60°F, visc., test,
cent 100°R., OF.

1 50 122 :

2 75 167 2.6 2.6 0.652 85.5 -

3 100 212 4.0) 6.6 +705 69.2 ub

4 125 257 6.2 12.8 +731 (62.1 18

5 150 302 5.1 17.9 «THE 5747 18

6 175 BMT 5.2 23.1 +765 53.5 19

7 200 392 5.0 28.1 +781 49.7 al

8 225 437 4.9 33.0 «798 45.8. 23

9 250 h82 5.9 38.9 812 42.8, ah

10 275 527 6.6 45.5 -826 39.8, 26
Distillation continued at 40 mm,

1 200 392 3.6 49,1 0.843 36.4 30. 4Q. 15
12 225 437 6.1 55.2 852 34.6 31 46 35
13 250 482 5.9 61.1 864 32.3 33 58 55
ith 275 527 5.5 66.6 -876 30.0 36 85 70
15 300 572 5.5 12.1 890 27.5 39 = «14590
Residuun 27.7 99.8 -995 16.7

Carbon residue of residuum, 8.2 percent; carbon residue of crude; -2.3 percent.
Base of crude: Intermediate

APPROXIMATE SUMMARY

Percent Sp. gr. Viscosit;.
Light gasoline 6.6 0,684
Total gasoline and naphtha 28.1 0.738
Kerosine distillate 10.8 «806
Gas oil 15.3 839
Nonviscous lubricating distillate 11.0 +856~ .879 50-100
Medium lubricating distillate 6.9 +879- .897 100-200
Viscous lubricating distillate - - Above 200
Residuun 27.7 +995
Distillation loss 2

239 - 58 -


RoI. 3783

inqreased from 0.68 to 0.83 barrel per well. A daily oil-producing rate of
about 0.9 barrel per well was maintained until January 1931, when production
was prorated. The low oil-producing rate allocated to the Colmar and Plymouth
fields during the proration period resulted in the suspension of vacuum
operations until oil-producing restrictions were removed in November 1931.
Vacuum was discontinued after air injection was begun on February 10, 1934.

Production records indicate that in 1915 only enough gas was produced
with the oil in the Colmar and Plymouth fields tc provide fuel for two gas
engines, No evidence of important water encroachment in the sand was ob-
served, and because gas dissolved in the oil under pressure supplied the
principal propulsive force to drive the oil to the producing wells, the
recovery of oil by primary producing methods was small.

Characteristics of Oil Sand

No wells were drilled in the Plymouth oil field after 1916, therefore
core analyses of the oil sand are not available. Drillers' logs indicate
that the Hoing sand is } to 22 feet thick. Characteristics of the producing
zone probably are comparable to those of the Hoing sand in the Colmar field.
Structural and isopachous maps and a cross ‘section of the Hoing sand are
illustrated in figures 9, 10 and 11.

Development

Injection of air into the Hoing sand was begun on February 10, 1934,
after Hamm well No. 1, an old oil well, was prepared as an injection well.
The well received air from a portable compressor at a daily rate of 80,000
cubic feet and a pressure of 45 pounds per square inch. Eight additional
oil wells were converted to injection wells by June 1, 1934 ,» and the daily
injection rate was reduced to 40,000 cubic feet per well at a maximum pres-
sure of 50 pounds per square inch. At the end of the year 16 oil wells had
been converted to injection wells, Development of th: Plymouth project may
be followed in table 15 to August 1, 1943, when 19 injection wells ( with a
spacing of 22 acres per well) and 42 oil wells (spaced 9.8 acres per well)
were in operation,

The initial rate of air injection into the Hoing sand proved to be
excessive, and channeling was evident. Wells nearest the injection wells
usually were affected within a week of the first injection of air. On
December 14, 1934, the compressor plant was shut down to reduce the delivery
rate of the two compressors. While plant adjustments were being made, 1/8-
inch orifice plates were installed in the meter run at each injection well
as a means of regulating air-injection rates and, to some extent, reservoir
pressure, This method of regulation later was proved unsuccessful and it
was abandoned, Air injection was resumed on May 1, 1935, at an average daily
injection rate of approximately 10,000 cubic feet per well. Since that time
the daily injection rate has ranged from 9,000 to 12,000 cubic feet per well.

239 - 4 -


R.I. 3783

TABLE 18, - Chemical and physical properties of crude oil produced _on
The Ohio Oil Co. Plymouth project from Hoing sand

GENERAL CHARACTERISTICS

Sulfur, percent, 0.26 Specific gravity, 0.648
Saybolt- Universal viscosity at 100°F., 48 sec. A.P.I. gravity, 35.4°
Saybolt Universal viscosity at 68°R., 63 sec, Color, greenish-black

DISTILLATION , BUREAU OF MINES HEMPEL METHOD
Distillation at atmospheric pressure, 753 mm. First drop, 33°C. (92°F. )

Fraction. Cut at-  Per- . Sum, er., API. C.I. SU. Cloud
No. °c. OR. cent per- CO/6Or. 60°F, visc., test
cent. 100°F, OF.

1 50 122. 7 0.7)

2 75, 167 1.8 2.5) 0.662 82.2 -

3 100 212 3.5 6.0 +709 68.1 16

y 125 257 6.4. 12.4 731 62.1 18

5 150 302 5.0 17.4 +748 57°87 18

6 175 347 5.0 22.) +765 53.5 19

7 200 392 5.5 27.9 «782 kON5 er

8 225 437 5.5 334 +798 45.8 23

9 250 482 5.5 38.9 812 428 ob

10 275 5e7 6.5 45.4 826 37.8 26
Distillation continued at 40 m,

1 200 .392 4.5 49,9 0.840 37.0. 29-39 20
1e 225 437 5.9 55.8 851 3h..8. 30. 46 35
13 250 82 5.6 61.4 ~865 32.1 3h 58 55
us 275 527 6.0 67.4 878 29.7 378 70
15: 300 572 563 72.7 «890 27.5 39 160 85
Residuum 27.1 99.8 0.956 16.5

Carbon residue of residuum, 9,0 percent;.carbon residue of crude, 2.4 percent.
Base of crude: Intermediate

APPROXIMATE SUMMARY

Percent Sp. gr. CA.P.I. Viscosity
Light gasoline 6.0 0,691 13.3
Total gasoline and naphtha 27.9 O.7aL 59.5
Kerosine distillate 11.0 805 ae)
Gas oil 15.9 +838: 37.4
Nonviscous lubricating distillate 10.6 «856-.880 33.8-29.3 50-100
Medium lubricating distillate 7.3 ~880-.895 29.3-26.6 100-200
Viscous lubricating distillate - - Above 200
Residiium -: 27.1 .956 16.5
Distillation loss 2

239 - 47 -


RI. 3185

TAME 2. - Active gas-tnjection operations ta I11inote (cont!d.)

Jaty 32, 1965
eestor aber Tejection pedi Taree ally ofl protastion, WT ors
ase “average Tvorage Uoasty —Tagal Govcription of geisha ne Woe ee ayy aires
apie ater Section Tow- anes. Company tnjece injec wolane Sajection
fot ap tin Hon Injecr
fot wile : presmare ted
Teper aatiy,
sa iar it ea! se.
25 Crawford 20 4. D, Toomer a TT Ate ant 2% 3 10 3 1923
Ritate oa
5% @ ‘to © 6 2 1. ee 6 a ‘ 2 1923
% 2 Cueurront & wt 6 & oe 0 8 2 x i 1938
Brow O11 Go
Do. 350 30 % Dinenoor Of1 Go. S$. Wilkin YO M0 2 30030 ar 10050 a 4 2 ag2h
Do. 930 wo 5 Kewanes O11 Co. Headley 160 eT 1 wy ‘& Air and 9 8 ‘Wo increase T 1937
a
De. 925 jo a ‘The Obio 011 Co. Shire 200-100 3 ag 8 wir ze 20 30 ” 8 19a
Dor 33 2 ant 3 ao. Pree 15010 a ae 2s ® 3 3 193
Do. 900, 5 cs Kewanee 011 Co. Wright 60 Be 2 ag 3 Air and 80 25 19 a 1937
oo
Do. 85 20 do. 2 do. Martin ho 16 1 7 3 do. 100 10 5 q T igh
‘Do. 900, ” bow 3 . do. Hooker 60 16 1 n 3 do. 15 3 5 6 gh.
Do. $5 tos Yamataka on co, Garttin 53 ST B35 we 3 gy 1 1337
Dow 925 30 do. 27a ‘Tide Water Asso- Dennis 80 2 16 Air and 30 30 x we 25 1932
‘ etated Ol Con ar
Dow 900, 20 to. 1 do. Dae Ho. 2 60 20 1 6 2 wir x 10 2 3 2 igh.
Do, 900, 5 to. 2 5 Due Bo. 2 40 20 1 8 4 tas wz 5 9 5 Feed
Dow oe 30 to. 15, 16, 21 and 22 ‘The Ohio 011 Co. Siler Oo 150, 1 Be 5 air 125 100 3 ‘Wo increase 2 193
Der % 5 a Gnertemn O61 De: Wall-mort 165855 1710 Ai ana st 6 7 1936
welopuent. Co o
Doe 90 30 te 0 Tianens Riel Drake = 98682 37 ae a ae a? 2 1936
on Gos
Do. 9500 30 te Brenneman Dee Wo 45 1 wo 3 Ae xo ar 3 20 as
2 hedonnel
Dow we RP me do. Kirtland 4010 a 2 3 do. yo + as wo M5 Wo 1937
Dow 950 yo to. do. Wekenman = 40 20 1 8 3 do. yy eeu T a3 8 1936
Do. 900 Bi to. a Dinsmoor O11 Co. Wilson bo 30 2 7 i do. 100 ‘50L) 1 G 4 1922
‘Do. 900, 0 to. 9 do. Grogan bo to 2 4 dow 100 oy BY 21 2 1922
De Ce re) oo fey M5 p02 & ime By ‘ i 132
De. e Pp By a Bans «10010 5 rr ae 2 2 18
Dow 85 do. 2 Kewanee 011 Co, Best. ho 20 1 9 2 air and 20 az 5 7 7 1940
pa
Dow 950 Ld to. s do. Headley- 80 25 2 9 4 do. sO 6 a 23 ua 1937
Ghalon
bm. 9 ao. Gurtis hk Pe ee ee 2 4B 2 1936
Do 950, Boy to. & do. ‘Shilte 85 10 1 10 2 do. ho 25 15 16 Os 1934
Det Soo ie Mamutara O11 Co, Shire 100 woe py 8 rd 3 is 331
Do. $0256 toe Bee 1 2 4 eB OR Fy 131
Dow 300, 25 do. Ww dow Clark 80 25 1 n ye dow jo 3 10 20 uw 1937
Be Bt a oo Pree = Wa ¢ 5 5 it io 131
Dow 900 Fd do. 2 do. Reedy 40 20 1 6 3 do. 30 3 H a 4 1937
‘Dow 950, ” do. s Hiagare on Stine oT 29 1 6 2 Cas 50 20 6 1939
orporation

239 = 16


R.I. 3783

TABLE 22. - Volumes of air injecteal/ and oil produced by months on
The Ohio Oil Co. Colmar project
(Bressure base, 14.4 1b. per sq. in. abs.; temperature base, 60° F.)

1935 1936 I 1937 1938 i 1939

Air; Oil Air {O42 | Air i Oil” Air | Oil | Air oil

injected, !produ linjectea, yproduced, injected, ‘produced, jinjected, | produced, |injected, Iproduced,
Mcu. ft. bbl. (IM cu. ft. bbl. i cu. ft. | bbl. iMou. ft. | bbl. |M cus ft. bbl.
January.. ) 7,436 6,303; 9,082 ;) 8,507 17,1467 7,729
February. j 5,616 if 2/8: 000) 9,160 :) i 9/500 +1) 7,048
March... | } 2/y0,000; 83500 |) | 10,558 |) | 9,006 +) 83512
April.... ) 1 9, Guo 2,75: 9,616 |) 7,884 ) 7,706
Mayesesee] . . 11,600! 12 7829 |) | 10,014 |) | 7,157" |) | 8,684
Juneseee. | 107148; 12/738 |) 2/e1,000; 93675 |)2/180,000! 73756 | )8/176,000} 8,758
July...) 2,716 11,365 117733 ‘) | 10,002 |) | 6,961 ) 8,118
August... } 1,859 12,455) 11,425 |! 12,065} 10,022 |) 6,987 ) 8,325
September 2/60, 000} 2,498 ) 121,042 | 15,201; 9,551 |) | 6,774 ) 8,088
October..|) . 4091 ) 10,136 | 14,319! 8,682 |) | 7,836 |) 8,135
Novenber. |). 47879 |) 2/40,000] 9,686 | 2/747000| 93060 |) | 6979) 7,392
December...|) . 5,639 1) 9,527 | 14,344] 9,546 |) 7,805 __|) 7,654
Total.. 60,000]21,662 | 12% 568/118,307 | 108,057/115,564 | 180, 000| 93,152 193,146 [96,178

See footnotes. on page 367

239 - 55


TYPICAL
INJECTION
WELL
COMPLETION

‘STIFLE 23

WATTLEWORTH 18

ee ee

UD | | ae

[cone osTaineD

way 1937

oa

4.4%] Micaceous SANDSTONE

a WERE
toe ik
PERMEABILITY porosity on conTeNT PERMEABILITY POROSITY OlL CONTENT
jaa ayy BARRELS PER
tan LiDARCYS PERCENT | BARRELS PER ACRE-FOOT urece]  MILLIDARCYS PERCENT ACRE-FoOT
reer FEET
7 290_ 499 600 510 15 20 2 400
qT ToT eT Ty tT
7 FEET BELOW SEA LEVE!
=<
<<
ees |e Ltt J
Gen 4
5B <<
00: i}
= a
EGEND
ae u | “
we. coo
“1 t SANDSTONE
Le a LL Sy sue
poo
7} / sano SHALE
08. I SHALEY SANDSTONE
jon: {
: I
: 1

CEMENT

CLAY

GRAVEL

FIGURE 2.- Analyses of Robinson-sand cores from wells in sec. 10, T. 7 N., R. 13 W., Crawford County, I11.


R.I. 3783
Results

The total oil produced by the Warnock project during primary and vacuum
operations, to the beginning of gas injection in May 1936, was 1,334 barrels
per acre. The cumulative oil production during gas injection to August 1,
1943, was 145 barrels per acre. An estimate of the oil gained as a result of
gas injection was made by extrapolating a production-decline curve (sec
fig. 7) and computing the oil gained as the difference between actual oil
production under gas injection and that expected under vacuum. An estimate
of the quantity of oil gained each year for the gas-injection period between
April 1936 and August 1943 is shown in table 13. The decrease inoil produc-
tion during 1939 and 1940 was a result of State proration, which was in
effect between February 1939 and December 1940.

TABLE 13. -. Oil-production statistics - Warnock project

i.._0i1 production, bbl. : Estimated oil

Year i Normal decline Actual i gained, bbl.
19ZEL/ Lecce cece owenee 6, eho T, 390 | 1,150
1937 seseeee 8,700 13,718 5,018
1938 ...eees 8,100 oe ye ' 6,331
1939 .ececee 7,500 9,925 i 2,4e5
IDO ....eee 6,950 11,232 i 4,282
OWL see... 6,450 13,389 6,939
VND sececcseece i 6,000 13,709 7,709
19h32/ 22, | 3,200 T7235 4 585
Total seseseceeess | 53,140 91,517 | 38,377

1/7 TIast 8 months. - 2/ First 7 months. °

Between May 1936 and August 1943, approximately 142,000,000 cubic feet
of air and gas were injected into the Robinson sand at an average pressure
of 106 pounds per square inch. A vacuum averaging 20 inches of mercury was
maintained on over half of the oil wells, so that the averege differential
pressure between the injection pressure and the pressure in most of the oil
wells has been 116 pounds per square inch. The ratio of cumulative gas in-
jected to oil produced’ was 1,550 cubic fect per barrel or approximately 3,700
cubic feet of gas for each barrel of oil estimated to have been gained. The
injection medium has been introduced at an average daily rate of approximately
340 cubic feet per foot of sand per injection well. The estimated volume of
oil gained by gas injection was 61 barrels per acre. The cumalative oil
production since 1906 was 1,479 barrels per acre.

The cost of developing the Warnock gas-injection project probably was
less than -that of the other three projects discussed in this report. No
wells were drilled during the development of this project, which, in itself,
was a major reduction in expense. Second-hand material and. equipment were
used when feasible, and the purchase of new equipment was held to a minimum.
The investment per acre in developing a project. today et. the higher costs of
labor and matérials would be greater than the original investment on the
Warnock project. - .

239 . ~'38 -


OIL PRODUCED- THOUSANDS OF BARRELS PER YEAR

| syMBots
130} A- NEW WELLS ACQUIRED =

| B- VACUUM OPERATIONS STARTED
r20l - PRODUCTION PRORATED ~ 11 MONTHS

D- AIR INJECTION STARTED
" E- GAIN DUE TO AIR INJECTION
F - ESTIMATED NATURAL DECLINE

"
90) 4+—|
60)
70
60 N
so \ x ny aa
40) | | |

; VAC \ /
30] a
20) oe
10
°
1910 rr 1920 v25 7930 Teas 1940 1545

YEAR

FIGURE 19.- Production curve, The Ohio Oi! Co., Colmar project, McDonough County, Ill.


420)

400;—

A-VACUUM OPERATIONS STARTED

»
8

B-AIR AND GAS INJECTION STARTED

7s

|
38 | SYMBOLS
|
|
\

C-GAIN DUE TO AIR AND GAS INJECTION

D-ESTIMATED NATURAL DECLINE

w
Q
5
| |

g

OIL PRODUCED - THOUSANDS OF BARRELS PER YEAR

1

80

AK

40F
\Y
: ro a
)
1908 10 tos 1920 1925
YEAR

FIGURE 4.- Product ion-decline curve, Tide Water Associated 051 Co., Henry
project, Crawford County, {I].


RAI. 3185

TWBLE 2, - Aotive gascinjootion operations in Tilinots (cont!4.)

July 31, 1943
sana company tease weber _ oil voile Injeotien setin __avrage ealy ofl petetton, wie iutin
ie ‘Tverage Average fom of Total Washer rage Average Fore re aircges
‘ps lake seetion Toms- Range njeoe amber afm Injection wins airge efter injection
fot” ness mp cry foot protsurey injovt-injestion aircgas
feet mie Reper oo
aa ies Say, toe
ous tte
: Johnson field
Casey ‘uso Clerk a om UL Kewanee 011 Co, = Larrison ‘lo 15 a 9 3 ar wo a n 16 B 1937
two 25 do. Banas 98. kM Hide Mtor wimer 06 5 2 Mr 50 a 7 8 1 sie
Hatet ol
Ugo 25 do. Sand ll om We do. Howe 120 ws a a5 2 dow no . wz 1 a Bt hy
Totale: OO we . a 7 a w os a
Luton fiel4
Weiler utr a eee 1,2;559510,11,12, «8H. SE, The Carter O11Co, Loudon 8,040 8,0405/ tS/ALT/ han y Y 10,655 1939
‘Paint Creek 1,537 Us mn Be 20 y Y Y ‘33 4 7
‘Bethel 9562 Uy 22,23, 21, 26,27 ,28, lah
FS on 38
— ° ” rele CO OO Gm
ow Yarnony field
mitersmirg 2,200 matte 295 no
me IBS nouns erie 28 & 8
bel no at Pe aed use we Mus'mter'hecs? ew 2,0002/1,7009/ uol/ 57ers 1,385 700. Ho Anarease 11,300 asta
ates 2100 18 3.30 $s ibm Gtatet etl co are tb 220
O'Hare 2a 5 and Sm 011 Co, = mony pa af
eleny
ad r ‘Totaler Te/ TO w aT Br Tee TT
Puymouth tld
Boing wo 1 Eancook 2 and 20 ‘The Ohio O11 Co. Plymouth = 450 350 ww w % Air us 225 B an 6 1934
fr)
Dawes a a a ws mB om B
Robinson field
Robinson, 00 Crawford 24, Bald Brow, mel 4010 ry 2 1 & ¥ 254 yy 930
— £8 ypommt ope 2 of pig yy @ ¥ : B
me 5 a. Banas 12m, tide Mater Assoe Meander To 100} as o 135

29

elated O11 Co.

“ae


ZA

RSW.

R4W.

HANCOCK COUNTY
MC DONOUGH |COUNTY

WA.RUGGLES [\

&

A,

\
]

io
CHAS. ALESHIRE

FIGURES ON
ISOPACHOUS LINES ARE
SAND THICKNESSES

IN FEET
QO 500 1000
SCALE:FEET
= 20
S
N
_—
LYON HEIRS TX R. SMITH ‘7
%0
M.c. SMITH
i)
stew, |] HH STODGEL
wees om

FIGURE 10.- Isopachous map of Hoing sand, Plymouth field, Hancock and McDonough Counties, mi.


R.I. 3783

Gas injection originated in Illinois in 1921, when the Dinsmoor Oil Co.
introduced gas through a well on the Mumford farm in the Casey field, Clark
County. The project, still in operation, produces from the Casey sand, which
occurs at an average depth of 450 feet. On August 1, 1943, the project in-
cluded 2 injection and 13 oil wells located on 40 acres and produced oil at
a greater rate than in 1920, the year preceding initial injection of gas.

Most properties in the old oil fields of southeastern Illinois produced
‘from sands that were subjected to vacuum when the gas-injection process was
first introduced in the State; and operators were reluctant to use a method
that might drive oil from their properties to adjacent, vacuum-operated
properties. Therefore the gas-injection-process was exploited cautiously,
usually by combining it with vacuum operations. The Illinois State Geo-
logical Survey sreported?/ that by 1932 gas-injection operations in the State
had affected 613 wells, of which 458 produced oil at an increased rate.
Since that date secondary-recovery methods involving the injection of gas
into oil reservoirs have been adopted in some of the newer, as well as older,
oil fields.

AIR-AND GAS-INJECTION PROJECTS IN ILLINOIS

Location of Gas-Injection Projects

Few systematic gas-injection projects have been developed in Illinois
other than those in fields discovered within the last 10 years. A majority
of these projects are in fields discovered near the turn of the century in
the south-eastern part of the State, and only four have been operated long
enough to prove their effectiveness in recovering additional oil. The
Robinson field, Crawford County, offers the most favorable opportunities
for profitable development of gas injection of any of the old oil fields,
and several well-organized projects have been started in this field within
the last 2 years. A map of Crawford County showing the productive area of
the Robinson sand and the location of all gas-injection projects in the
Robinson field on July 31, 1943 is shown in figure l.

Shallower oi1 sands north of the Robinson field, in the Johnson, Casey,
and Siggins fiolds of Clark and Cumberland Counties, also have been subjected
to gas injection; but results are not encovraging pecan: se of their low oil
saturation .and variable permeability. In deeper oil sands south of the
Robinson field, in Lawrence, Wabash, and White Counties, gas injection has
been successful. Except for the Bridgeport field, however, the old oil
ficlds in this arca are small and offcr limited opportunity for devclopment.
Two of the largest. gas-injection projects in operation in the old oil ficlds.
arc in the Colmar and Plymouth ficlds, Hancock and McDonough Counties, in
the west-contral part of the State.

act

; Preliminary Summary of Results
Obtained from a Survoy of Re ssuring Operations in the Southeastern
Tllinois Oil Ficld: Illinois Petroleum Ne. 23, Press Bulletin Serios,
Illinois State Gcol. Survey, Scopt. 2h, 1932, 22 pp.

97 Bell, A. H., end Sqvirce,

259 ~6-


R.I. 3783

Qperating Practice

A compressor plant is located on the Hendricks lease near the center of
the field. The plant is composed essentially of fur Ingersoll-Rand, Hori-
zontal, twin-cylinder (8-: -1/2- by 10-inch) compressors and their prime movers.
The prime movers consist of one 35-horsepower and three 30-horsepower oil
engines. The compressor cylinders operate under single-stage compression
and discharge into the same header at an average pressure of 50 pounds per
Square inch. Moisture is condensed from the compressed air by reducing its
temperature at the plant. A cooling coil, consisting of approximately 100
feet of 8- 1/4-inch pipe arranged in a U shape, was constructed outside the
compressor building. After compression, air from the header flows through
the coil where its temperature is reduced by the transfer of heat to the
coil, and moisture is condensed. The water that accumulates in the coil is
blown periodically to the atmosphere. The heat lost by radiation does not
decrease the temperature of the air substantially, however, because at the
customary rate of flow of air through the coil, the differential between the
temperature of the atmosphere and that of the coil usually is too small to
effect a large reduction in temperature.

The compressed-air distribution system consists of four 3-inch trunk
lines, 2-inch lateral lines from the trunk lines to injection wells, and
traps. to remove water. Three 3-inch lines, 1 to 1.5 miles in length and
0.5 mile apart, are laid north-south and connected by another 3-inch line
about 1 mile long, laid east-west through the center of the field. Air is
supplied to the injecta on wells through 2-inch lines connected at convenient
points to the 34-inch lines.

Back pressure on the highly permeable Hoing sand is maintained in both
the Colmar and Plymouth oil fields to minimize excessive channeling of the
injection medium. In the Colmar field, as in the Plymouth field, back pres-
sure is maintained by venting to the atmosphere at restricted rates the air
and gas produced through the casing of the oil wells. On the whole, the pre-
cautions taken for preventing excessive channeling have been satisfactory,
but channeling of the air to one or more producing wells occurs ocasionally.
Water is injected into the sand through the nearest injection well as a
temporary corrective measure for persistent channeling. As much as 3,000
barrels of water have been injected into the sand through one well in
several treatments.

The pressure within the reservoir has varied widely during air injec-
tion. A large number of fluid-level measurements made in 1938 indicate that
the bottom-hole pressures at that time averaged approximately 15 pounds per
square inch but ranged from 6 to 22 pounds per square inch. Fluid-level
measurements made in the last 2 years verified that bottom-hole pressures
have continued to vary eppreciably from one well to another. The lack of
uniformity of reservoir pressure probably has resulted in the migration of
oil from high- to low-pressure producing areas, especially wheve the high-
pressure areas are structurally high.

239 - 53




RoI. 3783

TABLE 22. - Volumes of air injecteal/ and_oil produced by months on
The Ohio Oil Co. Colmar project (Cont'd. )
(Pressure base, 14.) lb. per sq. in. abs.; temperature base, 60° F. )

i 19ho 19h 19he I 19h3
Air Oil Air | Oil Air] Oil | Air 1 oil
injected, | produced, | injected, : produced, injected,! produced, injected, | produced,
Mcu. ft, bbl, Mu, ft. bbl. | Mu. ft. ! bbl. | Mcu. ft. |; dbl.
January...) 7,530 |) Sn) 8,587 OT 2) a 000 | 6,327
Februery../) 7,931) ) 2/36, 000] 6,932 \) 2/88,000' 7,217 |” 20, 208 | 6,427
March.....,) 2/68,000 8,170 18 1407, 6,973) : 7,1. | 212853 | 8,287
April.....!) 8,526 |) ~ | 7,539 |) | 7,233 | 21,510 | 6,720
Mays..ee0e) 19,809 |» 8,703 }) 2/ p 8,068) ) iy ogg; 95039 20,128 | 6,568
June, .sset) \ 7,239 |) £/90,000). 7,464 |) 075) 7154 | 20,208 | 8,010
Tulysseeee|), 8,174 |) | 7,842 ) 7,071 | 19,651 | 6,0h2
hugust....| )2/ 119, 000 8,2h9 |) | 7,260 |) 8,770 |
Septenber. |) 7199 | 2,385) 75495 J2/a5h, 000: 8,689 |
October...) 7470 |) | 7,715 ) 6,919 | |
‘Noveribor..|) 6,94. j) 2/54,000} 7,010 |) , 6,477 | :
December..| ) 7,379 |) i 6,798 ) | 8 163 |
Total.. 206 , 809 93,479 | 220,730! 88,219" | 286,075 | 92,160 Pah 530 TRS sor
i/ Volumes of air computed from oocasional tests.
“B/ Estimated.
259 - 56 -


Za

s
£ 18 Ms &
s1 4 & £
ry
45 37 s,
§ J.N. BARNES.
$0404 g30
43 42
e e e
26 4l 40 a4
e
7 8 7 t po 4
2 : A id gio Pi2
£. MEWMAW 3 ou e
ar 8
a 2 8 H 7
e
2 6 J. CULP : e 93 ¢
5
= e e
ee e e . ° .
g 5 7 6 6 a
a e@ “ay &
4 3 e SCHWENKE
10 18 $s,
e . e
29 $ f
e e |? :
e 9 26
28 %| &
2 20 g
e e
sg 4 ot 27
MMC CLAIN FEE
e
§ 35 3 12 e g
15 2 %
A SYMBOLS
& % & ~*~ e e@ OL WELL
J.N. BARNES 20 ABANDONED OIL WELL
ft & f & INJECTION WELL
. e & INJECTION WELL
e ° yous 9 CONVERTED TO
19 48 pump 7
7 OIL WELL
2 e7 we go 2
£2 2] f Row gy
COMPRESSOR
MCCLAIN] ¢ Ae
cl 4 ¢
4 ee
ry 3 '
$3 WM. WARNOCK FE!

2000
SCAL

: FEET

FIGURE 6.- Map of The Ohio Oi! Co. Warnock gas-injection project, Crawford County,

We, July 31, 1943.