45

R.14 W. “RAZ W.

5
H i
3° 18. 17 16° 2 *
T
14
|__| Oll-productive limit
s. pn coved

Recovery from individual wells, M bbl.
© Under 25 §
© 25-100
over 100

Q , 2

SCALE- MILES.

FIGURE 26. - Oil-Recovery Map, Lansing-Kansas Gty Formation,
West Half.

Water Encroachment and Accidental Flooding

General

During the early life of the field only wells in structural troughs pro-
duced water with oil; however, by 1959 more than half of all wells were pro-
ducing appreciable quantities of water. A part of this increased water
production was the result of the natural encroachment of edge water, but in
many areas extraneous water also entered the wells or the productive zones
from leaks in casings or improperly plugged wells. Studies of the oil- and
water-production histories of individual wells, together with studies of
analyses of produced water, show that parts of the field have been subjected
to several floods that were either natural or accidental. The most important
of these floods are summarized in table 8 and shown in figure 28. No attempt
has been made to assign additional oil recovery to the natural floods.

Upper Zone
In the upper zone, edge water encroached into some areas of the field,

but probably no more than 10 percent of the oil-productive areas was flooded.
Edge water rose rapidly in some areas adjacent to original water sources but


CORRELATION INDEX

50

40

30

20

dolomite

Arbuckle

f | | | | | |

2 4 6 8 10 12 14
FRACTION NUMBER

FIGURE 6. - Correlation Index Versus Fraction Number,
Representative Oil Samples.

15




54

equivalent to 21.0 percent of the estimated volume of oil originally under-
lying these properties. The 332,000 barrels of oil gained by waterflooding is
equivalent to 36.9 percent of the primary recovery. Total recovery to the end
of 1952 was 28.8 percent of the oil originally in place.

Natural Flood D

Flood D borders a structurally low area where dry holes drilled in 1939
and 1940 encountered water in the Lansing-Kansas City formation. Figure 31
shows the original oil-productive limit and the positions in 1944 and 1948
of an advancing water front. The advancement lines are somewhat arbitrary
because they do not represent total saturation in all Lansing-Kansas City mem-
bers. They enclose areas where water production as of the indicated date had
increased to 75 to 90 percent of the total fluid. The water advance was
definitely associated with structure, moving rapidly into a structural low
a the NE1/4 sec. 27 and bypassing structurally higher areas in secs. 23 and
26.

14

28
i LEGEND
N © Oil well

1 Abondoned oil wall

219902900 3.900
© Woter-input wall

‘SCALE~ FEET

18
30

lo watts
2

-
THTTTTTITTT ITT

1937 | 1936 T 1939 Tis40 T i941 | i942 T1943 Tisaa T1945 T1946 T1947 Tisae T1949 T1950

FIGURE 31. - Natural Flood D, Progressive Water Encroachment
and Production-History Graph.


65

R14 Ww. |

— —10 u
Texoco Texaco

350}-

©U Oil well open in upper zone only

3, ade —_\IT r
| ty, gue Is
+
200- LEGEND Y N |

3
T

Yaar wall was affected or injection
begon

@® Woter-input well '
Ls vy note |__-# soroerger yg it

100 2 |
© 4000-2000 3,000 !
sok |
_
0 ee re
an |

sot
Woter produced
“or 109,000 bbl. by
\ planned tloodin
Co < Primary production — —
670,000 bbl.

LOL | Normal dec, est
tert St

Ss
FIGURE 34. - Waterflood Area I, Progressive Development and
Production-History Graph.

YEARLY OIL AND WATER PRODUCTION AND WATER INJECTION, thousond barrels

|
7

Waterflood Area II

Leases in this flood area, which includes all or parts of secs. 15, 16,
21, 22, 23, 26, and 27, T. 14S., R. 14 W. (fig. 35), are operated by nine
companies. The Pan American Petroleum Corp. leases comprise the oldest part
of the flood. The Cooperative Refinery Association-Fink leases are included
in the flood area, although separated from the larger area by an unflooded
lease. By the end of 1959, 1,501 acres had been affected by water flooding.

Structurally, the tops of the Lansing-Kansas City formation in producing
wells in this flood area range from 1,157 feet to 1,112 feet below sea level.
This flood area includes one major closure, which is among the highest in the
Hall-Gurney field, and three minor structural closures. Most wells are open in
the upper and G zones, and the combined oil-productive thicknesses average 15
feet. The map in figure 35 shows four wells, marked with a U, which are open
in the upper Lansing-Kansas City zone only, and one well open only in the G zone.


Report of Investigations 6134

Mele

ALNNOD NOLYVE

M2ly

XINNOO T13assnu

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suns 1m ge

aque 2001 §

sou ag

19m $08 pauopucay yf

em 509

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em

|
|

(Faces p. 6)

FIGURE 4. - Location and Status of Wells and Leases,

Hall-Gurney Field, East Half.


TABLE 9, - Summary of data pertaining to planned waterfloods, January 1960

Number Oil recovery, bbl.
Area | Date of Number | Cumulative] of oil Natural
flood- | first Date of | of in- water wells or acci-

Flood ed, in- first put injected, | pro- Primary dental Planned
designation | acres | jection | increase | wells bbl. ducing | methods flooding flooding
Tosscecceece 232] 1955 1955 6 1,684,176 ll 670,000 -- 109,000
Tleeeeeeeeee | 1,501 | 1952 1952 20 6,414,511 57 4,605,000 | +108,000 | 1,329,000
III.......6.] 1,167] 1946 1946 14 5,709,000] 36 | 3,402,000 | +220,000 995,000
Iv.. one 376 | 1947 1950 4 1,811,615 12 739,000 -- 202,500
Veccccccceee 60] 1958 1959 1 217,000 3 301,000 -- 900
Vig eccceeeee 369] 1950 1951 ll 1,497,000 21 2,479,000 -- 193,000

Total... | 3,705 | ..seeee |e 56 17,333,302] 140 [12,196,000 328,000 | 2,829,400

1 Part of total oil gained by accidental floods (fig. 28).

09


22

2 Ww.

R13 W,

R.14 W,

RUSSELL COUNTY

od

TY

BARTON COUN

FIGURE 11. - Structure Contour Map, Pre-Pennsylvanian Surtace.




29

LEGEND

Granite wash

Ee] Arbuckle dolomite 8

FT} sener ccemine

dl

3254

3
8

y} VY) Percent water

8

2888 3 8
ee oes ee ee ee

=S
SSS
SI
T T

1504

T
8

OIL PRODUCTION, thousond borrele

T
-
&

too

3
3
T
2
&
WATER IN TOTAL FLUID, percent

4 welts
T
3

T
3

6

mi
1935 ‘36 ‘37 ‘38 ‘39 "40 ‘al ‘42 “43 ‘44 "45 “46 "47 ‘48 ‘49 ‘SO ‘SI ‘52 'S3 "54 ‘SS 'S6 ‘ST ‘SB 'S9 ‘60

FIGURE 15. - Yearly Oil Production, Lower Formations,
Representative Area, West Half.

Gorham sand. From this representative area of 1,336 acres, the oil recovery
averaged 3,918 barrels per acre. Through 1959, 40 oil-productive wells had been
abandoned because of advancing water. Oil production declined from a peak of
395,000 barrels from 38 wells in 1943 to 118,000 barrels from 31 wells in 1959.
Water production from these 31 remaining wells represented approximately 86
percent of the total fluid produced in 1958.

Representative Area, East Half

The eastern representative area is outlined in figure 16. Two structural
highs are present in this area which comprises 2,644 oil-productive acres. Oil
has been produced from 1,880 acres of the Gorham sand and from 764 acres of
the Arbuckle dolomite. Data from wells completed in 1940 indicate that the
original oil-water contact was approximately 1,460 feet below sea level through-
out the area. The original oil-productive thickness for the combined Arbuckle


50

R14 Ww.

OIL AND WATER PRODUCTION, thousand barrels

HE

© Oil well

# Abandoned oil well
@ Water-input well

@ Abandoned water-input well

~> Dry hole

1,000 -—
900
800 ;-
700}-
600+

500;
400p~—
350
300
250

200/-

150 }—

_)|

Water

15)

aan

Zz

° 1,000

SCALE-FEET

a ee

oo

2,000

{|

Teaol
v940l

Tal 1'q2 |'a3 Taq l'45 |'46 1471 4a T'a9l*s0l's1

YEARS

T52 T'53 T'sq T'55 M56 157 T'5e M59

FIGURE 29. - Accidental Flood B, Progressive Water Encroachment
and Production-History Graph.


TABLE 5. - Dry holes within oil-productive limits, lower formations

Top sand,|Total depth,
Location, Date Productive|feet from] feet from
1/4 1/4 sec. completed] formation |sea level] sea level Production Remarks?
T. 14S., R. 12 We
SW SE NW 29,...... 5-13-54 | Arbuckle
dolomite.| -1,453 -1,454 Water......+...|PB to L-KC on com-
pletion.
NW SE NW 29.... 12-30-54 |....do....| -1,445 -1,453 seeeeedOw. . Do.
NE SW NW 31. 3-3-45 |Gorham....| -1,449 -1,481 eee eedOee ° Do.
NE SE NW 31.. «| 10-19-54 |Arbuckle
dolomite.| -1,452 “1,456 |... -doseeeeee Do.
N NW NE 31....... 3-13-47 |]Gorham....] -1,456 -1,556 Water at
-1,453. Do.
S NE NE 31.. 10-15-47 |....do....| -1,445 -1,447 Watersseseceees Do.
SE NE 31.. 4-24-49 |....do....] -1,443 71,444 Drill stem
test--20 feet
of mud. No oil.
NW SE 32,...... 7-25-43 |Arbuckle
dolomite.| -1,460 -1,462 Rainbow oil....|Test 1/4 oil--5 W,
1955.
S SW SW 33, 7-28-42 |Gorham....| -1,453 -1,468 Tested dry.. S.I, to 1950.
S NW SW 33, 12-4-42 |....do «| 71,454 -1,495 Water.... PB to L-KC,
NE SW SW 33... 1-17-55 |....do....] -1,452 -1,460 sence dO. Do.
T. 14S., R. 13 Wet
NW NW NW 20....... | 12-11-49 |Arbuckle
dolomite.| -1,423 -1,457 Water at
1,423, Deepened for water
disposal.
S S NW 29....... 1-18-51 |Gorham....} -1,411 -1,416 Slight show
oil, 700 feet
of water--30
minutes.
T. 14S., R. 14 We:
SW NE NW 14,...... 9-27-56 |Sandy
dolomite.} -1,413 -1,421 Water..........|Located in struc-

See footnotes at end of table.

tural trough.

4


53

p.S.i. would be reasonable. According to Volosin (7), a barrel of Lansing-
Kansas City oil with a stock-tank gravity of 39° API should contain approxi-
mately 340 cubic feet of gas in solution at a pressure of 1,100 p.s.i. A
barrel of oil containing 340 cubic feet of gas in colution has a formation-
volume factor of 1.245 at 120° F,

The volume of stock-tank oil originally underlying each lease was calcu-
lated by the following equation:

n = 2158 AHESo,
Bo

where

N=Stock-tank oil originally in place, barrelss
A=Areal extent, acres;

H=Average net oil-productive thickness, feets
$=Estimated porosity, fractions

So=Original reservoir-oil saturation, fractions
Bo=Original formation volume factor.

History and Results

Production histories of wells in the area of flood C suggest that extran-
eous water originally entered the Lansing-Kansas City formation through a well
in the NW1/4 sec, 25. Granite wash water presumably entered the formation
through a faulty plug, although no one well has been noted as a source of the
water. A shallow structural trough, dipping to the southwest, may have aided
the spread of the flood.

Well A (fig. 30) produced considerable water when completed in 1941, By
1945, seven other wells were affected by the spreading flood water as shown by
the water-advancement lines. By 1950 a total of 15 wells had shown an increase
in the rate of oil or water production as a result of the spreading flood.
Water samples taken in 1942 and 1949 from well B in the SW1/4 sec. 24 had com-
positions similar to normal Lansing-Kansas City water. Although extraneous
water had not yet reached this well, production had been affected. During
1947, Dakota water entered well C through a casing leak but apparently did not
affect the oil or water production of other wells in the area. Wells in the
sw1/4 sec. 24 had some increases in the rates of water production, but in all
wells these increases were associated with casing leaks reported in the in-
dividual wells. After 1950, well A and other wells in the area were converted
to input wells in a planned flood. Results of the planned flooding are dis-
cussed in another section. A normal percentage-decline rate for this area
(table 7) was used to calculate the volume of additional oil recovered as a
result of accidental flooding.

The volume of oil gained through 1952, determined by subtracting the es-
timated primary oil production from the actual oil production, was 332,000
barrels, Primary oil recovery through 1952 was 900,000 barrels of oil,




35

Depth,

— Lime, white, finely crystalline, pin-point porosity
‘Shale, grayish blue

Lime, tan, finely crystolline, fossiliferous, with some white chert, pin-point to oolitic porosity

Lime, buff, finely crystalline, portly oolitic, pinpoint to vugular porosity

— Lime, white, crystalline, portly oolitic with vugulor porosity at the top becoming dense ond cherty —|

with ‘depth
Bale, dork gray,
Time,’ gray, fossiliterous
Lime, gray, cherty, dense
Shale, dork groy

— Lime, white, finely crystalline, oolitic and generally porous with cnert inclusions near the bose

— Shale, block and gray 4
Lime, gray, shaly, slight porosity
Shole, groy
Lime, gray, poorly sorted granular at top becoming coarsely crystalline at bose, dense
Shale, brown and gray

— Lime, gray, oolitic, shaly, dense

Lower zone —————»}+——G_ zone —>}+ upper zone —=y

shale, black, carbonaceous, shading to brown and gray, friable

ST ee
7 Lice rae oh dep wh tr nn
a 4- 3150-4 4
L

— Shale, black.
Lime, white, crystalline with shole lominations, dense

FIGURE 19. - Gamma Ray-Neutron Log and Description of
Lansing-Kansas City Formation.

members, A through L. Identification of these individual limestone members
by formation samples was not generally possible, but the members were traced
readily by Morgan (4) by correlating gamma ray-neutron logs. In this study
the formation members A through F were grouped as upper zone, the G member
was considered as a separate zone, and members H through L were designated as
lower zone.

Cross sections were drawn through the field along the lines G-H, J-K, and
L-M in figure 18. These cross sections (figs. 20 and 21) show the lack of
structural relief across most of the field; only well 7 (fig. 20) is appre-
ciably lower. The top of the A member, on which structural contours were
drawn, is a gradational contact with limestone replacing shale deeper in the
member. It normally is about 15 thit thick with only 2 to 4 feet of porous
limestone either at the top or bottom of the member. Wells 1, 2, 6, 8, 9, and
10 of figures 20 and 21 have thin porous intervals. In oil-productive areas,
casings normally were perforated opposite this porous interval, but in only
a few wells did the A member contribute appreciably to the total well produc-
tivity. Because of the thinness and shaly nature of this member, these porous
intervals are difficult to recognize from the gamma ray-neutron log. In some
areas the A member has been called Iatan limestone, but correlation throughout
the field indicates that the Iatan is absent.


Se
g
wy we aod

2

640. CE Artich

Z,

73

S

202,500 bbl. by
plonned flo

-<3
Normal decline, est.

240 .-— LEGEND

230 (Oi! well open in both zon
3220 eu oil well open in upper zone only

Z1Ob ©  Yeor well wos affected or
3 58 injection began
E200F- ¥ Abandoned ot! well
3 90 @ woter-input wel
= a0 ory hole
S 7
ed i
B eof
Zyso/. 9 000-2900 3000
5 140
g SCALE - FEET
3 0b 5
Z zor
3
zllob
2 £
5100, £
3 sob
3
E80 ou produced

produce
§ 7or TM
¥
$ 6o-
2 sok
g *° Primary production
S 40F 739,000 bbl.
3 =>
3 Cc
z
S$ 1 4
¥
o}—,
i936! waol TT

TisssTT 1959

FIGURE 39. - Waterflood Area IV, Progressive Development and

Production-History Graph.


STATE OF KANSAS,

re [>] cos om

RZ Ww

RaW

RIS Ww. |

we. Ausse county
Sate county

FIGURE 1. - Location of Hall-Gurney Field, Russell County, Kansas.

ACKNOWLEDGMENTS

This engineering study of the Hall-Gurney Oilfield, Russell County, Kans.,
grew out of suggestions by members of the Kansas Independent Oil and Gas Asso-
ciation that engineers of the Bureau of Mines undertake studies designed to
improve oil recovery from Kansas fields. Their help and cooperation is
appreciated.

The authors gratefully acknowledge the assistance of officials and em-
ployees of the Aylward Drilling Co.3 Cities Service Petroleum Co.3 Continental
Oil Co.3 Cooperative Refinery Associations J. J. Hall Operating Co., Inc.3
National Cooperative Refinery Associations Pan American Petroleum Corp.; Shields
Oil Producers; Skelly Oil Co.3 Sunray Mid-Continent Oil Co.3 Texaco, Inc.3
Theodore Gores Julian Oil and Royalty Co.s$ Murfin Drilling Co.3 and many other
individuals and companies who made engineering and statistical data available.
Completeness of the oil-production data in this report is a result of the
cooperation of the Oil Tax Assessor, Russell County, Kans.


CONTENTS

Introduction and SUMMATY..ccccecccecererccccvcvcccccccscres
Acknowledgments..eeeeesee
General geology.....
Development...ccceccecccscoe

Discovery and history..

Drilling and completion practices.
PLOdUCTION. ..ecececercecccccccececccee

Properties of produced oils.
Analyses of produced waters..

Lower formations..
Reservoir conditions... se eeecccccece
Structure and stratigraphy.....
Lithology..cccccccceccscces
Reservoir fluidS..cssccesccecesece
Production mechanisms and recovery..
Representative area, west half....
Representative area, east half....
Discussion..
Lansing-Kansas City formation
Reservoir ConditionS...ccccccccccccccececs
Structure and stratigraphy......eeeee
Lithology...ccccscece
Reservoir fluids.......

Upper zone......e.

G Zone.....

Lower zone.

Oil production history.
Initial production........

Normal decline rates.

Oil TECOVETY. .ccrecsccccccccvcccccceveccees

Water encroachment and accidental flooding.........0.
General...ssccsccccccccccccscccsces
Upper Zone.

G zone.....
Natural flood A....
Accidental flood B...
Accidental flood C...
Primary development..
Original oil in place.
History and results..
Natural flood D.... eee
Natural fl00d Evscccccsscccacccsccccccccscccccces

Page

NDAKDAVTITANYE


32

in the mid 1940's, but decreased gradually in the 1950's; water production in-
creased from 50 to 93 percent of the total fluids produced. In 1959 the cumu-
lative oil recovery was 8,832,116 barrels, representing 3,340 barrels per acre
from the 2,644 oil-productive acres.

Two methods were used to estimate the ultimate oil recovery from this area.
The production-decline graph shown in figure 17 was extrapolated to an economic
limit of 10,000 barrels, indicating a future recovery of an additional 1.7
million barrels of oil. The ultimate oil recovery also was estimated by
extrapolating a curve plotting water percentage versus cumulative oil recovery
to an economic limit of 97 percent water production. The estimated oil-re-
covery totals, derived by both methods, were in close agreement at 10.5
million barrels.

Between 1938 and 1946 oil produced from the area was prorated; during
this period the daily rate of production averaged 24 barrels of oil per well.
The total daily fluid withdrawals averaged only 33 barrels per well. After
this period, oil production was not prorated, and wells were produced at maxi-
mum capacities. Possibly the tendency towards irregular water advance was
greater during the later years.

Discussion

Behaviors of individual wells and leases indicate that these oil-produc-
tive sands have high horizontal and vertical permeabilities, limiting successful
plug-back operations within the same productive interval. The few plug backs
attempted failed to yield more than temporary relief from steadily increasing
percentages of water production. Both cement and plastic were tried.

In a few areas oil recovery could be hastened and perhaps improved by
water injection through selected wells. In general these areas lie upward from
porosity and permeability "pinchouts" restricting advancing edge water. One
such area lies north of a small granite high in sec. 36, T. 14 S., R. 14 W.
Other areas are in sections 10 and 14 of the same township.

The structure and water-encroachment pattern indicate several potential
areas where lower formations should still be oil saturated. These areas are
unshaded and enclosed by dashed lines in figure 12. Three of these areas are
as follows:

Productive 1960 estimated
Section | Township | Range formation water level, feet
Qeceeee 14S, 14 W. | Sandy dolomite...... -1,410
14S, 14 We | cece eee edOrcecceeee -1,397
27-28... 4s. 13 W. | Arbuckle dolomite... -1,400

The Arbuckle may be too impermeable or tight to yield oil in commercial quan-
tities in the last area.


59

The maximum flood-oil gain for any one year was 80,000 barrels in 1945,
but in 1959, the annual oil production was 17,000 barrels more than the esti-
mated primary producing rate,

Planned Waterflooding

The increased oil production resulting from natural and accidental floods
encouraged many producers to inject water into the Lansing-Kansas City formation.
On many leases this injection was merely disposal of produced water into one or
more converted oil wells.

In six separate areas, covering 42 leases, the volume of water injected
exceeds the volumes of oil and water produced. In the following pages these
six areas are discussed as integral waterflood areas, although they may in-
clude leases operated by several companies. The enclosed areas and production-
history graphs shown in planned flood illustrations include only those wells
affected by waterflooding as of January 1, 1960. Table 9 is a summary of data
for the six areas,

Water for injection is principally brine produced from Lansing-Kansas
City and lower formation wells in the vicinity of the input wells. Ona few
leases Dakota or shallow fresh water is used either alone or with produced
brine. Table 10 shows mineral analyses of several waters being injected.
Closed injection systems, with little or no treatment or filtering of the
water, are used on most leases

During October 1960 tests were made at several of the input wells to
determine corrosivity and plugging tendencies of the injected waters. Table
11 shows the amount in milligrams per liter of dissolved corrosive gases which
could corrode pipe and connections. In only two samples was the oxygen con-
centration high enough to cause corrosion in the presence of carbon dioxide.
However, the comparatively high concentration of carbon dioxide in several
samples could cause corrosion.

The last three columns of table 11 indicate the amounts of unstable ions
in the brine that could contribute to the formation of precipitates. If a
water is supersaturated with carbonates (all but one of the waters tested
were supersaturated), precipitation might occur if a physical change in the
system takes place that would liberate carbon dioxide, such as an increase
in temperature or a decrease in pressure.

Three of the injected waters contained substantial quantities of dissol-
ved iron which, in the presence of free oxygen, could oxidize to form pre-
cipitates and plug formation pores


68

and 9, divided on a 30-30-40 percent basis, respectively. This allocation
attempted to offset the effects of the previous, uncontrolled flooding from
casing leaks in wells 1 and 2. During 1955 average injection rates into all
three wells totaled 1,115 barrels of water per day with wells 2 and 9 each
receiving 35 percent of the total and well 1 receiving the remaining 30 percent.

Because of the corrosiveness of dissolved carbon dioxide in the Dakota
supply water, filming amine inhibitors were injected into the annuli of the
supply wells. After leaks developed in the input wells, steel tubing, inter-
nally coated with baked phenolic and epoxy plastics, was installed. Filters
were not used because the negligible amounts of precipitates formed by the
mixing of Dakota and Lansing-Kansas City water did not affect input rates.

Five of the mineral analyses shown in table 10 are of waters being in-
jected in Waterflood Area II, Lansing-Kansas City water does not contain
enough barium or strontium to cause trouble when mixed with waters high in
sulfates. Table 11 shows that the carbon dioxide content of the injection
waters ranges from 88 to 440 milligrams per liter - high enough to corrode
iron pipe. Carbonate supersaturation ranges from 30 to 90 milligrams per
liter.

Most water injection systems are open, a few are closed. None of the
systems are elaborate, and the only water treatment is adding corrosion in-
hibitors. Cement-lined pipe is used extensively.

Results of Flooding

During 1952, two wells showed increases in rates of oil and water pro-
duction as a result of accidental flooding from casing leaks in Pan American
Petroleum Corp.-Krug-A wells 1 and 2, By 1955, 11 wells in the smaller inside
area outlined in figure 35 had been affected by water injected into the first
3 wells.

A study of production from the Krug-Olson-Driscoll leases (5) shows oil

recovery by waterflooding was approximately 535,000 barrels, equivalent to

29 percent of the primary recovery or 7.5 percent of the 7,098,000 barrels of
oil originally underlying these leases. Available information indicates that
the rate of oil production from the Krug-Olson-Driscoll leases reached a peak
in March 1959 and started to decline. Extrapolation of the production curve
at an assumed annual decline rate of 20 percent, normal for many waterflooded
properties, to an economic limit of 28,000 barrels in 1966, shows that an
additional 406,000 barrels of oil would be recovered. This total waterflood
recovery would be equivalent to 51 percent of the primary oil production and
would increase the total recovery to approximately 39.3 percent of the oil
originally in place. Average residual-oil saturation, in terms of stock-tank
oil, would be reduced to 38.5 percent of the pore space.

The increased oil production from the Krug-Olson-Driscoll leases encour-
aged other producers to inject water on adjacent leases. By 1960 a total of

124002000 barrels of water annually was being injected into 20 wells on 16
eases,


4 | ured ob mines 6134

report of investigations

PETROLEUM-ENGINEERING STUDY
OF THE HALL-GURNEY OILFIELD,
RUSSELL COUNTY, KANS.

By C. H. Riggs, Larman J. Heath, Don C. Ward,
and Ray V. Huff

metadc38700 |

UNITED STATES DEPARTMENT OF THE INTERIOR
BUREAU OF MINES

1963


This publication has been cataloged as follows:

Riggs, C H.

Petroleum-engineering study of the Hall-Gumey oilfield,
Russell County, Kans., by C.H. Riggs and others. [Wash-
ington] U. S. Dept. of the Interior, Bureau of Mines [1963]

v, 86 p. illus., maps, tables. 27 cm. (U.S. Bureau of Mines.
Report of investigations 6134)

1, Petroleum engineering = Kansas. I. Title: Hall-Gumey oilfield,
Russell County, Kans, (Series)

TN23.U7 no. 6134 622.06173

U.S. Dept. of the Int. Library.

For sale by the Superintendent of Documents, U.S. Government Printing Office
Washington 25 D.C.


20

R14 W. R13 Ww

ARBUCKLE DOLOMITE

SCALE, MILES
° v 2 3
ARBUCKLE DOLOMITE
EXPLANATION 1
A-B, C-D, E-F, 1s

Location of cross sections Ss.
shown in figure 10.

FIGURE 8.- Areal Geology, Lower Formations.

FIGURE 9. - Areal Geology, Lower Formations.

A core analysis and a radioactivity log for one off-structure well about
1/2 mile north of the oil-productive limits were available. Average porosity
of the core samples was 19 percent, and permeabilities were as high as 700
millidarcys. The vertical permeabilities were as high as the horizontal
permeabilities in most instances. The radioactivity log was compared with the
analyses of cores from this well. Using this relationship porosities of the
oil-productive formations in other wells were estimated where logs but no
cores were available.

A transitional series composed of Gorham sand, shale, limestone, shale
and lime conglomerate, and cherty conglomerates overlies the beds of Cambrian
and Ordovician periods. The Gorham sand of Pennsylvanian age ranges froma
fine-to a medium-grained, subangular, and subrounded sand. Oil productive
areas of other transitional-series beds have been called Gorham. In general,


75

After a heavy fracture treatment, well No. 10 took about 350 barrels of
water daily on a vacuums but three months later, injection pressures increased
gradually and had reached 490 p.s.i. by late 1959. By January 1, 1960, more
than 217,000 barrels of water, handled in an open system without treating or
filtering, had been injected into this well.

Tests made in October 1960 showed that the injected brine contained dis-
solved carbon dioxide and some hydrogen sulfide. (See table 11.) Filter-
flow tests showed 71 milligrams of entrained oil per liter of brine and some
calcium sulfate particles. These solids caused marked reductions in the rate
of flow through the filter and could plug small pores in the formation.

By January 1, 1960, increased oil recovery from the three wells affected
was approximately 900 barrels.

Waterflood Area VI

Area VI includes parts of secs. 26, 27, and 35, T. 145., R. 13 W. Five
leases are included; four are operated by Continental Oil Co., and one is
operated by Shields Oil Producers, Inc. A total of 369 acres, as shown in
figure 41, had been affected by the end of 1959,

Seven wells were completed in 1937. As development continued, the rate
of oil production from 32 wells reached a peak in 1942 of 316,000 barrels
(fig. 41). Ten wells produce from both upper and G zones, but most wells
produce from the upper zone only.

In 1950 Shields Oil Producers, Inc., began injecting water produced from
the Letsch wells into the Letsch No. 1 well in the NE1/4NE1/4 SE1/4, sec. 27.
This injection sustained oil production from that lease. Continental Oil Co.
converted seven wells for water injection in 1956, A closed system with a
corrosion inhibitor added to the water was used on the Continental leases.
Shields Oil Producers, Inc. continued to inject water in an open system on the
Letsch lease. Other input wells were added in 1957 and 1958, and by 1959
almost 450,000 barrels of water per year was being injected into 11 wells at
pressures up to 650 p.s.i.

Table 10 shows the mineral analyses of water from the Continental Oil Co.
supply well and from the Letsch No. 8 input well. The latter well receives
produced waters whereas the other input wells receive water from the supply
well. In October 1960 a field analysis of injection water was made at the
Continental Oil Co., Letsch No. 11 well to determine the amounts of unstable
compounds. Results of this analysis are shown in table 11. Negligible amounts
of corrosive gases and unstable compounds were present in this water.

Figure 41 shows the years when water injection into the ll input wells was
begun and when producing wells first responded to water injection. Through
1959, 21 wells on 369 acres had been affected by water injection. The lower
half of figure 41 is a production-history and water-injection graph of the
area under flood. The expected normal decline for each lease was extrapolated


70

| nw naw

2a 9
Gites Songs wy TRE z
3
6
$
20 8
3 8
encticn
Gore z
3 du} 3 é
we | &
3 7
3 Nd “
& 2 s
$ / ” gu
su 2 |, gt
¥ 3
ag UBoxberge?. recht 8 | Stecter a | Mkey | pristy 49 Phinney SS
mrs eB ge Oger
| g St miner 0 |
3 s|l7
% Miler E

E Hickey

LEGEND
Oil well open in both zones
t sppo__2000 uO wel open in upper zo0e only
‘ SCALE - FEET Year well wos offected or injection began

Ory hole

Se
s
© Woter-input well
& '
R.A. —Cooperative Refinery Association

FIGURE 37. - Waterflood Area III, Progressive Development.

with depths greater than 1,140 feet below sea level cuts through the Skelly Ben
Rein lease.

The first well, completed in 1935, had an initial potential of 414 barrels
of oil per day. Seventy-four wells with potentials ranging from 60 to 3,100
barrels of oil per day had been completed by the end of 1942. Most oil wells
were productive in both upper and G zones; however, 13 wells, marked U on the
map in figure 37, produced from the upper zone only. Peak annual production
was 589,000 barrels of oil in 1942, as shown in figure 38. New completions in
the early 1950's resulted in increased production rates which were short lived.
Primary production for each well was assumed to have declined at the percentage
rates shown in table 7 and to have reached an economic limit by 1957, All pro-
duction thereafter is attributed to the to the waterflood, Cumulative oil re-
covery by primary methods is estimated to be 3,402,000 barrels.


in lower formations. After 1940 many wells were drilled to test the lower for-
mations, and others were deepened after flush-production recovery from the
Lansing-Kansas City formation.

Most wells were drilled with rotary rigs to the top of the producing for-
mation. After casing was set and cemented, the wells were carefully completed
using cable tools. In wells deepened from the Lansing-Kansas City formation,
either 4-1/2- or 5-1/2-inch liners were set below the original casing. Many
wells were acidized at completion, using from 1,000 to 10,000 gallons.

All oil wells were equipped for pumping. Common working-barrel-type pumps
as well as various plunger-type pumps were used. Electric submersible pumps
have been used in a few wells to handle large volumes of encroaching water.

In some areas lack of gas to operate engines may have resulted in premature
abandonment of wells.

PRODUCTION
Producing Formations

Most of the produced oil has been obtained from the lower formations, the
Lansing-Kansas City formation, and the Tarkio formation. The lower formations
include the Gorham sand of Pennsylvanian age, the Arbuckle dolomite and sandy
dolomite of Cambrian and Ordovician periods, and the granite wash. Figure 5,

a graphical presentation of the yearly oil production, shows that to January 1,
1960, approximately 72 million barrels of oil, or 88 percent of the total re-
covery, was from the Lansing-Kansas City and the lower formations. More than
9 million barrels of oil was recovered from the Tarkio and miscellaneous for-
mations, including the Topeka, Toronto, Douglas, and Plattsmouth.

A general summary of oil recovery from each formation underlying indivi-
dual productive leases is shown in table 2. On leases where production data
from individual formations were not available, oil recovery was allocated to
the different formations according to individual well-production tests or
representative decline curves

Produced Fluids
Gas

Each of two Tarkio wells and three Lansing-Kansas City wells originally
produced up to 11 million cubic feet of gas daily. Accumulations of free gas
were limited to isolated areas. Analyses or other data concerning properties
of produced gases are not available. In a few instances, during the early
life of the field, dissolved gas was adequate to permit Lansing-Kansas City
wells to flow; but such flow was too weak to justify continuance without
mechanical aid.


40

water saturation values for the selected cores are shown in column 6 of table

6. Data obtained from desaturation tests on all cores were used to plot the
curve in figure 24, an approximate relationship between porosity and irreducible
water saturation. Although individual measurements depart widely from the
relationship shown by the curve, the curve does provide usable values for inter-
preting average connate water conditions in the Lansing-Kansas City formation.

Upper Zone

Structurally low wells along the north and northeast edges of the field
produced water from the upper zone when completed. Water also was encountered
in the upper zone in small isolated areas along the south and southwest flanks
of the field but did not underlie the oil-productive zone in most of the field.
In general the top of the water-producing transition zone was about 1,170 feet
below sea level along the north edge of the field and as deep as 1,200 feet
below sea level in structurally higher areas

This range in depth to original water reflects a lack of vertical permea-
bility between the separate oil-productive members. Thus, along the edges of
the field the A or B member may have contained mobile water; whereas in the cen-
ter of the field only the deeper members contained water.

G Zone

Original water conditions in the G zone were much more complex than in the
upper zone. In general the G zone was not oil productive wherever the upper
zone contained water. However, in some areas the original water level in the
G zone was more dependent upon the depth in the formation than upon structure.
In the east part of the field, in the SE1/4 sec. 3, T. 15 S., R. 12 W., water
was recorded in the G zone at a depth of 1,220 feet. This was a structurally
high area, and water was encountered 10 to 14 feet below the top of the G zone,
or about 102 feet below the top of the Lansing-Kansas City formation. Ina
structurally low area in the wi/2 sec. 4, T. 15 S., R. 12 W., water was en-
countered at depths of about 1,260 feet below sea level or about 130 feet
below the top of the Lansing-Kansas City formation. Other wells in this
general area, although completed at depths approaching 1,250 feet below sea
level, did not produce water originally.

Apparently, in some areas the top of the G zone did not contain water
regardless of structural position. In other areas particularly in the east
side of the field, the depth to water ranged from 1,230 to 1,260 feet below
sea levels; but the relationship to structure was not obvious.

In T. 14 S., R. 13 W., water was produced from wells at depths 100 feet
below the top of the formation regardless of structure; these depths range from
1,220 to 1,240 feet below sea level. In much of T. 14 S., R. 14 W., the ori-
ginal water level also was about 100 feet below the top of the Lansing-Kansas
City formation. Variations from this were noted in the structurally highest
areas where the depth to water was slightly more than 100 feet and in the
lower areas where the depth to water was slightly less


82

Analyses of cores from 36 wells
producing from one or more of the Tarkio
sands show that the average porosity for
individual wells ranges from 15 to 30
percent and the average for all wells is
23 percent. The average permeability for
all 36 wells is 62 millidarcys, and the
average permeability for individual wells
ranges from 5 to 207 millidarcys. The
reported oil-productive thicknesses for
these wells average 8 feet.

Ist sond

‘Langdon

Table 13 lists the results of core
analyses of the Tarkio section shown in
figure 44, Porosities of the oil-pro-
ductive intervals range from 21 to 32
percent, and permeabilities range from
6.8 to 217 millidarcys.

Torkle

Tarkio oil production, which began
in 1936, was not significant until the
early 1950's. At that time, production
from many Lansing-Kansas City and lower

FIGURE 44. - Gamma Ray-Neutron formation wells was nearing an economic
Log of Tarkio limit and producers began testing shal-
Section. low formations. Because of many suc-

cessful recompletions in the shallower
Tarkio formavion, new wells were drilled and production developed in former
nonproductive areas.

Two methods are employed in completing new wells. In some, casing is set
at the top of the Tarkios whereas, in other wells, casing is set through the
entire series and perforated opposite productive intervals.

Figure 45 shows the oil-producing areas and status of Tarkio wells. Many
of the wells shown as dry were drilled early in the life of the field and do
not necessarily condemn that area. Testing of other areas has been deferred
pending depletion of deeper formations.

To January 1, 1960, a total of 458 wells had produced 8,097,749 barrels
of oil from the Tarkio, and 333 wells were still producing. Figure 5 shows
that the rate of Tarkio oil production reached a peak in 1953, Drilling
activity increased in 1959, resulting in the completion of many new producing
and input wells.

The areas outlined on figure 45 represent the probable drainage areas of
the Tarkio wells. .Outside areas could be and possibly are oil productive.


TABLE 10, - Mineral analyses of brines injected into the Lansing-Kansas City formation

Milligrams per liter
Bicar-
Lease Specific] Calcium | Magnesium| Sodium | bonate| Sulfate | Chloride| Total | Formation
Company and well | gravity| (ca) (Mg) (Na) | (Hco,)| (So,) | (C1) | solids source
Flood area II:
Aylward Drill- |[Hall B., W6+..] 1.022 | 1,350 40 | 7,280) 525 812 | 13,120 | 23,227] Shallow.
ing. Hall A 4, 11047 goo} 1,410 | 23,937| 835 | 5,444 | 34,390 | 66,616] Dakota.
all A le 11094 | 8,140/ 2,260 | 39,300] 140 874 | 80,840 |131,554| Lansing-Kansas
City and Ar-
buckle.
Pan American
Petroleum.....4 Krug A., WS...| 1,016 280 268 | 8,050] --- | 2,400 | 11,500 | 22,496] Dakota and
Shallow.
Cooperative Re-
finery Asso-
ciation.......4 Horace Fink
Seeseceeeeeee] 14080 | 6,610] 2,520 --- | 300 | 1,160 | 68,000 } 133,000] Mixture.
Flood area III:
Aylward Drill-
ing. «| Boxberger 4...] 1.093 | 8,400] 2,120 | 37,839| 159 | 1,510 | 78,185 |128,213| Lansing-Kansas
City and Ar-
buckle.
Cities Service
Petroleum,....| Ebel B., WS...| 1.010 353 165 --- | 681 | 1,080 | 5,540 | 11,600] Shallow.
Cooperative Re-
finery Asso-
ciation........ Phinney tank..| 1.035 | 2,890] 1,270 --- | 339 716 | 29,800 | 49,800] Mixture.
Flood area Vs
Skelly Oil.....4 Colliver, WS..| 1.005 230 33 665 | 263 130 | 1,280 | 2,601] Shallow.
Flood area VI:
Continental Letsch, WS....] 1.006 400 15 1,450] 348 360 2,520 | 5,093 Do.
Letsch 8......| 1.052 | 3,848] 1,284 | 18,100) 207 517 | 37,940 | 61,896| Lansing-Kansas
City and Ar-
buckle.
Miscel laneou:
Aylward Drill-
ing seeee| Hall B lease..} 1.089 | 7,840] 1,235 | 40,200] 298 | 1,718 | 78,000 |129,291| Lansing-Kansas
City and Ar-
Smokey Hill buckle.
Petroleum.....| Michel 4......] 1.113 | 13,306] 1,537 | 46,620] 129 757 | 99,280 |161,629| Lansing-Kansas

City.

+ WS-Water supply

well,

19


TABLE 5. - Dry holes within oil-productive limits, lower formations (Con. )

Top sand,|Total depth,
Location, Date Productive] feet from} feet from
1/4 1/4 sec. completed| formation |sea level] sea level Production Remarks?
NE NE NE 28...006- 4-22-39 | Sandy
dolomite.| -1,390 -1,399 100 bbl. oil,
no water. PB to L-KC for
waterflood produc-
tion.
T. 15 S., R. 12 W.:
N NE NW 4, 6-9-48 |Gorham....{ -1,451 -1,455 Waterssecececee
SE SE NE 4. 8-5-41 |....do....| -1,429 -1,452 | .....+eeeeeee0-)Possible tight sand,
no record.
S NE NE 4-22-43 |....do....] -1,422 -1,438 Do.
SW SE SE 4........ 9-10-50 |....do....) -1,439 1,465
PB to L-KC.
SE NE SW 4........ 9-28-50 |...-do....| -1,428 -1,446 Tight sand.
10-16-43 |....do. -1,457 -1,487
11-2-54 |....do. -1,442 -1,445 PB to L-KC,
6-28-48 |....do....] -1,455 -1,485 . Do.
7-16-48 |....d0....| -1,443 -1,481 Arbuckle dolo-
mite, watered
out. Gorham tight.
5-6-48 |Arbuckle
dolomite.| -1,444 -1,448 tececeeeeceeeee|PB to L-KC,
6-5-59 |....do....| -1,454 -1,486 Hole full of
water.
seeeeeee [oceeeeccee| coeeee eeeeee seecceeceveeese|No information,
11-19-42 |Arbuckle
dolomite.| .. . . oe cee PB to L-KC,
N N NW 9.....006 3-5-53 |Gorham....| -1,443 -1,445 5 bbl. oil
148 W. Pumped 3 weeks.
SE NW SE 9......4. 1-18-48 |Arbuckle
dolomite.| -1,420 -1,430 No record. PB to L-KC,
NW SW SE 9.....006 1-4-49 |....do....] -1,435 -1,446 seeeee dow. Do.
NW SE SE 9... 7-31-50 |....do....| -1,447 -1,451 Dry-eceeee Do.
SW SW SW 10....... 7-27-45 |....do....] -1,428 -1,428 eee edOrceceee Do.

9%




R.14 W. ony R13 W.

R. 2 W.

T T
T,

14 14) °
s. s. ‘

LE G E N OD

Status of G zone wells, January, 1960
© Oil well
# Abandoned oil well
© Water -input well
T + Dry hole t
=1160' structure, top of Lonsing-Kansos City Formation 15

; ros Original oil-productive limit $ i s.
Average porosity and permeability values for cored wells ° 19. a
Porosity,% Permeability, md. |
B > att 139.0 +—— -
° 1 2 3 4 T
N c ee 206 384.0 GI | Vv
SCALE - MILES o © 164 65 x poe
—eE + 174 38 i
| Fo 175 19
6 © I74 29.7
ft -—-—-—--FE. 4 SS Ett co jy
Riaw BARTON "COUNTY RI3W. T EF
16
s

FIGURE 23. - Original Oil-Productive Limit as Related to Structure,
G Zone, Lansing-Kansas City Formation.

6€


Bureau of Mines

Report of Investigations 6134

sxteay 8 9 10 " 2 3
PAN AMERICAN SACO PAN AMERICAN COOPERATIVE i a
SKELLY
J ones PETROLEUM CORP, ol co. PETROLEUM CORP. REFINERY ASSOCIATION OL co SKELLY CONTINENTAL TEXACO,
JE. Driscoll No. Fru ru in
hos 9 A No.l Krug A No! Rein No.7 Phinney No.9 ‘Opdycke No. 16 OIL CO. INC.
R.S.Hall No.6. 'W.S. Goodheart No.6 K
Perret pistons
rations. Intervals
| > <x TOP oF _LANSIN' KANSAS cITy yo
——$
z
d 1200-— _
Fe TOP OF G ZONE T.D.2900°
< + PBT.D. 3000 es]
g 10.3090"
3 1300 =
ra $0.31
o Base of eesng aus
z
z
5 L
Pn
8
1400f- arse or | 10. 3088
D.3i60 ey
Top granite wosh’ Top Gorham sond/*°- 373
7 1 9 20 ai 22 23 24 25 26
SMOKEY HILL JONES SHELBURNE, CARL MOTZKUS PAN AMERICAN ene DUKE @ wooo SHINDHELM PICKRELL Ol PRODUCING, LEE PHILLIPS
PETROLEUM CO. Nc. PETROLEUM CORP. on co. DRILLING CO Wwe. OIL co.
Kepko No. 3 Groy No.2 H.F Major No. 1 AC.Zeman Nol Ptacek No.3 Krause B No.2 Weber No Grizzet!_No.! Hilgenberg No. I Staudinger A No. 2 M
1100,
: LI LANSING- KANSAS r
3 a —< —
5 elt ge +4
5 Ly
a c g
> ° & = 13
& 1200b 5
s
3 ry q
o 1 H
6
3 ° H ~
8
a - H
z 1300 4 ld rd
5 L
8 o
=
° LEGEND
T.D.— TOTAL DEPTH
1400 LANSING ~ KANSAS P.8.— PLUG BACK
|| — a 1} _
L ‘daest H _ HS
TO. 3257° fe wes —
Top Gorham sond Top Gorham sand! Top Arbuckle 70-3289! To. Use Tosais aS
dolomite Arbuckle
10.3170" To aiomite Tor Arbuckle Top Quarta

‘Top Arbuckle dolomite

FIGURE 21. - Cross Sections J-K and L-M, Lansing-Kansas City Formation.

(Faces p. 36)


TABLE 12, - Plugging characteristics of injected waters

Weight of Percent composition
Throughput rate > retained solids of inorganic solids
cc. per min, after: Organic,| Inorganic,| retained on discs
Company Lease and well [200 cc.[500 cc.]700 cc.| mg./1. mg./1. Fe CaCO, CaSO,
Flood area I:
Texaco, Inc.........+++.|5.Boxberger 2....| 0.1 -- -- 249 53 55 ie) 45
Flood area II:
Texaco, Inc «+++|G.Boxberger A 4,.| 2 2 2 19 7 o) fo) 100
Dowseceescece «(Gurney 3........./ 15.1 6.2 -- 108 92 93 7 i}
Pan American Petroleum..|Krug A 9.........| 30.5 22.6 18,1 37 56 7 13 80
Do... woe[Rein 2..ceeeeeeee] 35.7 34.3 29.2 37 36 30 70 0
Olson, WS..s.eee- 5.7 -- -- 55 49 78 22 ie}
Boxberger 1l......| 42.2 40.1 37.0 15 16 70 30 i}
Cooperative Refinery. Phinney 9. 44.2 41. 38.1 16 10 3 2 95
Aylward Drilling.. Hall A 4, 3 3 53,931 794 70 25 5
Do... eee Hall A 7.... 40.1 37.0 15 16 70 30 0
Flood area III:
Skelly Oil....seeeeeeeee| Phinney 5....0004| 47.3 41.7 39.0 27 20 12 12 76
Cities Service
Petroleum. Ebel B 3. 17.6 10.3 -- 150 77 69 11 20
Do. Hickey 23.6 15.2 9.8 6 1 94 6 (e)
Flood area IV:
Skelly Oil.......+.++++-|Opdycke 10.......| 40.8 | 40.5 | 39.9 19 48 0 52 48
Flood area V:
Skelly Oil..............|Colliver 10......] 36.1 20.5 17.7 71 2 14 5 81
Flood area VI:
Continental Oil.........|Letsch 1........./ 35.5 29.7 22.1 89 4 0 100 O
MiScellaneous:
Cities Service
Petroleum......seseeeee(Graham 3.......46| 29.7 27.4 25.6 17 9 25 14 61
1 At a head of 1 meter and initial flow rate of 61 cc. per minute, 3 Plugged immediately.

2 Filter bypassed.

fos
BR


74

The Skelly Oil Co., Geo. C. Ehrlich No. 5 well was converted in 1947 and
for several years received water produced from other wells on the lease. The
volume of water injected into this well was small and apparently did not affect
adjacent producing wells. The conversion of a second well on the Opdycke lease
in 1950 caused an early increase in the rate of oil production. Other input
wells were added in 1953 and 1958,

Lease water, handled in an open system, is being injected into the for-
mation through cement-lined tubing. Until 1959 all input wells received water
under vacuum, but during that year pressure on the three Opdycke input wells
was increased to about 233 p.s.i., using two 4- by 6-inch pumps. The input
well on the Ehrlich lease continued to receive water under a vacuum, Water
injected in 1960 into Skelly Oil Co., Opdycke No. 10 well contained considerable
carbon dioxide and hydrogen sulfide but little dissolved iron. Filter flow
tests of injected brine showed negligible plugging by suspended solids or
entrained oil.

Figure 39 shows the year oil-producing wells were affected by injection.

The estimated oil recovery by waterflooding through 1959, based on extrapola-
tion of the normal production decline curve, was 202,500 barrels. This quan-
tity is equivalent to 27 percent of the 739,000 barrels of primary oil. Since
1950 the volume of water injected has exceeded total fluid productions there-
fore, the area and number of wells affected should continue to increase. The
volume of oil produced by waterflooding increased in 1959 and should continue
to increase for several years.

Waterflood Area V

In May 1958 Skelly Oil Co. began to inject water from a shallow well into
the Colliver, No.10 well, in sec, 28, T. 14 S., R. 13 W. Figure 40 shows the
wells on the lease and the area affected by the injection as of January 1, 1960.

Twelve Lansing-Kansas
City wells were completed
on the Colliver lease in
1938, 1939, and 1940. Eight
of these wells were completed
in the upper zone, but in the
early 1950's six were deep-
ened to the G zone. Well
No. 10, open in both upper
and G zones, was converted

@ re oe

I ween for injection in 1958. All
except four wells were open
FIGURE 40. - Waterflood Area V, Progressive in both upper and G zones.

Development.


33

Dry holes within the oil-productive limits, particularily in the east half
of the field, indicate that advancing water displaced oil from most of the
interwell areas. However, it is reasonable to expect that additional oil could
by recovered from structurally high areas where wells currently produce large
volumes of water.

The possibility of depressing a water cone and of changing either the
permeability or wettability of the reservoir rock to water should be considered
as a means for decreasing water production and increasing economic oil recovery.
Several types of fluids could be injected into producing wells in an attempt to
accomplish this end result. Gas or air could be injected into wells that
produce large quantities of water to change pressure patterns and force bypassed
oil to adjacent wells. Injected air also should preferentially displace water
from injection wells.

Reverse wetting agents have been used in laboratory and field trials to
reduce the permeability of reservoir rock to water (3). Some abandoned or
nearly abandoned wells producing from the lower formations could profit from
effective treatments.

LANSING-KANSAS CITY FORMATION
Reservoir Conditions
Structure and Stratigraphy

The Lansing-Kansas City formation is composed of a series of limestones
and shales that were deposited in shallow seas that alternately covered and
retreated from the land surface. These beds were deposited unconformably
on the erosional surfaces of pre-Pennsylvanian rocks. The Arbuckle dolomite
and other pre-Pennsylvanian rocks had been eroded from the structurally highest
areas of the Precambrian ridge in the western part of the fields here the
Lansing-Kansas City formation rests on igneous rocks.

The structure on top of the Lansing-Kansas City formation is shown in
figure 18. Areas above 1,140 feet subsea are shaded to illustrate the flat-
anticlinal structure of the field.

Although the structure on top of the Lansing-Kansas City formation gen-
erally conforms with that shown by contours drawn on top of the pre-Pennsyl-
vanian beds (fig. 11), off-structure thickening of early Pennsylvanian beds
has made less pronounced the relief on top of the Lansing-Kansas City forma-
tion. However, at some places, the structural positions of locally high and
low areas are reversed on the two maps. Most Lansing-Kansas City oil produc-
tion comes from wells within the area defined by the 1,160-foot subsea contour
lines in figure 18,

Figure 19 is a composite gamma ray-neutron log of the Lansing-Kansas City
formation with an accompanying description of individual members, The Lansing-
Kansas City formation in the central Kansas uplift area generally includes 12


PETROLEUM-ENGINEERING STUDY
OF THE HALL-GURNEY OILFIELD,
RUSSELL COUNTY, KANS.

By C. H. Riggs, Larman J. Heath, Don C. Ward,
and Ray V. Huff

» * 6 * » © » » & » » report of investigations 6134

UNITED STATES DEPARTMENT OF THE INTERIOR
Stewart L. Udall, Secretary

BUREAU OF MINES
Marling J. Ankeny, Director

This engineering study was prepared through a cooperative agreement between the Bureau of Mines,
U.S. Department of the Interior, and the Kansas State Board of Health,


52

Ey

LEGEND
{ © Oil well

# Abandoned oil well

Pa
| wacrr

[/

RaW.
}32,000 bbl. by waterflooding
(36.5% primary)

Wi} £
. Water LA 1},

Normal decline, est.

16

14

production, est.
900,000 barrels

°
1936 119371 19381 193911940 | 1941 | 19421 1943.1 19441 1945 | 1946 | 1947 11948 | 1949 11950 T1951 | 1952 T
YEARS

FIGURE 30. - Accidental Flood C, Progressive Water Encroachment
and Production-History Graph.

Since original free gas was absent in most of the Lansing-Kansas City
reservoirs, the initial fractional oil saturation was equivalent to 1 minus
the fractional connate-water saturation. For an average formation porosity at
each well, an average water saturation was read from the linear graph (fig. 24).
The original reservoir-oil saturation averaged 82 percent. The weighted aver-
age reservoir characteristics of the 333 oil-productive acres included in flood
C are tabulated:

wee Feeteccceceeees 12.9

percent........ 19.5
do.. - 18.0

«+ 82.0

» 1,245

-.» barrels..... 4,280,000

Net oil-productive thickness........66
Estimated poroSity..ccccccccccccsccece
Connate-water saturation teeeeeeee
Original reservoir-oil saturation.....
Original formation volume factor... .
Stock-tank oil originally in place........

Early records of this part of the field reported 2,600 to 2,900 feet of
crude oil in casings under static conditions. Crude-oil columns of 39° API
gravity would reflect a formation pressure between 950 and 1,050 p.s.i. In
many fields, a pressure gradient of 0.4 p.s.i. per foot of depth has been used.
Using this relationship, the pressure at a depth of 2,900 feet would be approxi-
mately 1,160 p.s.i. Thus, an estimated original formation pressure of 1,100


T.
14
s.
Status of upper zone wells, January 1960
+ Oil well
¥ Abanconed oil well
® Woter-input well
+ Dry hole *
T ~1160' structure, top of Lansing-Kansos City formation 5 T
15 re Original oil-productive limit - 15
s Averoge porosity and permeability values for cored wells i too, \" Ss.
Porosity, % Permeability, md. ” ¥
° 1 2 3 A+ 19.8 470.0
Be 16.7 53.9 7
SCALE - MILES nce 15.9 22.9
dv ® 13.2 1.7 ”
E+ 9.3 9.2
ad 30.6 27.0
G6 ®@ 16.3 62.9
H# 13.1 8.7 *
4-—-—- #8 Ett 2-9 Jy
R.I4w. BARTON 'COUNTY RI3W. T
‘8 ti 16
s rt Ss

FIGURE 22. - Origiral Oil-Productive Limit as Reiated to Structure,
Upper Zone, Lansing-Kansas City Formation.

8e




16

Analyses of Produced Waters

During the study of the Hall-Gurney field many samples of brines from the
producing wells were analyzed in Bureau of Mines laboratories, and brine
analyses from other laboratories were available for study. Table 4 reports
analyses of representative brine samples from the various producing formations
in the Hall-Gurney field arranged in order of increasing formation depths.

The analyses not only reveal differences in the compositions of brines
from the several formations but also show considerable well-to-well variation
in samples taken from the same formation and in samples taken on different
dates from the same well. Numerous methods for comparing analyses were tried
to determine which of the measured properties were most definitive of the
individual characteristics of a brine from a particular formation.

The specific gravities and sulfate contents were most useful in separating
and identifying brines from different formations. Figure 7 shows a plot of
specific gravities of brine samples versus sulfate contents. Each individual
point represents one water analysis, and the enclosed areas represent the
range of analytical determinations for each type of water. Each of the lower
formation brines has a wide range in sulfate content with specific gravities
ranging from 1.013 to 1.044. Analyses of samples from each formation are
identified by different symbols.

Dakota waters are only slightly heavier but contain considerably more
sulfates than lower formation waters; whereas Lansing-Kansas City, Topeka, and
Tarkio waters are definitely heavier but have lower sulfate contents than the
Dakota brines. The specific gravities of the Lansing-Kansas City brines range
from 1.074 to 1.118 with a relatively narrow range in sulfate content from
0 to 320 milligrams per liter (fig. 7). In general, water from the lower
beds of the Lansing-Kansas City formation is lighter and has a slightly lower
sulfate content as compared with water from the upper beds. However, these
variations are slight. Shallow or surface water has a comparatively low
sulfate content and low specific gravity.

The amounts of minor trace elements such as barium, strontium, potassium,
and lithium in representative samples of each brine were compared. Figure 8
is a plot of strontium versus potassium contents of brines from the various
formations. One Dakota water sample had a low strontium and potassium con-
tent, but a sample from another well had a high content of both of these
elements. Waters from the lower formations all have somewhat similar stron-
tium contents, but their potassium contents range from 40 to 124 milligrams
per liter. Very little distinction could be made between the Arbuckle, sandy
dolomite, and Gorham waters on the basis of the strontium or the potassium
contents, Brine samples from the Tarkio have high potassium and comparatively
low strontium contents; whereas, brines from the Lansing-Kansas City formation
have high strontium and moderately high potassium contents. The one sample
of Topeka water was high in potassium and very high in strontium.


Tanatng-Ranoes Clty

otal

Tarrels

‘Taracoy Toe,-C. Pokarek..
Biagk-faroal cine.

Major
P. Major

W, Indias.

By

8
8

§

Ss8ua8

E SeBena 2

Be
3

a
3
2
2
3
5
5
?
6
z
a
i

23,886
nigh
21,58

130,787
270;a10

1,155,008

510,924
059,819
168,809
123549

2,084

easel
19819

18,4098

198,598

218,308
286,319
Poll?

wut © 5 un was

oS EuSeue oF



24

wells were still oil
productive at the end of
1959. Dry holes, inside
14 and adjacent to oil-pro-
s. ductive areas, also are
shown on the map.

The first wells
drilled were high structur-
ally, and, therefore, appre-
« ciable quantities of water

were not produced until

after 1940. However, by

1950 more water than oil

was being produced from

most wells. Many of the
wells still being operated
are producing either large
volumes or high percentages
Tt of water. Operation of a
'5 well was discontinued when
a water production represented
95 to 98 percent of the
total produced fluid. Dry

LEGEN

Recovery per cere, Jonuary 1960
(Lower formations), M Bb.

Ory toe a = ® holes and former oil wells

i 2 = that were abandoned because
SCALE - MILES, aE of high water production

” “ * * “ ” * were used for brine disposal.
W-—-L_-—J_- Cop J RUSSELL clouNTY | = Data concerning dry holes

16 vf Tt within the oil-productive

T. BARTON COUNTY
Ss. q 16 limits are shown in table 5.
R.l2 W. s.

Representative Area,
FIGURE 13. - Oil Recovery Map, Lower Formations, West Half

East Half.
asta An area of 1,336 acres

(fig. 14) along the south
flank of a Precambrian ridge was selected to exemplify reservoir conditions
and production mechanisms in the lower formations of the west half of the
field. In this area, 50 wells produced oil from the sandy dolomite, 2 wells
from the Arbuckle dolomite, 15 wells from the Gorham sand, and 1 well from
the granite wash. In many wells only a few feet of the oil-productive for-
mations were penetrated. The original oil-water contact was at approximately
1,415 feet below sea level in sec. 35, T. 14 S., R. 14 W., but was somewhat
higher in sec. 29, T. 14 S., R. 13 W. However, bottom water originally was
not present under most of this oil-productive area.

Edge water, advancing from south to north, forced the progressive aban-
donment of wells as illustrated in figure 14 by the advancement lines for 1940,
1950, and 1960. The dates wells were abandoned, the producing depths, the
changing fractions of water production, and the ratios of oil and water vis-
cosities were used as guides to estimate horizontal and vertical water advances.


44

T

T

YEARLY OIL PRODUCTION, milton barrels

owl TT Toast TTT Teal TOT T Tewst TTT Tesol TT 1 TessT TT Toss

FIGURE 25. - Oil Production History, Lansing-Kansas Gty Formation.

1,600,000 barrels by 1959. Oil recovery by primary methods to January 1960 was
41,827,000 barrels.

Table 2 includes 011 recoveries from the Lansing-Kansas City formation for
each lease in the Hall-Gurney field. The recoveries per acre for each lease
are shown in figures 26 and 27. Oil recoveries from the different leases range
from O to more than 4,000 barrels per acre. This range depends upon many
factors: Well density, original oil in place, drainage across lease boundaries,
producing mechanism, and others. A comparison of figures 26 and 27 with the
structure contour map (fig. 18) shows greater oil recovery from the structur-
ally high leases.

With few exceptions, the amount of oil recovered from any well is not
phenomenal, Oil recovery from the lease on which the discovery well was
drilled (sec, 30, T, 14 S., R. 13 W.) was more than 14,000 barrels per acre.
This well produced oil for several years before other wells were drilled in
the area.

As of January 1960, oil recovery from 787 wells on 16,902 productive acres
in the field averaged 2,700 barrels per acre.


TABLE 11. - Dissolved corrosive gases and unstable compounds of injected waters

a
N
Milligrams per liter
‘Alka- Super
Carbon | Hydrogen| linity | saturation | Ferrous
Company Lease and well pH | Oxygen | dioxide | sulfide | as HCO, as CaCO, iron
Area I:
Texaco, Inc....| S. Boxberger 2..../5.9| 1.3 458 276 550 80 4.4
Area II:
Texaco, Inc....| G. Boxberger A 4../5.9| 0 194 56 210 50 3.2
Texaco, Inc....| Gurney 3°........../6.2] 0 172 54 270 60 2.8
Pan American Krug A ? eel ol 88 15 370 90 2.2
Petroleum.....| Rein 2... «| - 22 176 83 190 90 6.8
O1SON,*seeeeeeeeeee| - | 0 440 5 980 30 6.8
Sunray Mid-Con-
tinent Oil....| Boxberger 1?.......] - 8 194 48 125 35 6.0
Area III:
Skelly Oil..... | Phinney 5.......006] - ie} 110 19 530 30 9.1
Cities Service
Petroleum.....| Ebel B 3+. weeee [6.2] 0 167 61 240 90 16.0
Cities Service
Petroleum..... | Hickey ®........../5.7| 1.0 308 167 445 70 1.1
Area IV:
Skelly Oil.....| Opdycke 10°........] - 6 396 296 550 150 6
Area V:
Skelly Oil.....] Colliver 10.......] - 0) 48 10 185 10 9.2
Area VI:
Continental
Oil........... | Letsch 11°.........] - O 26 10 280 30 2.9
Miscellaneous:
Cities Service
Petroleum,.... | Graham 3 .......++-{5-8| 02 132 14 125 23 6

Mixture of Lansing-Kansas City and lower formation water.
Lansing-Kansas City water.
Mixture of Lansing-Kansas City and Tarkio water.

4
5

Dakota supply water.
Shallow water.


18

113) ae
TARKIO

LANSING - KANSAS CITY
Loshe

108 Lower
FORMATION

LEGEND

© Sandy dolomite

(2 Gorhom sond

SPECIFIC GRAVITY
3
T

tos 4 Arbuckle dolomite

<7 smutow
rr oo ee
1,000 2,000 ‘3000 “4,000 5,000 ‘6000

SULFATE, mg./1.

FIGURE 7. - Plot of Specific Gravity Versus Sulfate Content,
Representative Formation Waters.

Figures 7 and 8 and similar plots of other ions were used to identify
formation sources of mixed waters produced from wells with casing leaks or
from wells in accidentally flooded areas.

LOWER FORMATIONS

Reservoir Conditions

Structure and Stratigraphy

The areal geology of the pre-Pennsylvanian surface is shown in figure 9,
This map is based primarily on interpretations of drillers’ logs and repre-
sents the writers' best evaluation of available data.


80

from the brine. Filming amine, or other inhibitors, limits corrosion of sur-
face equipment. Transite* or cement-lined surface pipes and plastic- or
cement-lined tubing are recommended for injection systems.

Although most input wells accept water at low pressures, entrained oil,
precipitated iron, or scale may plug the finer pores in the reservoir and limit
displacement by water to the more open channels. Adequate settling and fil-
tering of the brine before injection should permit higher sweep efficiency
and increase oil recovery. Waterflooding experience in other limestone fields
has shown that slow imbibition of water into minute pores resulted in improved
oil recovery.

Control of Injected Water. - Discontinuous and unpredictable porosity in
the upper zone (members A thru F) precludes the possibility of large-scale
and carefully controlled flooding of any single member alone. Best results
will be obtained where all upper zone members are open in both input and pro-
ducing wells and have been treated with acid.

Porosity and permeability are more uniform and continuous in the G zone.
The G zone was subjected to several accidental floods and now has a higher
average water saturation than the upper zone. For this reason the G zone may
accept most of the water entering an input well open in both upper and G zones
Where both upper and G zones are being flooded, input water should be intro-
duced into the upper and G zones separately, either through different wells
or through dual injection strings.

Input profiles, used successfully in other waterflooded areas, could help
to determine which members are accepting adequate quantities of water.

Buckley and Leverett (1) developed theories and equations to predict
waterflood behavior in homogeneous sands, Guerrero and Earlougher (2) analyzed
several methods for predicting waterflood behavior and compared predicted with
actual waterflooding results. Apparently actual reservoir conditions usually
are more complex than those assumed for theoretical predictions because rates
and ultimate recoveries predicted by theoretical methods were higher than the
actual rates and recoveries. In the study of the Hall-Gurney field, data were
not adequate to permit calculations by any of the theoretical methods.

In the absence of data for such calculations, waterflood histories of
other projects in this and similar fields can be used to predict the behavior
of individual floods. Such comparisons should be used with care. Accurate
injection and production records for each individual well are helpful in
managing the waterflood operations.

The volume of water required to fill the formation surrounding the well
should be roughly equivalent to the cumulative quantities of oil, gas, and water
produced from the time the property was first developed. A plot of cumulative
fluid production since injection started versus cumulative water injected often
4

Reference to specific brands is made to facilitate understanding and does
not imply endorsement of such items by the Bureau of Mines


TABLE 1. - Field and production data to Jan. 1, 1960

Lower Lansing- Tarkio | Miscellaneous} Field

No. formations | Kansas City] sands formations total
1 |Date of discovery..ccccceccceseceeeee| 5-18-35 5-12-31 | 2-5-36 11-26-36 5-12-31
2 |Depth of wells.. . ooo feet... 3,100 2,850 2,500 -- --

3 |Productive area..........0++.aCTeS... 9,043 16,902 5,895 641 124,299
4 |Original formation volume factor..... 1.04 1,245 -- -- --

5 |Number of producing wells to 1-1-60 390 787 458 36 11,476
6 |Well density........acres per well... 23.2 21.5 12.9 17.8 16.5
7 |Natural recovery mechanism. seeee (2) (3) 4 (3) --

8 |Year of maximum production.....seeeee 1950 1942 1953 1948 1943
9 {Maximum annual production...thousand

barrels...sseeeeeeee 1,826 3,801 | 1,503 90 4,767
10 |Production 1959........5006 887 1,617 460 29 2,993
11 |Recovery to 1-1-60. eeeeeeeedOeee 26,836 45,637 8,098 1,368 81,939
12 |Recovery to 1-1-60. barrels
PET ACTC.eceeeeeeee een eeceeeeee 2,967 2,700 1,374 2,134 3,372

13 |Active wells 1959.....eceeeee 228 486 333 18 21,029
14 |Productive area 1959....... 5,253 10,510 3,995 319 117,227
15 Area under floddesccsccccsccceesdOves te) 53,705 |®1,900 0 15,141
1 Some wells productive in two or more formations.
2 Water drive.

3 Solution gas and water drive.
4 Solution gas.
: Area actually affected by flooding to Jan. 1, 1960.

Estimated from number and location of input wells.


63

Tests were made at several of the input wells to determine the possible
plugging characteristics of the water. The decrease in the rate of flow through
fine filter discs after passing measured quantities of water are indicated in
columns 3,4, and 5, table 12. Columns 6 and 7 show the weights in milligrams
per liter of organic and inorganic material retained on the filter discss and
columns 8, 9, and 10 show the approximate percentage composition of the inor-
ganic material. The amount of organic material was large in most samples and
was the principal cause of decreased throughput rates. Inorganic material,
principally iron compounds and calcium sulfate, could cause some plugging of
fine pores in the formation.

Waterflood Area I

Three leases operated by Texaco, Inc. in the SE1/4 sec. 10, Swi/4 sec. 11,
and NWw1/4 sec. 14, T. 14S., R. 14 W., compose Area I, Of the 480 acres in-
cluded in the leases, only 232 acres (fig. 34) had been affected by the flood
to January 1960,

This area is low on the flank of the structure along the south edge of the
field. The top of the Lansing-Kansas City formation is approximately 1,145
feet below sea level. Production is from the upper zone only, as the G zone
originally contained water. The first well on these properties was completed
in 1943, and three others were completed in 1944, Annual oil production
reached a peak of 95,000 barrels from 13 wells during 1949 and then declined
about 15 percent per year.

During the period 1954 through 1957, six oil wells were converted for
water injection by treating with acid and installing cement-lined tubing set
on a packer. Water produced from Arbuckle and Lansing-Kansas City wells is
directed through a closed system without filtering or treatment. Five of the
six input wells received water on a vacuum, but in 1959 a pressure of 350 p.s.i.
was required at one input well near the northeast corner of the flood.

Table 11 shows that the injected brine contains corrosive gases, some iron,
and unstable carbonates that could cause trouble. Filter-flow tests shown
in table 12 indicate severe plugging of the filter disc by entrained oil and
some plugging by iron compounds and calcium sulfate,

By January 1, 1960, eleven oil wells on 232 acres had shown increases in
the rates of oil production as a result of the injection of 1,684,000 barrels
of water. The number below each producing well in figure 34 shows the year
when the well was first affected. Increased oil recovery amounted to 109,000
barrels, 16 percent of the primary oil production. Part of this increase may
have resulted from acid treatments and cleanouts. Water production increased
rapidly in the late 1950's and in 1959 exceeded the volume of water injected.
The cumulative water-injected to oil-produced ratio was 15 to 1. Yearly oil
production by waterflooding reached a peak in 1958 and began to decline in
1959. The decline should continue because all Lansing-Kansas City wells in
the area have been affected by water injection.


69

The graph in figure 36 shows that the rate of oil production from Area II
began to increase in 1953 and continued to increase through 1959. During this
period the primary oil-production rate probably would have declined about 8.5
percent per year. Through 1959 a total of 1,329,000 barrels of oil, equivalent
to 29 percent of the total primary production, had been recovered by the in-
jection of 6,400,000 barrels of water. Ultimate flood-oil recovery should ex-
ceed 2 million barrels, more than 1,300 barrels per acre, from the 1,501 affected
acres,

wok ta 1
&

450

Om prowene—_ |

soot

assole

300}

33

200

1soh

woter

YEARLY OIL AND WATER PRODUCED AND WATER INJECTED, thousond barrels

1,329,000 bbl. by
planned tlooding

too

sob: '

J Normal decline, est.

PPTs TTT Teal TTT Tossa TTT Tres? TT Tr

FIGURE 36. - Waterflood Area II, Production-History Graph.

Waterflood Area III

Area III includes 1,167 acres in parts of secs. 19 and 30, T. 14 S.,
R. 13 W., and secs, 24, 25, and 26, T, 14S., R. 14 W., (fig. 37). The area
comprises 15 leases operated by 8 companies. It is in a structurally high
part of the field, where the average depth to the top of the Lansing-Kansas
City formation is less than 1,130 feet below sea level. A structural trough


43,

44,

45.

%

10.

ll.

12,

13.

ILLUSTRATIONS (Con. )

Areas suitable for waterflooding, G zone, January

1960. ere eccceccccccccnccssccecssccesccccscvccsecces
Gamma ray-neutron log of Tarkio section.....-sseeeceee

Tarkio formation, oil producing area and wells,
January 1960. ..ecccceccccccccccccccccecccsccccsccees

TABLES
Field and production data to Jan. 1, 1960.......2ecee6

Oil recovery to Jan. 1, 1960, by leases and producing
formations, Hall-Gurney field, Russell County,

KanS.cecccccccccccccccvvccscccceccccccscvssscscseces
Chemical and physical properties of crude oils........
Chemical properties of produced waters.....esccceccees

Dry holes within oil-productive limits, lower

FOrMALIONS. .oeeeecevcccccrcccccccccccccccesscccscces

Analyses and descriptions of selected Lansing-Kansas
City Core SaMpleS...cccccccccccceccccvcccce

Percentage decline in annual oil production for
Lansing-Kansas City wells.......cccccccccccccccccone

Summary of data pertaining to natural or accidental
WAteETFlOOdS. ce ereeeecrcsrccccccccccccssceccccscesoes

Summary of data pertaining to planned waterfloods,
January 1960....secccceccccccccccccccccscccccrsceces

Mineral analyses of brines injected into the Lansing-
Kansas City formation.

Dissolved corrosive gases and unstable compounds of
injected WaterS...ccccccccccccccccccsccccccsccssscee

Plugging characteristics of injected waters.........05

Core analysis, Tarkio SandS....ccsccceccccccccccccccce

Page

79

82

84

14

17

25

41

43

43

60

62
64

83


67

Several leases have been subjected to accidental floods by Arbuckle and
Dakota water since 1941. (See accidental flood B.) Accidental flooding has
affected oil recovery from the area, but the increased recovery (108,000
barrels) has been masked by that of the planned flood.

Waterflood Development

Early in 1953 a pilot flood was started on the Pan American Petroleum
Corp.-Krug-A lease when wells 1, 2, and 9 were converted for water injection.
During conversion operations, wells 1 and 2 were noted to have casing leaks
opposite the Dakota formation, which permitted accidental flooding of the
Lansing-Kansas City formation. Conversion of the wells included repairing
the casing leaks, installing tubing on packers, loading the annulus with fresh
water, and treating with 8,000 to 10,000 gallons of acid.

During 1956 the pilot flood area was expanded to include the Olson-A and
C, the Krug-B, and the Skelly Oil Co.-Driscoll leases. One additional oil
well was drilled, and 23 other wells were deepened to approximately 140 feet
below the top the Lansing-Kansas City formation.

Reservoir characteristics of the 480 acres comprising the Krug-Olson-
Drilcoll flood were determined from gamma ray-neutron logs and other data by
methods described earlier. (See flood C.) Reservoir data for the Krug-
Olson-Driscoll waterflood are as follows:

Average Connate- | Original Original
net oil- water reservoir- | stock-tank
Areal | productive | Estimated | satura- oil oil in
extent, | thickness, | porosity, | tion, saturation, place,
acres feet percent | percent percent barrels
Leases (A) (H) () (Sw) (So) (N)
Krug A..eeee 160 17.6 18.9 20.0 80.0 2,652,000
Krug B... 120 12.4 16.1 25.0 75.0 1,114,000
Driscoll.. 40 13.1 16.3 25.0 75.0 397,000
Olson A. 80 18.8 18.5 20.0 80.0 1,391,000
Olson C... 80 19.8 19.4 19.0 81.0 1,544,000
Total...| 480 eee eee eee sees 7,098,000
Weighted
aver-
age... eee 16.5 18.2 21.0 79.0 eee eeees

Operation of the Flood

Water for the original three input wells was produced from supply wells
completed in the Dakota sand. Subsurface centrifugal pumps raised the water
to a water-supply tank equipped with liquid-level controls. Water flowed from
the supply tank through cement-asbestos pipes to the input wells. The origi-
nal plan was to inject about 1,000 barrels of water per day into wells 1, 2,


R.14 W. RAS WwW R. 12 W.
| : :
, : re | pH HT! t . ; 7
a i TL i-productive limit, upper zone, Lansing-Konsos City formation a
s}ou | a AL Fl TT TT . - » . |
=e is “ Lf
k i
| i mp ade |: l-|-
® C ——+ TM s cd
|
. . T) Pe) Ik
| ae
ar aoa7e
SCALE - MILES Ky T
LEGEND ia »
t Floodable oreas e FBP | b
8 Poor il ] | Ss.
(REQ s000 4 L " »
co‘ Areos now flooded [-]
“4 . . »
a baat tL dL
16 T
Ss 's

FIGURE 42. - Areas Suitable for Waterflooding, Upper Zone, January 1960.

8L


46

did not invade structurally
low areas. Along the south
edge of the field, water
14 14 moved in a trough across the

] 8 south line of sec. 32, T. 14 W.,
R. 13 W., and advanced to a
limited extent along the west
” « edge of sec. 31 of the same
township. A structural re-
Oi prvetve nt entrant just west of the
» » TM center of the south line
of sec. 26, T. 14S., R. 14 W.,
provided another avenue for
limited water advance. Ex-
amples of edge-water advance
in the upper zone are dis-
cussed in more detail under
nL natural floods A, D, and E.

[a

T. G Zone

” a Natural water encroach-
ment into the G zone was less
pronounced than in the upper
zone. Undoubtedly much of
a) the water produced from wells
ScaLe-miLes ‘ . in the G zone was the result
COUNTY of either poor plugging ;
jw country — operations or leaking casings
T that started numerous acci-
s. dental floods; this will be
discussed later. In T. 14S.,
R. 13 W., the water level
rose from 1940 to 1958. The
amount of rise was estimated
either on the basis of in-
creasing volumes of water being produced or from the depths of wells and the
dates they were abandoned. In structurally high areas of this township the
water rose to an estimated 1,218 feet subsea from 1,230 feet. In other areas,
where the original water level was approximately 1,240 feet below sea level,
the rise was 8 feet, bringing the water level to 1,232 feet below sea level.
A limited amount of water encroached central parts of the field from a struct-
ural trough in the southeast corner of sec. 20, T. 14 S., R. 13 W. A similar
encroachment, moving southwest through the center of sec. 19, increased water
production but did not completely flood any of the wells.

Ow 100

RUSSELL

BARTON

FIGURE 27. - Oil-Recovery Map, Lansing-Kansas
Gty Formation, East Half.

Formation water moved east from a structural trough near the center of
sec. 21, T. 14S., R. 14 W. The first wells in this area, completed in 1939
and 1940, produced little water from the G zone, but by 1942 at least two of
them were producing substantial quantities of water. By 1944 average water


42

TABLE 6. - Analyses and descriptions of selected Lansing-Kansas City
core samples (Con. )

Permeability, Irreducible
Depth millidarcys water
and hori- | verti- | Porosity, content,
member | zontal cal percent percent Core description
Well No. 2
29996... 1.8 -- 15.5 -- Oolitic limestone, fair poro-
sity, no stain.
3054H... -- 3.4 10.4 -- White, fossiliferous lime-
stone, pinpoint porosity,
poor to fair stain.

Lower Zone

In general the J and deeper members
of the Lansing-Kansas City formation are
not oil productive along the north edge
of the field. The J member probably
contains water in this area, although
confirmatory evidence is lacking. Pro-
duction from the J member seems to be
associated with an absence of water in
the G zone throughout the central and
southern parts of the field. Because of
the very few attempted well completions,
little information regarding fluid satu-
10 ration of lower zone members is available.

AVERAGE POROSITY, prewnt

Qil Production History
FIGURE 24. - Approximate Relation-

ship Between Connate Initial Production

Water Saturation and

Porosity, Lansing- Recorded initial production rates
Kansas City Forma- for several Lansing-Kansas City wells
tion. completed in the late 1930's were as

high as 3,000. barrels of oil daily.
However, state-wide proration limited individual well production to less than
100 barrels per day. Proration continued to restrict individual well-producing
rates until 1946, when most wells could not produce their prorated allowables.

Normal Decline Rates

To evaluate the results of the natural and accidental waterflooding and
planned flooding operations, normal percentage decline rates were calculated


TUBLE 2, ~ G12 recovery to Iesses o0d formations, Coonty, tans,

Toner Foreatione
Taree “Sealy Waloars Crentta vad Lansing-Fansan City Tarkio Miscetenwces rout
Prodacer2/ and lease Barrels [sores [Wella | Harrele [Acree [Wells | Barrels [loreo | Wells | Brveis [ores [valis| Barrels] sores | Valls] Barrels [lores [Wile | tarrela | Welle | ervels [Wells

A Soy Re 32 Wat

sos] a7 a
aos) 99 5
2 tons | 36 i
33k | ap 2
160 5
120 1
to 2
song | oney 5
3 | seen i
#6 3
Tovkng O11 Cov-Rarlichsessees | seeeee wiht} 60 whee | 6
Soomler, Be Bncrow esvcs | 372) 10 re) 2
secy 8
Lees] “Shawtory Be BeoFinkesseeeoee sessees aaron] 10 a
2 ‘Conps-Biakreesessssens mn 65,138] Lo i
10 ry

"% 3
ye ssssees >
2 " i
3 INSEE 7
2 2
30 H

uo
2° 5
~e ry
2 i
& H
5 é
02) 85 $
sesssesss fences sayoes| 50 3
aist| 0 H
225,353| 110 wz
399] 160 >
rep t9 1
63) 5
Soraso| fo 2
res3| 100 Ftd
825] "t Fd


Bureau of Mines Report of Investigations 6134

DEPTH BELOW SEA LEVEL, feet

1 2 3 4 5 6 7
COOPERATIVE PAN AMERICAN TEXACO COOPERATIVE. AYLWARD SKELLY NATIONAL COOPERATIVE
REFINERY ASSOCIATION PETROLEUM CORP INC. REFINERY ASSOCIATION ORILLING, CO. OIL co. REFINERY ASSOCIATION
G Krug “AT No. 1 S.Boxberger No. 3 Boxberger No. | Horace Fink No. | Holl “A” No.18 JE.Driscoll No. | Mai No. 2 H
1100
Porous intervals Casing perforations
/ KANSAS CITY x
L 4 TOP oF LANSING — oo S
= =
2 a E|
1200 - | =
TOP OF =
F - =
L > , — 4
T.0. 3140 — SN
1 1.0. 3134" _ _ TM
3
Lj BASE oF 6 ZONE 7.0. 3090"
1300 4 TT a
3 LEGEND
=
a T.D. — Total depth
2 P.B. — Plug back
x
3
1400 ;— _ BAS oF alisIng— CITY
=) = BASE OF LANSIN KANSAS CIT
10 3287" —~tap sondy To. 38 Top sondy Top sandy dolomite
Base of ca dolomite dolomite
T.D. 3280"
Top Arbuckle dolomite
~a4
~— 7.0. 3205'

FIGURE 20. - Cross Section G-H, Lansing-Kansas City Formation. (Faces p. 36)


37

The 1,160-foot-subsea contour lines were superimposed on the well-status
maps of both the upper and G zones as presented in figures 22 and 23. As can
been seen from these figures, the oil-productive areas evidently were more
dependent on porosity and permeability conditions than on structural relief
Except in the northwest and southeast extremities of the field, most of the
oil-productive areas of the upper and G zones lay within the 1,160-foot subsea
lines. However much of the area within these contour lines was not oil-pro
ductive, especially in the southeast part of the field and in the G zone in
the extreme northwest part.

Lithology

Cores from two wells were available for analysis in the Bureau of Mines
core laboratory. Table 6 gives core descriptions and the results of analyses
of selected core samples from these two wells. The formation-sample descrip-
tion (fig. 19) and the core-sample description (table 6) show that most
Lansing-Kansas City beds are similar and are comprised of white, grey, or buff,
finely crystalline limestone. Many porous streaks are associated with oolitic
and fossiliferous intervals within the separate members; oolitic, oolicastic,
vugular, and pinpoint porosities are prevalent. However, many of these porous
streaks also have low permeabilities

Average porosities and permeabilities for wells A through N (figs. 22 and
23) were determined from analyses by commercial laboratories. Data from analy-
ses of cores from eight wells show that, in the upper zone, porous samples with
porosities greater than 7 percent had an average porosity of 15.2 percent.
However, for core samples having porosities between 7 and 12 percent, one-half
had permeabilities less than 0.1 millidarcy, and thus could be considered non-
productive. In the G. zone, samples from six wells with porosities greater
than 7 percent and with permeabilities greater than 0.1 millidarcy, had an
average porosity of 15.9 percent. Of samples having porosities less than 10
percent, one-half had permeabilities less than 0.1 millidarcys whereas only 18
percent of the samples with porosities greater than 12 percent were impermeable.
In the lower zone, porous samples from five wells, with porosities greater than
7 percent and permeabilities greater than 0.1 millidarcy, had an average poro-
sity of 10.8 percent. Of samples having porosities greater than 7 percent,
only one-tenth were impermeable.

Reservoir Fluids

Three wells in the structurally highest parts of the field initially
produced 8 to 11 million cubic feet of gas daily from the upper zone of the
Lansing-Kansas City formation. Throughout the rest of the field, pore spaces
originally were filled with oil or water in percentages depending somewhat on
structural position and capillary properties of the reservoir rock. Above the
top of the transition zone, normally referred to as the oil-water contact,
original water was fixed or immobile. The percentage of the pore spaces
originally filled with immobile or connate water was determined by the re-
stored-state method on core plugs from two wells. These core samples were
saturated in the laboratory with brine representative of the Lansing-Kansas
City formation and desaturated by nitrogen at pressures up to 50 p.s.i. Residual


66

—16 15
78 rh CRA RA.
| 4) &
4
Se
4 ry
438 59
a ink \oroce Fink|\ Herb, Flak ‘60
1 Texaco Texaco
3 : SS 3
$- Z 5 $6 yg 56 A
6 $8
Zz
6
3 guile 3 @
56 S| sr bly 5
—2i _—7> Boxberger-8 | EP Guney 98». Gurney
(al piegerg Sunray | Texaco | Saco
fy 3 3
3 ed Bla S/R £126
A
[Cora O71 Z
Royalty 3
ry
Holl 14

LEGEND

Oil well open in both zones

Oil well open in upper zone only 26

Oil well open in G zone only

Year well was affected or injection began

Woter-input well

Ory hole a
A. — Cooperative Refinery Association hw

1000

wu
*
Es)
Abandoned oil well
@
Se
cR.

SCALE - FEET

FIGURE 35. - Waterflood Area II, Progressive Development.

Primary Development

The first well was completed in 1935 and had an initial daily potential of
360 barrels of oil, Field development was slow, and drilling was not extensive
until wells with high initial production rates had been completed in 1939.
Eighty-six oil wells had been completed by the close of 1959. Wells were
drilled about 100 feet into the Lansing-Kansas City formation and completed
with casing set at the top of the formation, leaving members A through G
open for production. Many wells were treated with 4,000 to 5,000 gallons of
acid and some with as much as 10,000 gallons.


Bureau of Mines

Report of Investigations 6134

RI3W.
6 6 5 3
rs
: as
3 as e =
ole 2 wey j 2 ra
lg e fe ra
ee] ve Slee ow Fe
¥ |
i
Le een
© OF wel
4% Peandened oi wl
‘Gos weil T
Ti] | © woter-input we wet 14
@ —toordones worn! wel Page
14. [8 © water disposor weit Geel ences! Ss.
@ —Avondones woter disposel well 4 [re alone
S. |p oon role o ler ar
©” Well number 3 le ese 7
3 Leose nomber ote “
wie va
1 Hl
» ale ele
30 2 20
7
g
a
5
¢ <
3 °
id .
%
7
é|
T ‘ JT.
15 ° ‘ a IS
s. Ss
¥

R.14W.

R13 W.

FIGURE 3. - Location and Status of Wells and Leases,
Hall-Gurney Field, West Half.

(Faces p. 6)


41

TABLE 6. - Analyses and descriptions of selected Lansing-Kansas City
core samples

Permeability, irreducible
Depth millidarcys water
and hori- | verti- | Porosity, content,
member | zontal | cal percent percent Core description
Well No. 1

2882A... 14.5 -- 13.3 -- White, finely crystalline to
oolitic limestone, pinpoint
to vugular porosity, fair to
good stain.

2888A... 3.4 1.3 9.7 39.7 White, dense to partly oolitic
limestone, spotted fair poro-
sity and slight stain.

White, fossiliferous to ooli-

29048... 7.3 ~~ 1946 29.0 } tic limestone, good pinpoint

29058... -- 4.3 18.3 31.0 porosity and stain,

2918B... 10.9 -- 21.4 28.3 White, crystalline limestone,
good pinpoint and vugular
porosity, good saturation.

29198... 4.3 -- 15.2 68.5 Partly oolitic limestone, fair
pinpoint porosity and stain.

White, finely crystalline
2965G... | 2420.0 -- 18.0 8.0 limestone, good pinpoint and

29666... | 3420.0 -- 17.9 7.0 vugular porosity, fair satu-
ration.

296%... 1.0 -- 8.3 -- White, finely crystalline,
partly oolitic limestone,
trace pinpoint porosity, poor
stain.

29756... | 30.0] 14.2 | 19.5 17.4 | [Miter Finely crystalline ool-

iestone, good porosity,
2977G...] 49.0] 4.4 22.8 11.5 fair saturation.

29826... 4, 8.6 15.8 25.0 White, finely crystalline,
partly oolitic limestone,
fair stain.

Well No. 2

2984G... 9.6 2.3 20.6 7.6 White, fossiliferous and ooli-
tic limestone, good oil
stain.

29866... 15.2 -- 22.4 11.3 White, oolitic limestone,
finely crystalline, good oil
stain.

6.9 -- 19.0 -- White, oolitic limestone, pin-

16.0 -- 18.9 8.5 point and oolitic porosity.

3.2 1.7 22.4 16.0 White, crystalline, fossili-
29956... 1.2 -- 17.8 36.8 ferous to oolitic limestone.



li

CONTENTS (Con. )

Accidental flood F.....
Accidental flood G..

Planned waterflooding....secccccee
Waterflood area I.....6..
Waterflood area II.....

Primary development...

Waterflood development.

Operation of the flood.

Results of flooding...

Waterflood area
Waterflood area
Waterflood area
Waterflood area
Potentialities....
Waterflooding..
AT@aSceeee

Procedures

Other improved recovery m

Tarkio SandS..csesscccccscssscevecs
Miscellaneous formations...
Bibliography...

ILLUSTRATIONS

1. Location of Hall-Gurney field, Russell County, Kans...
2. Gamma ray-neutron 10g......eccceccccccccccccccvccscees

3. Location and status of wells and leases, Hall-Gurney
field, west half..

4. Location and status of wells and leases, Hall-Gurney
field, east half......cccecccccccceccccccccsccsecces

5. Production history of oil-producing zones....eseeeeeee

6. Correlation index versus fraction number, representa-
tive oil samples........

7. Plot of specific gravity versus sulfate content,
representative formation waters.....scccccecccccsees

8. Plot of strontium versus potassium content, repre-
sentative formation Waters....cccscccccccccccccecces

15

18

19


58

LEGEND

© Oil well

§ Abandoned oil well
+> Dry hole

@ Water-input well

A—Arbuckle

A-D —Arbuckle-Dokoto

L-KC.—Lansing- ~
Kansos City

D— Dakota

L-Kc-
+

"41

D~'52

LKC-"42
-

|— Qil-productive limit

° 1000 2000 3000

SCALE- FEET

300
280
260
240
220
200
180
160
140
120
100
80
60
40
20

ews TTT TT TTT

—T
2 we

et

2

Normal decline,
est.

—S |

Primary production

1,991,000 bbl. est.

380,000 bbl. waterflooding
(19% of primary)

OIL AND WATER PRODUCTION, thousand bbi.

°

1938! '391'40 M41 Ma2la3 aq a5l46 14

YEARS

7148la9l'50l'51 M’521'531'54l'55 156 1'57 M'5el's9

FIGURE 33. - Accidental Flood G, Progressive Water Encroachment
and Production-History Graph.



TABLE 4, - Chemical properties of produced waters

Milligrams per liter

Formation Specific | Calcium | Magnesium] Sodium | Strontium | Potassium | Bicarbonate] Sulfate | Chloride] Total
source gravity (Ca) (Mg) (Na) (sr) (K) (HCO, ) (so, ) (C1) | solids
1,005 226 33 665 263 130 1,280] 2,601
Shallow sssseeee | 13 O06 366 22 726 244 241 13567] 3,166
Dakotasssesesese | {+033 425 580 | 14,519 30 61 969 3,198 22,050] 41,832
1,047 416 1,410 | 23,737 384 200 835 5,444 34,390 | 66,816
1,123 11,780 3,740 | 49,700 320 --- 110 859 108,320 | 174,829
1,123 11,585 3,600 | 46,400 315 --- 128 383 102,800 | 165,211
1,123 10,335 4,050 | 48,423 305 167 3 1,293 104,600 | 169,246
1.130 11,880 4,105 | 52,076 300 144 49 144 113,460 | 182,758
Topeka 1,107 8,050 3,200 | 42,065 1,250 135 137 64 90,000 | 144,901
sereserees | iog 11,680 4,050 | 51,518 --- --- 3 --- 119,000 | 186,321
1,095 8,800 2,400 | 38,463 31 trace 83,300 | 133,831
1,088 10,830 1,300 | 22,867 49 trace 74,800 | 110,549
Lansing- 1.104 8,855 3,100 | 38,583 99 199 85,100 | 136,598
Kansas City.... }d 1,112 9.627 3.100 | 44,300 100 272 95,000 | 152,872
1.082 6,822 2,128 | 32,144 96 310 67,705 | 109,205
1,096 8,228 2,852 | 36,646 --- 98 102 79,240 | 127,166
1,088 7,570 2,648 | 34,536 oo o-- 102 240 74,125 | 119,221
1,023 990 400 9,115 110 85 586 1,276 16,000] 28,562
1,023 1,060 315 8,621 140 79 441 700 15,700} 27,056
Gorham. .++++++++ |o 1,023 1,000 400 8,405 130 95 475 1,286 15,100] 26,891
1.019 1,300 340 oo- --- --- 468 1,280 12,700| ----

1.020 1,328 325 --- --- --- --- 2,780 11,000
1,018 1,308 359 7,211 92 89 525 1,812 13,100| 24,496
Arbuckle, 1.027 2,010 484 90 109 481 2,500 18,300] 33,765
1,022 1,596 274 104 66 539 1,957 14,300] 26,670
1.020 800 300 100 105 788 318 13,500] 23,406
1,023 1,174 300 126 102 689 255 17,000] 28,844
1.020 868 200 132 100 799 4ll 11,600] 20,510
Sandy 1.030 1,900 400 --- --- 179 18,300 | 30,871
dolomite....+-. | 1.027 1,724 500 1,950 17,600} 32,083
1.027 1,270 517 400 18,400] ----

1,022 1,290 390 600 16,800

1.025 1,376 546 oo 2+ oo o-- 400 19,000

1.025 1,320 600 9,420 180 80 642 279 18,500

LT


56

R12 W.
LEGEND
© it walt
N T. ‘58
2 1000 2,000 14-31 "50°
SCALE-FEET s. .
:
.
°
isoh ay . co
10h oo
130 "58:

lope
Hob
Joo

80 Water
woe ‘71,000 bbl. by waterflooding

{15.1% of primary)
1943 | 1944 T1945 Ti946 Ti947 T1948 Ti99 T1950 T1951 T1952 T 19537 1954 T1955 T1956 | 1957 | 1958 T 1959 [

YYW
mal decline, est,

Nor

OIL AND WATER PRODUCTION, thousand barrels
2
&
T

FIGURE 32. - Accidental Flood F, Progressive Water Encroachment
and Production-History Graph.

the west edge of the area. Well F, a structurally high well completed in the
upper zone of the Lansing-Kansas City formation, had no increase in water
production until 1956.

Water samples taken in 1958 and 1959 from Lansing-Kansas City wells C,
D, E, and F (fig. 32) were contaminated with Arbuckle water. Faulty plugging
is assumed to have permitted some Arbuckle water to enter the Lansing-Kansas
City formation, but no one well is identified as the source of the water. In
1959 wells were still producing, and daily water production was about the
same aS in 1949, Apparently only a limited amount of Arbuckle water entered
the Lansing-Kansas City formation. This extraneous water is being exhausted.

Figure 32 shows the oil and water production of the nine affected wells.
The expected normal percentage-decline rate for these wells (table 7) was
estimated from the production histories of adjacent wells.


Ria Ww R13 Ww R12 w.

ica. |. -]-1-1-]-
SS :
BS Ammer . _ “|
a ene | ~ |.
' | A i
s A ad cane tet a wt » » s
Leet Uae lla aod ts .
a l@ Cf fr
add y Hoty
. ” a % tL! \ Pie | CH ? — ] “ ve
1 LI Ge
¢ tq
‘ i , i yy
° 1 2 3 ’ fe IPFA
_———
| ‘SCALE-MILES. "y ih. i]
15 4 LEGE 4 2 Lk E |e x
s Natural or accidental floods $ ] s.
| Planned flood areas » BS ots
© Woter-input or disposal well + ee rf
; —_
a RLY SS
Te haw anton TeouwtY abe i; >
T
$ oy ‘8
R12 W.

FIGURE 28. - Location of Planned and Natural or Accidental Waterfloods,
Lansing-Kansas City Formation, January 1960.

67


‘TUBLE 2. - OLL recovery to Jan. 1, 1960, by leases and producing formations, fa:l-Ourasy fteld, Russell comty, Fane. (Con)

Lower formations

‘corhan Treaokle Sandy dolowite Oranite wash Lmsing-Fanses City texto Miscellaneous Toul
Barrels [deres[ wells | Barrels [teres [wells | Serrois [herve | woils | Barrels [Acres [wills] Barrels [sores | wile | berreie [teres [Wile | Bervele [Wells | barrels

|
eI

23,066

212,551
70,438 :

rey wee
77,095
243,313

"58,585
Let

Re
$5,t7|
vee | 28,007

‘Smokey HLL1-Roges.
‘Skelly Of} Co.-0. C,

3329
2,090,824
23,345
B62
291225

ag, 988
21686
38,Lg
12,066
394198
20}

BIS BSBEIS Ss Byes!

8 si gess 55:
Uemerue Menu HnuRE Une @ AMeue Peme,

4

1

2

IED i rays | 6
Fassessrene ipeeees bette tees 183m |
. 23,695 2

EID | H9;2i8 fae [2 397,605 | 5

seeeeeaee tees sess feseee sees | uso | 2

8
5
4
6
5



T. 16 S., R. 12 We:

SW SE SW 10....... | 10-19-51
SE SW NE 14......- 2-8-56

NE SW SE 14.. 3-22-57
NW NW SW 15,...... | 3-22-46

NE SW NE l6...006 7-2-54

E W SW 16....... 2-7-58
3-4-49
9-5-48
3-18-50
2-15-52

3-3-59
9-18-51

4-14-50

10-13-50
9-6-53

S NW NE 29....006 8-4-58

SW SE NE 6.....006 6-1-51

Arbuckle
dolomite.
see edOeeee

oeeedo.
woe edOveee

wee edOveee

oe edOeeee
oe dOveee
2 dOseee
dowese
do..ee
do.

do.eee
do..ee
dow...
wee edOeeee

oe edO.ee.

-1,433
-1,508

1,471
-1,602

-1,447

-1,462
-1,455
-1,450
1,463
-1,463
-1,456
-1,450
-1,472
1,469
-1,462
-1,469

-1,447

Dry...
Water.

eee eeedOeeeeeee

Small show.....

Show oil, black
water.

Water after
acid.

Drilled to granite
wash.

PB to L-KC,

Disposal well in
granite wash.

No record.
Do.
Do.
Do.
Do.
Do.

Dry.

PB to L-KC.

Plugged.

Abandoned.
Do.

Squeeze cement
twice.

1

PB--Plug Back; L-KC--Lansing-Kansas City; and S,I,--Shut In.

[x4


43

for different areas of the field. Most of the wells had been either deepened,
acidized, or fractureds few had long uninterrupted production histories. In
each of several different areas the production histories of selected wells were
used to determine representative normal percentage-decline rates.

For each area a smooth decline curve, beginning with the year of maximum
oil production, was drawn using plotted annual production rates. Average
annual production rates read from this smooth curve were used to calculate
percentage declines in yearly oil production. Table 7 shows the percentage
decline per year after the year of maximum oil production for seven groups of
wells, The percentage-decline rate for the first of these groups is almost a
constant values whereas for the other groups declines are of the harmonic
type, proportional to the production rates

TABLE 7. - Percentage decline in annual oil production for Lansing-

Kansas City wells

Years 4 wells 8. wells
after used for used for Planned floods
maximum accidental | accidental 21 wells,| Area Area Area | Area
production flood F flood C fieldwide II III v VI
16.2 39 35.0 32.3 27.8 32.4 | 43.6
15.5 28 31.0 31.3 24.4 26.5 | 30.4
14.9 16 26.5 22.6 24,2 24.9 | 19.6
14.3 12 22.4 19.2 22.5 22.2 | 16.9
13.6 10 19.9 |?16.8] 18.9 | 19.7] 11.8
13.0 9 16.3 | 13.4] 17.4 | 16.2] *9.6
12.4 8 14.0 12.0 15.0 |*12.4 TL
11.7 17 12,1 10.1 14,1 11.0 6.8
11.1 6 10.5 9.1 13.2 10.1 6.5
10.5 5 9.2 8.5 12.3 9.0 6.1
9.9 5 8.3 -- 11.4 8.7| 5.6
-- 5 7.5 -- 10.9 8.3 --
-- 5 6.9 -- 19.5 8.1 --
-- -- 6.4 -- 9.0 6.8 --
1 Percentages for subsequent years obtained by extrapolation.

It was assumed that, for each group, the percentage-decline rate should
reach a constant minimum value between 5 and 10 percent per year sometime be-
tween the lOth and 15th year after the year of maximum production. The percen-
vage-decline rates presented in the table are as reasonably accurate as available
data permit and were used in estimating the increased oil recoveries from flooded
areas.

Oil Recovery

Figure 25 shows that oil production from Lansing-Kansas City wells reached
a maximum of approximately 3,800,000 barrels during 1942 and declined to


a
ct 2
20 esoen
56 2
Eo 2
2 i
3s i
a i

lenny ses
ros] 2

| 5 H

nl 3 3

3] 1

wl} ot i

aloo 4

1 i

2 3

ake IEE) at 2%

4 4

b é

2 2

i i

a a

2 2

rt a

3 A

‘

a

3 2

sesse i

ree sive] 22] 2 suo | 2
sessetee wanor| 2] 2 ranor | 2
EEE ‘asa |
EEEI! Beieo |

a 1,260 10] 2 ree |b
nin | Finale) ] 2 | ttf ae Poser Bios | 2
man] Aone) 4] rayne
seseese oneee 18,996 2 reese | a
ye2n| | 2 anys |
ubfaie] 38 | 2 uses | 2
ese | eeeseeeee, seeeeee seeee see | eveee 19,678 2 19,678 1
ests | sassssanefoceee exr,344| 0 1
In 2 Bi| 2 H
Enh i i
i Fd
2 it 3
sees & i
mn é
seen 2 ago
» Sh | deestge
5 x10] ik soiinfitic [inti | igs [75 | derisat
ee 10, 36, 740] 183, 15,636,067 |16,902 | 767 | 8,097,719 15,895 58 | 1,368,234 | _36 161,938,502

7 Wor incation o figure 3-

1 Comlata name of companies or inlividuals are Listed: rao bing Co, Ia Frenne Ptrofing co, of Tia Meade Driling Co} Mamet & beris—Bemat & brie ol peetion
Trenton aeane Sey ul ow) mac Sarmall~aiach-narba OL Coy Cale hwptom-able imran Mowe a Lin fo Carian O € Ryety oy Gitien Sarton cities Service Petrolnes Gon Geloratow dolore
Ss ap Gomme ~Contoetal ou eps nk Lore ecompetir tinry Hagens wu Palng Soy Ful tf Poth ae Gary Pao Omtaietree cute OW Ge} item Sat
Sot, BAL! Sodsrods dy mall Operating Covy'Isc) Beimirdeh U Pagsomlaerioh & Pagan, ince) SayunJepheee Well Servicing Con) JuLieo-vulian O1L & Roynty’Goqy Iaysteneoystos Petrolems, Toe.j Haein Ott Gos, Ine}
Aiaten"h uso i coy tarp moter ning, ay tvieumre ihn Cy) aul, Lennie Rem Opens Rot ta Bciin, en ertinurin sling ca atoms Be
Soeoeiztion Of PrediaingTM—0U en Aardeat Pan tnoricen Petrolote Cotpey Pallipe, ivorunt Pailipe OL Co,y PeillipePalilips Potrelee Cony lskrolin-Plcbwll Drilling Go.) 3 & 8 Pipes & 3 Pipe end
Say cay seen ‘Slacaircsineisir Oi Gee ou) smokey tlicseotny HAL ftrolem Go. Sokdom ohio utrolem Guy Stecrar~ Sear, utrolemy Inu} StensSteren tn Serre)

Produce
Nadtconts-—Saarey Wid-Continent O11 Co,y Renn, Gaa—Tenmesess Gas & Oil Co.) Wiikinson—-Miikinsoa Drilling, Tae.) tood—dood Petrolemn 0o.j Temnitts Tlamutts Driling Co,j Yaroell—1
1 Combined With Tease Wo, 6, 2006 27. WY Combined with lease No, 3, 00, 16, J Combined with lease Ko, 2, o8e, 2, 6/ Conbined with Lease Wo. li, sec, 22. 1/ combined with Lease Ho. by seo. 29.



76

\ a |
2 26
Shee Continental
2 yoy 0
_—_ fu a) * & $ Ea Woter injected
pear | a ° 5
hy £\e% , Q F
Uo au
LEGEND 3 4 a
400F- © Oil well open in both zones ”

2 , 4
: fy Oi-ctt open in aspersone | 3 .
5 or ection begen >» i
2 Abandoned ol well 3 . '
= © Woter-input well 4 H
Bf : an
2
5 i
s !
2 H
&
2 cool
3 ia produced 4
ia r 5
& Primary production
g 2,479,000 bbl
5
°
2
© oof
3
> Te Wier proguced
iti nea

iad rc “Lt

|
|
wl 1 Teal 1 T T toast T 1 T Tesol T T TV TosT T TT Toso

FIGURE 41. - Waterflood Area VI, Progressive Development and
Production-History Graph.

to an economic limit of three barrels of oil per well per day, and oil pro-
duction after that is considered to be the result of planned flooding. The
normal decline curve shown in figure 41 is the sum of the individual lease
decline curves. Through 1959 total oil recovery by planned flooding amounted
to 193,000 barrels, about 8 percent of the oil produced by primary methods.
Nearly 1-1/2 million barrels of water has been injected; the accumulative
water-injected to oil-produced ratio was 5.5 as of January 1960,

Potentialities
Waterf looding
Areas
Many factors should be considered in evaluating properties for waterflood

development. The primary oil recovery, thickness, porosity, and probable oil
and water saturation of the formations are valuable guides. In the absence


R.14 W. ~ R13 W. R. 12 Ww.

ra

im Se. .

ae
{
Ve

S|
Us
iS

° 1 2 3

SCALE- MILES |

Contour interval - 20° 0
; N vont
Areas above 1140' subsea ,

ah

ar!

“Ths

4 FT

_ RUSSELL COUNTY . q

Sag (ane
x 2 : |e. = .

BARTON COUNTY - . TZ |

G-H, J-K, L-M. Location of cross secti im
shown in FIGURES 20 and 21. x 2:
ea
m

FIGURE 18. - Structure Contour Map, Top of Lansing-Kansas City Formation.



71

Yearly oil production was sustained between 1944 and 1952 at a level higher
than normal as a result of an accidental flood. (See accidental flood Cc.) A
total of 220,000 barrels of oil has been attributed for this area to the acci-
dental flood.

The first input well in the area, the Skelly Oil Co., Phinney No. 1,
sec. 30, T. 14 S., R. 13 W., was converted in 1946 for disposal of produced
brine into the Lansing-Kansas City formation. An increase in the rate of oil
production from the Phinney-lease wells prompted operators of adjacent leases
to dispose of produced brine in similar manner. Planned water injection on a
large scale began in 1955 with seven active input wells. Between 1956 and 1959,
eight other wells were converted for water injecting enlarging the flood area
to 1,167 acres (fig. 37). In converting for water injecting many producers
deepened or acidized former oil wells and installed tubing.

Table 10 shows mineral analyses of waters being injected in flood Area III
Most of the water is brine produced from Lansing-Kansas City or lower formation
wells, Additional water for two leases is supplied by Dakota wells. Injection
water is handled in both closed and open systems with no filtering and little
or no treatment. Injection pressures at some wells in sec. 25 have been in-
creased to as high as 620 p.s.i.3 but edge wells still receive water on vacuum,
Field analyses of brine samples, taken at each of three input wells in Area
III, are shown in table 11. Brine injected into one of the wells contained
considerable carbon dioxide and hydrogen sulfide; whereas, brine at another
well contained less dissolved gases but more ferrous iron. Filter flow tests
shown in table 12 indicate that entrained oil, iron oxide, or calcium sulfate
could plug finer pores in the formation.

The graph (fig. 38) shows a slight decline in annual oil production be-
tween 1945 and 1952. Without the sustaining effects of accidental and planned
flooding, the decline would have been much greater. After 1954 an increase in
the volume of water injected resulted in increased rates of oil and water pro-
duction. Through December 31, 1959, the increased recovery resulting from
planned flooding was estimated to be 995,000 barrels of oil, equivalent to 29
percent of that recovered by primary methods

By January 1960 a total of 5,709,000 barrels of water had been injected,
and 4,228,000 barrels of water had been produced. During the early years of
the flood, fluid produced exceeded the volume of fluid injected3 but from 1955
through 1960, the net injected water exceeded the volume of produced fluids by
more than two million barrels, This increase in reservoir fluid should extend
the flood area to other wells and leases

Waterflood Area IV

Area IV includes two leases operated by Skelly Oil Co., the W. Opdycke,
and the Geo. C. Ehrlich leases, in secs. 29 and 32, T. 14S,, R. 13 W. Figure
39 is a map and production-history graph of the properties. Water injection
into four wells increased the rate of oil production from 13 wells on 376 acres


TABLE 8. - Summary of data pertaining to natural or accidental waterfloods

Oil recovered, bbl.?

Area Primary Date of Source Number of
flooded, | development, first of oil wells | Primary |Accidental
Flood designation acres year increase water producing!| methods flooding
Natural flood A.....+ 120 1943 1952 |Upper zone, 4 -- --
Lansing-
Kansas City,
Accidental flood B... 408 1940 1942 |Dakota and 12 -- -
Arbuckle.
Accidental flood C... 333 1940 1941 |Arbuckle and 14 900,000} 332,000
Granite
Wash.
Natural flood D...... 971 1938 1940 |Upper zone, 27 -- --
Lansing-
Kansas City.
Natural flood E.. . 138 1943 1945 4 -- --
Accidental flood F... 297 1945 1948 9 471,000 71,000
Accidental flood G?..| 1,046 1942 1944 |Dakota and 17 1,991,000} 380,000
Arbuckle.
Accidental flooding
in planned flood
ATCASs ss eceececceeee -- >: --_ | = -- -- 139,000
Totalecccccccccccccscccccnccccssccscccsscsssssascspesessssscssscsssrsccssscsssesseses 922,000

1 As of end of discussed period.
2 Production also affected by natural water encroachment.

8v


72

o

Woter injected

Oil produced

220,000 bbl. by
eccidental flooding

Primary production
402,000 bbl.

YEARLY OIL AND WATER PRODUCTION AND WATER INJECTED, th
g
3

‘995,000 bbl. by
planned tlooding

Normal decline, est.

TTT Tesol TTT Twsst TT Tose

ss? TT YT feel T TT Ties

FIGURE 38. - Waterflood Area III, Production-History Graph.

The north part of this area is structurally high, approximately 1,127 feet
below sea level. Wells at the south end of the Opdycke lease lie in a small
structural trough, 1,140 feet below sea levels and those on the Ehrlich lease
are slightly higher at 1,135 feet below sea level. All but two wells either
were completed in both upper and G zones or were deepened to produce from both
zones.

The first wells in this area were completed in the lower formations, but
in 1936 they were plugged back and recompleted’ in the Lansing-Kansas City
formation with initial production rates of about 250 barrels of oil per day.
Nineteen additional wells, with initial oil-production rates ranging from 116
to 2,200 barrels per day, were completed by December 1941, resulting in a peak
oil production rate of 126,000 barrels for that year. The annual oil pro-
duction declined to a low of 23,000 barrels in 1949 before water injection
became effective. From 1941 through 1949, the rate of decline in production
dropped from 30 to 15 percent per year. Wells in this area were not influenced
by either natural or accidental flooding, although a casing leak caused the
water production to double during 1946,


21

HORIZONTAL SCALE, MILES

° r 2 3

DEPTH BELOW SEA LEVEL, fest

DEPTH BELOW SEA LEVEL, foot

ew, [ees een

E-aw SEWF
NEWSER OF LANSING- KANSAS CITY FORMATION

ee 380
— Se

DEPTH BELOW SEA LEVEL, feet

FIGURE 10. - Cross Sections, Lower Formations.

the cherty conglomerates, which are not oil productive, lie in structually
low areas and in places are 150 feet thick.

Reservoir Fluids

Much of the porosity in the lower formations was developed during the Penn-
syivanian unconformity period. Oil accumulated in these pore spaces wherever
structural conditions were favorable. In general sandy dolomite, Arbuckle
dolomite, and overlying Gorham sand are continuously permeable within the
oil-productuve areas of the Hall-Gurney field. Analyses of many samples of
water produced from the several formations in different areas of the field
show the waters to be so similar in chamical characteristics that a common
source is evident (table 4).

Apparently an impermeable barrier divides the east and west halves of
the field in the approximate position of the match line in figures 12 and 13.
In the west half, oil accumulated in sand and sandy dolomite surrounding a
granite ridge. The oil-water contact was about 1,415 feet below sea level.
In large areas in the east helf of the field, oil accumulated in both the
Arbuckle dolomite and the Gorham sand at depths less than 1,460 feet below
sea level.

A continuous and common bottom water underlay the oil in all but the
structurally highest areas of the field surrounding the granite ridge. With
few exceptions bottom or edge water moved readily through all formations to
replace produced oil.


PETROLEUM-ENGINEERING STUDY OF THE HALL-GURNEY OILFIELD,
RUSSELL COUNTY, KANS.!

by

C. H. Riggs’, Larman J. Heath, Don C. Ward2, and Ray V. Huff2

INTRODUCTION AND SUMMARY

This report describes the development, oil recovery, and potentialities of
productive formations in the Hall-Gurney field, Russell County, Kans. It is
presented as part of a general program to aid and promote increased recovery
from petroleum reservoirs. The report is based on studies of well logs, drill
cuttings, and oil- and water-production histories of individual wells and
leases. The geological interpretations follow closely those in published
literature with only slight local modifications. Oil and water analyses, made
at a Bureau of Mines research center, were supplemented by many analyses ob-
tained from oil-producing and service companies.

The Hall-Gurney field, in south central Russell County, Kans., (fig. 1)
was discovered in 1931 but was not developed extensively until 1941. By 1960
the rate of oil production from the field had declined to the extent that many
wells were abandoned. In some areas natural productive forces have effected
good recovery. However, in other areas inefficient waterflooding, both natural
and accidental, has adversely affected recovery potentialities

Total oil recovery to January 1, 1960 amounted to 82 million barrels, 27
million from the lower formations, 46 million from the Lansing-Kansas City
formation, 8 million from the Tarkio sands, and 1 million from miscellaneous
formations. A summary of field and production data is shown in table l.

Several waterflooding projects now in operation should increase oil re-
covery as much as 50 percent more than that obtained from the same properties
by primary production methods. The report indicates 9,000 acres where economi-
cal oil recovery from the Lansing-Kansas City formation can be effected by
properly engineered waterflooding.

Some differences in behavior and efficiencies of natural water drives in
the lower formations are also illustrated.

1 Work on manuscript completed December 1961.
2 Petroleum engineer, Bartlesville Petroleum Research Center, Bureau of Mines,
Bartlesville, Okla.


36

The B member probably is the most oil-productive member of the Lansing-
Kansas City formation, in both quantity and areal distribution. It has been
called the 30-foot zone because the porous interval normally is 30 feet below
the top of the A member. Porous intervals are 1 to 2 feet thick in tight
shaly areas, such as in well 22 (fig. 21) and are many feet thick in other
areas, such as in well 4 (fig. 20). As can been seen from the cross sections,
a porous interval is present in all wells.

Member C is very thin and originally was selected by Morgan primarily
as an aid in correlation.- In the Hall-Gurney field the C member is not readily
identifiable in most wells as it merges with either the B or D members. (See
wells 1, 12, and 17, figs. 20 and 21.)

The D member is oil-productive ‘in many areas where the B member is pro-
ductive, although its productive area is less extensive than that of the B
member. Where major shale breaks are absent between members B, C, and D, the
porous portions of these members merge in comprising the 30-foot zone (well 4,
fig. 20).

Members E and F originally were named for correlation purposes and rarely
are thick enough to be commercially productive. However, in some areas, the
two members have merged and have yielded significant quantities of oil. As
can be seen in the gamma ray-neutron logs of the cross sections, the radio-
active shales above and below the E and F members are good correlative beds.

The G member is the thickest limestone member of the Lansing-Kansas City
formation and has been classed as a separate zone. Oil production usually is
found in the upper portion called the 90-foot zone. This porous interval
normally is several feet thick; the net oil-productive thickness is limited
in many areas only by the water level. Wells 1, 2, 3, and 5 (fig. 20) are
examples of wells having fairly thick porous intervals in the G member. In
other areas a shale break within the G member spearates the 90-foot zone from
a lower porous interval called the 120-foot zone, as shown in wells 19, 20,
22, and 24 (fig. 21). Where this second porous interval lies above the water
table, oil production is favorable.

Water is present in much of the lower portions of the G member and, in
off-structure wells, saturates the entire porous interval, The approximate
original water levels for wells 22, 23, 24, and 25 are shown in cross section
L-M of figure 21. These wells were nonproductive in the Lansing-Kansas City
formations water levels were above the porous interval of the G member in
wells 23, 24, and 25, and were only a short distance below in well 22,

In the lower zone, oil production is scattered and infrequent. The logs
of many wells show porous intervals for these members (figs. 20 and 21), but
in only a few has oil been found in commercially producible quantities. The
J is the most productive member of the lower zone. These members, although
indicated as porous in gamma ray-neutron logs of many wells, will not yield

fluid, either because of lack of fluid saturations or low horizontal permea-
ilities.




30

R12 Ww.

oi well
# Abondoned ci well(ABD)
+ bry hole |
| ap
otf
1400-4 234 5678 a
3) 3) =) 3} x} a] S| 2 sa) se} s) SB] aS 2) 2] S|
d af x ex ol xl 2 *Sl a 3 yy
FA 3 5/8} gla ajg] 68} 5] oe] 8, BL gi® §| 3
$ 3 EH yy 3
Sao oa vaso
3 IMA BARBUCKL nl
g BUCKLE DOLOMITE,
z
Fa
& 1800. 1800
3
LEGEND
VERTICAL WATER ADVANCE SCALE, MILES
ZZ 1940-1960 ° i 1 1
i) $4

FIGURE 16. - Water Encroachment, Lower Formations,
Representative Area, East Half.

dolomite and Gorham sand sections averaged 15 feet. Average porosity for this
oil-productive section, calculated from seven gamma ray-neutron logs, is 17
percent.

Figure 16 shows the horizontal and vertical advances of water during the
period 1940 through 1960. Oil-producing wells adjacent to shallow, structural
through were abandoned because of early increases in the rates of water pro-
duction, By 1950 water encroachment had forced the abandonment of 10 oil
wells, Twenty-one dry holes, drilled between 1940 and 1950 within the water-
flushed areas, probably would have produced oil is completed earlier. These


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15.

16.

17.

18.

19,

20.

2l.

22,

23.

24.

25.

ILLUSTRATIONS (Con. )

Areal geology, lower formationS....csscccccccescccceee
Cross sections, lower formations....cccceccseccccccsoes
Structure contour map, pre-Pennsylvanian surface......
Oil recovery map, lower formations, west half.......0.
Oil. recovery map, lower formations, east half.......e.

Water encroachment, lower formations, representative
area, west half.........5

Yearly oil production, lower formations, representa-
tive area, west half...ccccccccccccscccccccccccccces

Water encroachment, lower formations, representative
area, CaSt Nalf.cccccccccccccccccccsvcccvcccssscccee

Yearly oil production, lower formations, representa-
tive area, east half....ccccsccccccccccccccccccceece

Structure contour map, top of Lansing-Kansas City
Formation. .sececccccccccvescvccsveces

Gamma ray-neutron log and description of Lansing-
Kansas City formation... ccccccccccccccccccccccccccccs

Cross section G-H, Lansing-Kansas City formation......

Cross sections J-K and L-M, Lansing-Kansas City

FOrMALION. .cesecsscccccccccccaccacccsccecccssccesces

Original oil-productive limit as related to structure,
upper zone, Lansing-Kansas City formation..

Original oil-productive limit as related to structure,
G zone, Lansing-Kansas City formation........seeeees

Approximate relationship between connate water
saturation and porosity, Lansing-Kansas City

FOTMATION. ces secececcccccccecccsccccsecccceescecsces

Oil production history, Lansing-Kansas City

FOTMALION. .cesececccceccccnccccccccceccscsceeeeceees

Page

23

24

28

29

30

31

34

35

36

36

38

39

42


55

After 1950 the pattern of water advance became more complex because sever-
al wells were converted for: injection of produced water. In some areas behind
the front, wells now produce less water than in 1950, indicating a limited
supply of edge water. Water produced from wells ahead of the front was iden-
tified by analysis to be Lansing-Kansas City water. However, Samples taken
from well A in the SE1/4NE1/4, sec, 27 in July 1946 and May 1948 showéd some
dilution with Arbuckle water. Water analyses, together with production data,
indicate that well B in the NW1/4SW1/4 sec. 26 was producing a considerable
quantity of Arbuckle water during 1957.

Yearly oil production from the affected wells (fig. 31) reached a peak
of 520,000 barrels during 1943 and then declined to approximately 70,000
barrels during 1950. In 1944, 1948, and 1950, water production was 570,000
barrels, 513,000 barrels, and 340,000 barrels, respectively.

Natural Flood E

The N1/2 sec. 25, T. 14 S., R. 13 W., was subjected to natural water en-
croachment beginning about 1943. Edge water moved south to flood out four
wells by 1950 and four more by 1959, A water sample, taken in 1959 from a
well at the front of the flood, was interpreted to be a mixture of two-thirds
Arbuckle and one-third Lansing-Kansas City water. Undoubtedly the natural
flood was augmented by Arbuckle water from an undetermined source.

Accidental Flood F

Parts of secs. 31 and 32, T. 14S., R. 12 W., (fig. 32) were subjected to
an accidental flood of Arbuckle water beginning in 1945, In this area the first
wells, drilled in 1943 and 1944, were cased through the Lansing-Kansas City
formation and completed in the Arbuckle dolomite. Before being completed in
the Lansing-Kansas City formation, seven wells were either productive or were
tested in the Arbuckle dolomite. The principal oil productive interval was
the C-D member; the G member also was open in four wells.

Reservoir characteristics of the 297 oil-productive acres in flood F,
determined from six gamma ray-neutron logs and other data, are as follows:

Net oil-productive thickness.......... coos feet.ccsccceee. 11.0

Estimated porosity....eecee oecccee « percent.... 17.1
Connate-water saturation........ sees dow... + 23.0
Original reservoir-oil saturation sees dO.eeeee + 77.0
Original formation volume factor... eee cececeeeens » 1,245

Stock-tank oil originally in place.. «» barrels..... 2,680,000
Well A (fig. 32), completed late in 1944 in both the upper and G zones of
the Lansing-Kansas City formation, initially produced 50 percent water. The
east-offset well, plugged back to the upper zone of the Lansing-Kansas City
formation in 1944, produced water as early as 1945, By 1958 the advancing
water front had extended nearly across the W1/2 sec. 32, as shown by the water-
advancement line. Apparently the flood progressed upstructure from a low along


TABLE 3. - Chemical and

physical properties of crude oils

Carbon Total
Viscosity residue,| Light |gasoline and| Kerosine Medium
Gravity] 100° F,,] Sulfur,| crude, |gasoline,} naphtha, |distillate,|distillate,|Residuum,
Formation | 60° F.,|] Saybolt | weight-| weight-| volume- volume- volume- volume- volume-
source OAPI seconds | percent] percent] percent percent percent percent percent
Tarkio.... 39.0 42 0.35 2.9 10.7 32.9 10.7 31.0 23.9
Topeka... 36.8 47 48 3.5 10.0 31.5 9.3 33.8 24.4
Platts-
mouth... 39.0 46 242 2.6 10.9 33.7 4.4 36.7 23.5
Lansing-
Kansas 37.8 44 239 2.8 6.9 31.3 12.8 32.1 22.4
City... 38.8 42 41 3.1 11.0 34.3 10.2 30.6 23.4
39.4 43 234 2.1 10.6 36.2 11.0 30.1 21.1
Gorham
sand.... 35.0 55 51 3.0 4.5 26.4 11.0 32.5 27.7
38.8 45 238 2.7 7.4 33.0 18.7 25.7 21.6
Arbuckle
dolo-
mite.... 34.0 51 045 3.6 5.6 26.4 10.2 35.8 27.5
Sandy
dolo- 35.6 51 48 2.7 6.2 29.2 10.3 33.0 27.0
mite.... 36.0 47 +43 3.1 6.5 28.8 18.1 26.9 25.8
36.8 45 246 3.0 8.3 30.8 16.9 27.1 24.6

cal


GENERAL GEOLOGY

The known geologic history of the central Kansas uplift area, described by
Walters (8)*, began with Cambrian seas transgressing a peneplained surface
where ridges and hills rose above the general level. These ridges were predom-
inantly quartzite, more resistant to weathering than the surrounding micaceous
and schistose rocks. Arkosic sands or granitic wash materials, resulting from
weathering of these Precambrian rocks, were deposited abundantly near the steep
slopes and in ravines or gullies on the highs. Later a basal sand was deposited
over broad lowlands surrounding these highs, incorporating some of the reworked
arkosic material near the unconformable contact.

Sandy dolomite and dolomitic sand were deposited over most of the area
during either late Cambrian or early Ordovician time. White, coarsely-crystal-
line dolomite subsequently was deposited conformably over the sandy dolomite;
later, a cherty dolomite was deposited over the area, completely covering the
Precambrian highs.

Presumably, beds of late Ordovician, Silurian, Devonian, and Mississippian
systems also were deposited over the central Kansas uplift area. Extensive
erosion and truncation in pre-Pennsylvanian and early Pennsylvanian time,
accompanied by a gradual uplifting of the area, removed these beds and most of
the cherty dolomite to re-expose the Precambrian highs

Meteoric waters leached carbonate material from the re-exposed sandy
dolomites, leaving a residual sand.

Walters and Price (9) state:

"Associated with the major unconformity at the base of the Pennsylvanian
is a variable thickness of non-carbonate rocks, in part oxidized to bright
shades of red and yellow."

These rocks, commonly lumped together as conglomerate, consist of cherts,
shales, clays, and sands.

Some differences exist concerning nomenclature of the producing sands in
the Hall-Gurney field. In this report, sand leached in place from the sandy
dolomites and dolomitic sands of Cambrian and Ordovician periods (even though
it may have been leached in Pennsylvanian times) is called sandy dolomite.

The overlying, white, crystalline dolomite is well known and generally is called
Arbuckle dolomite. Sand composed of material transported during Pennsylvanian
time is called Gorham sand.

In the eastern part of the field the upper surface of the white, crystal-
line Arbuckle dolomite suggests solution valleys and sink holess many were
filled later with Gorham sand deposits of Pennsylvanian age. Subsequent or
contemporary erosion often left mounds or ridges of the more resistant Gorham
sand. The Gorham and older rocks are called lower formations in this report.

3 Underlined numbers in parentheses refer to items in the bibliography at the
end of this report.



19

The map shows a Pre-

+1700 cambrian ridge in the wes-
Lanane- 1 200] tern part of the field and
weak wanaas ony esol TOPEKA smaller exposures of Pre-

cambrian rocks at the south-
east end of the field.

1200

“or "820 0 woo Sandy dolomite, which
surrounds the main granite
400,- ,  Tidge in the west half,
axora

does not outcrop on the
pre-Pennsylvanian surface
at the southeast end of the
00 owes romarions field. Discontinuous

. TM lenses of Gorham sand over-
1 ernom sen lie the Arbuckle dolomite
oor . in a spotted distribution

goncora extending southeast from
the main granite ridge.

fe a a
5184030400607 809010010 BD 189 0d BO 160170180190 P00

POTASSIUM, mat These deposits of Gorham
. . sand grade laterally and
FIGURE 8. - Plot of Strontium Versus Potassium vertically into impermeable
Content, Representative Formation and unproductive shales and
Waters. conglomerates.

Three structure cross sections in figure 10 depict the attitude and re-
lationship of the lower formations to a marker horizon in the overlying Lansing-
Kansas City formation. The vertical scale has been exaggerated for illustra-
tive purposes. The maximum inclination of the beds is less than 2°, Apparently
the Gorham sand was deposited in channels or troughs bordering topographic
highs of the pre-Pennsylvanian surface, but its location is erratic.

Figure 1l is a contour map showing the structure of the pre-Pennsylvanian
surface. The highest area, less than 1,380 feet below sea level, is the Pre-
cambrian hill in secs. 22, 23, 25, 26, and 27, T. 14S., R. 14 W. In the
east half of the field the highest areas are small isolated hills with tops
between 1,400 and 1,420 feet below sea level.

Lithology

Precambrian ridges are essentially red quartzite, apparently more resis-
tant than the black schist and other rocks found in strucurally lower wells.
Some arkosic materials are mixed with the quartzite in the granite wash.

Samples of drill cuttings from the sandy dolomite show a wide range in -
lithologic character from almost pure sand to finely-crystalline dolomite with
little sand. In general the entire section may be considered sandy and porous
with the percentage of sand increasing with depth.

The overlying white, crystalline dolomite ranges from dense to coarsely
crystalline. During subaerial erosion, solution channels and vugs were devel-
oped, and secondary calcite was deposited in larger openings.


R14 Ww, R13 W. j R. 12 W.
ety +
Ep 1 . : « 2 2 ' LEGEND
+ + © Oil well
# # Abandoned oil well

© Water-input well

c? |, @ Abondoned water-input well
rr 4 > Dry hole
4
+L ORF Area from which oil hos {
n been produced N
s—-s6
+ Were | &
[7 at * s.
in, He ! 2
raas ee
2 Te SCALE - MILES
G a
\ *
bi jab h
+
q A
o ¥
a 4 g Te
4 +
. aT o

oF

FIGURE 45. - Tarkio Formation, Oil Producing Area and Wells, January 1960.

v8


77

of reliable data on oil and water saturations, the past oil- and water-produc-
tion history and the formation source of brine being produced from the property
are important criteria. As previously pointed out, much of the Hall-Gurney
field was subjected to natural and accidental flooding. Such flooding seriously
limits potentialities for planned flood development.

All factors that could contribute to an evaluation of the leases were
considered in the preparation of figures 42 and 43, which show areas of the
upper and G zones suitable for planned waterflood development. The heaviest
shaded areas are most satisfactory for planned flooding. For the upper zone,
8,737 acres are considered floodable; of this amount only 1,940 acres are
considered good. For the 5,938 acres of the G zone considered floodable,
1,577 are rated good and 2,350 fair. These maps also show by dashed lines
the areas, totaling 3,705 acres, being flooded as of January 1960. In gen-
eral, floods have been started on the majority of the leases considered most
suitable for planned flooding.

Procedures

Source and Treatment of Brine for Flooding. - Ample quantities of water
for planned flooding are available either from the lower formations at a depth
of 3,100 feet or from the Dakota sandstone at about 300 feet. Surface waters
have been used in many areas; however, sources of supply are undependable, and
such waters often require seasonal changes in methods of treating and filtering.

On many leases adequate quantities of brine are produced with oil from
the lower formations; however, this brine often contains entrained oil that
could plug minute pores in the formation. Brine produced from water supply
wells completed below the oil zone should be free of such entrained oil. The
lower formation brines contain dissolved hydrogen sulfide, in quantities ran-
ging from 100 to 300 milligrams per liter, which could cause corrosion of
equipment and possibly plug the formations with iron sulfide.

Dakota and shallow waters have a high content of dissolved carbon diox-
ide. Surface and shallow waters often contain dissolved oxygen, and oxygen may
dissolve in any water open to the air,

Watkins and Kincheloe (10) pointed out that in brines containing only a
few milligrams per liter or oxygen, a rapid increase in the rate of corrosion
of iron occurs when the amount of dissolved carbon dioxide increases. The
rate of corrosion in the presence of carbon dioxide and hydrogen sulfide in-
creases rapidly with an increase of these gases until the carbon dioxide con-
tent reaches about 100 milligrams per liter or the hydrogen sulfide about 150
milligrams per liter. A hydrogen sulfide concentration above 150 milligrams
per liter may inhibit corrosion by carbon dioxide.

Dissolved carbon dioxide and hydrogen sulfide may be removed by aeration;
however, oxygen picked up by such aeration often is more corrosive than the
original gases. Closed systems, wherein a blanket of either oil or gas is
maintained above stored brine, are usually satisfactory for excluding oxygen


Submersion during late Pennsylvanian time permitted unconformable deposition
of Lansing-Kansas City limestone over the entire area. Members of the Lansing-
Kansas City formation drape gently and indiscriminately over all, reflecting
little of the rugged pre-Pennsylvanian surface.

Accompanying a gradual withdrawal of the seas, shales and interbedded sands
of the late Pennsylvanian period were deposited over the area. Repeated up-
lifting and moderate folding distorted the rocks into their present structures
and permitted oil to accumulate in pores developed in part during subaerial
erosion, Figure 2 is a gamma ray-neutron log showing the stratigraphic rela-
tionship of the oil-productive members of the Hall-Gurney field.

“7

DEVELOPMENT

Gomme
roy

curve ——=

Dougios. Discovery and History

Neutron curve
The first oil well in
; the area, the J. J. Hall and
a Russell Oil Corp. No. 1
2 soo! Miller, in the SW1/4SE1/4SE1/4
sec, 30, T. 14 S., R. 13 W.,
i Topeko was completed on May 12, 1931
4 This discovery opened what
was then called the Hall
pool. On February 15, 1935,
Hartman and Blair completed
4 sorhom the No. 1 Gurney in the
F FH Plottsmouth anuckle SE1/4SE1/4NW1/4 sec. 23,
Sandy dowomte Te 14 S., R. 14 W., to open
"| SSN] Granite the Gurney pool. Further
© Oi! productive interval development opened the
Letsch, south Letsch, south-
FIGURE 2. - Gamma Ray-Neutron Log. west Letsch, and Berrick
pools which later were joined
with the Hall pool. The Allon, south Gurney, and Michel pools were consoli-
dated with the Gurney pool. Further drilling showed these pools to be in one
large field, ultimately redesignated as the Hall-Gurney field. The annual rate
of completions gradually increased to a peak of 156 wells in 1941. Drilling
activity slowed to about 50 wells per year during World War II. After the
war, development increased; during 1953 a total of 152 wells were drilled.
Since then, drilling has decreased each year, reaching a low of 19 wells in
1959. A total of 1,884 wells, including 408 dry holes, were drilled within
the limits of the Hall-Gurney field (figs. 3 and 4).

Lansing ~ Konsas City

Torkio

Drilling and Completion Practices

The first oil production was from wells completed in the Lansing-Kansas
City formation However, as the limits of the Hall and Gurney pools were ex-
panded and eventually joined, many wells failing to produce oil in commercial
quantities from the Lansing-Kansas City formation were deepened and completed


TABLE 13. - Core analysis, Tarkio sands

Coring Coring
time, Porosity, | Permeability, time, Porosity, | Permeability,
Depth, feet minutes | percent millidarcys Depth, feet minutes | percent millidarcys
Upper Tarkio: Second sand -
First sand: continued:
2242. Leseeeee 13 20.4 2.4 2268.6..eeceee 5 18.4 4
2243.0.eeeeee 16 19.6 7 2269.0. . e000 6 22.8 4.1
2243.8 23 28.2 1104.8 10 18.7 6
2244,1.. 23 26.0 163.4 10 24.4 2.2
2245. lessees 20 28.3 234.1 ll 20.0 1.2
19 27.5 2107.1 ll 25.9 5.8
23 22.1 12 13 18.7 2
25 21.3 111.8" 2273. 2.eeceeee 13 24.7 53.1
25 23.6 19.0 2274.0. .eeeeee 7 21.5 2
15 26.7 133.6 2274.6... 7 21.4 2.9
15 23.2 2.6
17 22.0 2 Tarkio limestone:

Second sand: 2301.1... 40 14.5 3
2261.1 13 23.2 18 2304.5. 55 8.1 0
2261.8.. 7 24.8 19.6 2308.1. 32 13.8 0
2262.9. 00000. 7 28.4 162.3 2310.7. 27 15.3 3
2263 .4...0008 7 29.6 2188.2 2315.5. 42 13.6 el
2264.0.. oe 13 32.7 2217.5 2319.0. 14 bd 2
2264.1...0006 13 30.4 2180.0 2320.6... 17 23.5 2
2264.6..00006 16 28.8 1147.8
2265.1 eee 16 23.8 113.8 Lower Tarkio:

2265.7 oe 16 26.4 128.8 2322.4. ..eeeee 8 29.6 117.1
2266.3....606 9 28.4 1173.0 2340.9. ceeeeee 16 26.1 2.0
2266.9...066- | 10 24.5 16.8 2341.9. .e00e 15 17.8 8

2267.4.. oe 10 32.6 1a 2342.5..00e8 15 28.8 118.1
2268.1. .eeee 5 27.5 117.5 2343.6..ceeeee 7 29.4 29.5

1 Considered to be oil-productive.
2 Broken.

€8




51

During 1944, water from the Dakota sandstone entered the Lansing-Kansas
City formation through well C, The Dakota water spread to the south and west
(as indicated by the dashed lines) affecting production from two other wells.

Apparently lower formation water entered the Lansing-Kansas City formation
through well D, a dry hole drilled in 1944, and spread to wells E, F, and G
during 1945, 1946, and 1947, respectively. A sample of water produced in 1954
from well H showed contamination by a lower formation water. Flood water con-
tinued to spread to the east, south, and west as indicated by the water-advance-
ment lines in figure 29.

Because yearly oil production from these properties during the period 1942
through 1957 was affected more by additional well completions than by the acci-
dental floods, no estimate was made of that part attributable to the flooding.
Water production reached a peak of 976,000 barrels per year during 1946 and
remained high until several wells, producing large quantities of water, were
abandoned in 1950 and 1951. Effects of the accidental floods persisted into
the late 1950's but were masked by planned waterflooding that was begun in 1955.

Accidental Flood C

Primary Development

The first well in accidentally flooded area C in secs. 24 and 25, T. 14 S.,
R. 14 W., was completed in 1936. During 1940 and 1941, 13 oil wells were com-
pleted in the B, C, and G members of the Lansing-Kansas City formation. Subse-
quently, three wells were completed in one or more of these members in 1943,
1947, and 1950. Nine of the early wells were drilled to the granite wash,
tested, and plugged back to the Lansing-Kansas City formation. During 1945,
two Lansing-Kansas City wells were deepened, tested in the granite wash, and
recompleted in the Lansing-Kansas City formation. Figure 30 is a map and pro-
duction-history graph of this area.

Original Oil in Place

Drillers' logs, completion reports, and workover records were available
for all 17 wells. Radioactivity logs were available for six of these wells.
Using these data, cross sections were drawn through all wells to determine the
oil-productive acreage of each lease. The cross sections also aided in esti-
mating the oil-productive thickness in each well, These thicknesses ranged
from 6 to 17 feet in individual wells, averaging 12.9 feet.

The average porosity of each oil-productive member in the six wells was
determined from the radioactivity logs. Porosities of oil-productive members
in the other wells were estimated from core descriptions, from initial pro-
duction data, and by interpolation. A weighted average porosity was determined
for each well, These porosities ranged from 14 to 22 percent, averaging 19.5
percent.


57

Total recovery through 1959 amounted to 542,000 barrels of oil, equivalent
to 20.2 percent of the volume of oil originally underlying these leases. The
primary recovery was estimated to be 471,000 barrels of oil. The 71,000 barrels
of oil gained as a result of the accidental flooding represents 15.1 percent
of the primary recovery.

Since 1957 the rate of oil production has declined. The advancing flood
front has passed these nine wells, and annual oil production should decline
about 20 percent per year. Ultimate oil recovery should approach 620,000
barrels or 23.1 percent of the stock-tank oil originally underlying these
leases,

Accidental Flood G

All or parts of secs. 3, 4, 5, 8, and 9, T. 15 S., R. 12 W., (fig. 33)
have been subjected to either natural or accidental waterflooding in the Lan-
sing-Kansas City formation. Most wells in this area were completed in the
lower formations during the years 1938 to 1945 but later were plugged back to
the Lansing-Kansas City formation. Wells in structural troughs on the east
and west sides of sec. 9 produced normal Lansing-Kansas City water when com-
pleted in the early 1940's.

Water-advancement lines in figure 33 show the progressive spread of the
flood as of 1950 and 1960. The flood advanced simultaneously from the east
and west and then spread to the north and south. Before 1952 most of the en-
croaching water was normal formation water. After 1952 Arbuckle water entered
the producing formation through one or more wells and supplemented the natural
flood.

In 1953 and 1955 Dakota water entered the formation through several wells
in secs, 3 and 4 and further complicated the flood. Figure 33 shows by symbol
the type of water being produced from sampled wells at indicated dates. For
example, L-KC-'42 indicates that a sample taken in 1942 was normal Lansing-
Kansas City water. The letters A or D indicate that Lansing-Kansas City
water was mixed with Arbuckle or Dakota water as of the indicated: year.

The lines on the map indicate when water in large quantities first reached
the producing wells. However, all wells behind the flood front are not com-
pletely "watered-out", and in some areas water is being exhausted. Many wells
still produce significant quantities of oil.

The lower half of figure 33 is a production-history graph of flood G,
showing the annual oil- and water-production rates. The normal percentage-
decline rate used for flood F was assumed to be representative for flood G.
Because many of the leases were developed during an extended period and most
of the leases were affected by the flood at different times, the primary oil
production from each lease was estimated separately and totaled. The total
primary recovery through 1959 thus was estimated to be 1,991,000 barrels of
oil. The difference between the estimated primary and the actual oil produc-
tion is the gain by accidental flooding. Flood-oil recovery amounted to
380,000 barrels, equivalent to 19 percent of the primary production.




85

MISCELLANEOUS FORMATIONS

Several other formations have been oil productive, but well tests indi-
cate that production from these formations will not be significant. First oil
production from the miscellaneous formations was in 1937, and the highest
annual rate was 90,000 barrels in 1948 (fig. 5).

Nearly 900,000 barrels of oil has been produced from 13 wells open in the
Topeka formation. This total includes production from four wells open in both
the Plattsmouth and Topeka formations. Four other wells produced 116,000
barrels of oil from the Plattsmouth formation. Eighteen wells, scattered
throughout the field, produced 318,000 barrels of oil from the Toronto lime-
stone. One Douglas-shale well produced 65,000 barrels of oil. Total recovery
to January 1960 from 36 wells in the four miscellaneous formations amounted to
1,368,000 barrels of oil. Approximately one-third of this amount (430,000
barrels of oil) was produced from a single Topeka well.


Lee

Bare
an

Beas

ou cil orp. "A Flak
Coop. af. Asooc.-Horb Flak.
 Kasoesctorace

‘
5
9
é
1
3
4
5
if
2

Be cok

Ss

Ss

Bun suaaone en ar a wie ennoow Be ewe

meaBan coonoun Ceo

seatss cassiss

See footaates at end of table,




81

yields a curve useful in estimating this volume. After filling the formation,
the ideal slope of a curve should be 1 (1 barrel of fluid produced for each
barrel of water injected). Where injection volumes greatly exceed fluid pro-
duction, measures should be taken to prevent loss of injected water to other
leases or formations.

Other Improved Recovery Methods

Although planned waterflooding can result in the recovery of much addi-
tional oil, other improved recovery methods can be used either alone or in
combination with waterflooding. Acid treatments and hydraulic fracturing have
increased the rate of oil production and, perhaps, the ultimate oil recovery
in many areas. Often acid is injected at high rates of speed and pressures to
give a combination treatment. Such treatments may open isolated pore spaces
and increase oil recovery.

Shooting or perforating sometimes increases oil-production rates, but
generally these methods are less successful in limestone than in sandstone
formations.

Many wells have been deepened to tap undrained members and thus increase
production rates. The upper and G zones are presumed to be exposed adequately
by existing wells, but the lower Lansing-Kansas City zone has not been tested
adequately. Structurally high areas that have not yet been tested in this
zone could produce additional oil. This zone should be tested thoroughly be-
fore wells are abandoned.

In other fields gas injection and gas. drive have increased oil recovery.

The lack of gas in large quantities in the Hall-Gurney area precludes its use
here.

Lack of continuous porosity in much of the upper zone makes the field
unsuitable for thermal recovery. Undoubtedly much oil will remain in the
Lansing-Kansas City formation after the rate of 011 production by present
methods reaches an economic limit.

TARKIO SANDS

The Tarkio sands, a series of separate lenticular sandstones within the
Dry, Langdon, and Willard shales, are oil productive in much of T. 14 S.,
R. 13 W., and a small part of T. 14 S., R. 14 W. Identification of the top of
the Tarkio has not always been consistent. Some producers recorded the first
sandy bed as the top of the Tarkios whereas, others selected the top of the
first oil-saturated bed. A gamma ray-neutron log of the Tarkio section is
shown in figure 44, The oil-productive beds within this section are difficult
to correlate between wells because of horizontal changes in lithology; however,
the overall thickness of the section generally is consistent throughout the
field. In the Dry shale, sand beds are thin and discontinuous; whereas, in the
Langdon shale, the fine-to-medium-grained, micaceous sand beds are thicker but

contain shale stringers, The Willard shale below the Tarkio lime includes sand
members of both types.


23

R. 14 W. R.13 W.

.
}—Oil-productive ind
T.
4
14 7 &
s| LEG END | + | nN 4
Recovery per acre, January 960 a 13 26 oe 20 2h 2
(Lower formations), M bbl. ms
as h ; +3
a ®, sf
4 +
a] ot aT |
ies
as ON RA
5-8 t 5a +
7 Over 8 i Xd I — _
@ i wall
$ Dry bole 2 \ ‘ 3 ‘ 3

)

SCALE - MILES

FIGURE 12. - Oil Recovery Map, Lower Formations, West Half.

Production Mechanisms and Recovery

The structure contour map (fig. 11) and the fluid-production histories
of early wells helped to determine the original limits of the oil-saturated
areas in the field (figs. 12 and 13). Most of the 9,043 oil-bearing acres
have been developed; and the recovery, in barrels per acre, is shown in the
figure by degrees of shading. Unshaded areas within the productive limits,
about 1,000 acres, represent either undeveloped areas or areas drilled after
advancing edge water made oil production uneconomical.

Through 1959, oil recovery averaged 3,337 barrels per acre from the
8,043 developed acres, or 2,967 barrels per acre from the 9,043 oil-bearing
acres. Figures 12 and 13 show that areas of high oil recovery are scattered
throughout the field. Oil recovery from a large area in secs. 14, 15, 16,
and 17, T. 15 S., R. 12 W., was low. Oil has been produced from 390 wells
drilled to the lower formations in the Hall-Gurney fields however, only 228


Lansing ~Kansos Cit
145,637,000 barrels

YEARLY OIL PRODUCTION, million barrels
T

Lower formations
26,836,000 barrels

Tarkio
8,098,000 bbi.

°
ial TT Iisas 940) i948] 950 1955\ sed

FIGURE 5. - Production History of Oil-Producing Zones.
Properties of Produced Oils

In the last 25 years, samples of oil from the various producing formations
in the Hall-Gurney field have been analyzed in Bureau of Mines laboratories.
Analyses representative of several producing formations are tabulated in
table 3. These analyses show the oils to be similar, having narrow ranges
in gravities, viscosities, and other distinguishing properties. All the oils
have an intermediate base and could have been formed under similar conditions,
perhaps from the same source material.

In further attempts to identify and distinguish the several oils, the
fraction number was plotted versus the correlation index (6), shown in figure
6. The trend of the plots show the oils to be similar.


47

production from structurally low wells was 50 barrels per day, compared with 20
to 30 barrels per day from structurally high wells. Apparently this natural
water drive advanced to the center of sec. 22 by 1944, and by 1948 many of the
edge wells were abandoned. In the mid-1950's, several wells in this general
area were converted for water injection. By 1958 the water-production problem
was very complex. A few of the most recently drilled wells, completed only in
the upper zone, also produced substantial quantities of water.

A structurally low area, southwest of the center of sec. 26, T. 14 S.,
R. 14 W., apparently was the source of water that in the early 1940's entered
and spread over the southeast-and northwest quarters of that section. Possibly
only the water originally present in this structural trough was available to
be produced from adjacent wells. Because the amount of water was limited, the
wells did not produce large quantities, and the water did not advance into
other areas.

Along the west edge of the field the only perceptible edge-water encroach-
ment was into the small structural re-entrant near the center of sec. 21,
affecting a few wells. Other major structural re-entrants apparently did not
influence water encroachment. - Based upon a study of the influx of water into
wells, the general rise of water was slight, ranging from 4 to 7 feet.

Natural Flood A

The production histories of Lansing-Kansas City wells in the E1/2 sec. 8,
T. 14 S., R. 14 W., show increases in the rates of oil and water production
from 1952 to 1956. Apparently these increases, noted from daily production
tests on individual wells, were the result of natural water encroaching from a
structural trough along the north edge of the property. Edge water, moving
south, affected structurally lower wells first. By 1957, four wells were pro-
ducing all water, and the remuining wells were producing large quantities of
water. Water from the Dakota sandstone entered the Lansing-Kansas City formation
through one well during 1957 and spread to adjacent wells. By 1960, 120 acres
had been affected by the combination flood (fig. 28).

Accidental Flood B

A water-encroachment map and production-history graph of Lansing-Kansas
City formation wells affected by accidental flood B are shown in figure 29.
Water from three sources affected many wells in this area producing from the
upper and G zones. Flooding from these three sources partially overlap in
time and area.

Well A in sec. 14, T. 14 S., R. 14 W., produced normal Lansing-Kansas City
water when completed in 19403 but 35 days later the produced water was contami-
nated with a lower formation water. A sample of water taken in 1944 from well
B (fig. 29) also showed contamination by a lower formation water. Apparently
the flood progressed to the southeast, south, and west as indicated by the
dated water-advancement lines.


iv

28.

29.

30.

31.

32.

33.

34,

35.
36.
37.
38.

39.

40.

41.

42,

ILLUSTRATIONS (Con. )

Oil-recovery map, Lansing-Kansas City formation,

WEST NAlf..cececercccccccccccvvcccccvevcscssvvccces

Oil-recovery map, Lansing-Kansas City formation,

Cast half. ..cccccccccccscccsccccncccecscssceessccces

Location of planned and natural or accidental water-
floods, Lansing-Kansas City formation, January

1960. eee eeccccccnccccercssccsercesesiscvsseeseeeee

Accidental flood B, progressive water encroachment and
production-history graph....

Accidental flood C, progressive water encroachment and
production-history Qraph..sscccecccccccccccccccscces

Natural flood D, progressive water encroachment and
production-history Qraph...ccccccccccccccccccccccece

Accidental flood F, progressive water encroachment and
production-history graph....cccccccccccccccccccccevs

Accidental flood G, progressive water encroachment and
production-history graph...scccccccccvccscccsccvcces

Waterflood area I, progressive development and
production-history graph.. oe

Waterflood area II, progressive development.....sseeee

Waterflood area II, production-history graph.. on

Waterflood area III, progressive development........0.

Waterflood area III, production-history graph..

Waterflood area IV, progressive development and
production-history graph... .cccccccccccccccceccscces

Waterflood area V, progressive development.....ssseses

Waterflood area VI, progressive development and
production-history graph........

Areas suitable for waterflooding, upper zone,
January 1960.....cccccccccccccccccccccncccecccvccese

Page

45

46

49

50

52

54

56

58

65
66
69
70

72

73

74

76

78


R13 Ww. R12 Ww

Field limit ,
aan One |
ee eee .
T Oil productive Feit, 6 zone, LeansingKansos City formation a X
; 1 4
° D ray Ty | ! on . . |
J
las
‘ LAN HALT ER .
aN pS
as as ae Sa { w tow |x
Te ESE auese
; | aa
q
+ | ;
0 1 2 3 7 LTA a
Rees
SCALE - MILES i- -) SLT
T LEGEND . | ee "ly
g (CO Froodabte areos 'S
WU | ° al im ° “
Fair oT] . .
@ Good | r I
(7 } areas now flooded 1 ‘ . .
4f.—--- Yo 8 8 wee ty | oy |
Riaw BARTON ' COUNTY RI3W. T Rew.
‘s iT ie

FIGURE 43. - Areas Suitable for Waterflooding, G Zone, January 1960.

6L


RaW, R13 Ww

A)
&
SANpy DOLOM!T|

ran ‘
<i sd ou wow wu ‘ aso
: Ted ae |

- Fic ie od fee el {

Z a a # Gl s g|

5 Cc 3

5

#1400 wy ZL 1400
4 : an Olea

8 x « a

8 “ « « <  *~ PRE~CAMBRIAN “ «

= REGEN x

E VERTICAL-WATER ADVANCE aos

Bs asol Seats, mbes TZ veso-n40 .

FIGURE 14. - Water Encroachment, Lower Formations,
Representative Area, West Half.

The horizontal and vertical water advances corresponded in a general way
to structure, but some fingering and coning indicated good vertical permeabili-
ty. No wells were plugged back within the same producing formation during
their productive lives. Several structurally high wells in the area were
abandoned early in the life of the fields whereas, other wells, structurally
lower, were still producing oil in 1959.

A small Precambrian hill in sec. 36, T. 14 S., R. 14 W., blocked the
upward advance of water. Wells to the north produced only moderate quantities
of water as compared with wells along the east and west sides of the hill that
produced large quantities of water.

The oil-production histories of wells in the representative area and the
increasing percentages of water in total fluids are shown in figure 15. The
cumulative oil recovery through 1959 amounted to 5,234,000 barrels; 4,338,000
barrels was recovered from the sandy dolomite and 755,000 barrels from the


BIBLIOGRAPHY

BUCKLEY, S. E., AND LEVERETT, M. C. Mechanism of Fluid Displacement in
Sands. Trans. AIME, Petrol. Devel. and Technol., vol. 146, 1942, pp. 107-
116.

GUERRERO, E. T., AND EARLOUGHER, R. C. Analysis and Comparison of Five
Methods Used to Predict Water-Flood Reserves and Performance. Presented,
Spring Meet., Mid-Continent District, Div. of Production, API, Tulsa,
Okla., Apr. 5-7, 1961, 11 pp.

KENNEDY, H. T., AND GUERRERO, E. T. The Effect of Surface and Interfacial
Tensions on the Recovery of Oil by Waterflooding. Trans. AIME, Petrol.
Devel. and Technol., vol. 201, 1954, pp. 124-131.

MORGAN, JOHN V.. Correlation of Radioactive Logs of the Lansing and Kansas
City Groups in Central Kansas. Trans. AIME, Petrol. Devel. and Technol.,
vol. 195, 1952, pp. 111-117.

RIGGS, C. H., HUFF, RAY V., AND WARD, DONC, Potentialities of the Lansing-
Kansas City Formation in the Hall-Gurney Field, Russell County, Kans.
Producers Monthly, vol. 4, No. 7, May 1960, pp. 18-25.

SMITH, HAROLD M. Correlation Index to Aid in Interpreting Crude-0il
Analyses. Bureau of Mines Tech. Paper 610, 1940, 34 pp., 4 figs.

VOLOSIN, J. H, Estimation of Primary Oil Reserves for Lansing-Kansas City
Reservoirs. Presented, L.K.C. Waterflood Conf., Great Bend and Kansas
Sec. of Soc. of Petrol. Eng. of AIME, Great Bend, Kans., Nov. 19, 1959,
14 pp.

WALTERS, ROBERT F, Buried Pre-Cambrian Hills in Northeastern Barton
County, Central Kansas, Bull. Am. Assoc. Petrol. Geol., vol. 30, May
1946, pp. 660-710.

WALTERS, ROBERT, AND PRICE, ARTHUR S. Kraft-Prusa Oilfield, Barton County,
Kans. Structure of Typical American Oil Fields, A Symposium, vol. III,
Am. Assoc. Petrol. Geol., April 1948, pp. 249-280.

WATKINS, J. WADE, AND KINCHELOE, G. W. Corrosion of Steel in Water by

Varied Ratios of Dissolved Gases. Corrosion, Vol. 14, No. 7, July 1958,
pp. 341 1-344 T,

U.S. GOVERNMENT PRINTING OFFICE : 1963 0—670894


dry holes, 500 or more feet from producing wells, emphasize the effectiveness

of the natural water drive in this area.

Between 1950 and 1960, four dry holes were drilled in areas flushed by
the advancing edge water, and eight'oil wells were abandoned. Data from these
dry and abandoned wells, together with estimates of oil-water contacts in
producing wells, indicate that the oil-water contacts rose about 20 feet be-
tween wells and as high as 30 feet at some producing wells. The cross section
Y-Y' (fig. 16) illustrates the irregular vertical rise in water at producing

wells,

At completion in 1950, well 19, shown on the cross section, encountered
water and very little oil in the Gorham sand at 1,439 feet below sea level
is reasonable to assume that this well would have produced oil if completed

earlier in the life of the field.

The oil- and water-production histories of this representative area are
illustrated in figure 173 yearly production from the Arbuckle dolomite and
the Gorham sand is differentiated. Annual production of oil reached a maximum

760 -| LEGEND

720 (Y] cornam sone y

6404

“] mar

SSFTTssws

SSS
SSSS

320-4

SSSSS

OIL PRODUCTION,

* .
a
i j
a .

1204

804

2 wells

404

Y
7214

Percent

C
Vy

69

L soe

OT eas Be 37 3A SD "40 "41 "42
FIGURE 15,- Yearly Oil Production, Lower Formations, Representative Area, East Half.

FIGURE 17. - Yearly Oil Production, Lower Formations,
Representative Area, East Half.

31

It