RI 7688

Bureau of Mines Report of Investigations/ 1972

Characteristics

Oilfields and Crude Oil

Cook Inlet Basin, Alaska

UNITED STATES DEPARTMENT OF THE INTERIOR
r

Report of Investigations 7688

Oilfields and Crude Oil

Characteristics

Cook Inlet Basin, Alaska

By Donald P. Blasko, Alaska Office of Mineral Resources,

Anchorage, Alaska

Welton J. Wenger and J. C. Morris, Laramie Energy Research

Center, Laramie, Wyo.

UNITED STATES DEPARTMENT OF THE INTERIOR

Rogers C. B. Morton, Secretary

BUREAU OF MINES

Elburt F. Osborn, Director
I

This publication has been cataloged as follows:

Blasko, Donald P

Oilfields and crude oil characteristics: Cook Inlet Basin,

Alaska, by Donald P. Blasko, Welton J. Wenger, and J. C.

Morris. [Washington] U.S. Dept. of the Interior, Bureau of

Mines [19721

44 p. illus., tables. (U.S. Bureau of Mines. Report of investigations 7688)

Includes bibliography.

1. Oilfields-Alaska-Cook Inlet Basin. 2. Secondary recovery of

oil-Alaska-Cook Inlet Basin. 3. Petroleum-Alaska-Cook Inlet

Basin-Analysis. I. Wenger, Welton J., jt. auth. II. Morris, Jesse

C., jt. auth. III. Title. (Series)

TN23.U7 no. 7688 622.06173

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

Page

Abstract ................................................................

Introduction ............................................................

Acknowledgments.........................................................

Early Alaskan oil exploration ..................................

Swanson River field .....................................................

Middle Ground Shoal field.............................. ...... ...........

Trading Bay field .......................................................

McArthur River field ....................................................

Granite Point field .....................................................

Undeveloped areas .......................................................

North Cook Inlet field................................... ..........

Redoubt Shoal field................................................

Characteristics of Cook Inlet Basin oils................................

Discussion ..............................................................

References ..............................................................

Appendix.--Unabridged oil analysis reports ..............................

ILLUSTRATIONS

1. Oilfields in the Cook Inlet Basin, Alaska...........................

2. Swanson River unit--Soldotna Creek unit (Swanson River field).......

3. Middle Ground Shoal field...........................................

4. Trading Bay field ...................................................

5. McArthur River field (Trading Bay unit).............................

6. Granite Point field.................................. ...............

7. Correlation index curves of Cook Inlet oils.........................

TABLES

1. Production and injection--fields in Cook Inlet Basin, Alaska........

1

1

3

3

6

9

13

15

17

20

20

20

20

24

25

26

2

5

10

12

16

18

23

2. Reservoir

3. Reservoir

4. Reservoir

(Middle

5. Reservoir

6. Reservoir

(Middle

7. Reservoir

Hemlock

8. Reservoir

(Middle

data, Swanson River field, Hemlock formation..............

data, Middle Ground Shoal field, Hemlock formation........

data, Middle Ground Shoal field, Tyonek formation

Ground Shoal member).................................. ..

data, Trading Bay field, Hemlock formation................

data, Trading Bay field, Tyonek formation

Ground Shoal member)......................................

data, McArthur River field (Trading Bay unit)

formation.................................................

data, Granite Point field, Tyonek formation

Ground Shoal member)......................................

7

8

9

9

13

13

19

9. Characteristics of some Cook Inlet oils............................. 21
OILFIELDS AND CRUDE OIL CHARACTERISTICS

Cook Inlet Basin, Alaska

by

Donald P. Blasko, Welton J. Wenger, 2 and J. C. Morris3

ABSTRACT

The first well that produced commercial quantities of oil in the Cook

Inlet Basin of Alaska was completed in 1957. Since that time oil production

in the basin has increased rapidly and by the end of 1969 had reached an

annual rate of 74 million barrels. Five major oilfields had been developed,

and two additional discoveries awaited development. Estimated amounts of

recoverable oil by primary and secondary recovery methods total 2.7 billion

barrels, or 36 percent of the estimated oil originally in place. Repressurization by injecting gas or water in formations containing undersaturated oil

has significantly increased the volume of recoverable oil. All production

has been from formations of the Tertiary age; that much of it is from depths

of 10,000 feet or more is unusual for Tertiary formations. The oils are low

in sulfur and contain low to moderate amounts of asphalt.

INTRODUCTION

The Cook Inlet Basin is in south-central Alaska. As shown in figure 1,

it is bounded by the Alaska Range on the west, northwest, and north; the

Talkeetna Mountains on the east; and the Barren Islands to the south, just

south of the Chugach Islands. Anchorage, Alaska's largest city, lies within

the basin area.

The climate of the Cook Inlet Basin is moderate; the region is warmed by

the Japanese current, which provides warm, moist air in contrast to the cold,

dry, arctic air of interior Alaska. Average July temperatures range from

68° F at Palmer in the north to 60° F at Homer in the south. January temperatures average 19° F at Palmer and 28° F at Homer. Precipitation is about

12 inches per year (11). 4

The land area of the Cook Inlet Basin includes rugged glacial mountains

that range in elevation up to 10,197 feet (Redoubt Volcano) on the west side

1 Petroleum engineer.

2 Research chemist.

3 Project leader.

4Underlined numbers in parentheses refer to items in the list of references

preceding the appendix.
I

2

FIGURE 1. - Oilfields in the Cook Inlet Basin, Alaska.
3

of the inlet. Relatively flat, dry land suitable for farming lies in the

northern Matanuska Valley. Low-lying swampy, muskeg-type land in the

western half of the Kenai Peninsula is in contrast to the mountains in the

eastern half of that peninsula. Permafrost is absent throughout the basin.

Cook inlet itself is a cold body of water characterized by 30-foot tides

that ebb and flood at velocities up to 13 knots. From mid-November to April,

the inlet is clogged with ice from its northern extremity at Anchorage south

to the northern tip of Kalgin Island.

Early exploration for oil in Alaska, which started at the turn of the

century, was not commercially productive although shows of oil-saturated

formations were found in many instances. It was not until the late 1950's

that exploration activities were undertaken on a major scale and techniques

were developed to cope with weather extremes and with the ice floes and high

tides that hampered early offshore operations.

Since the time of the discovery of oil on the Kenai Peninsula in 1957,

the petroleum industry has had a great impact upon the development of the State

of Alaska. Coinciding with the advent of statehood, the discovery of oil

provided the impetus for a stable industry that has grown to be the most

important mineral-producing industry in the State. This Bureau of Mines

report gives details on the development of oil production in the Cook Inlet

Basin and discusses the characteristics of the oils that are produced. The

production data are arranged by fields in the chronological order of their

discovery and development. The characteristics of 19 oils from the different

fields are compared. Unabridged analysis reports of the oils are given in

the appendix.

ACKNOWLEDGMENTS

The cooperation of the State of Alaska Department of Natural Resources,

Division of Oil and Gas, in providing production figures, well locations,

reservoir characteristics, and other general information is greatly appreciated. Individual oil companies supplied information and crude oil samples

on which the analyses were made.

EARLY ALASKAN OIL EXPLORATION

The earliest attempts to find oil in Alaska took place in the Cook Inlet

Basin. Oil seeps were noted on the west shore of the basin as early as 1853

(3, 7). During 1896, the Alaska Petroleum Co. was organized and began leasing

land for future drilling. The first well drilled to find crude oil was

spudded in 1900 near the south end of the Iniskin Peninsula near Bowser

Creek (3) southwest of Chinitna Bay. Exact records are not available, but

the well probably was drilled to about 1,000 feet. Oil shows were encountered, and the well was bottomed in the Tuxedni formation of Middle Jurassic

age. The well was abandoned because of zones of salt water flowing under

high pressure.
4

Three wells were drilled in the Oil Bay area, south of Chinitna Bay,

between 1904 and 1906. All three were abandoned in Jurassic sediments. The

deepest of the three, drilled to 900 feet, produced 10 barrels of oil per day

(5). Difficulty with high-pressure water zones and sloughing formations was

experienced with each well.

In the Dry Bay area of the Iniskin Peninsula, southwest of Chinitna Bay,

two wells were drilled during the early 1900's by the Alaska Petroleum Co.

(3). Both wells were abandoned at shallow depths owing to lost tools and

equipment troubles. In 1921 the Anchorage Oil and Development Co. drilled an

exploratory well east of Anchorage, and between 1926 and 1930 a firm known as

Peterson Oil Association made an attempt to find production near Chickaloon

just northeast of Palmer. These ventures were unsuccessful.

The earliest recorded deep-drilling exploration in the Cook Inlet Basin

was in 1936. During that year, Havenstrite Oil spudded the Iniskin Bay

Association No. 1 in the C sec 8, T 5 S, R 23 W (SM)s south of Chinitna Bay

on the Iniskin Peninsula on the west shore of Cook Inlet. The drilling of

that well progressed only during the late summer and fall, which was characteristic of early drilling in Alaska. It took 3 years to complete the well,

which produced enough gas to run the powerplant. A high-gravity, low-sulfur,

paraffin-base oil was encountered, but the apparent producing interval of

5,604 feet to 7,156 feet did not yield oil in commercial quantities. Total

depth drilled was 8,775 feet.

Between 1940 and 1954, exploratory work in the Cook Inlet Basin, as in

most of Alaska, was almost at a standstill. In the only Alaskan activity

reported in this period, the U.S. Navy was carrying out extensive exploration

to evaluate the possibilities of Naval Petroleum Reserve No. 4, in an area

north of the Arctic Circle.

In 1954 Havenstrite Oil began drilling the Iniskin unit No. 1 in the same

general area on the Iniskin Peninsula as that of the well drilled in 1936.

Drilling was suspended in November 1959, and the well was finally plugged and

abandoned in 1964. Total depth of the well was 9,476 feet, and the bit was

reportedly drilling in Jurassic volcanics when the well was abandoned.

Between 6,000 feet and 9,300 feet the formation was saturated with crude oil,

but the lack of permeability prohibited production. This low permeability

may be in part the result of swelling clays within the volcanics being drilled.

Another area of significant exploratory interest in the 1950's was in the

northern upland regions of the Cook Inlet Basin southwest of the hamlet of

Willow, near Houston. The Bureau of Mines, while drilling core holes for coal

samples, encountered natural gas flows at around 450 feet (6). This quasidiscovery led to oil- and gas-leasing activity in the area and, ultimately,

to the spudding of four wells between 1954 and 1959 by Anchorage Gas and

Development, Inc. Although shows of natural gas were encountered, none of

the wells was commercially productive. The Rosetta No. 3, drilled to a total

depth of 6,109 feet, was the deepest of the four; the others reached

SSeward Meridian.
5

R 9 W

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LEGEND

* Oil Well

x-* Oil Well, surface location to

bottom of hole location

% Oil Well, shut-in

X Gas Well, shut-in

- Dry Hole

* Gas Injection Well

f Gas Injection Well, shut-in

@ Water Disposal Well

. Soldotna Greek Unit Boundary

/ Swanson River Unit Boundary

T

7

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FIGURE 2. - Swanson River Unit-Soldotna Creek Unit (Swanson River Field).
6

approximately 1,500 feet. Since that time, there have been several dry holes

drilled on the west side of the Knik Arm.

The modern oil boom in Alaska began in 1957 when Richfield Oil Corp.

drilled the discovery well in what is now the Swanson River field.

SWANSON RIVER FIELD

The Swanson River field lies north and west of Kenai and consists of two

units, the Swanson River unit and the Soldotna Creek unit (fig. 2). Standard

Oil Co. of California operates the field for itself and for Atlantic Richfield

Co., Union Oil Co. of California, and Marathon Oil Co. Production data for

crude oil, natural gas, and water are included in table 1, and reservoir data

are given in table 2.

The discovery well, a joint venture of Richfield Oil Co. and Standard

Oil Co. of California, was drilled by Richfield on the Kenai Peninsula about

14 miles north of Soldotna. The well was drilled on federally owned land in

the Kenai National Moose Range; the land had been unitized for drilling

purposes in 1956. The well produced 900 barrels of oil per day from the

Hemlock formation of Tertiary age.

Land to the south of the Swanson River unit, also on the Kenai National

Moose Range, was unitized effective December 1959 as the Soldotna Creek unit.

A well was spudded within the newly formed unit during the same month, and

the Soldotna Creek unit No. 1 (No. 14-4) was completed as a wildcat discovery

in March 1960. Oil was produced from the Hemlock formation.

The Swanson River unit No. 10 (No. 212-10), completed during 1960, was

the first dry-gas well in the Swanson River unit. Production was from shallow

sands of Tertiary age in the Sterling formation.

Development drilling in the Swanson River unit to the end of 1963 resulted

in 26 oil producers, four dry-gas producers, nine dry holes, and one waterdisposal well. Development drilling in the Soldotna Creek unit resulted in

33 oil wells, two dry-gas wells, and four dry holes. There was no further

development drilling in the Swanson River field until mid-1969. During 1969,

two wells were completed as oil producers in the Soldotna Creek unit, and a

third was spudded.

Recoverable oil reserves in the field have been significantly increased

by gas repressurization. The original producing mechanism of the Hemlock

formation in the Swanson River field was reservoir fluid expansion. At the

onset of production, little water was produced with the oil, and this was only

from wells on the edge of the reservoir. The oil under normal reservoir conditions was undersaturated; gas-oil ratios averaged about 180 to 1. The

reservoir characteristics (table 2) indicated that the reservoir would be

susceptible to gas repressurization.
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TABLE 2. - Reservoir data, Swanson River field,

Hemlock formation

Initial reservoir pressure ............psi.. 5,650

Saturation pressure ...................psi.. 1,000-1,400

Gravity ............................. ° API.. 29.7-36

Reservoir temperature ................. ° F.. 180

Net pay thickness ......................ft.. 8-300

Porosity .............................. pct.. 18-26

Permeability ........................... md.. 0-3,275

Connate water.........................pct.. 40

Formation volume factor.................... 1.12

Original gas-oil ratio............scf/STB.. 105-550

The gas repressurization program of the Hemlock formation in the Soldotna

Creek unit began in November 1962. Produced gas was gathered from wells in

both the Soldotna Creek unit and the Swanson River unit and was injected

through one injection well in the Soldotna Creek unit. By the end of the

year, another injection well had been added, and a total of 252,160 Mcf of

gas had been injected. Another injection well was added in March 1963.

In 1965 Standard Oil Co. of California began expanding the reservoir

repressurization program in the field. In May 1966, gas was injected in the

Swanson River unit for the first time, using three injection wells. By early

1966, increased volumes of gas were being injected in the Soldotna Creek unit.

Average daily injection rates increased from 12,000 Mcf in 1965 to 89,000 Mcf

in 1966 to 192,592 Mcf in December of 1969.

Owing to production problems, the six shallow dry-gas wells in the Swanson

River field were shut in, which made it necessary to obtain injection gas from

the Kenai unit gasfield 20 miles to the south. Under terms of an agreement

with Union Oil Co., operator of the Kenai unit, the gas that is obtained from

the Kenai unit and injected in the Swanson River field will be reclaimed by

Union Oil when the reservoir is depleted of oil.

At the end of December 1969, the two units combined had 41 wells producing oil, and 10 wells were shut in. Ten wells had been converted to gasinjection wells, and gas was being injected through eight of them. One dry

hole was being used for produced water disposal, and a well drilled for water

disposal was being used to inject produced water into nonproductive formations

at about 3,000 feet.

Using reservoir data as the basis of determination, it has been estimated

that the amount of oil originally in place in the Swanson River field was

1.6 billion barrels. Of the original oil in place, it is estimated that a

total of 647 million barrels, about 40 percent, is recoverable by both primary

and secondary means. Cumulative production to the end of 1969 was nearly

102 million barrels, or 6 percent of the original oil in place and 15 percent

of the estimated recoverable oil.
9

The producing operations in the field are fully automated, and metering

devices are housed in enclosures. The crude oil moves from the field via an

8-inch diameter, 22-mile-long pipeline to a small refinery and tanker terminal

at Nikiski. Standard Oil Co. of California's 20,000 barrel-per-day refinery

makes jet fuel, heating fuel, and diesel oil; the residuum goes to west coast

refineries for further processing. Oil that is shipped from the tanker

terminal also goes to west coast refineries.

MIDDLE GROUND SHOAL FIELD

The Middle Ground Shoal field (fig. 3) is about 4 miles west of East

Foreland in offshore Cook Inlet waters on State-leased lands. Included in the

field is the South Middle Ground Shoal unit, which is operated by Shell Oil

Co. for itself and its partners, Atlantic Richfield Co. and Standard Oil Co.

of California. The remainder (northern portion) of the field is operated by

Amoco Production Co. whose partners are Skelly Oil, Phillips Petroleum, and

Atlantic Richfield Co. Data on the production of crude oil, natural gas, and

water are included in table 1; reservoir characteristics are given in tables 3

and 4.

TABLE 3. - Reservoir data, Middle Ground Shoal field,

Hemlock formation

Initial reservoir pressure ..................psi.. 3,655

Saturation pressure .........................psi.. 1,500

Gravity ................................. API.. 36-38

Reservoir temperature ....................... F.. 155

Net pay thickness ............................ft. 500

Porosity .................................... pct. 11

Permeability ............................. md.. 10

Estimated connate water .....................pct.. 40

Estimated formation volume factor................ 1.12

Original gas-oil ratio..................scf/STB.. 430

TABLE 4. - Reservoir data, Middle Ground Shoal field, Tyonek formation

(Middle Ground Shoal member)

Initial reservoir pressure .............................. psi.. 2,210

Saturation pressure ............. .... ............... psi.. 1,900

Gravity ................................................. ° API.. 36-38

Reservoir temperature . .......................... ..° F . 125

Net pay thickness ......................................... ft.. 300

Porosity ................................................... t.. 16

Permeability ............................................... md. 100

Estimated connate water .................................... pet.. 45

Estimated formation volume factor ............................... 1.12

Original gas-oil ratio ................................. scf/STB. 400

The discovery of the Middle Ground Shoal field was made by Amoco Production Co. The company spudded the Middle Ground Shoal-State 17595 No. 1

during May 1962. The well blew out under high-pressure gas twice, and after
10

T

10

N

T

9

N

T

8

N

T

7

N

LEGEND

c-*, Oil Well, platform to bottom of hole

e*d)Dual Producer (counts as two wells)

) Triple Producer (counts as three wells)

a' Oil Well, suspended

' Oil Well, shut-in e Water injection well

-' GasWell, abandoned - Dry hole

d Well Suspended

o Well Drilling

Platform Location

/ / Unit Boundary

FIGURE 3. - Middle Ground Shoal Field.
11

being controlled the second time, was plugged and abandoned. Amoco then

spudded Middle Ground Shoal-State 17595 No. 2 in May 1963 but suspended

operations late in 1963. Shell Oil Co. spudded the S.R.S. (Shell, Richfield,

Standard) Middle Ground Shoal-State No. 1 late in 1963. Ice floes in the

Cook Inlet forced suspension of the operations for the winter, and the well

was reentered in. the spring. The well was tested in the Hemlock conglomerate

during September 1964 and produced 650 barrels of oil per day.

During 1964, Amoco Production brought in Middle Ground Shoal-State 17595

No. 4 for 5,000 barrels of oil per day. Production was from five different

sands in the Tyonek and Hemlock formations of Tertiary age. This well confirmed the potential of the Middle Ground Shoal structure.

Amoco Production Co. and Shell Oil Co. then constructed the first

permanent drilling and development platforms in offshore Cook Inlet. By the

end of 1965, Shell had completed three wells on platform A and began transmitting oil to shore facilities via a dual 8-inch pipeline. During April

1966, Amoco began production from its platform Baker and transmitted oil via

the 8-inch line to shore facilities on East Foreland. The 8-inch pipeline

is commonly owned by both Shell and Amoco. Shell Oil Co. added another

development platform in the Middle Ground Shoal field (platform C) during

1967). From the beginning of development drilling in 1965 to the end of

1969, Shell had drilled a total of 32 wells from the two platforms, resulting

in 30 oil wells, one dry hole, and one water-injection well.

Amoco completed an oil well nearly 4 miles south of what was then the

known producing limits of the Middle Ground Shoal field in 1965. Subsequent

drilling indicated that the new producing area was not a new field discovery

but a southern extension of the Middle Ground Shoal field. This area was

unitized in 1967 and became the South Middle Ground Shoal unit. Amoco erected

another platform (Dillon) for development of the unit. Toward the end of

1969, 11 wells had been drilled from platform Dillon, which resulted in 10 oil

wells, with operations suspended in one well. All producing wells are completed in the Hemlock formation at South Middle Ground Shoal. Oil moves to

the East Foreland receiving facility via Amoco's dual 8-inch pipeline.

On platform Baker, 13 wells have been drilled including a recompletion

of Middle Ground Shoal-State 17595 No. 4, a well which had been drilled from

a temporary platform. Of the remaining 12 wells, 10 were oil wells, one was

a water supply well, and operations were suspended in one well. Five of the

12 oil wells are dual completion wells, and one is a triple completion well.

Water is being injected for pressure maintenance in both the Tyonek and

Hemlock formations of Tertiary age in the Middle Ground Shoal field. Both

reservoirs are undersaturated and have undergone a rapid reservoir pressure

decline. Reservoir characteristics (tables 3-4) indicated that the formations

would be susceptible to water injection as a form of pressure maintenance.

During August 1968, Shell Oil Co. began a pilot water-injection program

through one well on its platform A. In February 1969 the program was advanced

to full-scale status, and injection in three wells began on platform A. By

the end of the year, water was being injected into wells on platform C also.
I

12

R 13 W

T

10

N

T

9

N

LEGEND

o-d Oil Well, platform to bottom of hole

J Dual Producer (counts as two wells)

, Oil Wel , shut- in

* Oil and Gas Well

o Well, drilling

- Dry Hole

® Water Injection Well

o Platform Location

FIGURE 4. - Trading Bay Field.
13

At the end of 1969, Shell was producing oil from 20 wells on platforms A

and C. Five wells on platform A and six wells on platform C had been converted

to water-injection wells, and injection rates averaged 33,626 barrels of water

per day during December 1969. Water for injection was being obtained from Cook

Inlet and treated and filtered before injection.

Amoco also has undertaken plans for a pressure-maintenance program with

water injection at its two platforms. In December 1969 the injection program

was started with the injection of 429,656 barrels of water into four wells.

At the end of 1969, Amoco's platform Baker had six wells producing oil

and two wells shut in. Two wells were being used for water injection. On

platform Dillon, eight wells were producing oil, and two wells were being used

for water injection.

Based upon reservoir characteristics, estimates of oil originally in

place in both producing zones in the Tertiary reservoir total 1,239 million

barrels. It is estimated that 20 percent of the oil will be recovered by

primary means and that 10 percent will be recovered by secondary operations

for a total recovery of 372 million barrels of oil. Cumulative production to

the end of 1969 was 35 million barrels, or 9 percent of the recoverable oil.

TRADING BAY FIELD

The Trading Bay field (fig. 4) is in offshore Cook Inlet, 4-1/2 miles

northwest of the Middle Ground Shoal field. Production data on the field are

included in table 1; reservoir characteristics are given in tables 5 and 6.

TABLE 5. - Reservoir data, Trading Bay field, Hemlock formation

Initial reservoir pressure ......................... psi.. 2,745

Saturation pressure ................................psi.. 1,622

Gravity ......................................... ° API . 31

Reservoir temperature .............................. ° F.. 136

Net pay thickness ................................... ft. 300

Porosity .......................................... .pct. 14.6

Permeability ........................................ md . 10

Connate water .................................... pct.. 40

Estimated formation volume factor....................... 1.17

Original gas-oil ratio .........................scf/STB.. 318

TABLE 6. - Reservoir data, Trading Bay field, Tyonek formation

(Middle Ground Shoal member)

Initial reservoir pressure .........................psi.. 2,613

Saturation pressure ................................ psi.. 1,921

Gravity .......................................... API.. 25.6

Reservoir temperature ..............................° F.. 112

Net pay thickness ...................................ft.. 1,000

Porosity ........................................... pct.. 25

Permeability ....................................... md.. 250

Connate water ......................................pct.. 45

Estimated formation volume factor....................... 1.11

Original gas-oil ratio .........................scf/STB.. 268
14

The discovery of the Trading Bay field was made by Union Oil Co. of

California in June 1965. The wildcat well, a joint venture between Union Oil

and Marathon Oil Co., discovered oil in commercial quantities in the Upper

Hemlock formation of Tertiary age. In 1966, while Union Oil Co. was constructing a permanent drilling and production platform (Monopod) on the

Trading Bay structure, Texaco Inc. completed a successful oil well to further

define the field. Atlantic Richfield Co. also completed a well in the field

in 1967. On the basis of these successful wells, platforms have been erected

by Texaco and its partner, Superior Oil Co., and by Atlantic Richfield.

Production from Union's Monopod began in January 1967. Texaco-Superior

began production from their platform (platform A) in September 1968.

Atlantic Richfield's platform (Spark) was completed and production begun

in 1969.

Drilling from Union Oil Co. of California's Monopod by the end of 1969

resulted in 16 oil wells and one dry hole. Seven oil wells were completed

in the Tyonek formation, two in the Hemlock formation, five in both the

Tyonek and Hemlock formations, and two dual completions to produce gas from

the Tyonek formation and oil from the Hemlock formation. Status of the wells

on the Monopod at the end of 1969 was as follows: Ten Tyonek formation wells

producing and two shut in, seven Hemlock formation wells producing and two

shut in, and both Tyonek dry-gas wells producing. (Well status on figure 4

will not reflect true status because of dually completed wells having different conditions of status.)

By the end of 1969, Texaco Inc. had completed a nine-well development

program on the Texaco-Superior platform A. One well was completed in each of

the Tyonek and Hemlock formations, and six wells were completed capable of

producing oil from both the Tyonek and Hemlock formations. At the end of

1969, there were seven wells producing oil and one well shut in.

Atlantic Richfield completed five wells to produce from both the Tyonek

and Hemlock formations on the platform Spark. All five of these wells were

producing at the end of 1969. In addition, two dry holes and one waterinjection well were drilled.

As is common in the fields in the Cook Inlet Basin, the Tertiary reservoir

is undersaturated, and pressure maintenance will be necessary for optimum oil

recovery. Plans were being made at the end of 1969 to initiate secondary

recovery by water injection.

Based upon reservoir characteristics (tables 4-5), the following estimates

have been made: (1) In the Tyonek formation, original oil in place approximates 1,345 million barrels, and total recovery is expected to be approximately

40 percent, or 538 million barrels; (2) the original oil in place in the

Hemlock reservoir is estimated to be 209 million barrels, and total recovery

will be about 40 percent or 84 million barrels; and (3) total recovery from

both producing reservoirs in the Trading Bay field will be about 622 million

barrels of oil.
15

Oil from the Trading Bay field is transmitted from the platforms through

dual 8-inch lines that run to treating facilities on the west shore of Cook

Inlet. Oil is then transmitted south to tanker loading facilities at Drift

River via the 20-inch Drift River pipeline.

McARTHUR RIVER FIELD

The McArthur River field (fig. 5) is located in offshore Cook Inlet near

the west shore of East Foreland. Production data on the field are included in

table 1.

The rapid development of the McArthur River field from late 1965 through

1966 often led to confusing nomenclature in the field. The discovery well,

completed by Union Oil Co. of California in November 1965, was designated

Grayling No. 1-A. This well together with others being drilled in the area

was first referred to as the Grayling field. In 1966, Union Oil Co. of

California completed the Kustatan State No. 1-A, which was thought to be the

discovery well of another field, the Dolly Varden. Also in 1966, Amoco

Production Co. completed the North Redoubt State No. 1, and Atlantic Richfield

completed the McArthur State No. 1. Eventually, it was learned that all these

wells were on the same structure, and they were combined into what is now the

McArthur River field.

Other confusing nomenclature arose when the McArthur River field was

unitized in 1967. At that time it was thought that the Trading Bay field was

part of the structure being unitized, so the unit was called the Trading Bay

Unit, with Union Oil Co. of California as the operator. Later drilling determined that the Trading Bay field was on a separate structure, so that field

was not included in the Trading Bay unit, although the name remained.

Union Oil Co. completed construction of its permanent drilling and production platform (Grayling) in 1967 near the location of their Grayling No. 1

discovery well; the first production from the platform and the field, recorded

during October of 1967, was from the Hemlock formation. Development drilling

continued, and in August 1968, Union announced that oil had been encountered

below the Hemlock formation in the Tertiary West Foreland formation. Production is also obtained from the shallower Tyonek formation (mid-Kenai). At

the end of 1969 on the Grayling platform, there were 12 wells producing oil

from the Hemlock formation and two wells shut in, three wells producing from

the West Foreland and Tyonek formations, four wells injecting water in the

Hemlock, and one well producing gas from the Tyonek formation.

The Atlantic Richfield Co., as suboperator of the Trading Bay unit,

erected the King Salmon platform during 1967, and production began early in

1968. The platform is located near its McArthur State No. 1 well. At the

end of 1969, there were eight wells producing oil from the Hemlock, two wells

shut in, one well producing gas from the Tyonek formation, and four wells

injecting water into the Hemlock formation.

Marathon Oil Co., an operating partner of Union Oil Co. of California in

Trading Bay unit and a suboperator of the unit, erected the Dolly Varden
R 14 W R 13 W

T

8

N

LEGEND

o-x Oil Well, platform to bottom of hole

*d) Dual Producer (counts as two wells)

# Oil Well, shut-in

* Gos Well

-- Dry hole

® Water injection well

o Platform Location

/ Unit Boundary

FIGURE 5. - McArthur River Field (Trading Bay Unit).
17

platform during 1967 and began drilling and production operations during 1968.

At the end of 1969, there were 13 wells producing oil from the Hemlock formation, one well shut in, one well producing gas from the Tyonek formation, and

six wells injecting water into the Hemlock formation.

Based upon reservoir characteristics (table 7) the amount of oil originally in place is estimated to be 1,820 million barrels. Recovery of the

original oil in place by normal pressure depletion is estimated at 18 percent.

Because the Hemlock formation is undersaturated, pressure maintenance by water

injection could probably recover an additional 17 to 20 percent of the oil.

Thus, it is estimated that a total of 35 percent of the original oil in place,

or 637 million barrels of oil, could be recovered.

TABLE 7. - Reservoir data, McArthur River field (Trading Bay unit)

Hemlock formation

Initial reservoir pressure ........................... psi.. 4,250

Saturation pressure...................................psi 1,782

Gravity ............................................ API.. 35

Reservoir temperature ................................ F.. 180

Net pay thickness ....................... ..........ft. 500

Porosity ............................................ pct. 10.5

Permeability ............. . ............... ...md. 53

Connate water .................. .................. ...pct.. 35

Formation volume factor .................................. 1.21

Original gas-oil ratio ........................... scf/STB.. 312

Oil from the McArthur River field reaches facilities on the west shore

via pipeline. The Dolly Varden and King Salmon platforms have twinned 8-inch

lines. The line from the Grayling platform is a twinned 10-inch line. After

the oil is treated at the onshore facility, it enters the Drift River pipeline

and is transmitted to the Drift River tanker terminal.

GRANITE POINT FIELD

The Granite Point field (fig. 6), the northernmost field in offshore Cook

Inlet, is located near the west shore of the inlet about 15 miles north of the

East Foreland. Production data are included in table 1.

The Granite Point field was discovered by Mobil Oil Co. in May 1965 while

drilling for itself and its lease partner, Union Oil Co. of California. Amoco

Production Co. completed an offset well about 1-1/2 miles northeast of the

Mobil discovery that produced over 2,400 barrels of oil per day. Production

was from the Tertiary Tyonek formation. Amoco drilled a number of expendable

wells from a temporary platform before determining the best location for its

permanent platform.

Amoco Production constructed two platforms on the Granite Point structure

during 1966. Both platforms were placed near the sites of previously drilled

holes. Both of Amoco's platforms (Anna and Bruce) are north and east of

Mobil's platform. Amoco began producing oil from Granite Point during March

1967.
27

34

C,

3

Tow

36

C

10

15

18

'Tower No. 2

22

R 12 W R II W

4

2

"I

28

33

6 4

A, 'r_ er No.

7 9

-13

., J

_--_ G.P Platform

(Mobil)

18

K '

16

19

-- _____

21

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

27 25 30 28

Well status 12-31-69

I-- 0

c:

LEGEND

Oil Well, platform to bottom of hole

Oil Well, shut-in

Dry hole

Water injection well, shut-in

Platform Location

FIGURE 6. - Granite Point Field.
19

During 1966, Mobil constructed a permanent drilling and production platform just south of their original discovery. Production from Mobil's platform

began in May 1967.

Oil in the Middle Ground Shoal member of the Tyonek formation is undersaturated with gas, as in other fields in the Cook Inlet Basin. Pressure

maintenance by water injection began on a limited scale in August 1968 on

Mobil's platform. Water was injected intermittently through one well until

mid-1969 when injection ceased. During the year, two wells were drilled

through which water will be injected in the future.

At the end of 1969 there were 15 wells producing oil on Mobil's platform,

two of which are to be used for water injection; one water-injection well was

shut in.

Amoco had 12 wells producing oil and one well shut in on platform Anna.

There were 10 wells producing and one well shut in on platform Bruce at the

end of 1969.

Based upon available reservoir data (table 8), it has been estimated that

there were 1,592 million barrels of oil originally in place in the Granite

Point field and that 15 percent would be recovered by primary means. Secondary recovery operations by water injection for pressure maintenance are

expected to recover an additional 15 percent of the oil, which would give a

total recovery of 30 percent.

TABLE 8. - Reservoir data, Granite Point field, Tyonek formation

(Middle Ground Shoal member)

Initial reservoir pressure ..........................psi.. 4,116

Saturation pressure .................................psi. 2,400

Gravity ..... .................................. API . 41-44

Reservoir temperature ............................... F.. 170

Net pay thickness .................................... ft. 600

Porosity ............................................pt. 14

Permeability ........................................ md 10

Estimated connate water.............................pct . 30

Estimated formation volume factor ........................ 1.1

Original gas-oil ratio ..........................scf/STB.. 960

Oil from Mobil's platform moves through twinned 8-inch pipelines to shore

facilities on the west side of Cook Inlet. There the oil enters the 20-inch

Drift River pipeline and moves to the terminus at the mouth of the Drift

River, south of the Forelands. From there the oil is transported by tankers

to west coast refineries in the "lower 48."

Oil from Amoco's two platforms is piped through two 15-mile long,

10-inch-diameter pipelines running south from the Granite Point field to

facilities on the East Foreland. The pipeline is under Cook Inlet for its

entire length. The oil is then piped from receiving facilities at East Foreland to the Kenai pipeline tanker loading dock at Nikiski for tanker shipment

to west coast refineries.
20

UNDEVELOPED AREAS

Two additional areas of offshore Cook Inlet have shown oil-producing

capabilities. A short description of each follows.

North Cock Inlet Field

The North Cook Inlet field (fig. 1) is in offshore Cook Inlet about

26 miles southwest of Anchorage.

The North Cook Inlet field was discovered by Amoco Production Co. as a

gas-condensate field. The discovery well was spudded in 1962 and, after

suffering blowout problems, was completed through a directionally drilled

relief well in 1964. Production was from the Tyonek formation at the daily

rate of 650 barrels of condensate and 5,000 Mcf of gas. The well and field

were shut in from discovery until 1969. In that year, Phillips Petroleum Co.,

the unit operator, began producing gas from the platform that had been erected

in the field. Also in 1969, drilling of the first well of a deep drilling

program was begun from the platform.

After Amoco's gas-condensate discovery, oil production from the Hemlock

formation was discovered by Shell Oil Co. in a well located about 2-1/2 miles

north of Amoco's well. This well has been shut in since discovery, and no

plans have been announced by Shell to develop that portion of the field.

Redoubt Shoal Field

In 1968, Amoco Production Co. announced a new field discovery in offshore

Cook Inlet south of the Forelands; this is the southernmost oil discovery in

the inlet. The discovery well is the only well drilled in the Redoubt Shoal

field (fig. 1) to the end of 1969, and it has been shut in since discovery.

Production was from the Hemlock formation. No plans have been revealed for

future development of the unitized field.

CHARACTERISTICS OF COOK INLET BASIN OILS

Some characteristics of 19 oils from the Cook Inlet Basin are shown in

table 9. The unabridged analysis reports on these oils are given in the

appendix, and the item number in table 9 is repeated on the reports in the

appendix for reference purposes.

Specific gravity and sulfur percentage values show no distinguishable

trends that can be related to formation or area. Samples from the nonproducing fields set the extremes of gravity and sulfur content: The condensate

from North Cook Inlet has the highest gravity and lowest sulfur content; the

oil from Redoubt Shoal has the lowest gravity and highest sulfur. Among oils

from the producing fields, the samples from Granite Point have higher

gravities and lower sulfur contents than do most of the other oils.
TABLE 9. - Characteristics of some Cook Inlet oils

Distillation yields,

Viscos- Ratio, __ volume-percent

Grav- ity Pour Sulfur, Nitrogen, Carbon nitrogen Frac. Frac. Frac.

Item Field Productive formation1 Depth, ity, Color2 at point, weight- weight- residue, to 1-3 Frac. 8-12 13-15 Resifeet ° API 100° F ° F percent percent weight- carbon (light 4-7 (kero- (lubri- duum

SUS 3 percent4 residue gaso- (naph- sine, cating

line) tha) gas- oil)

oil)

1 Cook Inlet, N ...... Middle Ground Shoal, cgl. 10,927 53.7 D.G. 29 <5 0.00 0.005 0.1 0.050 29.6 39.4 21.4 5.0 1.7

2 Granite Point ...... Middle Ground Shoal, ss.. 8,650 42.8 B.G. 34 <5 .02 .039 1.1 .035 17.7 27.4 24.4 13.5 14.4

3 Granite Point ...... Middle Ground Shoal, ss.. 8,181 40.9 B.G. 34 <5 .05 .054 1.8 .030 15.7 26.8 23.3 13.7 16.2

4 McArthur River ..... Hemlock, cgl ............. 9,370 33.0 B.G. 45 35 .09 .146 4.3 .034 8.6 21.0 26.3 16.0 27.4

5 McArthur River ..... Hemlock, cgl ............. 10,662 33.4 G.B. 45 <5 .07 .156 5.1 .031 9.9 20.7 22.0 15.8 29.1

6 McArthur River..... Hemlock, cgl ............. 9,486 32.7 B.B. 45 5 .09 .142 4.8 .030 7.6 19.6 26.8 16.5 27.6

7 McArthur River..... Hemlock, cgl............. 10,660 34.2 B.B. 37 20 .08 .132 4.2 .031 8.8 20.6 24.3 15.6 28.6

8 McArthur River..... Tyonek, cgl .............. 11,349 33.0 G.B. 47 35 .11 .149 1.1 .044 6.5 21.1 26.0 18.3 26.4

9 McArthur River ..... West Foreland, ss ........ 11,350 30.6 B.B. 59 <5 .15 .186 6.8 .027 6.7 19.2 21.9 16.8 31.0

10 Middle Ground Shoal Middle Ground Shoal, cgl. 8,400 33.8 G.B. 44 <5 .06 .124 4.0 .031 10.1 21.2 26.2 15.6 25.3

11 Middle Ground Shoal Hemlock, cgl ............. 7,483 35.0 G.B. 40 <5 .05 .115 3.5 .033 9.1 21.1 26.0 16.2 25.1

12 Redoubt Shoal ...... Hemlock, cgl ............. 10,000 27.7 B.B. 100 10 .22 .211 8.4 .025 8.6 12.7 21.9 15.7 37.5

13 Swanson River ...... Hemlock, cgl ............. 11,000 29.7 B.B. 61 <5 .16 .203 8.1 .025 7.7 19.7 24.9 16.3 31.4

14 Swanson River ...... Hemlock, cgl ............. 10,900 33.8 G.B. 46 10 .05 .133 4.0 .033 12.5 17.8 24.6 15.0 27.8

15 Swanson River ...... Hemlock, cgl ............. 11,200 30.2 G.B. 65 15 .08 .161 7.4 .022 11.2 14.3 24.6 14.6 32.9

16 Swanson River ...... Hemlock,cgl .............. 11,000 33.4 G.B. 46 10 .05 .133 3.4 .039 9.2 19.8 23.5 16.3 29.1

17 Swanson River ...... Hemlock, cgl ............. 11,000 36.0 G.B. 40 <5 .03 .095 4.3 .022 10.7 23.5 23.6 15.4 24.8

18 Trading Bay ........ Middle Ground Shoal, ss.. 5,363 31.0 B.B. 53 <5 .05 .149 4.3 .035 9.7 18.8 23.4 16.0 30.5

19 Trading Bay ........ Hemlock, cgl ............. 10,500 32.3 B.G. 45 20 .11 .026 4.7 .028 3.9 25.1 31.1 17.7 26.2

1

Abbreviation: cgl. = conglomerate; ss. = sandstone. 2 Colors are designated as follows: D.G. = dark green; B.G. = brownish green; G.B. = greenish black; B.B. = brownish black.

3SUS = Saybolt Universal Seconds. 4

Carbon residue values are equivalent to those obtained by the Conradson method, ASTM designation D189-46.
22

A notable characteristic of these Cook Inlet oils is the low sulfur content. All of the sulfur percentages are considerably less than 0.5, which is

the upper limit proposed for so-called "low-sulfur" oils (12). The highest

sulfur percentage is 0.22 percent in the oil from Redoubt Shoal, and all but

five of the oils contain less than 0.1 percent.

The nitrogen percentage of the oils, although not high (0.005 to 0.211),

has an unusual relationship to the sulfur content. Most crude oils have

sulfur contents five to 10 times higher than the nitrogen content. A

comparison of sulfur and nitrogen percentages in table 9 shows that all but

one of the oils contain more nitrogen than sulfur. Among the few oils with

more nitrogen than sulfur are some oils from Utah that are also produced

from Tertiary formations (13).

The nitrogen in petroleum has been related to the carbon residue percentage, and therefore to the asphalt content of the oil (1). A study of 153 crude

oils showed that 85 percent or more of the nitrogen in the oils remained in

the residues after distillation (2). In 1957 at the 131st meeting of the

American Chemical Society, Analytical Chemistry Division, J. S. Ball and

H. M. Smith presented a paper based on a study of 1,002 crude oils; the average ratio of nitrogen percentages to carbon residue in these oils was found

to be 0.050. For the Cook Inlet oils, as shown in table 8, this ratio averages 0.032, which indicates a lower-than-average nitrogen percentage compared

with the carbon residue value.

The asphalt content of a crude oil may be estimated from the carbon

residue percentage (10); the amount of 100-penetration asphalt that may be

obtained from a crude oil is calculated by multiplying the carbon residue

percentage by 4.9. A survey of carbon residue percentages in table 9 reveals

that these oils will have a wide range of asphalt content, from a low of 0.49

percent for the North Cook Inlet condensate (item 1) to a high of 41 percent

for the Redoubt Shoal sample (item 12). Between these extremes the oils

average about 21.5 percent asphalt and are considered to be moderately

asphaltic.

A few of the oils are waxy, as indicated by their high pour points; for

example, items 4, 7, and 8 (table 9) have pour points of 35°, 20°, and 35° F,

respectively. These three oils also contain significant carbon residue

percentages, which indicate asphalt contents of 15 to 20 percent. Oils that

are both waxy and asphaltic are uncommon, although they have been noted in

other areas such as the Uinta Basin of Utah (13).

The correlation index (CI) has been used to characterize the molecular

structures of the hydrocarbons in petroleum fractions (8-9). The CI scale,

a function of the density and boiling range of the fraction, is arranged so

that the straight-chain paraffins have an index of zero, and benzene,

representing the aromatics, has an index of 100. The branched paraffins,

cyclic paraffins (naphthenes), alkyl-substituted aromatics, and mixtures of

the various types will have intermediate values.
x

LU

Z

0

I-

<r

-_j

LU

Q

C) Co

23

4 6 8 10 12 14

FRACTION NUMBER

FIGURE 7. - Correlation Index Curves of Cook Inlet Oils.

Correlation index values are plotted in figure 7. The average CI curve

for the Cook Inlet oils, obtained by plotting the average values of corresponding fractions of the oils versus the distillation fraction number, is

shown in the center. Included in the figure are the upper and lower extremes

of the CI curves on fractions of individual oils (items 18 and 1, respectively,

in table 8); curves for all other oils have similar shapes and values that
24

fall within these extremes. The relative proximity of the curves and the

similarity of their shapes suggest that variations in composition between

fractions are not greatly different among the Cook Inlet oils. In each of

the oils there is indicated a steady progression from a predominance of

open-chain paraffins in the low-boiling fractions toward a predominance of

naphthenic and/or aromatic types in the higher boiling ranges.

DISCUSSION

Since the first major discovery in 1957, oil production in the Cook

Inlet Basin has boosted Alaska to the status of a major oil-producing State.

By the end of 1969, the basin had produced more than 233 million barrels of

oil, and annual production rates had reached more than 74 million barrels

(table 1). Estimated recoverable reserves, by both primary and secondary

recovery methods, are 2.7 billion barrels, which is about 36 percent of the

estimated 7.8 billion barrels of oil in place in the basin. Techniques

developed by the oil industry to cope successfully with the weather extremes,

high tides, and ice floes in the Cook Inlet will doubtless prove of great

value in developing oil resources in other parts of Alaska.

All of the Cook Inlet Basin production has been from Tertiary formations.

Generally, the reservoir oils have been undersaturated, and repressurization

by injection of gas or water has significantly increased the amount of

recoverable oil.

Some unusual features may be noted from the analyses of the Cook Inlet

oils. In most of the oils, the nitrogen content is higher than the sulfur

content. Of interest to petroleum geologists is the occurrence of darkcolored asphaltic oils at depths greater than 10,000 feet, which is a rare

instance in other areas (4). It is of further interest to find productive

Tertiary formations at these depths; 12 of the 19 oils listed in table 9

are produced from depths of 10,000 feet or greater.

Because of the low sulfur content of the Cook Inlet oils, they should be

preferred sources of nonpolluting fuels and should present a minimum of

problems for refiners.
25

REFERENCES

1. Ball, John S., D. R. Latham, and R. V. Helm. Nitrogen in Petroleum

Asphalt. J. Chem. and Eng. Data, v. 4, No. 2, 1959, pp. 167-170.

2. Ball, J. S., M. L. Whisman, arid W. J. Wenger. Nitrogen Content of Crude

Petroleums. Ind. Eng. Chem. v. 43, 1951, pp. 2577-2581.

3. Emmons, S. F., and C. W. Hayes. Contributions to Economic Geology,

1903. U.S. Geol. Survey Bull. 225, 1904, 527 pp.

4. Hunt, J. M., and J. P. Forsman. Relation of Crude Oil Composition to

Stratigraphy in the Wind River Basin. 12th Ann. Field Conf. Guidebook,

Wyo. Geol. Assoc., 1957, pp. 105-111.

5. Martin, G. C. Preliminary Report on Petroleum in Alaska. U.S. Geol.

Survey Bull. 719, 1921, 83 pp.

6. May, R. R., and R. S. Warfield. Investigation of Subbituminous-Coal Beds

Near Houston, Westward Extremity of Matanuska Coalfield, Alaska.

BuMines Rept. of Inv. 5350, 1957, 20 pp.

7. Miller, Don J., Thomas G. Payne, and George Gryc. Geology of Possible

Petroleum Provinces in Alaska. U.S. Geol. Survey Bull. 1094, 1959,

131 pp.

8. Smith, Harold M. Correlation Index To Aid in Interpreting Crude-Oil

Analyses. BuMines Tech. Paper 610, 1940, 34 pp.

9. Smith, H. M., and J. S. Ball. Crude Oil Characterization by the Bureau

of Mines Routine Method. Petrol. Eng., v. 26, June 1954, pp. C12-C14.

10. Smith, N. A. C., H. M. Smith, and C. M. McKinney. Refining Properties of

New Crudes. Part I: Significance and Interpretation of Bureau of

Mines Routine Crude Oil Analysis. Petrol. Processing, v. 6, No. 6,

June 1950, pp. 609-614.

11. U.S. Dept. of Commerce, Weather Bureau. Climatography of the U.S.

No. 60-49, Climates of the States, Alaska. Wash., D. C., September

1959, 22 pp.

12. Wenger, W. J., and J. C. Morris. Processing Characteristics of Crude

Oils From the Williston Basin in Montana, North Dakota, and South

Dakota. BuMines Rept. of Inv. 7183, 1968, 95 pp.

13. . Utah Crude Oils: Characteristics of 67 Samples. BuMines Rept.

of Inv. 7352, 1971, 51 pp.
26

APPENDIX.--UNABRIDGED OIL ANALYSIS REPORTS

Bureau of Mines .. Laramie._

Sample -PC-65.-2...

---- Laboratory

Item 1

IDENTIFICATION

North Cook Inlet field

Middle Ground Shoa.: onglomerate-Tertiary

(Tyonek formation)

10,927-10,947 feet

GENERAL CHARACTERISTICS

Alaska

Seward Meridian

SW1/4SW1/4, sec. 6,

T 11 N, R 9 W

Gravity, specific. -P0:.764--- -..- Gravity, o

Sulfur, percent, ... .....

Viscosity, Sayboh. Universal at o100°2 29 sec

API, -_537 -..-..---------- Pour point, ° F., below 5

Color, .--.- I-----------.dark reen

.........---..-.-- Nitrogen, percent, 0 005 ------ ----

DISTILLATION, BUREAU OF MINES ROUTINE METHOD

STAGE 1-Distillation at atmospheric pressure, - , ......760 m. Hg

First drop, 79 ........ ° F.

gr'C Refractive S. U. Cloud

No. o . e r... t percent 60/60° F. 60° F. dispersion vise No .t p . n. at 206 C. spe i 1 00° F .

1.... . 122 5.0- 5.. . .638 90.3.o7- - 2 ...... 167 9.2 14.2 .675 1 78.1 9.8 1.37507 125.8

3...... .. 212 15.4 29.6 716 66.1 19 1.39816 . 1230.---

4...... 257 13.9 43.5 .740 59.7 22 1.41018 125.8 ...... 302 10.1 53.6 .754 56.2 21 1.41862 127.9

6 ...... 347 - 8.4 62.0 .770 . -52,3 22 1.42727 130,.3

7...... 392 .. 7.0 69.0 .784 . 49.0 22 1.43495 130,6

8 ...... 437 5.9 - 74.9 .800 45.4 24-- 1-.44264 130.0

9 ...... 482 ..4 79.3 .815 -- 42-- 26 ..1.45054 134.4

10 ...... 527 5 .55 84.8 - . 830.1 39Q 01 _ 28 - I- 1, 45889- 1-40.3. _____ _____

STAGE 2-Distillation continued at 40 mm. Hg

... ... ..... 392 2 .2 I 87. -o 0 .85o0 35.0 34 146763 142z ....3 .. - .5

12 437 34 9 90.4 . . 852- I 34.6 31 1.47129 144.1 44 25

13 .... 482 1.6 92.0 .870 - 31.1 36 1 .47757 145.7 53 .. 45

14 . 527 1.6 .93.6881 29.1 38 65 60

1. ..6 572 i .8 .95.4 . .8.99 25 .9 44....- I .. 110 65

Residuum. ... 1.7 .97.1 .948 .. 17.8 . _ _____

Carbon residue, Conradson: Residuum, _4'.8 percent; crude, 0_. 1_._ percent.

APPROXIMATE SUMMARY

| __ _____ Percent Sp. gr. API Viscosity

Light gasoline . .... ............ . 29. 0.690 73.6._ ~~~~~~~~-' ' : ' ' ' -- ' :''''' :-.-':-:--'--'------"-- i ------- -0--"--------- -- ---- -- -- -- - Total gasoline and naphtha ...... ............ ........ 69 .0 .729 626

Kerosine distillate .............................. ...-- ...--

Gas oil ........ .... ............................... .... .... ........ 1 1 2 .-... 844 .. -36-.2-

Nonviscous lubricating distillate . .......... .................... . . 3.6 ,-865 - - ,894 . 1-26 .8_- 50-100

Medium lubricating distillate ............................ ... 1.3 '894 .- 907 26.88-_24.5 100-200

Viscous lubricating distillate .................... ... .. ....... . Above. 200

Residuum . ........ ... .. .. 1.7 - 948 - 17.8

Distillation loss .................. ................................. ... , 2 .. , 9-., 
Fraction ut

Noo temp. F.

1........ 122

2...... 167

3...... 212

4...... 257

5...... 302

...... 347

7...... .- 392 

8...... 437

9 ...... 482

10 ...... 527

11 ...... 392

12 ...... . 437 -

13 ...... 482

14 ...... 527

15 ...... 572

Residuum. | ...... .

---------- ;------

Percent

6.0

3.1

8.6

9.4

I

27

1.3

4.9

4.7

3.9

4.9

14.4

STAGE 2-Distillation continued at 40 mm. Hg

64.6 .861 32.8 39 I 1.47562 , - - - .- - . Z - - - -- -- - - --

69.5 .864 32.3 37 11.47809 i 

74.2 i .875. 30.2 38 1..48451

78.1 1 .895 26.6 45

83.0 .907 24.5 47

97.4 1 .964 15.3

Bureau of Mines _

Sample

Laramie

PC-65-77

IDENTIFICATION

.. Laboratory

Item 2

Alaska

Seward Meridian

SW1/4NW1/4, sec. 13,

T 10 N, R 12 W

Granite Point field

Middle Ground Shoal sandstone-Tertiary

(Tyonek formation)

8,650-8,770 feet GENER AL CHARACTERISTICS

Gravity, specific, -_ .. 812 (Gravity, o AP

Sulfur, percent, -..... 02 .

Viscosity, Saybolt Universal at 1000_ F .-, 34 sec.

I, - 42.,8 ...... Pour point, o F., ... below 5

Color, brownish .green

-...-....--- ..--- Nitrogen, percent, .0_3.9. 0..9...

DISTILLATION, BUREAU OF MINES ROUTINE METHOD

STAGE 1--Distillation at atmospheric pressure, - -760..... mm. Hg

First drop, 8--1 .... o F.

Sulm,

percent

6.0

9.1

17.7

27.1

Sp. gr.,

60/60° F.

0.657

.689

.725

.746

o API,

60° F.

83.9

73. 9

63.7

58.2

54.0

50.1

46.9

43.0

39.6

36.8

Reifractive

C.I. index,

nr at 20° C.

-. - - --

.763

.779

.793

.811

.827

.841

17

24

25

25

26

26

29

31

33

1.38532

I 1.40158

1.41337

1 1.42395

1.43201

1.44012

1.44922

1.45895

1.46699

134.4

136.6

136.4

141.0

146.2

152.4

.... i--------- "126.9

129.8

131.0

S. U. Specific

dispersion 1000 F. 100° Fp.

l

Cloud

test,

OF.

155.2

157.1

159.7

40 40----;-.... 43

53

70

qio- 110-

10

20

60

' 80.

Carbon residue, Conradson: Residuum, . 6 4 pi.,cent; crude, 1.1- percent.

APPROXIMATE SUMMARY

Percent Sp. gr. ° API Viscosity

Light gasoline ... ............ ..... -. 17.7 96 .71_8_ 7.... 

Total gasoline and naphtha ..... ... ........... ........ .. 1 -- 739 60.0

Kerosine distillate ................. ............... . .... 5.5 .- 811 __ 43_ 0__

Gas oil ............. ....... ...... .... 19.7 -8..846 .. 835., 8.

Nonviscous lubricating distillate .............................. 8.9 .872-,904 .30_,8-25.0 50-100

Medium lubricating distillate .................. .. ... . -. 3 8 904-.__ 14 . 25.,0-23.3 100-200

Viscous lubricating distillate ................................... .. - Above 200

Residuum .................................. ... ... .... 1 4 . . 4. 15..

Distillation loss .................. ....................... . .
28

Bureau of Mines -------Lari-,e_._rie ... ..... Laboratory

Sample --.-- F 6-f13.........--

Item 3

IDENTIFICATION

Granite Point field

Middle Ground Shoal sandstone -Tertiary

(Tyonek formation)

8 181-8,570 feet 8,181-8,570 feet GENERAL CHARACTERISTICS

Gravity, specific, 0821 --------. Gravity, ° API, 4......9 ....

Sulfur, percent, .---- 05

Viscosity, Saybolt Universal at .....l: .. °.F..._ _ 34 sec.. ..............

Alaska

Seward Meridian

SE1/4SE1/4, sec. 1,

T 10 N, R 12 W

Pour point, F., .. below 5------. Color brownish___ .green Nitrogen, Nitrogen, percent . 054--------.. percent, __-.?.-05_4_. -----------

DISTILLATION, BUREAU OF MINES ROUTINE METHOD

STAGE 1-Distillation at atmospheric pressure, _._.7.6_0....- mm. Hg

First drop, ..-86 ° F.

Cut I o I I Refractive Secific . U. Cloud Fraction P s u Spr., API. pecic te Pere. Pactio t1 F. C I . index, visec., test, No . per60 0 F. . n at 20 C. dispersion 100°F. F.

1 ...... 122 3,,.1 _ 3. 7 - -0_652 ... -.....- e .. .-- - - -

2 ...... .... 167 40 ! - 7.7. .671 . 79.49 4 . 8.0 - -1.37796. 1-23_,4_

3 ...... 212 8.0 i 15.7 o.720 65.0 - 21 1.39-9-9-6- -122.8-

4 ...... 257 --. 9.0 Q 24-.. .742- - .59.2- -- 23_ -- -1.4114. 8 a .-- 125_-.-7-

5....... 302 .6,5 31_2 _-.758 -- 55.2..-- 23--- 142134 2.4--127._8__

6 ...... 347 6 0 37.2 .775 - 51.-L-. 24 -- .4308.7---2.6-

7 ...... 392 -53 3 42.5 - 90-- - 47.6 - 25 .- 1.43-856 -- 13-2e.-8-

8 ....... 437 - 5.4 -47.9 I- 06 - 44.-L- 27 --- -. .446-63. -- L33.5-

9 ...... 482 5.7 53.6 822 40.6 29 1.45668 141.8

10...... 27 6 60.2.- . 839 - 37.2 1 32- 1.1,46545 .147.3 __

STAGE 2-Distillation continued at 40 mm. Hg

1 ...... .... 3 392 9 6.1 .861 32.8 - 39 - 1.47659 150.1 43 15

12.... 437 4 .7 65 8 .863 32.5 [ 36 i 1.47865 155.1 44 25

13 ..482 4.7 70. 5 .873 30.6 37 I1.48436 157.6 52 45

14 ...... 6 527 4. 1 746 .. .. 89.1 27,3 ..... .-- - . . ----- - 7 -. 71.7 - 65......

15 ...... 572 4.9 79.5 .903 .. 25.2 i 46 120 80

Residuum. i...... 16.2 95.7 .... 967 14.8 !

Carbon residue, Conradson: Residuum, 9...4 percent; crude, 1---.---8 percent.

APPROXIMATE SUMMARY

Percent Sp. gr. 0 API Viscosity

Light gasoline ......................... ... ............... 3...... 15 - 7 --- ----- 0691 -- --- 73_ --....--

Total gasoline and naphtha .. . ....... ....... .... ..... . -5 736 5 60.-8 .----

Kerosine distillate ............. ............... ... ....... .. ... I, . ! .8. 14 2. 3

Gas oil ............. . . ...................................-- 13,4 .---.- 853... -- 34......

Nonviscous lubricating distillate .................. . . .. .... .. .. ..... . .8 - ,871- 898 .3_1_ .0-_26.1 50-100

Medium lubricating distillate ...... ....... ......... .. ... .. .. .. . 4 4 .898-:. 910 26 _1-24_.0 100-200

Viscous lubricating distillate ... ------- ------ Above 200

Residuum .... ................ ........ ........ .. ... 16 . . .... ,967 . -14,8 ..

D istillation loss ....... .... ... ... ..... ............... ..... . . .. ............
29

Bureau of Mines .-..- Larami......--------. Laboratory

Sample ---. PC-.fi6-------4.....

IDENTIFICATION

McArthur River field

Hemlock conglomerate-Tertiary

9,370-9,770 feet

GENERAL CHARACTERISTICS

Gravity, specific, - 0-.-86Q0__ .. Gravity, ° API, --. 33.0.............

Sulfur, percent, ---.---. Q9........

Viscosity, Saybolt Universal at .....-100 F._,_4.5 . sec .........................

Item 4

Alaska

Seward Meridian

NWl/4SEl/4, sec. 29,

T 9 N, R 13 W

Pour point, ° F., -.- 35-- ........ .....

Color, ____brownish g -r-reen..

Nitrogen, percent, 0...- ... 46 ..

DISTILLATION, BUREAU OF MINES ROUTINE METHOD

STAGE 1-Distillation at atmospheric pressure, --- 760 ----- mm. Hg

First drop, .90Q F.

Fraction Cut S API, Refractive S. U. Cloud

temp. Percent percet 6060 F. 600 F CI. peci vise., test, No . 6 at 20 C. dispercesion 100 F. F.

1 ...... 122 . .1.2.. , .... 71 79.......--

2 ...... 167 2.1 33.3 . 676 _. _ 77.8 .- 10 -1,.37987. .. 1247..7

3 .... 212 5._32 -, 8.6 0.. ... 0 ... 21 1,39966 126..1

4 ...... 257_ 5....7 .14.3 . . 743. 58.9. 23 ------ .1.41195 128._1

5 ...... 302 .6- 6.3 0.6. - .._ 760 - 54.7 -- 24 1. 42233 -- 132. 4

6..... 347 -- 4.5 251.. - .777 - - 5-6 25 -. - -- 1.. 431Q4 -136.-1-

7 ...... ..... 392 -- 4.5 29.6 792 -...- 472 - ..- 26. 143917- . -135.5

8 ...... 437 --.... 4.7 34.3 . 8Q9-- -- 43.4- ---- 28 --. - -1-44806. 1_363_

9 ...... 482 5 .. 3_8 . -- . 825 . -. - 40 31- -- - 145749- -1475-

10 ...... 527 _6_..8 46.-6 6- .- -. 841- -- 36-8 -33--- -. 146720 -g- 1518_____ _____

STAGE 2-Distillation continued at 40 mm. Hg

11 .... 3922 . ..... 3.8 . 5Q4 .85 7 .. 336 .6-37 .1,47592 156.1 39 10

12 ...... 437 --...... 55- 55.9 .... 863- .. 325 .--- -- -- 1.479B.8. -158.-44 ---.45 .....25.......

13 ...... 482 --- 5.3 - 61.2. ...876 .-- 30Q0- -39- ._ 1.48632. 159.4 -- 52 ........40..

14 ...... 527 --.. 5-Q- 66.2 .--.. ..895 .--- 26.6 - _45_. 69 55

15 ...... 572 5- 7 . 71-9-- .907 .. . 47 . ... 12 ......... ..

Residuum. ..... 2. _99_...986 12.0 _____2_7 __- 

Carbon residue, Conradson: Residuum, 13, 7 percent; crude, . 3 percent.

APPROXIMATE SUMMARY

Percent Sp. gr. 0 API Viscosity

Light gasoline .. ..... . .......... .. ... . . ....... 8 t.6 0702 70 .1

Total gasoline and naphtha ......................... .... .. . ; 6-=- -. --....... . .. --- .; ...... 57.9 ....

Kerosine distillate ........ .. . ......... ................. .. . 2 . 818-- 4-1

-.5

Gas oil ............................................. -- 9......854- 34.2 .

Nonviscous lubricating distillate .............. ........ ........ .. . ........ 2 .. 872 902 -4 ; 30. 8- 25. 50-100

Medium lubricating distillate .............................. .. - - 5 .... .. .. 9. 02- ,914 2__5. 4-23.:3 100-200

Viscous lubricating distillate .................... ..... . . .. Above 200

Residuum ................ ............................. 27..4 . 86 12.Q 0

Distillation loss . . . . ...... ....................... ......... . .7.
30

Bureau of Mines

Sample

Laramie

PC-66-62 __ Laboratory

IDENTIFICATION

McArthur River field

Hemlock conglomerate-Tertiary

10,662-10,824 feet

Item 5

Alaska

Seward Meridian

NW1/4NE1/4, sec. 4,

T 8 N, R 13 W

GENERAL CHARACTERISTICS

Gravity, specific, ____0.-858 Gravity, ° API, --. 33.4 pour P.... . point, ° F., elow .. 5................._..

Sulfur, percent, -.----- 07 Color -.- gr-ee-nish__black. .

Viscosity, Saybolt Universal at -. 100°F, -45 sec. ........... .-- Nitrogen, percent, Q. 156

DISTILLATION, BUREAU OF MINES ROUTINE METHOD

STAGE 1-Distillation at atmospheric pressure ..760 -.-..- mm. Hg

First drop, - -84 .-- ° F.

Fraction Cut Sum, API, Refractive Specific S U. Cloud temp. Percent Sum, Sp. gr., ~C 1. index No. 2. percent 60/60, F. 600 F. dispersion Vise test

I ...... 122 2.9 .. 2.9 -- 0.674 .8,4- ------ --- ----------.

2 ...... .,167 - - 2.7 ....- 5.6 ..... 692 - 73.0 18 ... 38526 .Q.-9-.

3 ...... 212 -- 4.3 9.9'9. .....- *724. , 63.9. -- 23 1.40116. -126-..5..

4 ...... 257 .. 5 6 - 15.5 745 i58.4- -. . 24- z 1..413.1 18.I.

5 ...... 302 54 _ 20..9 .......760 -- 54.7. 2.4 .- .1.4225Q .... 4..8_

6 ...... 347 -.... 43 ! . 25.2- -- 7.79 - 0.1- 2-6 1433- ..... 8 136..5

7......... 392 - 5 4 30.6- . -. 794 ... 46._7- 2.7 -- -L1.43_934 - 136._7__

8 ...... 437 3.4 34.0 .811 43.0 29 1.44823 141,4

9...... 482 - 5.0 39-.0 .827 -- 39.6 31 1.45819 148.7-

10 . 527 6.6 4... .841 6 36.8 ..... 33.. 1.46752 .. 57.0.

STAGE 2-Distillation continued at 40 mm. Hg

11 ....... 392 - -1..8 -_ 47.4 .861 32.8 39 . 1.47633 158.0 39 5

12 ...... 437 5. 2 52.6 .865 32.1 37 1.47886 160 .9 42 10

13 ...... 482 5.4 58.0 .875 30.2 38 1.48476 161.0 51 25

14 ...... 527 50 27,5 42..... -- ----- ---- 67 50

15 ...... 572 5.4 68.4 .902 25.4 45 . 110 70

Residuum. ..... .... 291 97.5 .988 11.7 ___

Carbon residue, Conradson: Residuum, 15-. 2 purcent; crude, -.5.-1]- percent.

APPROXIMATE SUMMARY

Percent Sp. gr. ° API Viscosity

Light gasoline 90.9 . -0,701 70Q,.4 Lightotal gasoline and naphtha................................. .... .................... ....... .......... Total gasoline and naphtha ., , , = 3.Q.-- - __.~_~ . ... .._74? -- 5.7.9

Kerosine distillate........................................ 3. .. 1-- -.- 43 08 1 1

Gas oil ........... ...................... ........ . -:-. 0.6 . . 849 .- 35.2

Nonviscous lubricating distillate .............................. . 9.9 .874- .899 30. 4-25.9 50-100

Medium lubricating distillate ............................ ........ 3.9 .899-.908 25..9-24.3 100-200

Viscous lubricating distillate . ................................... Above 200

Residuum ............................................... 29. 1 1 -.2. .988 98.. 1 -.7

D istillation loss ......................................... . 2 , 5
31

Bureau of Mines L-----aramie ---........... Laboratory

Sample -- PC-.66--66-----....

IDENTIFICATION

McArthur River field

Hemlock conglomerate-Tertiary

9,486-9,600 feet

tti-m 6

Alaska

Seward Meridian

NW1/4NW1/4, sec. 19,

T 9 N, R 13 W

Pour point, ° F., --- ... 5..............5.......

Color, brownish black

Nitrogen, percent, Q.-142------

GENERAL CHARACTERISTICS

Gravity, specific, 0.-862 Gravity, ° API, .32.7 .....-. ..........

Sulfur, percent, -_..----- 9

9 . ......

Viscosity, Saybolt Universal at lOF.-.45_-_seca.t..7.7.F.5 e.....

DISTILLATION, BUREAU OF MINES ROUTINE METHOD1

STAGE 1-Distillation at atmospheric pressure ------ 7----. mm. Hg

First drop, -. 8-8--- - F.

Fraction Cut I Refractive S. U. Cloud t Percelnt pte. 60P600 F 600 F. Caidex0i n dispersion visc, test, at 0.0 1000 F.

I ...... 122 -2. 1 2.1 0.704 69.5-----

2 ...... 167 -1.5 3.6 .679 .76.9 - 12--- 1^38645- 123.1---

3...... 212 4.0 7.6 .719 - 65,3 - 21 ...... 1.40044- 124.+6---

4...... 257 6.1 13.7 .,742 -- 592 1-23----- 1.41160- 1265--

5...... 302 43 18.0 ,758 55-2 . 23 1420716-131-5 ----

6 .... 347 4.7 22.7 I . 773 -- 51,6 23 --- 142910 -- 134-1 -----

7 ...... 392 - 4.5 27.2 789 - 47.8 24 1.43748 137.2

8 ...... 437 4.7 31.9 1 .807 i 43.8 27 1.44707 137.1

9 ..... 482 .0 36.9 ' .823 . 40.4 30 -- -1.45636 144.-5

10 ...... 527 6.9 43.8 .839 37,.2 _ 32 1..46556 153,0 ____

STAGEI 2-Distillation continued at 40 mm. Hg

1 ...... 392 4..2 48.0 , .857 . 33.6 1..37 - 147536- 1565 - 38 -- 5-

12 ...... 437 -. 6,0. ' 54.0 J .864 -32.3 37 - 1.47956 168-.1-- 44 - 20

13 . 482 4.9 58.9 .877 29,9 39 1.48682 1.62,A- 54 35

14 ...... 527 5.5 64.4 .900 2 5.7 1 47 75 - 65

15 572 6.1 70.5 I .924 - -21.6 55 - - - - |---------------135 - Q

Residuum. . . . . . . .. 27.6 98.1 ,.989 11.6

Carbon residue, Conradson: Residuum, _15. 1,pcent; crude, 4-.8 percent.

APPROXIMATE SUMMARY

_ Percent Sp. gr. ° API Viscosity

Light gasoline .. . . . . . . . . . ... . ..... ................. . 1 - 7_6 -- -- 0.7_07 _- 68 .6 .-.- Tgn_ _-]_ . _]_____.._ _.... . -27-.7--....- 8-- 

Total gasoline and naphtha . . . . . ............... .. . . . . . . . ............ 748 57.

Kerosine distillate .......................... .. . . ... 7 15 42.. 1

Gas oil .... ........................................... 7. .853 - 34.4

Nonviscous lubricating distillate ............ .... . ....... ............. ............. 9 50-100

Medium lubricating distillate ...................... ....... . .. 6.5 .. 910- t.93 7 24 _ ° 0-19..5, _ _ 100-200

Viscous lubricating distillate .................. ............... ... -- -.. ---......---- - - -- -- Above 200

R esiduum ............................... ............... . ... 276 989 - 1 .6

D istillation loss ..... ... . ..... ............ ... ........ . 1. 9
32

Bureau of Mines ..... La.ramie Laboratory

Sample -- PC- 667 -6..................

IDENTIFICATION

McArthur River field

Hemlock conglomerate-Tertiary

10,660-10,857 feet

Item 7

Alaska

Seward Meridian

SE1/4SE1/4, sec. 18,

T 8 N, R 13 W

Pour point, o F., ........ 20....

Color, _brown.i-sh. black..............

Nitrogen, percent, 0.. 32...... _2

GENERAL CHARACTERISTICS

Gravity, specific, 0.854...... Gravity, ° API, .... 34.2

Sulfur, percent, -- .-----.-- 08-

Viscosity, Saybolt Universal at l o --F--_.3-7__sec.;...7..7.°F.L._4.9..sec

DISTILLATION, BUREAU OF MINES ROUTINE METHOD

STAGE 1-Distillation at atmospheric pressure, 76__0 .-- mm. Hg

First drop, _84 -... F.

Cut q Refractive S. U. Cloud Fraction sum, Sp. gr., A tAPI, C a pecific No. te. percent p 60/60 F. 600 F. Sndex, loF. tn. at 200 C. d r0 F. F.

1 ...... 122 2.1 2.1 0. 716 66.1 -

2...... .. 167 -2.3 4.4 .672 -- 79...1.. 8.4 1. 38011 120.1'

3...... .. 212 -- 44 - 8.-8 .717 - - 65. 9 20 1. 39816 127.2

4 ...... 257 6.0 14.8 .742 59.2 23 1.41166 127.4

5 302 5.2 260.0 .758 ....... .... 552 23 1.42088 1285 ...... 32 ---- --------------------........... -------------------- 5.2-------- 1.42088 --- 128.5....

6 ...... 347 5.0 25.0 .775 51.1 24 1.43041 133.3

7...... 392 4!- ----------- 29.4 -..... ----- .. .791 ~ :4. 47.4 ---7---------- 2--........-i------6 25 1.43906 .. 134.9 g--9------------

8.... .... 437 361 -4.7 .809 ---- 43.4 28 1.44801 137. 5

9...... .. 482 5.2 39.3 .824 40.2 30 1.45717 145.6

10 ........ 527 6.7 46.0 .839 ------ 37. -----2 32 1.46598 154.,5 ......

STAGE 2-Distillation continued at 40 mm. Hg

11 ...... 392 - 2.6 48.6 .860 33.0 38 1.47587 153.9 37 below 5

12. 437 5-1 53-.!7 .862 32.7 - 36 1. 47824 157.6 -- 43 - - ----

13 ..... 482 5.3 1 59.0 .872 30.8 37 1.48431 161.4 51 -- -35---

14 ...... 527 5. 1 64.1 .891 27.3 43 68 55

15 ...... 572 5.2 69.3 .911 23.8 49 -! 110 75

Residuum. . ....... 286 - 97.9 .977 13.3

Carbon residue, Conradson: Residuum, 1-3 1 percent; crude, .4._:2__ percent.

APPROXIMATE SUMMARY

Percent Sp. gr. ° API Viscosity

Light gasoline ....... . . . . . . .. . . . .. ..... . ... .--- .. . 8 8. - 0, .5 69 ------...

Total gasoline and naphtha .......... ...... ........ , , , , ....... , 57-!.. ' ----

Kerosine distillate ........... .. ......... ... .. 9. 817 ..... 41. 7

Gas oil ............................... .... 16 6 ........ - ° .853 ...... 34---

Nonviscous lubricating distillate ........................ . . . . 870-. 7l. 905_ °0 3.1..1-24. 9 50-100

Medium lubricating distillate ..............................-..... 4, 5 - - 2 2-4--9-- _ - -22- 1 100-200

Viscous lubricating distillate ................. .. .... ........ .. , .........------.......... ! - ........... Above 200

Residuum ........ .............................. ........- 28 .6 ........ 97_7 ......... 13.3......

Distillation loss .... ........ .. ............................ 2.1
33

Bureau of Mines -Larami-e .------- Laboratory

Sample -- PC 7.0300_ -3..._0.0 .

Item 8 IDENTIFICATION

McArthur River field

Tyonek Conglomerate-Tertiary

11,349 feet (approximate)

Alaska

Seward Meridian

SW1/4NW1/4, sec 33,

T 9 N, R 13 W GENERAL CHARACTERISTICS

Gravity, specific s __Q.860 Gravity, ...... _--- API, - 33.0 ........... Pour point, ° F., -35.........................

Sulfur, percent, -.---- 11-.- --- - Color, _gxreen ish black....................

Viscosity, Saybolt Universal atl1 0 0 F, 47 sec; at 77 F, 60 sec. Nitrogen, percent, 0. 149

DISTILLATION, BUREAU OF MINES ROUTINE METHOD

STAGE 1-Distillation at atmospheric pressure, _760 ---...... mm. Hg

First drop, .- 91 °--- F.

Fraction Cut I I Sum, Sp. r., ° API. R SU.Cloud

ten p. index, Spcii visc test, No. |teP- F. Percent percent 60/60° F. 60 F. n. at 20° C. dispersion 100° F. o F.

1 ...... 122 -- o 8 0.8 , ......

2 ..... I167 1.5 2.3 0.686 74.8 15 1.38728 127.7

3 ...... 212 4.21 6.5 .721 64.8 22 1.40236 125.5

4 ...... 257 6.5 

--- si -- -- i§0.... 13.0 -- -- -- -- -- .740 -- .... -.--- - ... 59.7 2--2- --- -- -- 22 -- -- 1.41065 ~---- -- --- 6-----.......---- 130.88-

5...... 302 5.0 18.0 .758_ 55.2, 23 1.41989 133.8

6 ...... 347 5.1 23.1 .773 51. 6 23 1.42853 133.9

7 ...... 392 -- 4.5 - 276 ,790 47.6 25 .43720 135.5

8 ...... 437 5.6- 33.2 .809 43.4 28 1.44685 138.8

9 ...... 482 - 4 .- 37.6 .824 40.2 - 30 1.45582 143.9

10 ..... 527 7.0 44.6 _ .... _837 -- 37.6 32 .... 1.46392 152.3

STAGE 2-Distillation continued at 40 mm. Hg

11 ...... 392 3.0 47,6 .6 .8511- 34.8 34 1.47406 153.5 38 10

12 437 6.0 53.6 .862 32.7 36 1.47768 156.8 43 30 .4 3 .. 51~.21 .. 7 587.8 - .... - 30 . 37 --- 48400 -873 .. . ..... -5828 ---- 13 ...... 482 5.2 58--------;---0- - --- --------- ----------- --- -- .. 8 52 50

14 ...... 527 5.0l, 63.8 .887 28.0 41 6 69 70

15 ...... 572 8.1 71.9 .904 25.0 46 110 95

Residuum. ......--. 26.4 98, | .982 12-.6

Carbon residue, Conradson: Residuum, -3 -. 6 percent; crude, 1 . 1 percent.

APPROXIMATE SUMMARY

____ _ Percent Sp. gr. 0 API Viscosity

Light gasoline and naptha.............. ................ ..... ...... .2 6. ----... .. - .68.. ........ 

Kerosine distillate .8..................................... . . . - 10_ 0 .816 , - -- 41.,9--

Gas oil . .................................................... 174 .850 35.0

Nonviscous lubricating distillate ............................. . . 1. .- .-00- -1 _8_7 - --- 25 .7 50-100

Medium lubricating distillate ..................... ................. ... 5.6 .900-.915 25.7-23.1 100-200

Viscous lubricating distillate ............. . . ............... .. ..... ..... Above 200

Residuum ......................... ...... 4 .982 12.626............ 

D istillation loss .......................................... . - -- . 7 -!
34

Bureau of Mines .--.. a-ra.ie .........---------- Laboratory

Sample ---.-- C _.70-0-3-0. -- _.........

IDENTIFICATION

McArthur River field

West Foreland sandstone - Tertiary

11,350 feet (approximate)

Item 9

Alaska

Seward Meridian

SW1/4NWl/4, sec 33,

T 9 N, R 13 W

Pour point, F. below 5

Color brownish black

Nitrogen, percent, 0---86 ....--

GENERAL CHARACTERISTICS

Gravity, specific, 0--Q.3.......---- Gravity, ° API, 36--...--30 ----

Sulfur, percent, .15 ------

Viscosity, Saybolt Universal at iQf 5_9.. seca-t.7.°F -... 67 -- sec..

DISTILLATION, BUREAU OF MINES ROUTINE METHOD

STAGE 1-Distillation at atmospheric pressure, F . 76_0-

First drop, -- 1.29...... 0 F.

mm. Hg

Fraction Cut - S , , ( ° AP I I Refractive . , S. U. Cloud No. te Percet Sum, Sp . gr, 0. P . ldeI , Specific S . Clod

No . P ercen prt 60/60 , . 60° F. i. de x

, di io tes F. percent / . F0. n, at 20 ' C. dspersion 1000 F. 0 F.

I ...... 122- 22 .. -... .. ----- ..... ... 

2...... . .. 167 -.- 1 .3 1 .3 0. 676 7 7.78 ___ 138441 128.1

3.... .. 212 5. 4 6.7 . 723 64.2 23 1.40146 134.5

4 ...... 257 4.1 110.8 .744 , 58.724 1.41236 127.3

5..... 302 4 15.5 7--------58.. 55.2. 23 1.41978 130.5 .

6 ...... . .347 . 5.0 !20.5 .. 7.... -79 50.1 26 . 1.43161 132.8

7...... 392 -4_ .-- 25.9 . 798 458 .45.8 -29 .. 1.44147 135.0

8.... .. . 437 3. Z8 29.7 .817 417 32 1. 45152 142_.7

9 ...... 482 -- 5.3. '35~0 --- - ...- 831.... 38.8 ... 33 1.45996 145o2

10 ...... 527 ... 6.8- h 41.8 -- -.. 844-- 62 36.`2 35 .1..46831 153.4__

STAGE 2-Distillation continued at 40 mm. Hg

11 ...... 392 ...1...6 --. 43_4 _ . -27 .. 8462 3i2. 39 1. 47834 157.0 41 10

12 ...... 437 -4.4- . 4_31.5 47.8 .868 .. 38 1.48075 160.1 44 15

13 ....... 482 5 8 I5 ..... ...... 87 1- _- ----7 - ..-- 40 1- .... 48717 1.-62.. 4 - 57 450 

14 .... 527 -.--- . .. 58 ..... .. ... 2 4 2 .. .. .......................... 3 ....... ... 6.. 0

15 ...... 572 6.1 .6. 6 90 I 252 46 - 1 25 -24-25 70

Residuum. ........ 31.0 ..- 95.. 6 1-002 9.7...________________

Carbon residue, Conradson: Residuum, .19. 1 p-rcent; crude, -- 6 8 percent.

APPROXIMATE SUMMARY

__Percent Sp. gr. ° API Viscosity

Light gasoline ... ..................................... --. _ _7. 0..- 1-- 4 66 .... -

Total gasoline and naphtha ........................................................ 259. ... 757. .. 55.4

Kerosine distillate ......................... .............. ..... 8 ....-..- 817..... -1 _4-1-7...-

Gas oil ............................................. 18.3 - .. ..... 8--48- -- 35.4 --

Nonviscous lubricating distillate .................... 0.8 - .873-896 30.6--2-6.4 50-100

Medium lubricating distillate ................. . ....... . 5-8 -896-.911- 26f-4-23-.8 100-200

Viscous lubricating distillate ............................................ ---- .................. ----.-- - Above 200

Residuum .......... .............................. .. .. 310 -1 ,002..- 9. 7....

Distillation loss ................... ....... ....... ..... ,____
35

Bureau of Mines --- I

Sample -- 1

IDE

Middle Ground Shoal field

Middle Ground Shoal conglomerate-Tertiary

(Tyonek formation)

8,400-8,865 feet

GENERA

Larami e

?C-65 -1

ENTIFICATION

L CHARACTERISTICS

Laboratory

Item 10

Alaska

Seward Meridian

SWl/4NW1/4, sec. 31,

T 9 N, R 12 W

Gravity, specific, -

Sulfur, percent, -

Viscosity, Saybolt

0.856

.06

Universal at

Gravity, ° API, 33.8 Pour point, ° F., _below 5......

Color, greenish black

10 ....-- Nitrogen, percent, --0_.124--- 0 F_,_ 44 - sec

DISTILLATION, BUREAU OF MINES ROUTINE METHOD

STAGE 1-Distillation at atmospheric pre.ssure, ----- 7-60_. . mm. Hg

First drop, 79. ...-- ° F. ton Sm SpgRefractive S. U. Cloud

Fraction Sum, S p. gr., API, C. I. index Scific vis test, rNo. Ctemp. Percent perentccF..F. F. ercent 60/60at d 20 C. dispersion 10F. F. 12 - - - .8 - - - - --- D _ -2 - - - - - - - - - - - - - - - - -

I ...... 1 18 656 84.2

2 ......... 167 2.6 4.4 .685 _ 75.1 15 1.38502 129--.2

3 ......... 212. - 5- 7 -10 ..- 727 ...... 6- 3. 1 125 1.40325 127 .2

4 ...... 257 . - 5.6 _ 15.7 . .-7.46 . 58.2 25-- .14137 1 132.1-.

5 ...... .302 5.4 21.1 ..763- 54.0- 25--- ----- 1.4237.2 -136;0;-.-

6 .... 347 5...347 5.2 26 .3 - .2779 5-0.1 26.----- 1-/43235 - 136 .0

...... 392 5.0 31.3 46.5 27 1 .44141 137

8 ...... 437 4 -4. 35.7 813 426 30 1.45081 139.7

9 ...... 482 5.8 41.5 .829 39_.2 32 1 .46023 148 08

10 ...... 527 8.0 4.9 .5 .845 -. 36.0 - 35 1. 46988 -156.4

STAGE 2-Distillation continued at 40 mm. Hg

11 ...... 392 1.8 I 51.3 864 32.3 40 1.47768 157 .7 39 5

12 ..... 437 6. 2 57.5 .866 31.9 37 1.48059 160.4 44 20

13 ..... 482 7.0 | 64.5 .880 29.3 41 1.48877 1763.0 -40

14 ...... 527 3'- 8 68.3- , . 900 25 .7 - 47 82 60

15 ...... 572 4 .8 73.1 - ,,..9-12- i 23-7 . 50i -- - - - -------------- , ----- 135.-- 6. 5 -

Residuum. ...... .253 .... _98.4 -- - .985 . 12.2 1 __

Carbon residue, Conradson: Residuum,1 3 .7 ppereent; crude, 4,_Q. percent.

APPROXIMATE SUMMARY

Percent Sp. gr. ° API Viscosity

Light gasoline ....................... . ... -- . 10.. -0.70Q3 Q. 69_ 8_

Total gasoline and naphtha ........................................ 48 .... 577

Kerosine distillate ..................... ........... . ----. 4.4 . 813 - 42.6

Gas oil ...........................................................-- 22.1 849 - 35.,2

Nonviscous lubricating distillate .............................. - -- 10.0- -873--.905- -3Q-,. -24-.9 50-100

Medium lubricating distillate ................................................ 5 .3 .9Q5--.918 2-4..-22-6 100-200

Viscous lubricating distillate . ............................... . --.-..-- - --- ---- Above 200

Residuum .......... .................. 25. t3 . .985 - 12.2

Distillation loss . . . ... ...... ............ 1 .6-__ _
36

Bureau of Mines --- Laramie_...____.___....... Laboratory

Sample --- E1-65-49.................

Item 11

IDENTIFICATION

Middle Ground Shoal field

Hemlock conglomerate-Tertiary

7,483-8,177 feet

Alaska

Seward Meridian

SE1/4NW1/4, sec. 1,

T 8 N, R 13 W

GENERAL CHARACTERISTICS

Gravity, specific, __0-.85_0 .---

Sulfur, percent, - ..... 05----.-

Viscosity, Saybolt Universal at

Gravity, ° API, 35 -----............------------ Pour point, ° F., _below .5..................

Color, _greenish .black..................

.-.- l-Q0°F, ..4._0 sec. ... ................ Nitrogen, percent, .... 1.15................

DISTILLATION, BUREAU OF MINES ROUTINE METHOD

STAGE 1-Distillation at atmospheric pressure, 760...... mm. Hg

First drop , 84 ....... F.

Fraction ut API, Sp Refractivet u m ° ecific . Cloud N tnip rce percent 60/60 F. 600 F. C. 1 . index, spei vise., testF o. . P ercent u r. n at 20° C. dispersion 100c o F.

1 ...... 122 -- 17---1.7 , 650-- 86.2 -

2 .. 167 2.4 41 675 78.1 -------9.8 -1.38282 ... 121.6....

3 ...... 212 5.0 9.1 - 72-2 64.5 22 1.40134 124.4

4 ...... 257 6,0 15.1 .745 -- 58.4 24 -- 1.41231 131.0

5 ...... 302 - 5,2 .-.- 20,3 . ,761 54.,4 24 1.42198 134.5

6 ...... 347 -- 5-.1 25.4 - .777 --- 50..6 25 - -1.43109 136..9

7 ...... 392 --.. 4._8 30.2- -i -. 794 .- -46 . 7 .. 27- -1.43962 138.2

8 .... ..... 437 4 . .- - .- .8----- 85-- 2 - 42..8 -- -- 3-0-3 .1,44955 140.- .8 ...... ... 482 5.5 --- -40-7- --.8297- 29 ---3-9----.2-- -- 32 1. 45953-- 151.4

10 ...... 527 -_65 - 47.2. - .-- 844 --- 36.2 -- --- 35 -- -1..46.904- -15-88

STAGE 2-Distillation continued at 40 mm. Hg

11 ...... 392 3- ! 2 50.4 - .861 - 32.,8 - 39 1,47793 162.0 38 5

12 ...... 437 -5.8 - 56-.2 -.- 867--- --31.7-- , - 3- 8 - -1,48090-. 162,7-- ... 43 ..........20

13 ..... 482 -- 63- 62.5 .8-8-0- - 29- 3 2- 41 -- -1.48832 -- 166, 9- 54 ......--- 50........

14 ...... 527 --5. 67.5 .898 26.1 46 74 65

15 ...... 572 4.9 724 908 24.3 48 130 80

Residuum. ........ 25.. ..... -975 ..983. _12,5 5 - _ 

Carbon residue, Conradson: Residuum, 120- percent; crude, . 3.-5 percent.

APPROXIMATE SUMMARY

Percent Sp. gr. 0 API Viscosity

Light gasoline ............................... ..........-... ..... 0 1~ 2.- 8-----. _8 ......

Total gasoline and naphtha ......................... ........ . 30 2 .------ _ 746 --- .-- 58. 2-

Kerosine distillate ........................................ ........... ......- 5 5 . _ 81.2 ------ 42 _8......

Gas oil .......................................... .... . 216 .... 850 -------- 35 --

Nonviscous lubricating distillate ................ .............. 10.5 t874-. 8 903 3034.4-25,2 50-100

Medium lubricating distillate ............. ........... . 5.1 _ 9Q03- .913-. 2,25.2-23.5 100-200

Viscous lubricating distillate ............................ .- ..... --- - - --.-- -- ---- ---- Above 200

Residuum .............................................. _25 1 ------ 9 3 -- ---.. 1.2 5 ....

Distillation loss ...................................................... 2 ______ 
37

Bureau of Mines -_La.ramie Laboratory

Sample .. P.C-69 -27_8________-__

IDENTIFICATION

Redoubt Shoal Field

Hemlock Conglomerate - Tertiary

10,000 Feet (approximate)

GENERAL CHARACTERISTICS

Gravity, specific, 0.889 Gravity, ° API, .27 7 ............

Sulfur, percent, 2 2 ....... 2

Viscosity, Saybolt Universal at 1_0._0_ _, _100 -.. _..at 13Q°E_.6sec

Item 12

Alaska

Seward Meridian

NW1/4, sec 19,

T7N, R13W

Pour point, ° F., -------.....10..................

Color, __brownish black

Nitrogen, percent, .0-.211.--.....--

DISTILLATION, BUREAU OF MINES ROUTINE METHOD

STAGE 1--Distillation at atmospheric pressure, -- 70 -.-.- mm. Hg

First drop, -- 88--- ° F.

Fraction Cut Sp. API, RSum, gr., efractive Spe S. U. Cloud

temp. Percent C.S0. index, vise., test, F. percent 60/60° F. 60° F. C . 2 dI, ispersion 100 F. F

...... 122 0.9 0. 9 0 .890 27.5

2 ...... 167 3-.3.. 4.2 .738 60.2 -- -40----- 1.42117- 145- .6 3 ..... 212 -4,4 . .8,6 -. 739 60Q,0 -- 30 --P 1.40853 -128-.Q

4 ...... 257 -2 _,9_ i 1.15-5 -. 7-60 .5427 - 31... 1.41943- .127-.8-

5 ...... 302 __2,9 9 14.4 -766 -.. -- 532 --- 27 .-- 1 1-.423Q8- 1.31.5-

6 ...... 347 3.-4 !17. ,776 -- o- 24 1.-43001- .134..6

7 ...... 392 3-5..5--- 21,.3 ..793- - 46.9 - -26 1. 43867-- _135-.2

8 ...... 437 _3_,_4 24.7 ._810 ... 43.2- -. 29-- 1.44718.- -139-.3-

9 ...... 482 -- 4.3 2-9-0- .8Z5-- -4Q ----- 31 145652 -144.6 - 10 ...... 527 6.4 35.4 .840.... 37.0 1 33 1.46566 152.4

STAGE 2-Distillation continued at 40 mm. Hg

11 ...... 392 - 2,.4 . 37.8 -,863 . - .325 l !40 -_..-. 147690- 4.1-- -39.-- -belw __5_

12 ...... 437 -. 5-.4- 43 .2 I .8-66- - 3.1, 9 ... 7 --- 1.48Q4- 151.... - 44 - --. 25---

13 ...... 482 . 5.1- 148,3 -- ,87.9 . ..-.Z9.5 .- - -. 40 --- 1.48727- -165-.2-- -- 53 .-.45--.-

14 ...... 527 I 5_.5- 53 .8. - .-89-9 ----. -. 5-9--_ .-- 47-- ---.- 7- .6---.-------77- -5

15 ...... 572 . 5.1 58o9 .-9-09-- -4.2--- -- 48-- -- 145-- -- 85

Residuum. ....... -37 5 .--1-9-6-4- .. .. 005 -. 3 ---- -- ---------- 1

Carbon residue, Conradson: Residuum, _1.9.8 percent; crude, ___8.4 percent.

APPROXIMATE SUMMARY

_ Percent Sp. gr. o API Viscosity

Light gasoline . ... .... ........... . ... .... ............. ,_ 8.6 -_ - Q 0 754 .- - - 56.2.---

Total gasoline and naphtha .................. . . . .... ... .. ... . . ... -6 _. 7. 6-6, 5 3

Kerosine distillate ............. ........................... !- 7 7 - ..818 41 .5

Gas oil ....................... ......... ......... .. . - ..14 .8 .-,856-- 338 --

Nonviscous lubricating distillate ..... ......................... i . .0 .-875- .903 30.2- _25 .2 50-100

Medium lubricating distillate ... ..................... ....... 6.1 -. .903-- .914_ 25_.2-23_.3 100-200

Viscous lubricating distillate ...................... ... ..... ... . Above 200

Residuum . .................................... .......... 37 .5-- . .005 9.

D istillation loss ............ . . ......................... 3 - .6 -
38

Bureau of Mines Laramie Laboratory

Sample P.....C-58-3-52-.]:-----

Item 13 IDENTIFICATION

Swanson River field

Hemlock conglomerate-Tertiary

11,000 feet (approximate)

Alaska

Seward Meridian

SWl/4SE1/4, sec. 10,

T 8 N, R 9 W GENERAL CHARACTERISTICS

Gravity, specific, .878 Gravity, ° API, 297 Pour point, F., below 5

Sulfur, percent, _0*l6.. . Color, ..-... brgwnish._ black........... Sulfurpercen --------------------------------------- Colr-broni-hblac Viscosity, Saybolt Universal at -.-lQQ°.F,.Sec;a.. 7.7°FF,..l. secNitrogen, percent, _.0203 ................

DISTILLATION, BUREAU OF MINES ROUTINE METHOD

STAGE 1-Distillation at atmospheric pressure, ----- 60..... mm. Hg

First drop 7-9- ° F.

Fai Cut Sum S Refractive Specific S. U. Cloud

No tem . P in. dex ispein test, No. o F. percent 60/60 1F. 60° F. nI at 20° C. dispersion 00 .o sF.

2 ...... 167 2.9 It. 8 .697 71.5 20 1.38618 126.4

3...... 212 2.9 7.7 .725 63.7 214 1i.40248 126.5

4 257 ...... 2 12.9 .737 - 60.5 - 20 -- l.4102- 128.8

5 ...... 302 6.0 18.9 .756 I 55;-7 2--. 1--4392- 130.1

6 . .. . 347 45 23. 77 ...... ....... 23 .. L.. 2893 133. 3... .

7 ...... . .392 4.O 27.4 .,790 __ 47.6__ 25 -- 1.3788 138.5

8 ... 437 4.3 31.7 .807 43.8 27 1l.4h685 l.2

9...... 482 48.8 36.5 .822 40.6- 29 1 45673 1 i9.3

10 ...... 527 6.7 3.2 - .837 -- -37.6- 32 . l67i5 156o4 _

STAGE 2-Distillation continued at 40 mm. Hg

11...... 392 - 32 ! 46 -8-- . .........3 7. .7582 ... 158. 3 .. 39 10

12 ... 437 .5o9 i 52.3 _.864 32.3 - 37 1.08024 162.4 - 5 20

13 ...... 482 53 576 .878 9...... 7 -......... O 1 ,87-57 161.....8 56 -.... I-- 45 ....

14 ..... 5 6 2-7 ... | f...2 .. 251.7 47 .- I---- ..890 8.3 65....

15 ..... 572 6 . - 1 68,6 ._ 912 29 50 . ....................... 8

Residunm. Residuum. i ...... __-_lo..__lQ . 6 .. 7,8......8;.....!_......... __.........I........ ........ 31L.4 -- 1000 -Q L016 1 7-8 --

Carbon residue, Conradson: Residuum, 22.3 percent; crude, __8_1-. percent.

APPROXIMATE SUMMARY

Percent Sp. gr. ° API Viscosity

Light gasoline . .................... ...... -. - ............ . ........... 

Total gasoline and naphtha....................... ...... . . . .-- .._ _ _ __ ._ *-:____- 2__~

Kerosine distillate . . . . . . . . ..................................... 9 9.1 . . .. .8----2.1

Gas oil ........ ................... .......................... 6.......

Nonviscous lubricating distillate ....... ....................... . | .... .... ... 93. --- - .1- .?903 50-100

Medium lubricating distillate ............ ..................... .. .903-.919 ... 7 .... 25.2?-22.5 100-200

Viscous lubricating distillate ............ ................ .... Above 200

Residuum ................. ................. .. 1 .... .. .. - . I ....

D istillation loss .... .. .................................... .. 0...
39

Light gasoline ........... . . .. . _ . _ . . . ....

Total gasoline and naphtha .................................

K erosine distillate ...................... .................

Gas . oil . .. . . .. . . . . . ........ . . . . . . . . . . . . . . . . . . . . . ......

Nonviscous lubricating distillate ......... ................ .....

Medium lubricating distillate ................... .............

Viscous lubricating distillate ................... . ........ ..

Residuum ..... ............................ .........

D istillation loss ................................ . ........

Bureau of Mines --.. L.aramie ---..--.-... Laboratory

Sample -- PC.- 6 5.-72.................. Item 14

IDENTIFICATION

Swanson River field (Soldotna Creek)

Hemlock conglomerate-Tertiary

10,900 feet (approximate)

GENERAL CHARACTERISTICS

Alaska

Seward Meridian

SE1/4SE1/4, sec. 33,

T 8 N, R 9 W

Gravity, specific, -

Sulfur, percent, -

Viscosity, Saybolt

.--U -05-- .......a

Universal at ._

Gravity, o API,

10_o.F._46 _see ......

_33.8. Pour ........-- point, ° F., 10....................... ---

Color, ___greenish black

.........------ .Nitrogen, percent, _0..a .33.....1.

DISTILLATION, BUREAU OF MINES ROUTINE METHOD

STAGE 1-Distillation at atmospheric pressure -,--- 760 - mm. Hg

First drop, -84 ... ° F.

Fraction Cut Sum, Sp. gr., API, Rfc Refractive Se U. Cloud o 

No temp. Percent 6p. F. 6 A C. I. index, vise., test, tep. Percent 60/60° F. 60° F. -- nat dispersion 1000SF. 0 F

1 ...... 122 -- 2,3 -_ Z3 .69... - ---- -

2 ...... 167 3,6- .- 5..9 .... 6-87 - 74.5 16- . 1. 3853.2 _127- ...-

3 ...... 212 62 2.5 --.. 730 62. 3 --- -26 - 1.-40408 __123.7---

4 ...... 257 -4.1 4 i_ 16.6 _.-749.. 57.4 - - 26 L.-414 -L2.6-.2-- l_94 

5 ...... 302 .- 44. 4 _ i 2! 1.0 Q _.. 761 .544 4 -.-- - 24 --- .142 169 -- 1L32-.-9---

6 ...... 347 -- _4.9 25-.9 _,7_76 509 ----. 24 -- 1._43018 ..1330 0--.

7 ...... 392 4.4 30.3 .792 47.2 26 1.43828 136.0

8 ...... 437 5.3 35.6 809 43.4 28 1.44762 140.4

9..... 482 4t 9 _ 40.5 .826 39.8 31 1.45776 146.7

10 ...... 527 i 7.1 47.6 1- [.842 . 36_,.6 --- -- j.34 1,46672 .. 155.5 ----

STAGE 2-Distillation continued at 40 mm. Hg

11 ...... 392 -19.-3- -- 4-8-.9 .....8.62 .... 32.-.7- 39 .-- [1.47536. 156.Z7.-- -- 41-- -1Q.......

12 ...... 437 .6.Q0-_ -..54_.9 .... _8_64_ - 32.3- 37- 1. 47819- .- 159-.1 -... 43--- -- 25...

13 ...... 482 _ 51- - -6.0..-0..- -874 - - -3-0-.4- . . -38 - 1.48451 ... 159-,9 - 5..- -- 53 -- -5Q.--

14 ....... 527 -.4.6- -- 64_.6 .- .8.92 . -2..1. ..- --- 3 4 --- ---- --- .74.--- -- 65..--

15 ...... 572 -53- 699. .903 25.2 46- - -- 120 - -80..

Residuum. ....... ... 27.8 -i _97.7 ... 993 1.1-0 ---. ________ ________

Carbon residue, Conradson: Residuum, _1-2,4 percent; crude, -4-. 0- percent.

APPROXIMATE SUMMARY

Percent

-. 12,5--

.30 ..3

5.3 - .

[ 20.1. ...

! .9.4

I- 4.8

l 27.8

2.3

Sp. gr.

-i...745...80 -...

-. 848 --.

.871-.-898

.898-. 909

I - _

° API

67.-8

.58.4 .~=

43..4 3. 3-5.4--

-31. a Q-26-J

26.-1-24.2

11.0O

Viscosity

50-100

100-200

Above 200
40

Bureau of Mines a..ie La.....i .. Laboratory

Sample --- PC-65-73

IDENTIFICATION

Swanson River field

Hemlock conglomerate-Tertiary

11,200 feet (approximate)

GENERAL CHARACTERISTICS

Gravity, specific, __0.875 .. .... Gravity, 0 API, ....- 30 ...2...

Sulfur, percent, .-.. ,.--08__08 .___

Viscosity, Saybolt Universal at -lQQ°.-65-sec-at-.7F,74 .. sec.

It=m 15

Alaska

Seward Meridian

SEl/4SW1/4, sec. 15,

T 8 N, R 9 W

Pour point, ° F. 15-- -----..

Color, ---- greenish--black ..... ......

Nitrogen, percent, Q0 1 .i------..

DISTILLATION, BUREAU OF MINES ROUTINE METHOD

STAGE 1-Distillation at atmospheric pressure, -760 mm. Hg

First drop, -84- ° F.

Fraction Cut Refractive Specifc S.U. Cloud

No. temp. Percent Sum 60/60S F. 60 P. C. 1. index Speci vise. Ctest,d NoF. percent 60/60 F C. . dispersion v

1 ...... 122 1.5 .- 1.5 -. - 0676- -77.8 -- -------- .

2 ...... 167 -4.9- -... 6.4-- --.. 701--- 7-22-- . -- 1.39063- -125_7-

3 ...... 212 --.4_.8 11.2 -- ..7_32 -61.-8 .27- 1-40 563 -- 127.7 --

4 ...... 257 -2- .2_. 13.4- -. 748 - _57.-7 -26 1.A41442....1254

5 ...... 302 36 - 17.0- - -.. 759-... 54.9 -. 23- - 1.42065 -130.6--

6 ...... 347 -4.4-- 21.4 .7.74 -- 513 ---- 23-- 142898 -131.7--

7 ...... 392 _4.-.L_ _ 25.5-.- -79_0 -. 47.6 - . 25--- 1,43709 - -134.0

8 ...... ... 437 43... 29. 8 -. -805..- 44.3 -- -26 -- 1.44548- -1392.6

98 ......... 4.G-- - .8. 823 . -34.6 -430 . ... 1-45484- -143.2

10 ...... 527 6.3 j 40.9 . -. 837 ..... 37.-6 - 32 146360 .- 150.3

STAGE 2-Distillation continued at 40 mm. Hg

11 ...... 392 3.0 43.9 - ,858- 33.4 - 37 1.47473 155.6 40 10

12 ...... 437 6.2 50.1 .864 32.3 37 1.47865 160.3 45 25 4- __2 ~-b .... ---- - ------- 5g - ------ 6.--. -- ......... . .5 --------------- .. -------------- . .... ...~ . ...---------- ----------- 13 ...... 482 4.0 54.1 .876 30.0 39 1.48461 162.5 54 45

14 ...... 527 --- 6.1 60.2 .890 27.5 2 76 65

15 ...... 572 4 -. 5 . 64 47 - 906 24. 7 47 !- _-130 80

Residuum. ....... 2..3 9 .97 6 ..... 1,003 9 6. ...

Carbon residue, Couradson: Residuum, .19.6 percent; crude, 74 7.. percent.

APPROXIMATE SUMMARY

-- ___ Percent Sp. gr. 0 API Viscosity

Light gasoline ......... . .......... -1.... ............ 2 - -0711--- 67 5-_-

Total gasoline and naphtha ..................... ......... ...; 25 5 . ----. 745 . .. 58_. 4 --

Kerosine distillate ........................................... .9, 1_ .14 423--.3 _

Gas oil ......................... .................... 15-1 - - .8-53--- -- 34-

Nonviscous lubricating distillate ......................... ...... - 9, 7 . 871-,_897 31. 0-_26.,3 _ 50-100

Medium lubricating distillate ...................... ... ... .... | . 5.3 . 897-_.913 26,.3-23.5- 100-200

Viscous lubricating distillate ................................. - Above 200

Residuum ................................ .......... ..... 32..9 - 1,003-- '- _9._6 _

D istillation loss ........................ ........ .... .. . 2 4
41

Bureau of Mines ----- Lar.amie .--.- Laboratory

Sample ----- PC-65_-7.4.................

IDENTIFICATION

Swanson River field

Hemlock conglomerate-Tertiary

11,000 feet (approximate)

Item 16

Alaska

Seward Meridian

NE1/4NW1/4, sec. 34,

T 8 N, R 9 W

GENERAL CHARACTERISTICS

Gravity, specific, .0,.8.58.......

Sulfur, percent, --- S-05----

Viscosity, Saybolt Universal at

Gravity, ° API,. .- -. 3

-lQO _0.F_,. e----...

3.4 ......... Pour point, ° F., ............ 10..................

Color, eenishblak.................

-...-.- Nitrogen, percent, .. 133..................

DISTILLATION, BUREAU OF MINES ROUTINE METHOD

STAGE 1-Distillation at atmospheric pressure, 7.6Q mm. Hg

First drop, ------ 2 ------ F.

FSp. raction t Sp gr., API,PIactive i I S. U. Cloud

No. F. Percent percen temp. P C.. index, visc., test, t peret 60/60° F. 60° F. C. I° C. dispnion S c t

o

e

F._60__F. n. at 200 C. dispersion 1000 F. F.

1 ...... 122 2. 8 2.8 0.650 86.2

2...... 167 . 2.5 5.3 .690 73.6 17 1.38807 124.5

3...... 212 3.9 9.2 .720 - 65.0-------- 21 1.39984 126.1

4...... 257 6.1 15.3 .74101 59.5 22 1. 41018 131. 3

5...... 302 4.6 19.9 .758 55.2 23 1.42012 133.0

6...... 347 4.8 ] 24.7 .775 51.1 24 1.42955 134.6

7...... 392 --.... 43 , - 2_ .792 __9,0 47,2 26 .143844 136.2

8...... 437 4.7 4 .7 7 ,808 43_.6 28 - 1.44696 139.7

9 ...... 482 --- 5.5 - !39.2. -- , 824-- 40.2 30 1.45636 146.7

10 ...... 527 6.-_ 46.0- , 840 37,0 33 1.46635 153.8

STAGE 2-Distillation continued at 40 mm. Hg

11 ........ 392- 1,4 47.4 .859 [ 33.2 - 38 1.47437 155.9 39- 10

12 ...... 437 5.1 52.5 .862 32.7 36 1.47731 156.1 41 20

13 ...... 482 -- 5. 1 - 57- -. , 872 --... 30... 37 1.48330 160. 5 51 40

14......... . 527 -- 4.8 . 62-,4 - 894 26. 8 ......44 67 60

15 ...... 572 - 6,4 ---- 68 ,-8- .--- 915 ,......23,1 ...... 51 . ........... 110 80

Residuum. ...... 29.1 ..- -7..9 . ..992 1 -.1 l..__________________- 

Carbon residue, Conradson: Residuum, 10. 1. percent; crude, 3. !4 percent.

APPROXIMATE SUMMARY

______ Percent Sp. gr. ° API Viscosity

Light gasoline .............................. _ . * *.. 9.2 . .- _0--. _ -691 ---------- 73_._3_

Total gasoline and naphtha ................................. . -

Kerosine distillate ............. ... .. ........................... | . 41 7

Gas oil . ................................................ 158 ~0 _ -- ..- 54-- -------4.2

Nonviscous lubricating distillate ............. ..... ............. 10. - 871. -_910 31_,0-24.,9 50-100

Medium lubricating distillate ............................... .... . 9-1-0- 92 -7 - __24 0-2_1_,_1 100-200

Viscous lubricating distillate ............................. ...-- . -- Above 200

Residuum ..... . ........ ................. ........... . _ 2 _9-._1 .. .. 992 .9..... - ..... I _.-

Distillation loss .......................................... -- --_ 1 __ 
42

Bureau of Mines .. L....aramie

Sample ..... PC-6575

IDENTIFICATION

..-- Laboratory

Item 17

Alaska

Seward Meridian

NW1/4, sec. 16,

T 7 N, R 9 W

Swanson River field (Soldotna Creek)

Hemlock conglomerate-Tertiary

11,000 feet (approximate)

GENERAL CHARACTERISTICS

Gravity, specific,

Sulfur, percent, --

Viscosity, Saybolt

0. 845

Universal at

Gravity, ° API, .... 3.6._ 0

100 °F. , 40 sec.

.---.-. Pour .. point, ° F., below 5

Color - --_- greenis.h black. ------

...-....-- Nitrogen, percent, __--0 09-5...- ------

DISTILLATION, BUREAU OF MINES ROUTINE METHOD

STAGE 1--Distillation at atmospheric pressure 760...... mm. Hg

First drop, ... 8-2 ° F.

racti Cut i o i Refractive Specific S. U. Cloud

tNo. temp. Percent Sum 60/60 ° C. 1 . index, vise., te No. .perreit 60/600 F. 600 F. dispersion vise

1 122 - 2.6 27.6 _70.651 8f.L _ _ 1

2 1. 67 2 7 5.3 .6751 78.1 9.8 1.37827 122.6

3 212 5.4 10.7 ,721 64.8 22 1.40068 120.9

4 ..... 257 8,3 190 .750 57.2 27 1.42123 134.6

5 ...... 302 5.4,4 24.4 76 54.4 24 1,42198 132.1

6. . . . . . 347 - 4.9 29.3 .777. 50,6 25 .1.43064 ... 134.4.

7 ...... . 392 4. .9 34.2 .790 .. 47,6 .. 25 1,43783 - 137.8

8...... 437 _4.7 38.9 .807 ... 43-81 . 27... - -144718 .....139..8..

9 ...... 482 4.9 . 43.8 -- 82 4- _ 40..2_. 30 1.45641..-.. 145..5-

10 ...... 527 6.7 50.5 -.. 839 - 37.2 -.. 32 -- 1^46604- 153.8_

STAGE 2-Distillation continued at 40 mm. Hg

11 .. ... . 392 -,8 523__ ... .858 _33,4 ' 37 1.47437 156.1 40 10

12...... 437 5.5 57.8 , 861 32.8 35 1.4768Q 157.4 42 20

13...... 482 6.0 63.8 .. ,8 873 ..... 30,6 37 148390 161 .........

14. ..... 527 .4.3 68,1 .892 27.1 43 .... 70 ..... 65.

15 .. . . 572 5.1 - 73.2., , 908 .- 24..3 48 .... -i ---- ..... 115- 8.....0...

Residuum. ...... ... 24.-8 . 9-8,0., .982 12-6___ ________________________

Carbon residue, Conradson: Residuum, _14. 9 prcent; crude, -4.-3 percent.

APPROXIMATE SUMMARY

Percent Sp. gr. ° API Viscosity

Light gasoline .. . .. .. ... 1 0 . 7 0.692 - 73t.0

Total gasoline and naphtha . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 34,2 .. 743 .--- 58.9

Kerosine distillate ........ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ........--- 9.6 -- .816...--- --- 41-

Gas oil ................................................ . .... 15. 6 - -.. 853...... 3.44 ....

Nonviscous lubricating distillate . . . . .............................. . -9.6 ..- 870-S.-Q3 .31.1-25-.2 50-100

Medium lubricating distillate .............................. . 4.2 .. 903-.917 25.2-22.8 100-200

Viscous lubricating distillate ............................... . . - ......................... - - ---- ---- Above 200

Residuum ............................................. , 24.8 . .982 ...... 12.6

D istillation loss .................... ............... ...... .
r.,

I F.

658

684

731

755

775

7951

815

833

846

858I

o API.

60o F.

75.4.

62.1

55.9

51.1

46.5

42.1

38.4

35.8

33.4

C. 1.

14

27

29

31

33

37

40

41

41

Refractive

index,

nI at 20° C.

-138214

1,40414

1.41734

1.42841

1. 43878

1.44977

1.46007

1.,46877

1.47706

43

11 ......

12 ......

13 ......

14 ......

15 ......

Residuum.

Bureau of Mines -....I La.ramnie--

Sample --.. PC-65-76

..... Laboratory

IDENTIFICATION

Trading Bay field

Middle Ground Shoal sandstone-Tertiary

(Tyonek formation)

5,363-5,444 feet

GENERAL CHARACTERISTICS

Item 18

Alaska

Seward Meridian

SW1/4NE1/4, sec. 4,

T 9 N, R 13 W

Gravity, specific, _-0.Q.1 ------ Graity, ty, API, - 31. ..0.. Pour point, o F., -.... o-- 5-------... .

Sulfur, percent, 0.....5 Color, browis.hblh__b1ck .....-------..

Viscosity, Saybolt Universal at 1q0.F,, 53 s ec, .Lat 77 F^,-66 ec. Nitrogen, percellt, - Q...... 49.........

DISTILLATION, BUREAU OF MINES ROUTINE METHOD

STAGE 1-Distillation at atmospheric pressure, -760Q .-- mm. Hg

First drop, ..---- 82. ° oF.

Specific s u . dispersion 1000

-1237-

-12 52.-

128.1l

1 1S- 1

141,Q

14ltl 141.1

147.5

154.8

161,1

Cloud

test, F.

392 -

437

482

527

572

. ..

1.5

5.0

5.6

4.7

5.7

30,5

STAGE 2-Distillation continued at 40 mm. Hg

46.9 - 8771 29.9 46 - 1.48476

51.9 .879 29.5 44 1.48692

57.5 .888 27.9 45 1.49244

62.2 .907 24.5 50

67.9 .918 - 22.6 53

98.4 .983 12.5

164.7

166.2

170.4

-- 4 ----- ----------

45 10

55 30

79 50

140 70

Carbon residue, Conradson: Residuum, 12- 5 p ,rcent; crude, 4.3 percent.

APPROXIMATE SUMMARY

P ercent Sp. gr. ° API Viscosity

Light gasoline .7 0, 707 68.6

Total gasoline and naphtla ... ................................ 5--- _- - - -__;7 .- 4_

Kerosine distillate ... .................... ....... ...

Gas oil .................................. ..... 23.4 ...-...- .. 857 .... 33 ..6 

Nonviscous lubricating distillate ................ -............ 9.7 883-. 911_ .2_8.8-2.3..8 50-100

Medium lubricating distillate ............. ........ -- - .6 . . -. 63 911-.924 - 23.-8-21-.6 100-200

Viscous lubricating distillate ......................... ....... . Above 200

Residuum ........... ........................ ......... 3. .. 983 . 12.5

Distillation loss ........ ........ ........................... . 1. 6 - I .
44

Bureau of Mines ---- La.ramie -- ------ Laboratory

Sample -.-- PC.- 67-80................

Item 19

IDENTIFICATION

Trading Bay field

Hemlock conglomerate-Tertiary

10,500 feet (approximate)

GENERAL CHARACTERISTICS

Gravity, specific, -Q.864 - .----. Gravity, ° API, 3....32-,.3......-

Sulfur, percent, -_- 11 .---.

Viscosity, Saybolt Universal at O.0 F.,._.45 sec; at 77°F ... 53..s.ec.

Alaska

Seward Meridian

SE1/4SW1/4, sec. 26,

T 10 N, R 13 W

Pour point, o F., ........ 20-.----- .

Color, ___trownish__ g..e.e.a ..---

Nitrogen, percent, -0 06 ..-------.

DISTILLATION, BUREAU OF MINES ROUTINE METHOD

STAGE 1-Distillation at atmospheric pressure, ... 76_0----.- mm. Hg

First drop, -.- 131 -° F.

Cut Refractive s.fi S.U. Cloud

raction temp. Percent ' p o, P C. '. index p vise test, No. - percent 60/60 F. 60 F. n0 at 20o C. dispersion o F.

1 ...... 122 ... . ..-.. ... .. .... ---- -- ----- -...- 

2...... 167 10 1.0 0.706 68.9 3 ..... 212 2.9 i 3.9 .- 711 67.5 17- 1.39534 126.7

4 ...... 257 5.3 9.2 .737 60.5 - ---- 20 1.40764 127.4

5 ...... 302 51 14.3 .754 56. 2 21 1.41786 129.3

6347........... 5.8 20.1 .771 52.0 22 1.42756 134.

...... 392 - 5.3 25.4 .788 48.1 24- i.43687i 136.4-

8 ....... 437 5.6 31.0 .807 43.8 27 1.4 461 138,

9 ....... 482 -- 6.1 37..-- --- .823_ .- .40-4- 4 - 30 - 1.4355-8_7 __145._5

10 ...... 527 . 7.79 45.0 .-8- 3839- _32 -2-- . - 32- 12.46582 -153.2 . __________

STAGE 2-Distillation continued at 40 mm. Hg

11....... 392 -4-,-8- -49.8-- --- .859- - -3---3.2 --- -- 38- .-47-6-13- --15Z.-0_ - -- 3-8-- --. 2.5......

12 ...... 437 , -- 6.7- ,_56 -5 - -- -^865- -32.1 -- -- 37- 1 .-4-8-003 -- --.- 157.5- -44-.3. ..... 3.5.--

13 ...... 482 -5,- 5 6_2.2 ----. 877 --- 29.9 39- 1.48757 160.2 52 --- 5.--

14 .......... 527 -. 5_3 . .5..67 -- -- 892 -27 .1- - 43- 7 -------. 5------7-3-

15 ....... 572 -6.7 -74,-2---.. --. 903 - 25-..2 -.. 46 -- - ..-..- ----- . - 9

Residuum. ....... ... 2..2 -O--- 4 - 984 12.3 .. . ___________...._____

Carbon residue, Conradson: Residuum, 1.5.8 percent; crude, -4.-7-. percent.

APPROXIMATE SUMMARY

Percent Sp. gr. 0 API Viscosity

Light gasoline .. 9 - -- - 0710 - ---- 67.,8----

Total gasoline and naphtha ........ . ........................ .. _- -. 7-5-5-- . -55.9---

Kerosine distillate ................. ............ . .. .. 11.. 7- - -- -- 5-- -- 42 1--

Gas oil ........ ........................................ .... .. -----.--- 855- -- 4 ---

Nonviscous lubricating distillate . ........................ .. -8.9....8.9 _-8-74-.-8-96 -30_-4-26,4 50-100

Medium lubricating distillate . . . ................................ .... 7-.4 .896_9909 26.4-24- 2 100-200

Viscous lubricating distillate ............ .. ..... .......... .. Above 200

Residuum .................... . . 2 , .2 I .-984 .. .1 .3

D istillation loss ... .... .... ...... ... .. ... . . .I..

u . . AO0¥R0 N Tn PRNTI5 OFFCF - IC i i-57835 -3

INT-BU.OF MINES,PGH.,PA. 17921