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-ALASKA•
HISTORICAL AND PRO.JECTED
OIL -AND GAS CONSUMPTION
PREPARED BY
THE tNSTITUTE <~OCtAL AND ECONOMIC RESEARCH
UNIVERSITY OF 'ALASKA
AND
' DIVISION OF MINERALS · AND ENERGY MANAGEMENT
DEPARTMENT OF NATURAL . RESOURCES
FOR
THE ALASKA STATE LEGISLATURE
,·
ARLIS
Alaska Resources L i~rary & T11fnrmation SerVices
. (.V. 4~1.rr-•
' "
J -, ·.
-ALASKA -
HISTORICAL AND PROJECTED
OIL AND GAS CONSUMPTION
for
Department of Natural Resources
State of.Alaska
by
Scott Goldsmith
.,
Associate Professor of Economics
Institute of Social and Economic Research
. University of Alaska
Anchorage ~ Fairbanks ~ Juneau
and
Kristina O'Connor
Energy Research Analyst
Division of Minerals and Energy Management
Department of Natural Resources
january 1981
Preface
-ALASKA -
HISTORICAL AND PROJECTED
OIL AND GAS CONSUMPTION
Table of Contents
I. Historical Oil and Gas Consumption in Alaska
A.
B.
c.
Total .••
Natural Gas •...•
Petroleum Liquids •
II. Oil and Natural Gas Consumption Projected to 2000
A. Summary . . . . . . . . . . . . . . . . . .
B. Projection Assumptions ••.•..••
C. Potential for Error in Projection
i
1
1
3
13
29
29
32
33
III. Present Oil and Gas Supply • • • • . • . • . • . • • • • . . . • • . • . • 37
IV. Surplus Oil and Gas . • • • • • • • • • • • • • . • • • • . . . . . . . . . 41
Appendix A: Data Sources A-1
Appendix B: Disposition of Royalty Oil and Gas B-1
Appendix C: Refinery and Pipeline Data ••.•••• C-1
.. _
I.
PREFACE
This study is in response toAlaska Statute, Section 38.05.183.
SALE OF ROYALTY.
(d) Oil or gas taken in kind by the state as its royalty share
may not be sold or otherwise disposed of for export from the
state until the commissioner determines that the royalty-in-
kind oil or gas is surplus to the present and projected intra-
state domestic and industrial needs. The commissioner shall
make public, in writing, the specific findings and reasons on
which his determination is based and shall, within 10 days of
the convening of a regular session of the legislature, submit
a report showing the immediate and long-range domestic and
industrial needs of the state for oil and gas and an analysis
of how these needs are to be met.
It .is the seventh in a series of reports on oil and gas consumption and
projections of future demands. The titles of previous reports are as
follows:
1. (1975) Present and Historical Demand for Oil and Gas in Alaska,
Alaska Oil Demand 1975-2000, and Future Alaskan Natural
Gas Demand by Georgia Bewley et al. Division of Geological
and Geophysical Survey, Department of Natural Resources,
State of Alaska, Fall "1975.
2. (1976) Energy Consumption in Alaska: Estimate .and Forecast by
Kent Miller and Oliver Scott Goldsmith. Institute of
Social and Economic Research. (ISER), University of Alaska,·
January 1977.
3. (1976) Historic and Projected Demand for Oil and Gas in Alaska:
1972-1995 by Kristina O'Connor. Divisiono£ Minerals and
Energy Management (DMEM).
4. (1977) Oil and Gas Consumption in Alaska 1976-2000 by Oliver Scott
Goldsmith and Tom Lane. ISER, January 1978.
5. (1978) Historic and Projected Oil and Gas Consumption by Kristina
O'Connor and Randall Montbrian. DMEM, February 1979.
6. (1979) Historic and Projected Oil and Gas Consumption by Oliver
Scott Goldsmith (ISER) and Kristina O'Connor (DMEM),
January 1980.
i
The data in each report has been presented in slightly different
format, and the sources available at the time each report was compiled
were not always similar so that differences among the historical figures
occur from time to time. In this current study, we have recalculated
two important historical data tables for the entire decade of the 1970s.
The information in the tables on motor vehicle fuel consumption and
natural gas use has been completely revised. As a result, in subsequent
years, production of this report should be greatly facilitated.
The analysis of oil and gas consumption in this stud~ is consistent
with two other efforts currently underway within the state to forecast
future energy needs. These are the following:
1. The Railbelt Electric Power Alternatives Study under
contract to Battelle Northwest Laboratories for the
Office of the Governor.
2. Long-Term Energy Plan for Alaska under contract to
Applied Economic Associates for the Division of
Energy and Power Development.
The primary integrating device utilized in all of these studies is the
Man in the Arctic Program (MAP) econometric model which provides estimates
of the level of future economic activity for the state and its various
regions.
ii
I. HISTORICAL OIL AND GAS
CONSUMPTION IN ALASKA
I.A. Total
Total use of petroleum in Alaska iri 1980 was 190.8 miHion barrels
of crude oil equivalent (BOE) or about 523 thousand BOE daily. The great
majority of this consisted of natural gas which accounted for 86 percent
of the total.
As Figure 1 indicates, reinjection of natural gas into oil fields
was the dominant use (64 percent), followed by motor yehicle fuels use
(9 percent). A·1 1
"""-'--'-other uses accounted for 27 percent of the total.
A large part of the natural gas used for reinjection will ultimately
be recovered from the field and should, thus, not be considered as con-
sumption. Adjusting for this total, consumption for 1980 is 67.7 million
BOE or 185 thousand BOE daily, of which 60 percent is natural gas and
40 percent, liquid petroleum. This is equivalent to 630 thousand mcf of
natural gas and 77 thousand barrels (3.2"million gallons) of petroleum
liquids daily.
Most of the growth in use between 1979 and 1980 can be attributable
to reinjection of natural gas, which increased by about 20 percent.
Consumption of natural gas for other uses rose less than one-half of
one percent, while consumption of liquid petroleum was up about
1 percent.
N
FIGURE 1. 1980 ESTIMATED OIL AND GAS USE IN ALASKA
Vehicle
Diesel~
2.8
(1. 5%)
Motor
Gasoline
4.3
(2.3%)
(millions of barrels of crude oil equivalent
and percentage of total use) · Gas Utili t~---~Othera 2.5 (1.3%) 4.6
Electric · (2.4%)
Ut:llity--.....__ ,
5.0 (2.6%) ~
Electric
Power
Used by
Producers--~
Space
Hea.t:y· 4.2
(2. 2%)
Generation 2.9
(1. 5%)
PETROLEUM LIQUIDS
27.2
(14.3%)
Oil
Pipe-
line
<E-Fuel
3.0
(1. 6%)
Jet
~Fuel
10.0
(5.2%)
LNG
8.7
9.7
(5.1%)
Ammonia
Urea Pro-
duction~
9.9
(5. 2%)
Cook Inlet
Reinjection
21.7
(11.4%) ,·
I ,
, ,
, ,
, , ,
. , ,
Prudhoe Bay
Reinjection
101.4
(53.1%)
R e i n j e c t i o n
(64.5%)
NATURAL GAS
163.6 (85. 7%)
aincludes military use and pipeline and power generation uses in Prudhoe Bay area .
. '
This pattern of growth is a continuation of the trend in recent
years. The use of natural gas for r~injection has been the most rapidly
growing category of use. This has been followed by growth in consumption
of natural gas attributable to an expansion of the ammonia-urea plant
on the Kenai Peninsula and consumption of both gas and fuel oil in con-
junction with production and transportation of the crude oil from the
Prudhoe Bay field. These growth trends are depicted in Tables lA and lB.
I.B. Natural Gas
Historical and 1980 estimated natural gas use is shown in Tables 2A
and 2B by market area and use. The market area distinction is important
because of the high transport cost of gas which presently precludes a
statewide market for gas.
Prudhoe Bay is the largest market, accounting for 68 percent or
627.8 million me£ of the total statewide use of 929.5 million mcf.
Almost all of this gas (92 percent)is reinjected, but a substantial
quantity is used on leases and provides fuel to the electricity generat-
ing plant connected with the field and to the first four pump stations
on the pipeline. These categories of consumption which can be loosely
termed as production and transportation related were 51.5 million me£
in 1980.
Cook Inlet is the market with the largest number and variety of
customers and accounts for virtually all of the rest of the natural gas
used in the state. Of the 300.7 million mcf expected to be used in
3
TABLE lA. ALASKA OIL AND GAS USE
(commodity units)
PETROLEUM LIQUIDS NATURAL GAS NATURAL GAS
(barrels of product) (mcf) (Net o{ Reinjection)
(mcf)
Total Daily Average Total Daily Average Total Daily Average
106 103 106 103 106 103
1970 217 594 144 395
1971 228 625 154 422
1972 223 611 147 403
1973 223 611 135 370
1974 228 625 141 386
1975 256 701 163 447
1976 24.5 67 271 743 160 438
1977 23.7 65 376 1,030 193 529
1978 26.2 72 603 1,652 217 595
1979 27.6 76 738 2,Q22 229 627
1980 (est.) 28.1 77 930 2,548 230 630
SOURCE: See later tables.
., 'I ..
,• ''
TABLE lB. ALASKA OIL AND GAS USE
(barrels of crude oil equivalents)
PETROLEUM LIQUIDS NATURAL GAS NATURAL GAS COMBINED OIL AND GAS
(Net of Reinjection) (Net of Reinjection of Gas)
Total Daily Average Total Daily Average Total Daily Averag~ Total Daily Average
106 103 106 10 3 106 103 106 10 3
1970 38 104
1971 40 110
1972 39 107
1973 39 107
1974 40 110
1975 45 123. 28 77
1976 23.8 65 48 132 28 77 51.8 142
1977 23.1 63 66 181 . 34 93 57.1 156
1978 25.3 69 106 290 38 104 63.3 173
1979 26.8 73. 130 356 40. 110 66.8 183
1980 27.2 75 164 449 41 112 68.2 187
(est.)
For conversion factors, see Tables 2B and SA, SB, and SC.
SOURCE: See later tables. ·
TOTAL USEb
COOK INLETc
Reinjection d
LNG Exports e
Ammonia Urea· Production
Electric Utility Salesg
Use on Lease,hVented,
and Shrinkage
Gas Utility Salesj
Military Sales k
Miscellaneous Sales
to Other Producers,
Refiners, and Pipelines
Item: Alaska Pipeline
Company Salesm
Item: Anchorage Natural
Gas Salesn
1970
216.89
73.14
' 57.10
f 17.86
8.25
46.61
6.718
..
6.110
1 1.10
17.238
11.099
-TABLE 2A.
1971 1972
2.27.93 222.80
73.88 76.13
63.24 59.87
19.49 20.58
10.31 13.16
45.25 36.56
8.243 8.952
6.549 6.473
.. 97 .1.08
20.729 24.093
14.080 17.610
''
HISTORICAL ALASKA NATURAL GAS USEa
(million mcf)
1973 1974 1975 1976 1977 1978 1979 1980(est)0
256.399 271.162 375.832 602.687 738.485 929.5
223.10 228.44 252.554 265.253 279.961 293.800 305.056 300.7
87.78 86.81 95.183 . 111 .. 082 115.131 114.074 li9.825 123.5
60.99 61.87 64.777 63.509 66.912 60.874 64.111 49.7
20.64 22.10 23.888 24.257 28.620 48.879 51.657 56.2
15.48 17.11 19.619 22.188 23.590 24.591 28.155 28.2
20.90 23.89 28.830 24.466 24.396 23.524 17.520 20.0
9.653 9.816 12.044 12.552 12.683 13.454 14.045 14.1
6.069 5.684 5.842 5.424 5.100 5.126 4.986 5.0
1.59 1.16 2.371 1.775 3.529 3.277· 4.757 4.0
26.402 26.847 30.423 28.281 28.780 30.295 30.6
20.139 20.996 24.281 23.130 22.538 23.489 25.004 25.6
TABLE 2A. (continued)
[;umtoE BAY
Reinjectionh
Use on Lease, Vented,
and Shlin~ageh
Pipelir.e Fuelh
Electric Power Generationh
GIRROW
GovermBent and
Utilit r Sa1esh
Use on Lease~ Vented,
and Sh ~inkageh .
1970 1971
0 0
0 0
See ac :ompanyin.g table notes on following page.
1972 1973 1974 1975
3.047
0 0 0 0
2.277
.770
0 b 0 0
.798
.267
.531
1976 1977 1978 1979 1980(est)0
5.077 94.992 307.994 432.498 627.8 I
0 68.080 271.854 390.136 576.2
3,414 24.069 20.787 25.068 30.9
1.663 2.843 7.261 8.930 11.8
0 0 8.092 8.364 8.8
.832 .879 .893 .931 1.0
.390 .504 .541 .582 .6
.. 442 .375 .352 .331 .4
00
TABLE 2A. Notes
a. Revised from reports of previous years.
h. State of Alaska, Department of Natural Resources, Division of Oil and Gas Conservation (DOGC),
Monthly Report of Gas Disposition.
c. Before 1975 from Natural Gas Demand and Supply to the Year 2000 in the Cook Inlet Basin of South
Central Alaska, Stanford Research Institute (SRI), prepared for Pacific LNG Company, November
1977, Table 3, p. 10. After 1974 from Monthly Report of Gas Disposition, DOGC •.
d; Before 1975 from SRI; after 1974 this is the sum of two items: (1) rental gas sales from the
Kenai and Beaver Creek gas fields reported in Kenai Gas Sales, internal document of DOGC, and
(2) injection from various gas fields reported in Monthly Report of Gas Disposition, DOGC.
e. Before 1975 from SRI; after 1974 this i's the sum of two items: (1) sales to Phillips LNG from
the Kenai and Beaver Creek gas fields reported in Kenai Gas Sales, internal document of DOGC,
and (2) sales from the North Cook Inlet gas field reported in Monthly Report of Gas Disposition,
DOGC.
f. Before 1975 from SRI; a~ter 1974 this is the sum of two items: (1) sales to Collier Chemical from
the Kenai and Beaver Creek gas fields reported in Kenai Gas Sales, internal document of DOGC, and
(2) sales from the McArthur River field reported in ~onthly Report of Gas Disposition, DOGC.
g. Before 1975 from SRI; after 1974 froin Electric utility sales reported by Anchorage Natural Gas to
Alaska Public Utilit:i.es Commission (APUC) plus Beluga River gas field sales .to Chugach Electric
reported in Monthly Report of Gas Disposition, DOGC.
h. Before 1975 from SRI; after 1974 from Monthly Report of Gas Disposition, DOGC. ·
j. Sales to final consumers reported in Annual Financial Reports to APUC. Includes Anchorage
Natural Gas and Kenai Utility Service Corporation. Anchorage Natural Gas Rate Schedule
.Categories revised in 1975, so earlier years obtained from internal records of Anchorage
Natural· Gas. ·
k. Annual Financial Reports to APUC of Alaska Pipeline Company and Anchorage Natural Gas.
TABLE 2A. Notes (continued)
1. This category is primarily composed of three components: (1) total sales from gas fields in
Cook Inlet net of sales from' (a) Beaver Creek, (b) Beluga River, (c) Kenai, (d) McArthur River,
(e) North Cook Inlet, taken from Monthly Report of Gas Disposition, DOGC; (2) the difference
between sales from Kenai and Beaver Creek gas fields reported in DOGC Monthly Report of Gas
Disposition and Kenai Gas Sales, working document of DOGC; and (3) the portion of Kenai and
Beaver Creek gas sales not attributable to Ammonia lJrea, LNG, rental for injection, Alaska
Pipeline Company, or Kenai Gas Utility from DOGC Kenai Gas Sales. This category is calculated
as the residual of Cook Inlet gas use and, therefore, does not exactly equal these three
compone11ts.
m. Consists of Anchorage Natural Gas Utility Sales (ineluding some sales to electric utilities and
military) and direct military sales. Annual Financial Report to APUC.
n. Sales to final consumers, utilities, and military. Annual Financial Report to APUC.
o. Estimates based upon first nine months of the year.
TABLE 2B. HISTORICAL ALASKA NATURAL GAS USE
(millions of barrels of crude oil equivalent)
1970 1971 1972 1973 1974 1975 1976 1977 1978 1979 1980(est)
TOTAL USE 45.1 47.7 66.1 106.1 130.0 163.6
I COOK INLET 38.2 40.1 39.2 39.3 40.2 44.4 46.7 49.3. 51.7 53.7 52.9
Reinjection 12.9 13.0 13.4 15.4 15.3 16.8 19.6 20.3 20.1 21.1 21.7
LNG Exports 10.0 11.1 10.5 10.7 10.9 11.4 11.2 11.8 10.7 11.3 . 8.7
Ammonia Urea Production 3.1 3.4 3.6 3.6 3.9 4.2 4.3 5.0 8.6 9.1 9.9
Electric Utility Sales 1.5 1.8 2.3 2.7 3.0 3.5 3.9 4.2 4.3 5.0 5.0
......
0 Use on Lease, Vented,
and Shrinkage 8.2 8.0 6.4 3.7 4.2 5.1 4.3 4.3 4.1 3.1 3.5
Gas Utility Sales 1.2 1.5 1.6 1.7 1.7 2.1 2.2 2.2 2.4 2.5 2.5
Military Sales 1.1 1.2 1.1 1.1 1.0 1.0 1.0 0.9 0.9 0.9 0.9
Miscellaneous Sales
to Other Producers,
Refiners, and Pipelines 0.2 0.2 0.2 . 0.3 0.2 0.4 0.3 0.6 0.6 0.8 0.7
Item: Alaska Pipeline
Company Sales 3.0 3.6 4.2 4.6 4.7 5.4 5.0 5.1 5.3 5.4
Item: Anchorage Natural
Gas Sales 2.0 2.5 3.1 3.5 3.7 4.3 4.1 4.0 4.1 4.4 4.5
1.
'·
1-'
1-'
TABLE 2B. (continued)
PRUDHOE BAY .
Reinjection·
Use o~ Lease, Vented,
and Shrinkage
Pipeline Fuel
Electric Power
·I BARROW
Government and
Utility Sales
Generation
Use on Lease, Vented,
and Shrinkage
:-·· •,
1970
0
0
See Table 2A for notes and sources.
1971
0
0
,·
Components may not add to totals due to rounding.
1972 1973 1974. 1975 1976
0.5 0.9
0 0 0 0 0
0.4 0.6
0.1 0.3
0 0 0 0 0
0.1 0.1
0 0.1
0.1 0.1
Conversion from.Natural Gas to Crude Oil Equivalent is based on 1.021 btu/cubic foot of gas.
(1. mcf gas x ~ 1760 = 1 barrel of crude oil equivalent)
1977 1978 1979 1980(est)
16.7 54.2 76.i 110.5
12.0 47.8 68.7 101.4
4.2 3.7 4.4 5.4
0.5 1 •. 3 1.6 2.1
0 1.4 1.5 1.5
0.2 0.2 0.2 0.2
o.i 0.1 0.1 0.1
. 0.1 0.1 0.1 0.1
1980, the uses by order of volume are as tallows (wtth p~rcentc;tges of
the market total in parentheses):
1. reinjection (41 percent)
2. ammonia-urea product~on (19 percent)
3. LNG exports (17 percent)
4. electric utility sales (9·percent)
5. use on lease, vented, and shrinkage (7 percent)
6. gas utility sales (5 percent)
7. military sales (1 percent)
8. miscellaneous sales (1 percent)
Tl1e Barrow market accounts for less than op.e-hal:.f of one percent of
the state total.
From this breakdown, it is clear that three large industrial uses
account for 95 percent of all na~ural gas use in the state (881.6 million
mcf). These are petroleum production, distribution, and refining..-related
uses; ammonia-urea production; and LNG production for export. Sales to
electric utilities, gas utilit.ies, and the military account for the
remainder which is 5 percent of the total,(47.9 million mcf or 8.5 mil-
lion BOE).
Recent important trends in natural gas use· aye the following:
· 1. Rapid increase in gas use for reinjecti.pn at Prudhoe Bay
with constant reinjection use in Coo~ Inlet;..
2. Doubling of gas use as feedstock in ammonia-urea produc-
tion in 1978.
12
3. Doubling of gas use in petroleum production, transportation,
and refining with the completion of the Alyeska pipeline in
1977.
4. Moderation in growth in sales of gas to electric and gas
utilities.
5. Relatively constant levels of military use and LNG exports.
I.e. Petroleum Liquids1
Petroleum liquids consumption can be divided into four categories,
of which vehicle transportation is the largest. Tables 3A and 3B show
that vehicle transportation accounted for 64 percent of the 1,180 million
gallons of product (28.1 million barrels of product) used in the state.
The remaining categories by order of consumption are space heating with
15 percent and oil pipeline related and electric power generation, ea.ch
with about 10 percent of the total.
Fuels for vehicle transportation include gasoline, jet fuel, and
diesel fuels used for highway, marine, and aviation uses. Tables 4 and
5 show the historical patterns of these fuels as. reported to the State
of Alaska Department of Revenue. (Some nontransport uses of fuel are
included in this data since they are reported with transport fuel.) Jet
fuel consumption dominates vehicle transport fuel use with 436 million
gallons (10.38 million barrels of product) followed by gasoline w{th
200 million gallons ( 4. 7 6 million barrels of product) and diesel with
120 million gallons (2.87 million barrels of product) (after netting out
nonvehicle transport diesel uses reported to Department of Revenue).
1 Natural gas liquids use is not considered in this analysis.
13
I-'
~
TABLE 3A. SUMMARY: ALASKA PETROLEUM LIQUIDS CONSUMPTION
(million barrels of product)
,._,
Vehi~::le Oil Electric Power b
Year Transportation a Pipeline b Space b Generation Total Heat
1970 0
1971 12.0 0
1972 13.1 0
1973 14.9 0
1974 16.7 0
1975 18.5 0
1976 18.5 0 3.7 2.3 24.5
1977 16.7 .7 3. 7 2.6 23.7
1978 17.2 2.3 L1. 0 2.7 26.2
1979 18.;1 2.6 L1.l 2.8 27.6
1980 (est.) 18.0 3.0 l •• 2 2.9 28.1
aTotal from Table 4E minus off-highway exempt diesel use (diesel for space heating
~and poWer generation) and Alyeska pipeline fuel consumption (pumping and other uses).
b See Table 6.
TABLE 3B .. SUMMARY: ALASKA PETROLEUM LIQUIDS CONSUMPTION
(million· barrels of crude oil equialent)
Vehicle dil Electric Power
Year· Tr.imsportation Pipeline Space Heat Generation Total --·
1970. 0 --
1971 11.53 0
1972. 12.49 0
1973 14.27 0
1974 16.06 0 --
I-' 1975 17.78 0 V1
1976 17.77 0 3.7 2.3 23.8
1977 15 .• 98 .7 3.7 2.6 .23.1
1978 16.33 2.3 4.0 2.7 25.3
1979 17.30 2~6 4.1 2.8 26.8
.1980 (est.) 17.11 3.0 4.2 2.9 27.2
For conversion factors, see Tables SA, SB, ~nd SC.
SOURCE: See Table 3A.
1-'
0'\
TABLE 4A. ALASKAN CONSUMPTION OF MOTOR VEHICLE FUELS: GASOLINEa
Highway Marine
Year Taxable Exempt b Taxable Exempt c
i971 100.136 12.929 5.645 .012
1972 .. 112_.129 . 28 •. 435 4.688 ~141
1973 119.550 14.752 6.395 .023
1974 128.850 12.634 6.352 .025
1975· 167.494 7.222 5.263 .200
1976 186.620 5.274 5.613 .267
1977 18Lll9 4.515. 6.060 .388
1978 179.069 8.290 7.160 .275
1979d 173.802 7.527 8.004 .292
1980 167.004 7.8'32 .7.663 .161
·(est.)
aFigures revised from reports from previous years
bMilitary and g~vernment
cMilit~ry, government, and nonpropulsion uses
dEstimate for .the year based on first 9 months
(million gallons)
Aviation·
Taxable Exempt b
8.588 2.595
9.288 4.130
i0.714 . 1.819
13.194 1. 728
13.370 1.215
13.784 1.289
15.249 1.521
15.145 .68~
16.373 .552
16.611 .486
SOURCE: Department of Revenue, Motor Fuel Tax Returns
·Total
Taxable Exempt
114.369 15.536
126.105 32;706
136.659 16.594
148~396 14~387
186.127 8.637
206.017 6.830
202.428 6.424
201.374 9.250
198.179 8.371
191.278 8.479
Grand Total
129.905
158.811
153.253
162.783
194.764
212.847
208.852
210.624
206.550
199.757
aFigures revised from reports from previous years
bMilitary, government, and electric utility power generation
cOff-Highway diesel is diesel sold for space heating and power generation
~ilitary and government
e 1 . Nonpropu s1.on
fEstimate for the year based on first 9 months
SOURCE: Department of Revenue, Motor Fuel Tax Returns
.....
00
TABLE 4C. ALASKAN CONSUMPTION OF MOTOF~ VEHICLE FUELS: JET FUELa
(million gallons)
Year Taxableb Exempt c Bonded d
1971 48.968 194 • .485 NA
1972 46.594 231.581 NA
1973 35.293 150.055 131.452
1974 79.647 144.386 116.939
1975 96.586 215.366 26~035
1976 . 95.488 189.734 32.765
1977 103.164 190.382 40.517
1978 113.006 220.789 33.117
1979 126.190 221.041 67.985
1980e (est.) 136.126 210.843 88.944
aFigures revised from reports from previous years
be. ·1· d · · 1v1 1an omest1c operat1ons
~il~tary and international operations utilizing domestic fuel
dinternational operations utilizing foreign fuel
eEstimate for the year based on first 9 months
SOURCE: Department of Revenue, Motor Fuel Tax Returns
Exempt and Bonded
194.485
. 231.581
281.507
261.375
241.401
222.499
230.899
253.906
289.026
299.787
Grand Total
243.453
278.175
316.800
341.022
337.987
317.987
334.063
366.912
415.216
435.913
TABLE 4D. ALASKAN CONSUMPTION OF MOTOR VEHICLE FUELS: OTHERa
(million gallons)
Year Taxable Highway Taxable Marine Total
1971 .848
1972 .469
1973 .249
1974 -.904
1975 .794
1976 1.174
1977 .593
1978 29.228
1979 91.563 .328 91. 82lb
1980c (est.) 87.099 .160 87.259
aAlmost all are turbine fuels that are essentially a type of diesel.
b . Components do not sum to total due to small adjustment (-.070) which
is not classified either as "Highway Other" or "Marine Other."
cEstimated based on data for first 9 months
SOURCE: Department of Revenue, Motor Fuel Tax Returns
19
TABLE 4E. ALASKAN CONSUMPTION OF MOTOR VEHICLE FUELS: TOTAL
(million gallons)
Diesel and Other
Year Gasoline Diesel Other Jet Fuel Total (primarily diesel) ----
1971 129.905 130.344 .848 243.453 504.550 131.192
1972 158.811 111.607 .469 278.175 549.062 112.076
1973 153.253 153.868 .249 316.800 624.170 154.117
1974 162.783 196.050 .904 341.022 700.759 196.954
1975 . 194.764 242.359 .794 337.987 775.904 243.153
1976 212.847 244.309 1.174 317.987 776.317 245.483
N
0.
1977 208.852 187.802 .593 334.063 731.310 188.395
1978 210.624 207.633 29.228 366.912 814.397 236.861
1979 206.550 .· 237.047 91.821 415.216 950.634 328.868
1980 (est.) 199.757 222.522 87.259 435.913 945.481 309.811
SOURCE: Department of Revenue, Motor Fuel Tax Returns
N
f-'
TABLE SA. ALASKAN CONSUMPTION OF MOTOR VEHICLE FUELS: GASOLINE
. BARRELS OF CRUDE OIL EQUIVALENT
(annual million barrels)a
Highway Marine Aviation Total
Year Taxable Exempt Taxable Exempt Taxable
1971 2.15 .28 .12 .00 .18
1972 2.41 .61 .10 .00 .20
1973 2.57 .32 .14 .00 .23
1974 2. 77 .27 .14 .00 .28
1975 3.60 .16 .11 .00 .29
1976 4.01 .11 .12 .01 .30
1977 3.89 .10 .13 .01 .33
1978 3.85 .18 .15 .01 .33
1979 3.74 .16 .17 .01 .35
1980 3.59 .17 .16 .00 .36
(est.)
aConversion assumes 1 barrel gasoline = 5.248 million btu.
(1 gallon gasoline x .0215 = 1 barrel crude oil equivalent)
See Table 4A for additional notes and source.
Components may not add to totals due to rounding.
Exempt Taxable Exempt
.06 2.46 .33
.09 2. 71 .70
.04 2.94 .36
.04 3.19 .31
.03 4.00 .19
.03 4.43 .15
.03 4.35 .14
.01 4.33 .20
.01 4.26 .18
.01 4.11 .18
Grand Total
2.79
3.41
3.29
3.50
4.19
4.58
4.49
4.53
4.44
4.29
N
N
TABLE SB. ALASKAN CONSUMPTION OF MOTOR VEHICLE FUELS: DIESEL
BARRELS OF CRUDE OIL EQUIVALENT
(annual million barrels)a
Off
Highway Highway Marine
Year Taxable Exempt Exempt Taxable Exempt-1~
1971 .83 1.72 .50 .07
1972 .69 1.32 .so .17
1973 .59 2.13 .51 .31
1974 1.57 2.40 .52 .05
1975 3.17 1. 70 .52 .18
1976 3.34 1.56 .60 .10
1977 2.36 1.08 .77 .28
1978 2.43 1.29 1.00 .24
1979 1.35 .94 1.95 1.27 .15
1980 1.44 .70 1.62 1.44 .12
(est.)
aConversion assumes 1 barrel diesel = 5.825 million btu.
(1 gallon diesel x .0239 1 barrel crude oil equivalent)
See T~ble 4B for additional notes and source.
Components may not add to totals due to rounding.
Exempt-B
NA
NA
.13
.16
.22
.25
NA
NA
NA
NA
Total
Taxable Exempt
1.33 1. 78
1.18 1.48
1.10 2.57
2.08 2.60
3.70 2.10
3.93 1.90
3.13 1.36
3.43 1.53
2.62 3.04
2.88 2.44
Grand Total
3.12
2.67
3.68
4.69
5.79
5.84
4.49
4.96
5.67
5.32
N w
TABLE 5C. ALASKAN CONSUMPTION OF MOTOR VEHICLE FUELS: JET FUEL
BARRELS OF CRUDE OIL EQUIVALENT
(annual million barrels)a
Year Taxable Exempt Bonded Exempt and Bonded
1971 1.13 4.47 NA 4.47
1972 1.07 5.33 NA 5.33
1973 .81 3.45 3.02 6.47
1974 1.83 3.32 2.69 6.01
1975 2.22 4.95 .60 5.55
1976 2.20 4.36 .75 5.12
1977 2.37 4.38 .93 5.31
1978 2.60 5.08 .76 5.84
1979 2.90 5.08 1.56 6.65
1980 (est.) 3.13 4.85 2.05 6.90
aConversion assumes 1 barrel jet fuel = 5.604 million btu.
(1 gallon jet fuel x .023 = 1 barrel crude oil equivalent)
See Table 4C for additional notes and source.
Components may not add to totals due to rounding.
Grand Total
5.60
6.40
7.29
7.85
7.78
7.32
7.69
8.44
9.55
10.03
TABLE 5D. ALASKAN CONSUMPTION OF MOTOR VEHICLE FUELS: OTHER
BARRELS OF CRUDE OIL EQUIVALENT
(annual million barrels)a
Year Taxable Highway Taxable Marine Total
1971 .02
1972 .01
1973 .01
1974 .02
1975 .02
1976 .03
1977 .01
1978 .70
1979 2.19 .01 2.19
1980 (est.) 2.08 .00 2.09
aConversion assumes 1 barrel diesel = 5.825 million btu.
(1 gallon diesel x .0239 1 barrel crude oil equivalent)
See Table 4D for additional notes and source.
Components may not add to totals due to rounding.
24
N
\.)1
Year Gasoline
1971 2.79
1972 3.41
1973 3.29
1974 3.50
1975 4.19
1976 4.58
1977 4.49
1978 4.53
1979 4.44
1980 (est.) 4.29
TABLE 5E. ALASKAN CONSUMPTION OF MOTOR VEHICLE FUELS: TOTAL
BARRELS OF CRUDE OIL EQUIVALENT
(annual million barrels)
Diesel Other Jet Fuel Total
3.12 .02 5.60 11.53
2.67 .01 6.40 12.49
3.68 .01 7.29 H.27
4.69 .02 7.85 16.06
5.79 .02 7.78 17.78
5.84 .03 7.32 17.77
4.49 .01 7.69 16.68
4.96 .70 8.44 18.63
5.67 2.19 9.55 21.85
5.32 2.09 10.03 21.73
See Table 4E for additional notes and source.
Diesel and Other
(primarily diesel)
3.14
2.68
3.69
4. 71
5.81
5.87
4.50
5.66
7.86
7.41
Recent trends in petroleum liquids use are as follows:
1. Rapid increase in jet fuel consumption in recent years.
2. Rapid increase in diesel consumption associated with pump
station requirements on Alyeska pipeline.
3. Moderation in growth of fuel oil use for space heating
and electricity generation.
4. Decline in consumption of gasoline and diesel fuel for
vehicle transportation in post-Alyeska pipeline construc-
tion years.
26
N
-....!
TABLE 6A. ALASKA PETROLEUM LIQUIDS CONSUMPTION
NOT REPORTED AS VEHICLE
TRANSPORTATION FUEL
(million barrels of product)
Oil Elec:tric Power
Year Pipeline Space Heat Generation Total
1970 0
1971 0
1972 0
1973 0
1974 0
1975 0
1976 0 3.674 2.340 6.014
1977 '• 73 3.7 2.57 7.0
1978 2.25 4.0 2.70 8.95
1979 2.58 4.1 2.79 9.47
1980 (est.) 2.95 4.2 2.9 10.05
SOURCES: (1976) Goldsmith and Lane, Oil and Gas Consumption in Alaska: 1976 to 2000,
prepared for the Alaska Royalty Oil and Gas Development Advisory
Board and the 1978 Alaska State Legislature, 1978.
(1977 to date) Oil Pipeline -Alyeska Pipeline Service Company; Space Heat -
based on growth rate of Anchorage gas utility sales; Electric
Utility -based on growth rate of electricity net generation state-
wide, taken from Alaska Power Administration internal worksheets.
TABLE 6B. ALASKA PETROLEUM LIQUIDS CONSUMPTION
NOT REPORTED AS VEHICLE
TRANSPORTATION FUEL
(million barrels of crude oil equivalent)
Oil Elec.tric Power
Year Pipeline Space Heat Generation Total
1970 0
1971 0
1972 0
1973 0
1974 0
N 1975 0 00
1976 0 3.674 2.340 6.014
1977 '· 73 3.7 2.57 7.0
1978 2.25 4.0 2.70 8.95
1979 2.58 4.1 2.79 9.47
1980 (est.) 2.95 4.2 2.9 10.05
aConversion assumes 1 barrel diesel = 5.825 million btu.
SOURCE: See Table 6A.
II.A. Summary
II. OIL AND NATURAL GAS CONSUMPTION
PROJECTED TO 2000
By 2000, it is possible that consumption of natural gas (not includ-·
ing reinjection) could increase by 100 percent from 230 to 459 million mcf
annually. Consumption of petroleum liquids could also double from 28.1
to 58.3 million barrels annually (Table 7). Summing annual consumption
estimates between 1981 and 2000 results in total natural gas;consumption
of 8,167 million mcf (8.1 trillion cubic feet) and petroleum liquids
·. consumption of 929 million barrels (. 9 billion barrels) .
The most rapid growth is likely in industrial use of petroleum liquids
which is dominated by the royalty oil refinery use of liquids. Electric
utility generation using petroleum liquids should also continue to in-
crease rapidly because of the unavailability of alternative generation
modes in many parts of the state combined with continued population
expansion. This continued population growth should also contribute to
a rapid increase in the use of liquid fuels for transportation and for
space heating although the growth rate for_the latter will be more
moderate.
Continued consumer preference for natural gas as a space heating
fuel in the Anchorage area combined with continued population grO"<;vth will
result in greatly increased tise of gas for this purpose. Industrial use
of gas could double, primarily the result of construction of a large LNG
29
w
0
TABLE 7A. 2000 PROJECriON OF ALASKA OIL AND GAS CONSUMPTION.
Vehicle Transportation
Liquids
Natural Gas
Utility El~ctricity Generation
Liquids
Natural Gas
Space Heat
Liquids
Natural Gas
Industd.al Usea
Liquids
Natural Gas
Total
·Liquids
Natural Gas
Liquids = million barrels
Natural Gas = million mcf
1980
18.0
0
2.9
28
4. 2.
14
3.0
188
28.1
230
2000
32
0
6.9
43
7. 4,
25
12
383
58.3
459
20-Year Total
(1981 to 2000)
500
0
100
785
'116
390
213
6,992
929
8,007
aFor petroleum liquids in 1980, this includes oil pipeline-related fuel use.
For natural gas in 1980, this includes all uses except consumption through gas utilities
and reinjection (which is primarily deferred consumption).
.TABLE 7B. 2000.PROJECTION OF ALASKA OIL AND GAS CONSUMPTION
(million barrels of crude oil equivalent)
Vehicle Transportation
Liquids
Natural Gas
Utility Electricity Generation·
Liquids
Natural Gas
Space Heat
Liquids
·Natural Gas
Industrial Use
Liquids
Natural Gas
Total
Liquids
Natural Gas
198d
17.4
0
2.8
4.'9
4.1
2.5
2.9
33.1
27.1
40
Conversion factors: .1760 for gas; .966 for liquids.
' '
2000
31
0
T'
8.
?
4
1'2
67
56
81
20-Year Total
(1981 to 2000)
483
0
97
138
112
69
206
1,231.
897
1,409
facility to ship gas toCalifornia. Use of gas for utility electricity
generation will expand at a more moderate rate as utilities are forced
\
to switch to alternative generating modes to meet continued load growth.
II.B. Projection Assumptions
This projection of oil and gas consumption to 2000 is quite simple
and based upon a limited number of assumptions. They are as follows:
• Population in Alaska grows to 700 thousand by 2000 as a result
of the growth of basic sector industries and state government activity
which stimulates the private economy. This is consistent,with the moder-
ate economic projection scenario which appears in the study Electric Power
Consumption for the Railbelt, ISER, 1980.
• Per capita use of vehicle transportation fuels remains constant
in the aggregate over time. Thus, the combination of high prices and
fuel economy standards (which apply primarily to gasoline and diesel
consumption) reduces consumption to the same extent that increasing real
incomes and increasing international air traffic increases consumption.
• The space heating mode split remains constant through the projec-
tion period. Gas is the preferred fuel for the majority of new consumers
in the Anchorage region; and fuel oil, elsewhere. New consumers utilize
fuel at the same rate as existing consumers, thus balancing the effects
of rising real incomes and rising real energy prices.
• New electricity generation in the railbelt until 1990 is pro-
vided by gas in Anchorage and oil in F.airbanks. Subsequently~ new load .
is served by some alternative; but the amount provided by oil and gas
does not decline. For the rest of the state, liquid fuel use for
32
...
electricity generation grows continuously for the next .twenty years;
Railbelt consumption growth is 4.5 percent annually, consistent with
the above-mentioned study. The annual growth rate for the rest of the
state is 5 percent. (The Fairbanks region is assumed to account for
25 percent of petroleum liquids consumption for electricity generation.)
• In<:Iustrial consumption specifically includes the large_ .projects
listed in Table 8. The new projects--LNG to California, the gas pipe-
line, and the Alaskan royalty oil refinery-~all begin operation in the
mid-1980s·so that the time profile of industrial consumption rises
rapidly to a level about double present use.
e All industrial projects continue at projected annual consumption
levels through the year 2000 independent of currently dedicated gas
·supplies or presently projected supplies of oil.
• Military consumption patterns follow those of the state in general.
II.C. Potential for Error in Projection
Actual consumption of oil and gas in future years could differ con-
siderably from these projections for.many reasons.
Industrial consumption is the largest projected end use for gas and
subject to the most uncertainty. Table 8 shows what projects have been
included in the projection and their average annual consumption rates.
Changing the assumptions about which large industrial projects will
actually be built and their timing could easily change the projection
of total natural gas consumption in 2000 by 10-to-20 percent. Industrial
33
TABLE 8. POTENTIAL AVERAGE ANNUAL DEMAND FOR OIL AND GAS
IN VARIOUS INDUSTRIAL PROCESSES
USE
Included in Projection
Existing Consumption··
LNG to Japan
Oil and Gas Production
Ammonia-Urea
Oil Pipeline
Military (gas sales only)
New Consumption (start date)
Alaskan Royalty Oil Refinery.(l984)
Gas Pipeline (1985) .
LNG to Califo~nia (1986)
Not Included in Projection
Aluminum Smelting
Iron Or~ Processing
Methanol Plant
Copper Processing
Polyethylene Plant
OIL
(million barrels)
3
9
GAS
(million nicf)
50-88
64
.55
12
5 ..
7
160
20-53
29
24
22
6
SOURCE: Goldsmith, Scott and Tom Lane. Oil and Gas .Consumption in Alaska 1976-2000.
Report for Alaska Royalty Oil and Gas Development Advisory Board and
Alaska State Legislature, 1978, and author's estimates.
r
use of oil is much smaller as a percentage but is also highly dependent
upon the assumptions made about particular projects.
. The level of transportation use of liquid fuels is dependent upon
a large number of f-actors. Jet fuel consumption depends primarily on
· . military requirements and international movements. Domestic flights
account for the smallest portion of use. Gasoline and diesel use are
both heavily dependent upon population and consumption per capita. Use
per capita: will be influenced positively by increases in real incomes
and negatively by higher prices and fuel economy standard~ in new motor
vehicles. Diesel will also be a function of large construction pr~ject
activity (pipelines, for example) and to a lesser extent of growth of
the fishing industry.
Use of fuels for space heating is subject to considerable uncer-
tainty over the next twenty years because of the possibility of the sub-
stitution of electricity, generated by hydropower, for oil and gas in the
railbelt. Alternatively, there is the possibility of substituting natural
gas, from Prudhoe Bay, for liquid fuels in the Fairbanks market. In
addition to this uncertainty concerning the mode split, space heating
requirements are a function of population, income, and the conservation
response to higher energy pric.es.
Projecting the use of fuels for electricity generation is also sub-··
ject to uncertainty related to choice of mode split. The ability of
Anchorage to provide for expanding electricity load with natural gas
35
and to continue to use gas for existing load i~ partially dependent upon
the economics of alternatives, but also upon government regulations on
the use of gas to generate electricity. For Fairbanks, economics is
more clearly a determinant of the potential for switching toward coal,
although government regulation is also a factor there. The possible
construction of the hydroelectric generating capability adds another
alternative generating mode to the possible substitutes for oil and gas.
Electricity consumption, itself, is related to population, income, and
price variables.
36
III. PRESENT OIL AND GAS SUPPLY
1 Estimated reserves of oil and gas in Alaska are presented in Tables 9
and 10 •. Crude oil reserves totala:bout 8,577 million barrels with about
1,064;8 million barrels comprising the state's royalty portion. Natural
gas reserves amount to about 32,791 billion cubic feet (BCFl with 3,876.1
comprisng the state's·royalty.
No new reserves were discovered in 1979,· but an increase in the gas
reserves of the Prudhoe Bay field may be noted in Table 10. The January
'·
1979 volume estimate of 21,000 BCF included only gas found in the gas
. cap. The three-dimensional·reservoir model and two years of oil pro-
duction history have ip.creased knowledge about the Prudhoe Bay field and
revealed the potential for additional reserves of gas in solution with
the oil.
The Alaska Oil and Gas Conservation Commission utilizes average reser-
voir pressures and corresponding volumes of production to estimate natural
gas reserves and production history curves to estimate oil reserves in the
Cook Inlet. The data: are continually changing and improving throughout
the life of a field, and, consequently, the reserve estimates also change
and improve.
1Reserves are defined as 'oil ,or natural gas resources that ltave been
discovered and developed, that are producible, but that have not yet been
removed from the reservoir.
37
TABLE 9 • ESTIMATED REMAINING RECOVERABLE OIL RESERVES
IN ALASKA AS OF JANUARY 1, 1980
Field ·Total State Royalty State Royalty
(million BBLS) (percent) (million BBLS)
Beave.r Creek* 1 0
Grimi te Point* 21 12.5 2.6
McArthur River* 118 12.5 14.8
Middle Ground Shoal* 36 0
Prudhoe Bay* 8,375 ·12.5 1,046.9
Swanson River* 22 0
Trading Bay* 4 12.5 .5
TOTAL 8,577 1,064.8
* Producing oil field
SOURCE: The 1979 Statistical Report published by the Oil and GaS' Conserva-
tion Commission. ·
38
TABLE 10. ESTIMATED REMAINING RECOVERABLE NATURAL.GAS RESERVES
IN ALASKA AS OF JANUARY 1, 1980
Field Total State Royalty State Royalty,
(BCF) (percent) (BCF)
Albert Kaloa 0 0
Beaver.Creek* 240 0
Beluga River* 767 7.99 61.3
Birch Hill 11 0
Falls Creek 13 0
Ivan River 101 0
Kenai* 1,313 ** 43.0
Lewis River 90 0
McArthur River* 78 12.5 9.8
Moquawkie 0 0
Nicolai Creek* 17 12.5 2.1
North Cook Inlet* 1,074 12.5 134.3
North Fork 12 0
North Middle Ground Shoal 0 12.5
Prudhoe Bay 29,000 12.5 3,625
South Barrow* 25 0
Sterling* 23 2.72237 .6
Swanson River 0 0
West Foreland 20 0
West Fork* 7 0
TOTAL 32,791 3,876.1
* Producing gas field
** Due to federal leases in the Kenai gas field, the effective state royalty
for the Kenai Unit and the Kenai Deep producing zones are 3.61635 percent
and 1.14069 percent, respectively. Royalty reserves are 41.9 BCF and
1.1 BCF, respectively.
SOURCE: The 1979 Statistical Report published by the Oil and Gas Conserva-
tion Commission.
39
Prudhoe Bay continues to dominate the oil and gas reserves picture.
Total Cook Inlet oil reserves comprise only about 2 percent of the total
known reserves in the state; while Cook Inlet royalty oil reserves total
about 2 percent of the total state royalties known to exist at this time.
The same situation occurs with the gas reserves. Cook Inlet gas
reserves comprise about 12 percent of the total reserves, and royalty gas
in Cook Inlet totals about 7 percent of the total state royalty gas.
40
IV. SURPLUS OIL AND GAS
A comparison of projected consumption levels with current estimated
remaining recoverable reserves indicates that presently identifiable
Alaskan needs for both petroleum liquids and natural gas ~ould be met
by Alaskan resources· through the year 2000 (Table 11).
State royalty oil could meet Alaskan liquid fuel requirements through
2000. Because of population growth royalty oil supply will exceed demand
in early years; later in the 1990s, the reverse will be the case.
State royalty gas, from both Cook Inlet and Prudhoe Bay; is insuf-
ficient to meet total projected instate gas requirements through 2000.
In addition, total present Cook Inlet reserves are not sufficient to
meet total Cook Inlet gas market demand through 2000 a$ projected.
41
TABLE 11. SURPLUS OIL AND GAS CALCULATION
Recoverable
Reserves as of
January 1, 1980
Estimated
Production a during 1980
Item: Estimated
Alaskan Consump-
tion during 1980
Estimated Remain-
ing Recoverable
Reserves as of b
January 1, 1981
Estimated Cumu-
lative Alaskan
Consumption from
1981 to 2000
Statewide
State
Total Royalty
8,577 1,065
585 72
28 --
7,992 993
929 --
Liquid Petroleum
(million barrels)
North Slope
State
Total Royalty
8,375 1,047
548 69
.
----
7,827 978
----
aAuthors' estimates
b Assumes no reserve additions during 1980
Cook Inlet Statewide
State State
Total Rovaltv Total Royalty
20.2 18 32,791 3,876
37 3 230 27
----230 27
165 15 32,561 3,849 ..
----8,007 --
Natural Gas
(million mcf)
North Slope
State
Total Royalty
29,025 3,625
53 7
53 7
28' 972 3,618
----
Cook Inlet
State
Total Royalty
3,766 251
177 12
177 12
3,589 239
----
APPENDIX A. DATA SOURCES
Data on current consumption is derived from the following documents:
Petroleum Liquids
State of Alaska, Department of Revenue. Motor Fuel Tax Returns
(monthly).
U.S·. Department of Energy~ Prime Suppliers Monthly Report (EIA-25) ·;
compiled by State of Alaska,, Department of Cottnilerce and Ec·ondmic
Pevelopment, Division -of Energy and Power Development.
U~S. Department of Interior,Alaslta Power Administration. Alaska
Electric Power Statistics (worksheets) • · .
Natural Gas
· State of Alaska, Department of Natural Resources, Division of Oil
arid Gas Conservation. Monthly Report of Gas Disposition.
Kenai Gas Sales (monthly).
Alaska Public Utilities;Commission. Annual Financial Reports of
Alaska Gas and Service Company, Kenai Utility Service Cor-
poration, Alaska Pipeline Company •.
The U.S. Department of Energy compiles information on energy consump-·
tion in Alaska. This. source of information does not at this time appear
to be of such a consistent or reliable quality as to warrant.its use for
policy decisions. The most recent compilation for Alaska is reproduced
on the following pages. The source of this information is U.S. Department
of Energy, Energy Information Administration, Energy Statistics Branch,
State Energy Data Report, April 1980, pp.,31-37.
Consumption of Energy by Type, State of Alaska
TRILLION RTU
Total Natural Nucle-.nr Hydru· Gl"'-Wood Tt•tnl
Coal ·Gas Petroleum· Power ell>ctric thermul untl 1-:ncrJ.:V
Year (Dry I Pow~r1 Power1 \Vnslc.•.' C.onsun1l'tl
Aviation l)jatll· Jet Kero-·Lubri; Motor Residual. Road' AII!Other Total
Asphalt Gasoline late Fuel• sene LPffi cants Gasoline: Fu•l Oil Petro-Petro-
Fuel: leum I cum
1960 8.485 2:034 0.312 5.581 15:628' 12.127' 0.511 0.303 0;5U 14.666 4.440 0.000· 4.021 5NJOI O:OOO· 0.000 0.000 O.IKKI' 7:!.~U:I
19.61 14.005 2.300; 0.55li 5:992 16.679 14.322i '0,237' 0.524 0:495 16.680 4.0'12 0.000 4:~»8 64.456. 0.000· 0.000 '· 0.000 O.OOtL ~li.U-12
1962 16.745 4.048: 0.489.-5;335 16.952 17:128C 0.136 0.382 0.520· 14.676.' 4.4'14 0.000 4:3:!0 6-1:322' Mou.· 0.000 U.Ullll: 0.01111' \111.:1:1:1
19.63 15.779 5.677, 0:589· 4;068 17:897· 17.476' 0:164 .0.461· 0.520 13.909' 4.668 0.0.00 5.130' 64.882· 0.000· 3.410· 0.000 0.111111' KM.KO(i
1964 15.465 6.9.54. 0.791: 3:584 20.361. 18.120, 0.047 0:606, 0.546. 1~.868· 5.011 0.000 4.891 U7:825. 0.000 3.:!74 0.000· 0.0011 !1.1.094
1965 12.393 7:837· 0.878 3.03~ 21:439' 18.217· 0.057, O.G49 0.5G2· 16:003: 5.5./8 0.000' 4.95:! 71'.339: o.QOO 3.655 0.009• 0.0011: nt.m:t
196U 21;225. 12:687, 1.644 2.505 22.980· 22.200', . 0.046 0.703 0.584 . 10.059: 6:2M 0.003 4.a07 71:286. 0.000' 3.293 0.000· 0.000. I(Jf>.46U ,
1967. 24.418 12.269. 0.832 3.474 25.018 27:305·. ··0.040: 0.747: 0:526: 14:089' 6.383 0.000 5.360· 82.773 0.000 3;786 o.ooo. o.ooo 1W.07G
1968 21.147 1a.o92: 0.740 3:3.66 27.755 30.'706: 0.051 0.794.' 0:578. 11'.583; 5.729 0.015 5.190 S6.49a. 0.000 3.781. 0.000 0.000. 124.!1~·1·
1969 17.443 44.050· 0.963: 3.071 28.361 38;0511 0.040 0.886 0;582: 12.617, 6.634 0.006 5.276 96.486· 0.000' 3.562 0.000 0.000' 15U,IU:l·
1970 17.020: 65.701 1.808< 2.297 29.601• 38,908-, 0.187 1.111: 0.593 13.766. 6.501 0.009• 5.227:; 100.008• o:ooo 3.807 0.000• 0.000, I~O.G31
1971 18.637 69.805 1.9491 1.995. 37,000, 43.598, 0.1871 1.302· 0:588• 14:942' 6.5&7 0.020 5.5()6. 113,705· 0.000 . 3.507 .0.000 0.000 1\19:371
1972· 16.552• 76.674. 2.116, 2.0,31: ' 36;158. 46:03.71' 0:119. 1;473 0.63.0 19.357, 7.331: 0.052. 6.257 12L560; o;ooo 3.594• 0:000· 0.000 ~09:!151
1973 17.641 64,3~8· L5so~· 2.f/17 37:187' 42.6671 O.!P2• 1.732 o:70.6'. 16.794: 6.608 0.042' 6.332 115·~7'l5; . 0.000: 2.973• 0.000· 0.000 191:&71,
1974' 16.284. 64:349• 1.397 2.386 38.393< 42.861: 0,595, 1.373,; 0,~6: 18.619; 6.903 0.241: 6 .. 70~ 120:•1&0; o.ooo· 3.407' 0.0001 0.000 195.325
1975 18.577 86:664. 1.976 .. 2.337: 40:460: 42:347:· 0.699 1.567 0:598 21.954· 6.9A1 0,139. 7.027 126.1>45. 0.000' 3.713 0.000' 0.000· 226.:5-16
1976 16.862. 9L9.22: 1.915 1:683, 55:431 ' 41:8141 0.365': 2.524'. 0.665. 24.615· 8.437 0.192' 8.647: ·146.414· ~.000· 3.978 o.ooo .. 0.000' 248'970'
1977· 12:858·, 118.723; 2.191: 1.864: 69:3.16.· 44;798] .0;490· 3,001· 01i95'· 25.449· 10.927 0.205 10.666 159.692 0:000' 5.343 0.000 0.000 286.836
1978 4.G98; 147:185· 2.085: z.~·· 6U76' 46.296; 0.465 3,699: 0.747· 23.81.11 '16:316 0.016 11.080: 168.293: 0.000. 4.924. '0.000• 0.000 3Hr.042
> I
N. P,IJYSICAL UNITS·
T.otal Natural Nuclear. Hydro-(leo.. WOod1
Gas. P,etro1tum· ... electric '·tli•rmal and: Coal. (Dryl: Power, POwer• Powei"· Waok•"
Year• Ayiation. l)ja~il-J.ett Kero-Lubri• Motor· Residual' Road· AIIOtJier, Tot.al
Asp,halt Gaeoline-late. FUeli sene· LPG>· canta: Gasoline., Fuel: Oil i>etro-P.et .....
.F)uel leum leum.
Thousand Billion ,
Million· Kilow~U 'Hours Short C.ubic Thousand BarrelS.
To no. F. eel
1960,. . 318' 1965', 47· 11011::; 2683. 225lr 90 7&: 84· 2792.: 706; 0.' 622 10457' 0 0 0 0
19~1: 525 2'l'l2: 844 1181:' 2!!6S· 2640: 42.; 131, 82. 3115', 648: 0> 756 11607 0: 0 0 0
1962· . 6'.!8 39.11' 74:' 10&7• 2910 . 31.4: 24:. 95· 86 2715'.: 712. o.: 722 . 11598; 0· 0 0 0
1963 6,19' 5506' 89• 806-3072' 3208· 29.: 1151 . 86 2648, 7~3 0 92~ 11724" 0.; 32!i' 0 0
19G4: 624 6738· 1'19. 7JO,; 3495. 3325, g.; 151 90 26403 7971 0; 933 12269 0: 3:!'l 0· 0
1965 513 7594: 132.: 661; 3680 1.':1271 10' lli2: 93. 3.0.47' 882, 0· 91;2. 12896: 0': :mo· 0 0
1966. 845 122112. 24S: 4!)6: 3946 40311 g .. J7u, 96: 1915. 995 • 0' 976 12886: o· :us 0· 0
1967 959 11889. 125-688. 4295: 49:>5:. 7• 186: 87 2682i 856 0 112( 15009• 0· 363' 0 0
1968 842 17548· Ill: 665. 4785. 5573; g .. 198· 95, 2205; 91!: 2 1181 15715 0· 364· 0 o·
1969. 710' 42726: 14~ 608.; 4869. ~8· 7:· 221 96: 2402i 11155:, I 1316 175U9.· 0: 341 ·0 0
1970. 725 63726; 272 455' 5082. 6979 33< 277 98: 2621' 103~ I' 1321 18173. 0. 3G:l 0· 0
1971· 787' 67706· 294. 395 6352' 78!16; 33 32ii. 97, 2844-1043 a. 1467 20659 0.' :!63 0 0
1972 702. 74658, 319: 402. 6201: 8227: 21• 367 104 3685·-1166. s: 1595 22102. 0: 346 0 0
197a 7'41• 630731 238 4U. 6384:, 7604: 18 432' 116 3197' 1051 6 1526 20!18·1 o• 286 0 0
1974 712:· 62874: 210· 47:3. 859.1 76611 105 342 111' 8545·, 1098 36 1()57 21830 0 326 0. 0
1976-, 804· 84751' 298 .. 463< 694<> 75671 123 391 99 4179· 1104 21 17!t2 2'l942 0· 3fi7 o· 0
1976 734 90121 289' 333: 9517 74?6' 64 !W· 110: 46910 1342 29 2114 26601 . 0 383 0 0
1977 577' 116278: 330 367 10183' 7991, 86 . 74S 115 4845. 1738 81 2445 21!1!80 0' 512 0· 0
1978 270' 145025• 311 440 10671' 8258• 82· 922 123 4583: 2596. 2 ~G55 30493 0 4'12 0 0
' Includes industrial and utility Procluc:tion, and net imports ofelec:tricily.
• Consumed at utilities to produce electricity. ·
• Liquefied petroleum gosca, including ethane. .
Note: Tol.nls muy nOt equal sum of components due. to independent rounding.
Not.e: Tot.als do not inc!ude·.wOod derived fuel consumed &j. the pulp and paper lndusttf which amounted to an esUmaied 1.0 quadrillion Btu in the United States in 1978. Also excludes small quontitk'S of other enel'IY
eourcee for which consist.ent historical data are lio.t availab e, ouch as solar enel'IY obtamed by·the use of'lhermal and phot.ovoltaic collectors; wind en"'lo'Y; and geothermal, bion1ass, and waste energy other than that
consumed at the .e)ectric utilities. . · ·
Consumption of Energy by End-Use Sector, State of Alaska
Trillion Btu
Electric· Total
Residential Comrriercial Industrial Transportation Utilitieo Energy
Consumed
¥ear
Without With Without With Without With Without With
Electricity
Distributed Ji~~tc;t!a. Electricity
Distributed
Electricity
Distributed•
Electricity
-Distributed
Electricity
Distribute<!•
Electricity
Distributed
Electricity
-Distribute<!•
1960 3.017 5.724 17.22.5 19.377 18.403 19.285 29.448 29A77 0.527 73.863
1961 3.388 6.057 19.!56 21.276 24.5.51 25.421 33.258 33.28R 0.407 86.042
1962 3.829 6.470 16.b76 18.774 28.110 28.970 36.089 36.119 0.410 90.3:!:!
1963 3.924 6.554 17.172 19.264 27.100 27.957 35.005 3S.032 6.548 SR.RO!l
1964 4.573 7.497 18.022 20.376 26.928 27.794 35.400 35.427 8.695 91.094
1965 4.933 8.318 19.100 22.174 23.619 24.298 37.756 37.782 9.817 92.573
1966 5.57S 9.395 16.979 20.467 35.350 36.080 39.488 39.517 11.100 105.460
1967 5.879 9.907 19.474 23.287 39.057 39.784 46.070 46.098 12.767 ll9.076
'1968 6.448 10.996 19.1.59 23.515 40.093-40.870 49.572 49.602· 14.243 124.984
1969 8.378 13.546 24.663 29.475 54.844 55.221 57.831 57.861 16.325 156.103
1970 10.088 16.253 27.095 32.659 52.369 53.552 78.13-4 78.166 18.852 180.631
1971 11.952 19.354 32.317 38.868 52.998 54.239 86.878 86.910 21.808 199.371
1972 12.830 20.147 33.394 40.303 63.247 64.690 84.767 84.8ll 24.142 209.951
1973 10.193 "18.212 30.847 38.892 60.508 61.948 72.473 72.519 26.717 191.571
1974 9.197 18.114 31.376 40.040 59.944 61.405 75.714 75.767 27.959 195.325
1975 15.278 25.873 32.393 40.106 74.926 80.650 79.874 79.917 32.426 226.546
1976 16.462 28.006 34.528 43.314 82.887 88.807 88.%7 88.844 36.500 248.970
1977 16.927 29.605 37.283 46.897 109.558 116.547 93.743 93.788 39.004 286.836 > 1978 18.955 32.043 40.053 50.071 128.103 135.3-47 98.556 98.581 40.033 316;042
I w I Including electrical -energy losses incurred in the generation and transmission or electricity.
Note: Totals may not equal sum of components due to indc~ndent rounding. •
Note: Totals do not include wood derived fuel consumed y the pulp and paper industry which amounted to an eotimated 1.0 quadrillion Btu in the
United Stotes in 1978. Also excludes small quantitieo of other energy sourceo for which consistent historical dato are not available, such ao solar ene~
:r~:ri~u~fit\~. use of thermal and photovoltaic collectors; wind energy; anc.t geothermal, biom.F.UIU, and w~te enel'l)' other than that c:onaumed at
Consumption of Energy by the Commercial Sector, State of Alaska
TRILLION BTU
Natural Electri· Electri· Total cal Coal Gas Petroleum city Energy Energy
Year !Dryl Sales Loeaes• Consumed
Bitu· Distil· ToW minous Anthra· Total Asphalt late LPG• Motor Residual Road Petro-Coal and cite Coal Fuel Gaso!ine Fuel Oil leu.m Lignite
"1960 1.110 0.000 1:11o 0.000 o·.312 7.495 0.028 6.703 1.578 0.000 16.115 0.615 1.037 1!1.377
1961 1.109 0.000 1.109 0.12?. 0.555 7.849 0.051 8.022 1.448 0.000 17.925 0.614 l.f>06 21.276
1962 1.327 0.000 t:327 0.019 0.489 8.307 0.037 5.434 1.06-1 0.000 15.3:10 0.614 1.4R:I 1H.77-1·
1963 O.R61 0.000 O.R61 1.664 0.589 8.673 0.046 4.496 0.843 0.000 14.647 0.615 1.•177 l!J.2(H
1964 0.672 0.000 O.li72 l.!lH7 0.791 9.571 0.060 4.183 0.758. 0.000 15.364 0.691i l.(iriK 20.:1'/li
1965 0.602 0.000 0.602 2.343 0.878 9.360 0.065 4.574 1.279 0.000 16.155 0.904 2.170 22.174
1966 0.763 0.000 0.7ti:l 2.647 1.644 . 10.104 0.064 0,401 ' 1.353 0.003 ·13.5G9 1.023 2.466 20.467
1967 0.699 0.000 0.699 2.809 0.832 10.443 0.074 3.264 1.352 0.000 15.966 1.123 2.690 23.287
1968 0.574 0.000 0.574 4.859 0.740 11:344 0.079 1.467 0.082 O.ot5 13.726 1.284 3.072 2:1.515
1969 0.559 0.000 0.559 11.360 0.963 10.528 ·0.059 1.050 0.138 0.006 12.744 1.415 3.397 29.475
1970 0.399 0.000 0.399 12.907 1.808 10.390 0.067 1.294 0.220' 0.009 13.789 1.622 3.942 32.6.~9
'1971 0.353 0.000 0.353 14.698 1.949 14.491 ' 0.077 0.591 0.138 0.020 17.266 1.907 4.644 38.868
1972 0.452 0.000 0.452 16.443 2.116 11.7.86 0.084 2.335 0.126 0.052 16.499 2.02.1 4.885 40.303
1973 0.241 0.000 0.241 12.523 1.580 14.178 0.124 2.078. 0.082 0.042 18.083 2.350 5.695 ' 38.892
1974 0.275 0.000 0.275 13.421 1.397 13.727 O.D78 2.169 0.069 0.241 17.680 2.501 6.163 40.040
1975 0.278 0.000 0.278 14.703 1.976 13.055 0.060 2.182 0.000 0.139 ' 17.412 2.229 5.483· 40.106
1976 0.231 o:ooo 0.231 14.461 1.915 16.120 0.064 1.526 0.000 0.192 19.836 2.554 6.232 43;314
1977 0.235 0.000 0.2.15 14.841 2.191 17.254 0.052 2.505 0.000 0.205 22.207 2.771 6.842 46.897
> 1978 .o.ooo 0.000 0.000 15.451 2.065 20.561 0.100 1.860 0.000 0.016 24.601 . 2.903 7.115 50.071
I
\.)1
PHYSICAL UNITS
Natural Electri-
Coal Gas Petroleum city
·(Dryl Sales
Bitu· Distil· Total Year minous Anthra· Total Asphalt late LPG• Motor Resldunl Road Petro-Coal and cite Coal Fuel Gasoline Fuel Oil !cum Lignite
Billion ~
Thousand Short Tons Cubic Thoiasand Barrela Kilowatt
Feet Hours
19f.O 42 0 42 0 47 1237 7 1276 251 ·o 2868 180
1961 ' 42 0 42 118 84 1347 13 1527 2.~0 0 3201 180
1962 50 0 50 . 18 74 1426 9 1034 169 0 2713 ISO
1963 32 0 32 1614 89 1489 11 856 134 .o 2579 180
1964 25 0 25 1925 119 1643 15 796 121 0 2694 204
1965 22 0 22 2270 132 1607 16 871 203 0 2829 265
1966 29 0 29 2562 248 !735 16 76 215 o. 2290 300
1967 26 0 26 2722 125 1793 18 621 215 0 2773 329
1968 21 0 21 4713 111 1947 20 279 13 2 2.173 376
1969 21 0 21 11018 145 1807 15 200 22 1' 2190 415
.1970 15 0 15 12519 272 1784 17 246 35 i 2356 475
1971 13 0 13 142.';6 294 2488 19 112 22 8 2938 559
1972 17 0 17 16011 319 2023 21 444 20 ·8 2836 593
1973 9 0 9 122'17 238 2434 31 396 13 6 3118 689
1974 II 0 11 13106 210 2367 19 413 11 36 3047 733
1975 11 0 11 14415 298 2241 15 415 0 21 2990 653
1976 9 o. 9 14191 289 2767 21 290 0 29 8396 748
1977 9 0 9 14564 ~30 2V62 13 477 0 31 3813 812 1978 0 0 0, 15208 311 3530 25 354 0 2 4222 851
'.Incurred in the gl"nern.t.io~ and transmi~ion·of electricity:
1 Liquefied petrolcun1 gn.ctes, including ethane.
Note: Totals mny not equal :sum of components Cue to inde!pendcnt ro·t,nding. .
Note: Excludes ~moll c;uantiti(!S of other energy sources for which-consistent hi'!torical data are not avaiblh1c, sud! aa solar energy obtained by. the \U'e of thermal and
photovoltaic collectors; wi~d enei-gy; and geothennnl, biomass, and was~ e.nergy.
Consumption of Ene~:gy by the Industrial Sector, State of Alaska
TRILI.ION BTU
Natural Hydro-F.lectri· ·Eitctri· Total
Coal cal Gas Petroleum electric city F.nergy Encrl.'Y
<Dry) Power Sales Consumed
Year LoSSt•s1
Bitu· Distil· ·Other Total minous Anthra· Total late . Jet Kero-LPG• Lubri· Motor Residual Petro-Petro-Coal and cite Coal Fuel Fuel sene 'cants Gasoline Fuel leum leum Lignite Products
1960 6.660 0.000 6.660 1.800 2.485 0.000. 0.511 0.024 0.092 0.000 2.764 4.021 9.887 0.000 0.252 O.G:IO 19.2Rf,
1961 12.242 0.000 12.242 1.934 2.716 0.000 0.185 .O.oi5 0.089 0.000 . 2.471 4.898 10.375 0.000 o.2r,2 0.618 2li42l"
1962 14.643 0.000 14.643 3.399 2.229 0.000 0.119 0.011 0.093 0.000 3.285 4.:l:l0 10.068 0.000 0.252 oJ;os 28.!170
1963 12.921 0.000 .12.921 2.268 2.921 0.000 0.129 0.001 . 0.093 0.000 3.637 5.130 11.911 0.000 0.2!)2 O.li05 27.9fi7
1964 12.107 0:000 12.107 2.239 3.479 0.000 0.000 0.004 0.098 0.000 4.109 4.891 12.581 0.000 0.256. 0.610 21.794
1965 8.741 0.000 8.741 1.794 3.864 0.000 0.000 0.003 0.101 0.432 3.741 4.953 • 13.0~4 0.000 0.200 0.4~0 2·1.298
1966 17.2'.17 0.000 .. ib:~~~. .4.204 4.489 0.000 0.000 0.058 0.105 0.553 4.336 4.307 I:I.~·IH 0.000 0.214 . 0.516 ,16.0KO
1967 20.953 0.000 2.816 6.816 0.000 0.000 0.005 0.095 1.315 2.698 5.360 15.288 0.000 0.214 0.513 39.7K-1
1968 17.657 0.000 17.657 5.026 6.914 0.000 0.006 0.000 0.104 0.843 4.355 5.190 17.411 0.000 0.229 0.548 40.870
1969 13.783 0.000 13.783 21.073 7.794 0.000 0.006 0.297 0.106 0.860 5.151 5.276 19.488 0.000 0.258 0.619 55.221
.• 1970 12.134 0.000 12.134 20.096 8.423 0.000 0.079 0.443· 0.106 0.561· 5.300 5.227 20.138 0.000 0.345 0.838 53.552
1971 13,353 0.000 13,353 19.637 7.776 0.000 0.079 0.526 0.106 1.012 4.942 5.566 20.007 0.000 0.361 0.880 64.2:!9
1972 11.647 0.000 11.547 29.141 5.499 0.000 0.045 0.629 0.113 4.356 5.653 6.257 22.558 0.000 0.423 1.021 64.690
1973 13.119 0.000 13.119 30.386 4.992 0.000 0.045 0.495 0.127 0.598 4.413 6.332 17.002 0.000 OA21 1.020 61.948
1974 11.227 0.0,00 11.227 29.059 6.885 0.000 0.159 0.595 0.121 0.502 4.690 6.706 19.659 0.000 0.42"~ ·1.039 61.405
1975 13.675 0.000 13.675 41.035 7.567 0.000 0.132 0.967 0.108 0.557 3.810 7.027 2.0.217 0.000. 1.655 4.069 80.650
1976 12.121 0.000 12.121 43.470 12.931 0.000 0.196 1.680 0.119 0.630 3.093 8.547 27.297 0.000 1.721 4.199 88.807
1977 8.129 0.000 8.129 67.904 15.663 0.000 0.242 2.480 0.125 0.653 8.697 10.666 33.52a 0.000. 2.015 4.974 116.547
1978 0.000 0.000 0.000 94.522 14.548 0.000 0.238 2.697 0.134 0.611 3.973 11.080 33;581 0.000 2.099 5.145 135.347 :r
"' PIIYSICA.L UNITS
Natural Hydro-Electri·
Coal Gna Petroleum electric city
"(Dry) Power Sales
Year Bilu· Distil· Other Total minous Anthra· Total Jet Kero-Lubri· Motor 1lesidual Petro-
Coal and cite Coal late Fuel sene LPG" can !II Gasoline Fuel leum 'Petre>-
Lignite Fuel Products leum
~
Thousand Barrels Million Thousand Short Tons • Cubic Kilowatt Hours Feet
1960 249 o· . 249 1793 427 0 90 6 15 0 438 62"Z 1598 0 74
1961 459 0 459 1869 466 0 33 4 15 0 393 756 1667 0 74
1962 549 0 649 8284 383 0 21 s 15 0 522 722 1667 0 74
1963 484 0 4K4 2200 501 0 23 0 15 0 578 929 2047 0 74
1964 45:1 0 453 2170 597 0 0 1 16 0 654 933 2201 0 75
1965 327 0 327 1738 662 0 0 1 17 32 595 962 2318 0 a9
1966 646 0· 646 4070 771 0 0 15 17 105 690 976 2574. 0 63
1967 783 0 783 2728 999 0 0 1 16 250 429 1127 2821 0 63
1968 659 ·-0 659 4874 1187 o· 1 0 17 180 693 11Rl 3239 0 67
1969 514 0 514 20439 1338 0 1 74 17 164 819 1316 3730 0 76
J970 . 452 0 452 19492 1446 0 14 110 18 107 843 1321 3859 0 101
1971 492 0 492 19047 1.335 0 14 181. 17 193 786 1467 3943 0 106
1972 429 0 429 28375 944 0 8 157 19 829 900 1595 4452 0 124
1973 4K9 0 489 29790 857 0 8 123 21 114 702 1526 a:u;t 0 12a
1974 430 0 430 28378 1182 0 23 148 20 -96 746 1657 3876 0 124
1975 530 0 530 40230 1299 0 32 241 18 106 606 17a2 4054 0 485
1976 469 0. 469 42659 2220 0 85 419 20 120 492 2114 5419 0 [,04
1977 312 0 312 66638 2689 0 48 618 21 124 58l! 2445 6528 ·o 590
1978 0 0 0 93033 2549 0 (2 672 22\ 116 6:12 26fi5 66K9 0 615
I Incurred in generation and transmission or electrici~y.
~ Uquel'il>d petroleum gnses, includin~ ethane.
Nott>: Totals do not include wood denved fuel consumed by the pulp and paper industry, if any, whieh amounted to an estimated 1.0 quadrillion Btu in the United Stutes in 1978. Also excludes small
q~nnUtics of other energy sources for which ~nsistent ·historical dat.Q. are not available, such as solar energ)' obtained by the use of thermal and photovolt.D.ic collectors; wind energy; and geothermal.
b1omass. and wuste energy.
Consumption of Energy by the Transportation Sector, State of Alaska
TRILLION BTU
Bitu·. Natural Electri• Electri• Total minoua Goa Petroleum city col Energy Coal and Energy
Yeer Lignite• !Dry I Sales Loeaea' Consumed
Aviation Distil· Jet Lubri; Motor Reaidual Total
late LPG' Petro-GD.Soline Fuel Fuel cants Gaaoline Fuel leum·
1960 . 0.117 0.002 5.581 3.142 12.127 0.000 0.419 7.963 0.096 29.329 0.008 0.021 29.477
1961 0.057 0.049 5.992 3.665 14.322 0.000 0.406 8.659 0.108 33.152 0.009 0.021 33.288
1962 0.060 0.075 5.335 3.798 17.128 0.000 0.427 9.142. 0.125 35.955 0.000 0.021 36.119
1963 0.049 0.043 4.068 . :.:.340 17.476 0.000 D.427 9.413 0.189 34.913 0.008 O.OIR 35.032
1964 0.046 0.000 3.584 3.397 18.120 0.001 0.448 9.6116 0.119. 35.354 0.008 0.019 36.427
1965 &:m 0.000 3.034 4.606 18.217 0.001 0.461 10.997 0.~11 37.727 0.008 O.OIR 37.7R2
1966 0.000 2.fi05 4.862 22.200 0.001 0.479 9.!05 0.283 39.436 0.008 0.020 39.517
1967 0.051 0.000 3.474 5.029 27.305 0.001 . 0 .. 432 9.509 0.269 46.019 0.008 0.020 46.098
1968 0.039 0.000 3.8S6 s.4r><r 30.705 0.000 0.474 9.273 0.276 49.533 0.009 0.022 49 .. 602
1969 0.023 0.000 3.071 4.753 38.051 0.001 0.477 ~0.706 0.748 57.808 0.009 0.021 57.861
1970 0.020 17.842 2.297 5.819 38.908 ·0.002 0.486 11.911 0.849 50.272 0.009 0.023 78.166
1971 O.DI8 17.743 1.995 8.248 43.598 0.002 0.483 13.339 1.452 69.117 0.009 0.023 86.910
1972 0.012. 9.021 2.031 12.950 46.037 0.000 0.517 12.666 1.534. .75.734 0.013 0.031 84.811
1973 0.009 0.173 2.077 10.875 42.567 0.000 0.579 14.118 2.075 72.290 0.014 0.033 72.5!9
1974 0.006 0.113 2.386 11.720 42.861 0.000 0.554 15.948 2.125 75.595 0.015 0.038 75.767
1975 0.002 0.096 2.337 12.256 42.347 0.000 0.491 !9.2!5• 8.131 7U76 0.012 0.030 79.917
1976 0.001 0.153 1.6&1 16.677 41.874 0.000 0.545 22.520 5.344 88.843 0.014 0.033 88.844
1977 0.001 0.265 1.854 !6;734 44.798 0.000 0.570 22.291 7.230 93.478 0.013 0.032 93.788
1978 0.000 9.190 2.2'.13 15.553 46.296 0.000 0.613 2L341 12.341 98.356 0.007 0.018 98.561
:r
-....! PHYSICAL UNITS
Bitu• Natural Electrl-minoua Gaa ' Petroleum ~ Coal and <Dry! Lignita•
Yeer Aviation Distil; Jet Lubri·. Motor Realdual Tatsl
Gaaoline lata Fu.el LPG' cai\ti Gaaoline Fuel Petro-
Fuel leum
~Biilio;" ~
Short Cubic Thouaand Barrels Kilowatt
Tons Feet HouiS
1960 4 2 1106 539 2251 0 69 1516 15 5497 2 1961. 2 47 1187 629 2640 0 87 1648 17 6189 3
1962 2 72 1057 652 3144 0 70 1740. 20 5683 3
1963 2 42 806 573 3208 0 70 1792 so 8480 2 -1964 2 0 710 686 3325 0 74 .• 844 19 6555 2
1965 I 0 601 791 3327 0 76 2094 65 6954 2
1966. 2 0 496 835 4031 0 79 1733 45 7219 2
1967 2 0 6lUl 863 4955 0 71 1810 43 8431 2
1968 1 0 665 936 5573 0 78 1765 44 9050 3
1969 1 0 608 816 6848 0 79 2036 119 10503 3
1970 I 17306 455 999 6979 0 80 2268 135 10916 3
1971 1 17210 . 395 1416 7806 0 80 2539 231 12467 3
1972 0 8784 402 2223 8227 0 85 2411 244 13593 4 1973 0 170 411 1867 7604 0 95 2686 330 12996 4
1974 0 110 473 2012 7661 0 91 3036 338 1~11 4
1975 0 94 463 2104 7567 0 81 3656 498 14870 4
1976 0 100 33.1 2!'63 7476 0 90 4237 850 15900 4
1977 0 2GO 3G7 2373 7991 0 94 4244 1150 16719 4
1978 0 187 440 2570 8258 0 101 4063 1963 . 17495 2
• No anthracite is.consumed by the transportation sector.
'Incurred in the generation and :transmission of electricity.
'Liquerwd petroleum gases, including cthttne.
Not.c: Totala may not equal sum of components due to independent rounding. .
N~te: Excludes small quantities of other energy sourcea for which conaistent hiatoricol data are not available, llllCb aa oolar energy obtained by the uae Q(
therm~l and phot.ovoltaic collectors; wind energ)'; and geothermal, biomass. and waste enell)'.
~ '~ . ~~
Consumption of Ene-rgy by the Electric Utilities, State of Alaska
TRILLION BTU
Natural Hyd,..,.. ~uclear Geo-Wood Total
Coal Gas Petroleum electri~ Electric thermo! and Energy
!Dry) Power• Power Power Woste Consumrd
Year Bitu-Distil· Pet ...... Toial minous Anthra· Total Jet Rea!dual
Coal and cite Coal lote Fuel I cum Fuel P~tro-
Lignite Fu~l Coke leum
1960 0.000 0.000 0.000 0.000 0.514 0.000 0.000 0.013 0.527 0.000 0.000 0.000 0.000 0.527
1961 0.000 0.000 0.000 0.000 0.363 0.000 0.000 0.044 0.407 0.000 0.000 0.000 0:000 0.407
1962 0.000 0.000 0.000 0.000 0.410 0.000 o.ooo 0.000 0.410 0.000 0.000 0.000 0.000 0.410
1963 1.485 0.000 1.485 0.995 0.657 0.000 0.000 0.000 0.657 3.410 0.000 0.000 0.000 6J>4N
1964 2.278 0.000 2.278 1.649 1.368 0.000 0.000 0.025 1.393 3.374 0.000 0.000 0.000 8.695
1965 2.697 0.000 2.697 2.218 US! 0.000 0.000. 0.116 1.247 3.655 0.000 0.000 0.000 9.817
1966 2.702 0.000 2.702 3.983 0.838 0.000 0.0!)0 0.283 1.122 3.293 0.000 0.000 0.000 11.100
1967 2.338 0.000 2.338 4.624 0.954 0.000 0.000 1.064. 2.018 3.786 0.000 0.000 0.000 12.767
1968 2.569 0.000 2.569 5.844 1.033 0.000 0.000 1.017 2.049 3.781 0.000 0.000 0.000 14.243
1969 2.776 0.000 2.776 6.904 2.487 0.000 0.000 0.597 3.084 3.562 0.000 0.000 0.000 !U.325
1970 4.253 Q.!)OO 4.253 8.452 2.208 0.000 0.000 0.132 2.340 3.807 0.000 0.000 0.000 !8.852
1971 4.724 0.000 4.724 10.619 2.633 0.000 0.000 . 8:8~~ 2.658 3.807 0.00.0 0.000 0.000 2!.808
1972 4.298 0.000 4.298 13.448 2.790 0.000 0.000 2.803 3.594 0.000 0.000 0.000 24.142
1973 4.141 0.000 4.141 16.191 3.373 0.000 0.000 . 0.038 3.410 2.973 0.000 0.000 0.000 26.717
1974 4.628 0.000 4.628 17.494 2.4!2 0.000 0.000 0.019 2.430 3.407 0.000 0.000 MOO 27.959
1975 4.472 0.000 4.472 20.129 4.112 0.000 0.000 0.000 4.112 8.713 0.000 . 0.000 0.000 32.426
1976 4.385 0.0?0 4.885 22.715 5.423 0.000 0.000 0.000 5.423 3.978 0.000 0.000 0.000 36.500
1977 4.367 0.000 4.367 24.216 5.077. 0.000 0.000 0.000 5.077 5.343 0.000 0.000 0.000 39.004
1978 4.698 0.000 4.698 25.262 5.149 0.000 0.000 0.000 5.149 4.924 0.000 0.000 o.ooo 40.033
:r
00 PHYSICAL UNITS
Natural Hyd,..,.. Nuclear Geo-Wood
Coal Gaa Petroleum electric Electric thermal and
(Dry) Power' Power Power Waata
Bitu· Diatil· Pet...... Total Year minous Anthra· Total late Jet leum Residual Pet,.· Coal and cite Coal Fuel Fuel Coke Fuel leum Lignite
Biii;;;""
Thouaand Short Tona Cubic Thousand Barrels Million Kilowatt Hours
Feet
1960 0 0 0 0 88 0 0 2 90 0 0 0 0
1961 0 0 (j 0 . 62 0 0 7 69 0 .0 0 ·o
1962 0 0 0 0 70 0 0 0 70 0 0 . 0 0
1963 84 0 84 965 113 0 0 0 118 325 0 0 0
1964 131 0 131 1598 235 0 0 4 239 322 0 0 0
1965 161• 0 151 2149 194 0 0 18 213 350. 0 0 0
1966 163 0 163 3856 144 0 0 45 189 316 0 0 0
1967 134 .o 134 4481 164 0 0 169 333 363 0 0 0
1968 149 0 149 5668 177 0 0 162 339 364 0 0 0
1969 163 0 163 6696 427 0 0 95 L2'l 341 0 0 0
1970 249 0 249 8198 379 0 0 21 400 363 0 0 0
1971 274 0 274 10300 452 0 0 4 456 363 0 0 0
1972 247 0 247 13094 479 0 0 2 481 346 0 0 0
1973 238 0 288 15812 579 0 0 6 585 286 0 0 0
1974 .266 0 266 17117 414 0 0 3 417 326 0 0 0
1975 257 0 257 19619 706 0 0 0 706 357 0 0 0 1976 252 0 252 22204 931 0 ij 0 931 383 0 0 0
1977 251 0 251 23534 . 872 0 0 0 872 512 0 0 0 1978 270 0 270 24431 884 0 0 0 884 472 0 0 0
' Includes net imports of eleetricit~. . ·
Note: Totals may not equal sumo components due to independent roundm, ..
APPENDIX B. DISPOSITION OF ROYALTY OIL AND GAS
B-1
TRADING BAY
Statistics relating to this field are shown on the attached table.
Current Status
All Royalty oil produced from this field is taken in kind and sold
to Tesoro-Alaska Petroleum Company.
Gas produced for this field is casinghead gas and was formerly
flared. DOGC Flaring Order Number 104 dated June 30, 1971, has
prohibited flaring since July 1, 1972, and this gas is now
recovered and used locally. This gas is considered to have no
value because the costs of extraction, compression, and
amortization purportedly exceed its value; therefore, no royalty
is p~id, but because of the recent price increases this gas should
be looked at agBin for proper value .
.•
Royalty Oil and Gas Status
Unit: Trading Bay
Location: West Side Cook Inlet (Offshore)
Operator: Union
Owners: Union 1 Amoco, Phillips, Area, Getty
Leases: ADL 17579, 17594, 17602, 18716, 18729, 18730, 18758, 18772, ~8777, 21068
Royalty: 12.5%
Price
Purchaser: $/Mcf $/Bbl
Tesoro
Date Initial Production:
Avg. Monthly Production Rate (10/31/80) gas:
Avg. Monthly Production Rate (11/30/80) oil:
Total Production to 10/31/80 (casinghead) gas;
Total Production to 9/30/79 oil:
Estimated percent produced to 10/31/80
RIV: Royalty in Value
RIK: Royalty in Kind
· 9~87 (as of Nov. 1980)
12-67 (oil)
12-68 (gas) .
122,285 Mcf
133,304 Bbls
51,781,247· Mcf
ap,502,934 sols
87.7% Oil
State Royalty Status
RIV
RIK
--.
KENAI UNIT AND KENAI DEEP
Statistics relating to this field are shown Dn the attached table.
Current Status
The Kenai Unit and Kenai Deep provide most of the gas sales in the
Cook Inlet area. The estimated quantity of Alaska State royalty
gas sales amounts to approximately 127,000 MCF per month. The
State does not receive the full 12 1/2% royalty share because of
the predominance of Federal leases in the unit and the_ recent
conveyance of land to CIRI. T~e price the State ieceives for its
royalty share results from prices paid under existing contracts
between the lessees and their purchasers. Anchorage Municipal
Light and Power has entered into a purchase contract with the
State to purchase its royalty share.
Royalty Oil and Gas Status
Kenai and Kenai Deep
Location:
Operator:
Owners:
Leases:
Kenai, Alaska
Union
Union, Marathon, Area, Chevron, Charles Schraier, Samuel Gray
Fed. A028047, A028055, A028056, A028103, A028140, A028142, A028143
State ADL 22330, 00460, 02397, 00588, 00593, 00594, 02411
Royalty: State's effective rate is 2.06879% from the Kenai Unit, 0% from Kenai Deep.
Purchaser:··
C it y .o f Kenai
Collier Chemical Corp.
Phillips~Marathon LNG
Alaska Pipeline
Rental Gas (Swanson River Oil Field)
Chevron Refining
Date Initial Production:
Avg. Monthly Production Rate (1980)
Cumulative Production to 11/30/80
Estimated percent produced to 10/31/80
RIV: ·Royalty in Value
Royalty Price
$/Mcf
0.29
0.18 & 0.61
0.52
0.52
0.16
0.52
l-62
6,640_,QOO Mcf
1,074,081,577 Mcf
9.9%
State Royalty Status
RIV
..
McARTHUR RIVER FIELD
Statistics relating to this field are shown on the attached table.
Current Status
All Royalty oil produced from this field is taken in kind and sold
to Tesoro-Alaska Petroleum Company.
Gas Produced from this field is casinghead gas and was formerly
flared. DDGC Flaring Order Number 104 dated June 30, 1971 has
prohibited flaring since July 1, 1972, and this gas is now
recovered and used locally. This gas is considered to have no
value because the costs of extraction, cqmpression, and
amortization purportedly exceed its value; therefore, no royalty
i~ paid, but due to the increasing value of this gas the net value
should be reevaluated.
Royalty Oil and Gas Status
McArthur River Field
Location: West Side -Cook Inlet (Offshore)
Operator:
Leases:
Royalty:
Purchaser:
·I
Union
ADL 18777, 17579
12.5%
Tesoro
Date Initial Production:
Avg. M.onthly Production Rate
Avg. Monthly Production Rate
Total Production to 10/31/80
Total Production to 10/31/8'0
(to 10/31/80)
(1980) oil:
(casinghead &
oil:
Estimated percent produced 10/31/80 (gas):
Estimated percent pr6duced 10/31/80 (oil):
RIV: Royalty in Value
RIK: Royalty in Kind
gas:
dry) gas.:
Price
$/M:cf $/Bb.l
8.97 (as of Nov. 1980)
12-67
571,.763 Mcf
1,740,0:29 Bbls
135 1 8 3 5 , 3:7 2 Me f
436,560tl76 Bbls
38%
.-. ,. 81%
State Royalty Status
RIV
RIK
GRANITE POINT FIELD
Statistics relating to this fiela are shown on the attached table.
Current Status
All Royalty oil produced from this field is taken in kind and sold
to Tesoro-Alaska Petroleum Company.
Gas produced from this field is casinghead gas and was formerly
flared. DOGC Flaring Order Number 194 dated June 30, 1971, has
prohibited flaring since July 1, 1972, and this gas is now
recovered and used locally. This gas is considered to have no
value because the CO$ts of extraction, compression, and
amortization purportedly exceed its value; therefore, no royalty
is paid, but due to recent increases in the value of this gas
there should be a reevaluation of this gas."
.. •·
Royalty Oil and Gas Status
Granite Point Field
Location: West Side -Cook Inlet (Offshore)
Operator:
Leases:
Royalty:
Purchaser:
..
Date Initial
Avg. Monthly
Avg. Monthly
Amoco
ADL 17586, 17587, 18742, 18761
12.5%
Tesoro
Amoco Platform (1)
Area (1)
Union (1)
Production:
Production Rate (1980) gas:
Production Rate (1980) oil:
Total Production to 10/31/80 (casinghead)
Total Production to 10/31/80 oil:
gas:
Estimated percent oil produced to 10/31/80:
Price
$/Mcf $/Bbl
0.118
0.10
0.118
12-67
12.00
275,736 Mcf
360,483 Bbls
73,546,506 Mcf
82,836,316 Bbls
":!'1 • . .. : ..
82%
. State Royalty Status
RIV
RIK
Footnotes: (1) Small amount of casinghead gas sold to.Amoco for use on platform,
the remainder has a negative value.
RIV: Royalty in Value
RIK: Royalty in Kind
..
. -.
PRUDHOE BAY
Statistics relating to this unit are shown on the attached table.
Current Status
Small quantities of casinghead gas are presently being sold to the
owners of the Trans-Alaska Pipeline. The State is receiving
royalty in value with the price being set by the owners of the gas
cap. They are using the price established by the Natural Gas
Policy Act of 1978 as their guideline. There presently isn't any
other market. The State's share of sales is 12 1/2%.
The State's royalty share of the oil produced is i2 1/2% with
56.5% of this share prese~tly being taken in kind and sold to
North Pole Refinery, Alaska Oil Company, Tesoro, and Chevron. The
State has requested that an additional 43.4% of the State's share
be taken in kind beginning July 1, 1981, which will go to, in
addition to the current purchasers, Golden Valley Electric
Association, Sh~ll, Union, Alaska Petroleum, .Oasis Petroleum, and
Energy Cooperative Incorporated. The remainder w~ll continue to
be taken in value which will be fully decontrolled by October 1981.
Royalty Oil and Gas Status
Unit: Prudhoe Bay
Location: Northslope (Onshore)
Operator: Arco-Sohio
Owners: See Attachment
Leases: See Attachment
Royalty: 12.5%
Purchaser: Price
$/Mcf $/Bbl
TAPS Owners 1~37
Topping Plant, Power-plant, & Pump Stations
Avg. Well Head Price 16.94
Date Initial Production:
Avg. Monthly Production Rate
Avg. Monthly Production Rate
Total Production to 10/31/80
Total Production to 10/31/80
Estimated percent produced to
Estimated percent produce~ to
RIV: Royalty in Value
RIK: Royalty in Kind
(1980) gas:
(1980) oil:
gas:
oil:
10/31/80:
10/31/80:
10-69
50,363,142 Mcf
46,448,708 Bbls
1,34~,185,727 Mcf
1.469;173,383 Bbls
18% oil
9% gas
(as of Oct 1980)
State Royalty Status
RIV
RIV RIK
'-.
Oh'NERS
~da Hcss-Amcr:-a~la Ifcss CorpOJ·.aflon
J:n.co.~--A-fJ:-aJ;i-ic Ril:~ifirJd. C~ii~1;ai;y. :· :·-. · ..
.. .. . . . . .. ·~ . .. : . .. . . .. . . . . .
13P Al:l~ka·-BP J\1ns'ka J~xpi_oration T11c. · . . . . . . .
Chcnon--Chc\T~n U.S.A., Inc. . . . -. . .
Exxon_.:._ Exxon Corporn fion -'. : . . ·.. . . . . ....
Gcttr-~Gefty oitdo;npany ..
H u;1l Ind.-· Hunl.Ii~cluslries···-.....
Cnrolinc nu·l~l T~-~Caroli\le.Ifunt Tnisl l'~sfate
· L:-amar Hunt Tr. Est.-L:~mar Hmit" Trust Estate
N. B. Hnnt-· N. B. Hnnt .... _-
\Ym. tfcrbcrt Hnnl Tr.-\Villi;un Herbert Hunt Trust Esfafe
LL<t·.E-'fhc Lo~1ishna Land :-~ncl }~xpJo.r:lfion Company
Maraflwn-:Marnfhon Oil Company
"Mobil-Mobil Oil Corporation
Phillips-Plti1lips Petroleum Company.
PJ:-acid-PJncid Oil Company
Sohio--Sohio Pcfrolcun; Company
LEASES
ADt. · .. _. \\'orling----......
No. of Sni:~l Ba~ic . :u-~~cc O.R.R. lnlcrest
. Dl-~C~j~li~ Acres No. Ropl!y . ·of Rl·c:ord Inll'll"l>l Owncrsl!ip ·
( Umi.~_t Mcridi:m~ ~bsh)
TJ 2~-Rl1 F.:, Sees. 9. 10". .' 1,280 . 41445 l/8 ~!obi1 :~nd Chcnon ~!obil-50% . Chc,·ron-50% ..
TI2N-Rl1E,Secs.IJ,l2. I,2SO 28235 l/8 A.R.Co. and Exxon A.R.Co.-50%
Enon-50%
Tl21X-Rl2E, Sec.7 .. 580 28254 l/8 A.R.Co. ~nd Exxon A.R.Co.-50%
F.:non-50%
Tl2N-R 15E, Sec. ~3. 24 1,2SO '34625 1/8 Sohio Petroleum Co. • Sohio-100% ..
TI2l\'-RJ5E, Sees. 21.22 1~280 34626 ·1/8 ~.R.Co, :tnd Exxol\ A.R.Co.-50%
Exxon-SO%
Tl2N-RlSE, Sces.l9, 20 1,225 34621 1/8 A.R.Co. and Exxon · A.R.Co.-50%
•Enon--'50%
Tl2N-Rl.JF., Sl·es. 23,24 1,280 3.4624 1/8 A.R.Co. and Exxon A.H.Co.--50%
Enon-50%
T!2~-Rl4E, Sec. 22 610 28297 1/8. .A..R.Co. ::md Enon A.il.Co.-50%
' Exxon-50%
Tl2N-R13E, Sec. 19 585 17469 . 1/8 Mobil :md Phillips ~!ohil-50%
J'J,iiJips-50%
! Tl2N-Rl2E, St'es. 23,24 1,280 11448 1/8 ~!obi! and Phillips ~!ohil-662).,%
Phillips;---33 1h% ·
Tl2N-_Rl2E, Sees. 21,22 1,280 28256 1/8 A.R.Co. and Enon A.R.Co.-50%
Enon-:50%
T12N-Rl2E,Sees. 17, 18, 19,20 .2,148 28255 1/8 ·A.R.Co. :md Exxon A.ll.Co.~SO%
E:non-50%
3 T12N-RllE, Sees. 13,14, 23,24 2,560 28237 1/8 A.RCo. aod Enon A.R.Co.--50%
Enon-50% .. Tl2N-Rll E, Sl·es. 15, lG, 21,22 2,560 41441 1/8 ~!obi! ;mrl Chevron ~!oLil-50%
Chev•on-50'7..
5 TI2i':·RIJE, St'es. 17, 18, 19,20 2,4-18 ·!(446 1/8 Mobil and Clacnon ~!ohil-'-50%
\.J.l., ron-50%
.6 Tl2N-RlOE, Sees. 13,24 1,280 25637 l/8 A.RCo., DP .-\t:.~h. A.R.Co.--50%
Sohio Petroleum llPAI:t~h-
Co. 37~%
Sohio-J 2 ~!z%
17 Tl2N-Rl l E, Sees. 29, 30, 32 l,S68 17449 l/8 l\!obit"and Chnron ~lnLil-50%
ChlTr cm-5U'7o
18 Tl2N·R11E, St·Clt. 27, 28, 33,34 2,560 28239 l/8 A.R.Co ... :md Euon A.H.Co.~50'7o
Ex.\on-SU7o
. 19 Tl2N-Rl J E, SL·cs. 25, 26, 35, 3G 2,560 2!:!238 l/8 A.R.Co. :1ncl Euon A.ll.Co.-50%
El\on-507..
20 Tl2N-HJ 2E, Sl·es. 29, 30, Jl, 32 2,459 28259 l/8 A.R.Co. :~ntl Enon .A.H.Co.-50'7o
Enun-50'h.
21 T J 21\' -H J ~E. Sees. 27, 28, JJ, 3·1 2,560 28258 l/8 All. Co. anti Exxon .A.H.Co.-50%
Euon-50'7..
22 TJ~N-1\121~. S,·l"!:. ~. 35, JG, 2,·100 28257 1/8 Mohil ;md Phillips· l\ !ul.il-50%
N/2 aml SE/4 Sl'c. 26 l'l•illips-50%
"See comment on pa!;e A-5.
: .
_::_ __ ;_ ___ __,X:"I"I}'I'f"L----:-:---. -·-----
\\'orling
Tract
No~
:-:o. or
Ancs
Scri.;\1
~o.
(Umiat !>fcri<li:m, ,\b~h)_: ;;·.< ~< :
· . 22A !l_~~-Il_I_2E, S\\"/-1 Sec .. 26 160 _ 28257
. -·· ~· ~ .. . . -
23 Tl2X-Ill3E, SI'C!'. ~9. 30, 31,32
24 TJ~X-Rl1J-:, Sec-!>. 27, 2S, 33,34
2.5 Tl2;\'-Rl3E, Sl·t.-s. 26, 35,36
26 Tl~;\'-Rl4 E,_Sces. 29, 31,32
2,-159
2,560
1,920' _.
1,871-
; J •.
-28279
28278.
28277
2.8299
27 T12;\'-RJ.fE, Sees. 27, 28, 33, 34. 2,560 28300
-28 TJ2X-Rl4E, Sees. 25, 26, 35, JG 2,560 28301
29 T12~-R15E,Sres:29,30,31,32 2,459. 34628-
30 T12~-R1SE, Sees. 27, 2S, 33, 34 2,560 · 34629
31 T12X-R 15E, Sec-!:. 25, 26, 35, 36
32 T12i"\-RIGE, Secs. 2!1, 30, 31,32
33 T12X-Rl6E,See!'.2i,28,33,34
34 Tl 2:\-R HiE, Set·~-2.5, 26, 3.5, 36
35 Tlll\-Hlf>E, Se~. 1, 2, ll, 12
36 TllN-RlllE, Sccs .. 3, -1, 9, 10
37 T1 l i'\-R l f>E, S,·e~. 5, 6, 7, 8
38 Tlli'\-H15E, Sers. I, 2, 11~ 12
39 Tlll\-R1SE, Scrs. 3, 4, 9,10
· 40 Tll:-\:R15E, Sccs.S, 6, 7, B
41 TIIN-RI4E, Sees. 1, 2, 11, 12..
42 Tl1~-RHE, Sees. 3, 4, 9, 10
43 T11~-Rl4E, St'es. 5, 6, 7, 8
44 Tl11\-R 13E, Sees. 1, 2, Jl, 12
45 Tll~-HI3E, Sees. 3, 4, 9, 10
46 Tl1;\'-Hl3E, Sc1-s. 5, 6, 7, 8
47 T11~-BJ2F.,Sces.l,2,11,12
48 TllN-R I 2£, Sees .. 3, 4, 9, 10
49 TlJN-Rl~E. Sees. 5, 6, 7, 8
SO TllN-RllE,Sccs. 1,2, 11,12
51 Tll~-R1JE, Sl't-s. 4, 9,10, N/2
antl S\\'/·1 St.·c. 3
SlA TllN:R~ 1 E, SE/4 Set:; 3
•see comment on p;a~;c A-5.
2,560
2,459
2,.'560
2,560
2,SGO
2,560
2,-169
2,560
2,560
2,469
2,560
2,560
2,469
2,560
2,560
2,469
2,560
2,560
2,469
2,560
2,400
160
34630
3-1635
3-1634
341>33
34636
2$337
28338
28320
34631
34632
28302
28303
28304
28280
28281
28282
28200
28261
47450
28240
282-il
28241
D:uic.
Ro~·alt)'
J..c,:-CC •
of Rec.:ord
.·
l/8 )..!nhil, J'liil!ips,
Chen on
1/8 Sohio Pc.!Jnlcum Co.
l/8 Sohio. f'drnlnun Co.
1/8 Snl•io Petroleum Co.
1/8 A.R.Co. ;md E:oon
1/8 A.R.Co. ;md Exxon
1/8 A.R.Co. :md F.:x,on
1/8 A.ll.C--1>. and Ex~on
l/8 A.R.Co. amlE:uon
l/8 Sol•io f'c.:lrnleum Co.
1/8 Snhio f'drnlcmn Co.
1/8 Sohio l'l'lloleum Co.
1/8 Sol•io f'droh-um tAl.
1/8 Sohio Pdrolc-m~ Co.
1/8 Sol1io f'clrolcum Co.
1/8 Sohio Petroleum Co.
1/8 Sohio f'drokmn Co.
1/8 A.R.Co. and E:uon
1/8 A.R.Co. and Ex:-.on
liB · A.R.Co. and Exxon
1/8 · A.R.Co.,and E:-.,on
1/8 A.R.Co. and Enon
1/8 Snhio f'rt.olcum Co.
1/8 Sol1io Prtmlt.-um Co.
1/8 Sohio l'drol<-um Co~
1/8 Snhio Pdrnh-urn Co.
l/8 J-!ohil :t;,d Phillips
1/S l\lohil, pJ,iJlips,
Clac\'ron .
1/8 A.Jl.Co. :tnd Enon
l/8 J-fohil ;md Phillips
1/8 ~lol•il, Phillips,
Chc-Hon
O.ll.R. lnkrnt
lnlcrrst Owner~hip
~!nhiJ-33~~%
Phillips-33 1!..%
Clu:non -33 1.~ '7o
• Sohio-l 00%
• Snllio-1 00%
• · Snllio-100%
A.R.Co_...:.....:;o%
F.noh-'-50'7..
. A.ll.Co.-50%
F.non-50%
A.R.Co.-50%
F.:non--50%
A.H.Co.-50%
E:o.on-50%
A.R .. Co.-50%
En on-SO%
SolJio-100%
Srihio-100%
Sohio-lClO%
•
S"),io-100%
Sol •io-:1 00%
• · S"hio-100%
Snhio--1 00%
•
•
•
•
•
Sol1io -100%
A.Jl.Co.-50%
Ex~on-50%
A.R.Co.-50'7..
Enon-50%
A.R ·co.-50%
Exxon-50%
A.R.Co.-50%
Enon--50%
A.n.Co.-50%
Enon-50<;0 ·
Snl1io-1 00%
Snl1io-I OO'iO
Sohio-JU0'7o
Snhio-100'7..
!>fol,ii-SO';;.
I'hillips-,50%
~ f ohil-33 1.3 <;.,
l'hillip~...:-3J ~3 o;;,
Clal·nun--33 '.3 <;.,
A.RCo.-50%
EnotJ-:iO'i ..
:-lol•il-50%
J'hillips--50%
:-!ohil-33 ~s 7o
l'hillips-33 1.-J 'i'o
Chc,:ron-33 ~%
• . ... .. ·... ADL.· • . ~o. of · Seri:~.l 11asic .... · ·· Tr:~d
No. Acres ~o. • Royalty ·.
T..c~~cc ·
of 11ccord
-(l"mia! :'\krioian, Al;~l:_a.} ':..·· . .-· · · · · • ·
52 Tll~~mJE,Scc."Js·>·. • · . 6-10. 2S244 1/8 .. ._., . , . ~--:. . ._ . . .. -... A.R.Co. :~ncl Euon
53 Tl lX-Rll E, See-S. 13, i4~ z4"' .. -1,920 28245 1/8 . A.R.Co. :mel Exxon . -.
1,8·10 2S262
. 6·10 . 282.62
1/8
1/8
54 Tll:--:-R12E, Stc~. 17., 18, 19
54A TllX-RI2F.:, Sr-c;. 2.0 · ", .. ·.--· ; ..
Cl•c,·;on
Chr-nnn, :'\lobil,
Phillips· :-...
55 TH~-Rl2E,Sees.15,16 •
.·.
55A TJ IX-1112E, Sr-es. 21,22 .. 1,280
. -.
28263 ··-1/8 :'\fobil :md Phillips . , . . . . .
2s2s3 -: 1!8. · ~iohil, Pi)illips,
Chevron
..... _.
ss· nt:--:-RJ2F.:, St:cs. 13, 14, 23,24 ·2,560 47451 l/8 ~lohil, Phillips,
Cht•\•ron
57 Tll:--:-R13E, Sre10. 17, 18, 19,20 2,-1SO
58 T11X~I113E, Sr-es. 15, 16, 21,22 2,560
59 TJ 1:--:-11 13E, Sees. 13, 14, 23, 24 2,560
GO T 11:'\-11 l-1F.:, Sec~. 17, l 8, 19, 20 2,-180
61 Tll:'\-11 I4E, Sees. 15,16, 21! 22 2,560
62 Tll~-R14E, Sr-es. 13, 14, 23,24 2,560
63 Tlli\-Rl5E, Sr-es.l7, 1B, 19,20 2,4SO
64 Tlli'-R15E, Sr-es. 15, 16, 21,22 2,560
65 · TllK-R15E, Sc_cs. 13, 14, 23,24 1,560
66 TllK-RlGE, Sees. 17. 1B,19 1,840
67 T11X-RI6E, Sr-cs. 15, 16 ],280
GB Tll 1'-R 1 6E, Sc-r-s. 13, 14 1,2SO
69 T11~-1116E, St·r-s. 30, 31,32 1,851
70 TllX-Rl5E, S<·cs. 25, 26, 35,36 2,560
71 TllX-Rl5E, Sr-r-s. 27, 2B, 33,34 2,560
72 TllN-R15E, Sr-es. 29, 30, 31,32 2,491
73 TllN-Rl4F.:, St'cs. 25, 26, 35,36 2,560
74 T11N·Ill-IE, S<·cs. 27, ~8. 33,34 2,560
75 Tll~-Rl4F.:, Scr-s. 29, 30, :n, 32 2,·191
76 TllN·Rl3E, Sr-r-s, 25, 26, 35,36 2,.5GO
71 Tlll\'-1113E, S<'es. 27, 2B, 3.'3, 3-t . 2,560
78 TllN-R13E, Sc-r-s. 29, 30, 31,32 2,-191 .
79 Tll ~-Ill 2E, Sr-cs. 25, 26, 35, 3G 2,560
•see comment on pal;e A-5.
2S~83 . 1/8
2S284: ·liB
21>285 1/8
28'305 1/8
2S305 1/8
28307 1/B
28321 1/B
28322 1/8
28323 .1/8
28339 1/B
ZB340 1/B
28341 1/8
28343 1/8
28324 1/8
2B325 1/8
28326 .1/8
28308 1/B
28309 1/B
2S310 1/8
2S286 1/B
2S287 • liB
2828B liB
28264 1/8
Sohio Pet rolc-mn Co.
Sol)io Pctrokurn Co.
Soltio Pctrolnrm Co.
Sohio Pet rolc-um Co.
A.R.(:o. ~nd E:non
A.R.Co. :mrl Euon
A:R.Co. :md Enon
A.R.Co. :md Exxon
A.R.Co. :md Exxon
Sol;io Pctwlcum Co.
Sohio Pr-trolc:-hm Co.
So.hio Pr-trolcum Co.
Soltio Pctroletnn Co.
A.R.Co. and Exxon
A.R.Co. and E:~.xon .
A.R.Co. and Euon
A.R.Co. :~nd Enon
Sol.io P<:lrolcnln Co.
SoMo Pc-trolL·nm Co.
Sohio Pctrolr-nm Co.
Sohio Pc-trolr-um Co.
Mobil and Phillips
A.R.Co. :md Euon
O.R.R.
lnkrt·~t
\\"mrm,;-
lnkrcst
O"·nrr~ltip .
•
A.RCo.-50'7..
Ex,on-50%
A.R.Co.-50'7..
Exxon-50';;
·chc:-non-100%
Cl•c,·~on-33 1,) %
~lobil-33 1.3 '7.:
Phillips-33 1.)%
:'\fohil-50~
Phillips-50%
~lohil-33 1.j%
Phillips-33 1,3%
Ch<'non-."33 1.)%
~lohil_:__33~)%
Phillips-3'3 ',) "i'c
Clwnon -3.) 'h '7o
Soltio-100%
Sohio-lOO'k
Sohio-1 00'7o
Sohio-1007o
A R.Co.-50'7o
f:,,on-50%
A.R.Co.-50%
E:nnn-50%
A.R.Co.-50%
Exxon-50%
A.R.Co.--50%
E:~o\Oil-507o
A.H.Co.-50%
Enon-50'7..
Sohio_:_100'7o
Sohio-100%
Sohio--IOO'io
• · Sohio-100%
A.I\.Co.-50';".,
Euon-50%
A.R.Co.-50%
E~ \On-50'7o
A. R.Co.-50<;.,
E:~.,on-50%
A.R.Co.-50%
f:,,on-50';;,
Snhio-IQO'Jo
• Srrhio--JOO'lo
• Sohio--IOO'lo
Soltio-100'7o
~lohil-50%
l'hillips-50%
A.H.Co.-50%
EHon--50'7o
... .
·-
-~---------.rrtc-------·-
Tr;,d .. ·• • . .• ::.-: .;:· • . :"\'o. of Sl·rial n."'~ic . l..c:·~~l'.C I . o.n.n.
\\'nrting -
lnh'11·~t
~wnrr_::l1ip 1-:o. · · D,·,niplion · . Ancs · No. Jloy:~lty • · of ~<·t·ord : !.!'!!~
--_-........ -:..----:--:-.... _ .... '~~---· _-::::;-::--_;_:~-~--._~ · .... :r. -_.·. ··. r .. ;· .... ·_ ..
( l·m•:~l :'\krlll,:~n, Ah-\a} · ·-· .. ·.. . · __ . -·., .· -. . . . . . . ·
~ ·..... .. . . . ~-· ·. .. .. :-· .. :.· . .. .._.:_:.-:. .. . .. . .. .. .. . ... --...
SO Tll~-Hl:?.E,Sl·cs.27,28,33,34 2,5GO 47452 "1/8 1-folJii,Phillips,·:
· · · " . ·. ~ :~· ~·:·:::. i;-~-"~~-. .• . . . _:~ : •. : · · ·· · · Chl·\· ron
•. .,_ .· .
81 Tl 1:-\-Rl~E. St>cs. 29, 30, 31, 32 2,491 47453
-•. .. .
82 T111'\-H 11 E, ~N:. Z5 : ... .' .
83 TlOl'\-RF_E~:~l'cs. 3, 4, 10 .
. -.. -. ---;. .. _ ···-··.
84 TJO:-.'-T\l~E,Sl'es. 1,'2, 11,12
85 TlO~-T\ l.1E, Sc-c:o;: 6, 7, 8, S/2
· :ltHl ::\E/4 Sl'e. 5 · · ·
S5A Tl 0~-!-13E, NW/4 S~c. 5
S6 TlO~-R 13£, S~cs. 3, 4, ?• 10
87 TJO:--:-RJ3E, Sees. 1, 2, 11, 12
88 T10:--:-R 1-lE,.St·l-s. 5, 6, 1, 8
S9 Tlll:--:-HI-IE, Sl'<'S. 3, 4, 9, 10
90 TlO~-Hl-11·:, Scc:o;. 1, 2, II, 12
91 TJ0~-1115E, St'C'S. 5, G, 7, 8
92 TJO:--:-IllSI::, Sees. 3, 4, 9, 10
93 TJO~-T\1SE, Sl'C"S. 1, 2, 11, 12
94 TIO~-HI6E, Sl·L~. 5, G, 7, 8
95 TIO:--:-T\JGE, Sc-cJ;. 4, 9
9G TI0~-1\JC>E, St·c. 16
•sre comment on pace A-5.
.
'
~ ..
G~O 28246
..
1,920 47454
.
2,5GO 2S265
·. .
2,341 •. 28289
1GO 2S289
-2,~60 47471
2,560 47472
;2,501 . 28313
2,5Cl0 28312
2,5GO 28311
2,501 28329
2,560 28328
2,5GO 2.8327
2,501 28345
1,280 . 28344
G·IO 2.8347
1/8
1/8
1/8
1/8
~tol•il, Phillips~
Ch~·\'fO';l
A.R;Co. ;ncl Enon
~fohi( Phillip~
Chevron .... .} -.
A.R:co. :~nd E:nori
"'
l/8 · }.fohil and Phi!Jips.
1/8
'i/8
1/8
1/8
1/8
1/8
1/8
1/8
l/8
1/8
1!8
:..tohil, PhiJlips,
Chen on
Anwr ... b. Ih-ss and
Getty
A.R.Co. aml E:o.xon
Snltio Pt.'l~ol~·•un Co.
Soltin Pd rolr-um Co.
A.T\.Co. :n11l E.uon
A.R.Co. and Exxon
A.rt.Co. :~ml F.non
A.H.C:o. ;uu.l F.non
A.Il.Co. :~ml Exxon
A.Il.Co. and Exxon
•
~ (,,},jJ-33 1.') 'k
Pltillip~-J.)If.J% .
Cia·' rnn-31 1.3 -;.,·
-~l,,hiJ-33 1.3~ -
l'hillips-33 1.3 'k
Chen on -33 1 ) o/o
A R Co. -.50'/'o
E~'on-50'7o
;\ lnhil--33 1,) 'k
l'hillips-33 1.3%
Cl'~'' ron-33',3%
A.R.Co.-SO%
E~~on-50%
:'--!ohil-50% ·
Phillips-50%
;\fohil-33 1,~%
Phillips-33 1.~%
· Che\'ron-33 1,3 '7o
AnH"r~<la
I k.\S-21 o/o
Gcur-~30 5%
LL&-E-13.25-;r,
l'bt id -9. J 25%
N. n. lTnnt-
G .. 11i:2S'7o
llunl lnd.-
.1 SG~5%
C:uolinl' Ilunt
Tr.-3.3%
\\'m. I krbcrt
llunt Tr.-
3.1%
Lam:•r llunt Tr.
F.st.--3.3 '7o
An ... r.~tla
Jh·ss--50%
Ccllr-50% .
A.l\.\.o.--SO%
E"im-50%
Suhio-JOO'lo
Sohin-100%
A.H.Co.--SO'lo
f:, '"n--50%
A.I\.Co.-50%
E• 'on-50'7o
A. 1\.Co.--SO'lo
E'"m-50%
A.J\.C:o.--50%
E' "'n-50'/o
A.J\.Co.-50'io
F."nn--50%
A.I\.C:o.-507o
E>'on-50'7o
--.,DL .----. \\'orting
. O.R.R. . lnlcrc5l;.. r:1Ct .{
~o. • De<cription
.... ·~. ~ .=-. ·-
( Umi:~t ~ft•ric1ian, A ~J<h)
37 . TIO~-HJGE, S("es. 17, 18, 19,20
38 TIO:'X-RISE, Sees. 13,14, 23,24
)9 .Tl0:'\-Rl5F., Sees. 15, 16, 21,22
JO T10:'\-Hl5F., S_ces. 17, 18, !9, 20
Jl TJO~-Rl4J;, Seao. 13, 14, 23,24
J2 Tl0i'\-Rl4E, Sees. 1~,.l6, 21,22
J3 TJO."-Rl-'E, Sees. 17, 18, 19, 2.0
)4 T10:-\-nl3E, Sees. 13, 14,.24
l5 TJO:-.=-HJ3E, Sees. 15,16
16 TJO:-.=.fil-tE, Sees. 27,28
17 T I 0:'\ · H J.1 E, Sees. 26, 36
17A TJO:'\-R1-1E, Sec. 25
18 TIO:'\-HJ5E, Sees. 29, 30,31, 32
l9 TlU:-\-R I 5E, Sees. 33, 34
f.IA TIO~-RISE, Sees. 27,28
:--:o. o£ Sen:tl na~ic "· ·~ . · ·· · Lm~
Roplty · of Rc:'i:ord AcH:s !':o •
:.. . .. -.... -
. ·." ....
2,512
2,SGO
2,5GO
2,512
2,5GO
2,5GO
2,512
28346
28332
28331
2S330
28315
28314
47475
1/8
1/8
1/8
1/8
1/8
1/8
1/8
1,920 47476 1/8
1,280 28290 1/8
. ),ZSO 47482" • 1/8
1,21>0 -28316 1/8
G-10 28316 1/8
2,523
1,2oo
1,280
28335
28334
28334
1/8
1/8
1/8
A.R.Co. :,ud Exxon
Sol1io Pdmlnun Go.
Sohio rdrolcum Co.
Snhio Pctr0lcurn Co.
. ~fohil and Phillips
.'.mcr:1da Hess,_ ct. ~1.
A.R.Co. ancl E"on
::.tobil .:~mll'hillips
A.R.Co. and Exxon
Chen on
d1~non, ).fobil,
Phillips
Sohio Pl'lroll'um Co.
~folJil antl Phillips
Mnl,il, i'J.illips.
Ch1.·non ·
0 Tl Oi'\-R 15E, Sees. 25, 26, 35, 36
1 TJ o:-:-n 16E, Set-s. 29, 30, 31
2,5GO
--~·~1:!3
215,767
28333
28349
1/8
1./8
Snhio Pctrol(:um Co.
Sohio Pctrokum Co."
I nkrt·st Ownt·r~hif'l_ :·
•
•
.t....n.Co.-50%
f."on-50%
A. n Co.-50%
c~,on-50%
Sol•io-100%
Sohio-100%
Sohio-100%
:'-luhil-50%
l'hillips-SO'lo
Amt·rad:l
Jkss-25%
C.-lty_:_25'7o
:'o.Luatl,on-25%
Pbc-id-7.5%
!\. n. llunt-5%
llunt Ind . ....:_
3.12.5%
Ca,nlinc Hunt
Tr.-3.125%
\\ 'm. ll<'rl.c'rt
Hunt Tr,-
3.125'7o
L:111iar Hunt Tr.
Est.---3.125%
AH.Co.-50%
Euun-:-50%
:'-lnhil-50%.
l'hillips--50%
A.f\.Co.-50%
f.x,un-50%
Clwnon --I 00%
\.lu·non-·-13 ~3%
~lnhil-31 1,~ 7o
l'hillips-:33 1,;,%
Sul•io--100~ ·
;\lnhil-50'7..
l'h ill ips-50%
~lohil-33 ~~ 7o
l'J.illips--33 1h '7o
Clwnun-33 1.~%
~uhio-100'7o ·
Sohio-100~
l3P ,\b~t:l, Inc. owns an ll'·t·rriding roy:1lty interest crJual to 75% of :11! net profits from Jlrll(luction Dclwccn
certain Jc,-cls of oil procluclion. · .
Tl,is Tract N""'lwr JOG was a'~i}!•wd to A.n.r.o. :md Exxon. Upon :~ppruv:1l uf tlu· :~"iJ:"'"<"IIl D)' the
Dirr-dor :1 new ,\DL !'>niall"o. will Lc t:;in·n to this Tr;~ct. .
. ·
. . t
...
NICOLAI CREEK
Statistics relating to this unit are shown on the attached table.
Current Status
Gas from this small field, when produced, is used only to provide
fuel for platform and shore facilities supporting petroleum
production in this area. However, at the present time there is no
production. There is no prospective purchaser for the State's
royalty share.
Royalty Oil and Gas Status
Unit:
Location:
Operator:
Owners:
Leases:
Royalty:
Purchaser:
··I
Nicolai Creek
West Side -Cook Inlet (Onshore-Offshore)
Texaco
Texaco, Superior
Fed. A034161, ADL 17585, 17598
12.5%
Amoco (1)
Royalty Price
$/Mcf
Date Initial Production: 10-68
Avg. Monthly Production Rate (1980) gas: -0-Mcf
Total Production to 10/31/80 (dry gas): 1,062,055 Mcf
Footnotes: (1) Shut-in
RIV: Royalty in Value
State Royalty Status
RIV
.• I
NORTH COOK INLET
Statistics relating to this field are shown on the attached table.
Current Status
Gas from this offshore field is primarily delivered to the
Phillips LNG plant a~d the products are subsequently sold in
Japan. However, in 1977, the State entered into agreements with
Phillips and Alaska Pipeline Company to sell the royalty share to
Alaska Pipeline Company for delivery to the Alaska market.
Royalty gas in excess of purchases by Alaska Pipeline Company is
purchased by Phillips.
\
Unit:
Location,:
Opera tal]:
Owners:
Leas~s:
Royal,ty:
North Cook Inlet
No~th Cook Inl~t
Phi._l.l ips
Philli:ps, Chevron
Royalty Oil and Gas. status
ADL,. 17 590., 1&741». 357e:3J,.., 1874J1l:,. 17'589.;
14. 5.%
A1:a,Ska~ P-i.pe.li,ne
Phil;lips ·
Roy.altx-, Price.
· · $/Mcf
L 90 (:HIK;; as of Nov 19.80 )•
2.0469 (RIV;; a:s of Jan· 1981)'
Date Ini:ti:_a:l Pro.dupti,_on,:: :3·,...69
Avg. Mon~hl,y Produc,tlon. Rate· ('198.0} gJ3s:: 2,955-.,896 M·c.f
Total Pvo_dqot~on to; 10/31:/-80: (;dry, g~s}: 490,487,024 Mcf
Est.imat-.eq. per_cent produ_qad. to 10/31/80: 18 .•. 6%:
··· State: Roy.al ty Status
RIK
RIV
Contr-aotS;< compl;eJ:ed l9Tl7 t:o~ ta.ke in k~i'n·d~ for sale to Alaska. Pipeli:ne. Company.
RIK: Royalty. in. Kind
RIV: Roy.al;ty in. Value
STERLING
Statistics relating to this field are shown on the attached table.
Current Status
.This is a small field in Kenai Peninsula. Since Federal leases
are involved, the State's royalty share is approximately 1.6% due
to the recent land conveyance to CIRI. The only gas sold from
this field is consumed locally. There is no gas pip~line
currently available to deliver this gas from this field to any
other market. Because of limited reserves, there is no prospect
of additional markets.
·Royalty Oil and Gas Status.
Unit: Sterling
Location: Kenai Peninsula (Onshore)
Operator: Union
Owners: Union, Marathon
Leases:
Royalty:
Fed. A028135, A028063, AOL 01836, 02497, 00479-A
12.5% (1)
Purchaser:
··I
Sport Lake Greenhouse
Date Initial Production:
Avg. Monthly Production Rate (11/30/80) gas:
Total Production to 10/31/80 {dry gas):
Estimated percent produced to 10/31./80:
Royalty Price
$/Mcf
0.40
5-62
2,000 Mcf
1,979,777 Mcf
8.1%
State Royalty Status
RIV
Footnotes: (1) A portion of Unit is owned by Federal govern~ent and CIRI~ The State's
effective rate is 1.55461%.
, ... ;.,
RIV: Royalty in Value
BELUGA RIVER
Statistics relating to this field are shown on the attached table.
Current Status
This operating unit is located on the North-West side of the Cook
Inlet. Chugach Electric is the only current purchaser of this
gas. Their contract price is as stated and results in the royalty
"in value" price. It is understood that Pacific Alaska LNG has
contracted to purchase gas from this field in the future.
Chugach Electric uses this gas for power generation which is
delivered to the Anchorage market.
There is no gas pipeline currently available to deliver gas from
this field to an~ other market.
There is no current purchaser for the State's royalty, and due to
the majority of Federal leases the State's share is 7.55% which
was reduced due to a reallocation of the royalty ~wnership. The
reallocation was due to changing the ownership from surface acre
to.reservoir p~rcentage.
Royalty Oil and Gas Status
Unit:
Location:
Operator:
Owners:
I
Beluga iRiver
I
West S~de -Cook Inlet (Onshore)
Chevron
Chevro~, Arco, Shell
Leases: Fed. Affi29656, A029657, ADL 17658, 17592, 17599, 21128, 21127, 21129, 21126
Royalty: 12.5% (1)
Purchaser:
··•
chugacf Electric
Date Initial Produ~tion:
!
Avg. Monthly Produbtion Rate (11/30/80) gas:
I
Total Production t~ 10/31/80 (dry gas):
I
Estimated percent produced to 9/30/79:
Footnotes: (1)
' I
I Federal leases involved.
!
RIV: Royalty in Vblue
·Royalty Price
$/Mcf
.1974
1-68
1,350,000 Mcf
104,006,863 Mcf
10.9%
State Royalty Status
RIV
State's effective royalty rate is 7.55%
.-•• f
. '
. • ~
MIDDLE GROUND SHOALS FIELD
Statistics relating to this field are shown on the attached table.
Current Status
All Royalty oil produced from this field is taken in kind and sold
to Tesoro-Alaska Petroleum Company •
Gas produced for this field is ca~inghe~d gas and was formerly
flared. DOGC Flaring Order Number 104 dated June 30, 1971, has
prohibited flaring since July 1, 1972, .and this gas is now
recovered and used locally. This gas is ~onsidered to have no
value because the costs of extraction, compression, and
amortization purportedly exceed its value; therefore, no roYalty
is paid.
Recent increases in gas prices a~e now becoming high enough to
cause the State to take another look.
Royalty Oil and Gas Status
Middle Ground Shoals Oil Field
Location:
Opel:'ator:
Leases:
Royalty:
Purchaser:
East Side ~ Cook Inlet (Offshore)
Shell & Amoco
ADL 17595, 18754, 18756, 18744, 18746
12.5%
Tesoro
Date Initial Production:
Avg. Mqnthly Production Rate (10/31/80) gas:
Avg. Monthly Production Rate (10/31/80) oil:
Total Production 10/31/80 (cas~nghead gas):
Total Production 10/31/80 oil:
Estimated percent pro-duced to 9/3.0/79 oil:
RIV: Royalty in Value
Price
$/Mcf $/Bbl
9-67
220,349 Mcf
400,788 Bbls
62,430,236 ··M:cf
128,696,691 Bbls
68%
10.77 (as of Nov. 1980)
State Royalty Status
RIV
..
II
. APPENDIX C. REFINERY AND PIPELINE DATA
..
C-1
(")
I
·N
J
STATE OF ALASKA.
PETROL~UM PROCESSING .PLANTS
REFINERY
NIIHSi<I
9hevron Refinery
. Tesoro Refinery
Phillips-Marat~on
LNG
Union Chemical
Division
Pacific Alaska ~NG
INTERIOR ALASKA
North· Pole. Refinery
VALDEZ
· Alpetco Company
.PLANT
CAPACITY
26,000 BPD
48,500 BPD
230,000
MCF/Day
Ammonia900,oo
tons/yr
Urea ?35,000
tons/yr
200,000
MCF/Day
initial
. 32,000 BPD
150,000 BPD
DATE
PLANT IN
OPERATION
1962
1969
( 1 7, 500 B PD)
. 1969
1969
Planned 1985
197.7
DATE
EXPANSIONS
1974, 1975,1977
1980 (7 500 BPD
Hydrocracker
Unit.)
1977
(?)
Planned 1985 (?)
SOURCE: State of Alaska, Department of Natural
Resources, Oil and Gas. Conservation
Commission. Annual Statistical
Report.
PLANT
PRODUCT
JP4, JA50, Furnace Oil, Diesels,
Fuel Oil, Asphalt, Unfinished
Gasoline. ·
Propane, Unleaded, Regular, and
Premium Gasoline, Jet A, Diesel
Fuel No. 2'Diesel, JP 4 and ·
No. 6 Fuel Oil.
Liquified Natural Gas.
Anhydrous Ammonia, Urea Pr.ills.
and Granules.
Liquified Natural Gas.
Military Jet Fuel, 1600-2400 BPD
Commerc.ial Jet Fuel, 3300-4300
Diesel/Heat;i.ng ·Fuel No.·. 1,
1000-1500
Diesel/Heating Fuel No. 2,·
1600-2200
Diesel Fuel Type No. 4
1000-4200 BPD.
(Proposed)
Unleaded Gasoline
Jet Fuel
Diesel
Naphtha
Benzene
Toiulene
Xylene
Sulfur
25,690 BPD
50,000 BPD
32,290 BPD
1t,500 BPD
2,530 BPu
5,640 BPD
6,172 BPD
190 tons/day
DESTINATION
. J;P4,-JASO; Furnace Oil, Diesels,
and Asphalt for Alaska;.
·unfinished: Gasoline, Low Sulfur
Fuels to Lower-48 states.
Alaska except No.6 Fuel Oil to
Lower-48 ·states.
Japan, by tanker, 2 tankers
capacity 71,500 cubic meters
each avg. one ship· every 10
days.
t
West Coast· and export by tanker
and bulk freighter.
Southern California one ship
every 13 days.
Fairbanks area, Nenana and
riv.er village.
Alaska, Lower-48,
world markets.
DESTINATION
West Coast of USA
Gulf Coast and East Coast of. USA via Panama Canal
East Coast and Virgin Island via Cape Horn
Alaska Refineries
BBLS OIL PER DAY
950,000
425,000
85,000
28,000
* Wilson, H.M., "North Slope Oil: A Bargin for Lower 48 Refineries",
Oil and Gas ~ournal, April 21, 1980. · ·
SOURCE: State of Alaska, Department of Natural Resources, Oil and Gas
Conservation Commission. Annual Statistical Report.
C-3