Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
Loading...
HomeMy WebLinkAboutCO 095Conservation Order Cover Page
XHVZE
This page is required for administrative purposes in managing the scanning process. It marks
the extent of scanning and identifies certain actions that have been taken. Please insure that it
retains it's current location in this file.
o_ � Conservation Order Category Identifier
Organizing (done)
RESCAN
❑ Color items:
❑ Grayscale items:
❑ Poor Quality Originals:
❑ Other:
NOTES:
BY: ROBIN ARIA
Scanning Preparation
BY: ROBIN
DIGITAL DATA
❑ Diskettes, No.
❑ Other, No/Type
OVERSIZED (Scannable with large
plotter/scanner)
❑ Maps:
❑ Other items
OVERSIZED (Not suitable for
plotter/scanner, may work with
'log' scanner)
❑ Logs of various kinds
❑ Other
DATE: lc�7
63 /S/
,6 TOTAL PAGES _/3
DATE:5-/9�7/63 /S/
Production Scanning
Stage 1 PAGE COUNT FROM SCANNED DOCUMENT: '
PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES NO
�..x-._
BY: CROBI MARIA DATE /S/
.__ .
Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO
BY: FAO TJ MARIA DATE:
(SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES)
General Notes or Comments about this Document:
5/21/03 ConservOrdCvrPg.wpd
STATE OF ALASKA
DEPARTMENT OF NATURAL RESOURCES
DIVISION OF OIL AND GAS
Alaska Oil and Gas Conservation Committee
3001 Porcupine Drive
Anchorage, Alaska 99504
Re: THE APPLICATION OF UNION OIL
COMPANY OF CALIFORNIA for modifica-
tion of Conservation Order No. 80
to Include the following pool rule:
Gas from a gas well may be permitted
to escape into the air without
Committee approval when such gas is
used to artificially lift oil from
a pool in cases of operational
necessity provided no such escape
be for more than 30 days in each
such case.
IT APPEARING THAT:
Conservation Order No. 95
McArthur River Field
McArthur River Middle Kenai
Gas Pool
October 8, 1970
1. Union Oil Company of California requested the referenced order by
letter dated August 12, 1970.
2. A notice of public hearing was published in the Anchorage Daily News
on August 15, 1970, pursuant to Title 11, Alaska Administrative Code,
Section 2009.
3. A public hearing was held in the Tien Crawford Memorial Building,
Anchorage, Alaska, on August 27, 1970, at which time the applicant
amended its original request to provide that escape of gas well gas
into the air may be permitted in excess of. 30 days upon Committee approval.
Testimony was presented by the applicant.
4. The record of the hearing of Conservation Order No. 95 was held open
through September 10, 1970, in order to receive additional reports.
AND IT FURTHER APPEARING THAT:
1. Most wells in the Hemlock Oil. Pool of the McArthur River Field have
ceased to flow because of a decline in reservoir pressure, and water is
being injected to arrest this pressure decline.
CONSERVATION ORDER NO. 95
Page 2
October 8, 1970
2. The oil production rate from the Hemlock Oil Pool is maintained by
means of gas lift operations, utilizing casinghead or gas in solution with
the produced oil.
3. Utilization of casinghead gas for gas lift purposes requires the
use of specially built compressors, and space limitations on the producing
platforms in the McArthur River Field preclude installation of "standby"
or "back-up" compressors.
4. The compressors must be shut down periodically for routine maintenance
and occasionally are shut down because of equipment failure.
5. During periods in which the compressors are inoperative, 9-'�1€f Hi-cabnt
casinghead gas is unavailable for gas lift operations, and most wells cease
producing from the Hemlock Oil Pool unless another gas supply is utilized.
6. Each of the producing platforms in the McArthur River Field has a
gas well available to supply gas to lift oil from the Hemlock Oil Pool
during periods a compressor is inoperative.
7. Reduced production from certain wells after shutdown may be evidence of
reservoir damage.
8. Such reservoir damage, if permanent, will result in reduced recovery
of oil from the Hemlock Oil Pool.
9. The likelihood of permanent reservoir damage will increase as
production and water injection operations in the Hemlock Oil Pool
continue.
10. Use of gas well gas to lift oil from the Hemlock Oil Pool should be
minimized.
11. The five day limit on use of gas well gas permitted to escape into
the air is too restrictive considering the time required to rep dir the
specially -built compressors, but 30 days is an excessive period of time.
12. Production from Hemlock Oil Pool wells may be interrupted for various
reasons, in which case applicant can obtain test data on such wells which
may provide evidence that shutdown of wells results in reservoir damage.
NOW, THEREFORE, IT IS ORDERED THAT Conservation Order No. 80 is amended
by adding the following rules thereto.
Rule 7. Use of Gas Well Gas
In the event any compressor which utilizes casinghead gas for lifting
oil from the Hemlock Oil Pool should become inoperative for any reason,
CONSERVATION ORDER NO. 95
Page 3
October 8, 1970
gas from the Middle Kenai Gas Pool may be utilized to lift such oil and then
be permitted to escape into the air without Committee approval for not to
exceed a total of 15 days in any quarterly calendar period.
Rule 8. Expiration
Rule 7 shall expire one year from the date hereof unless extended
by the Committee upon a satisfactory showing that shutdown of Hemlock
Oil Pool wells results in reservoir damage.
DONE at Anchorage, Alaska, and dated October 8, 1970.
Thomas R. Marshall, Jr., Executive Secretary
Alaska Oil and Gas Conservation Committee
Concurrence:
46� M-1 . 0 -
1lomer L. Burreff, Chairman
Alaska Oil and Gas Conservation Committee
** e-A
0. K. Gilbreth, Jr. , Membe
Alaska Oil and Gas Conservation Committee
Telecopy No.
(907) 276-7542
June 12, 1990
A D M I N I S T R A T I V E A P P R 0 V A L N 0. 95.20
Re: Extension of Conservation Order No. 95,
McArthur River Field, Middle Kenai Gas Pool.
Robert T Anderson
District Land Manager
Unocal Corporation
P 0 Box 190247
Anchorage, AK 99519-0247
Dear Mr Anderson:
On June 1. 1990 an application was received from Unocal
Corporation stating that all measures incorporated in
past years to minimize gas flaring are still in effect.
We have also reviewed testimony relevant to this matter
submitted as part of Conservation Order No. 95-A.
Pursuant to Rule 8 of Conservation Order No. 95, the
Alaska Oil and Gas Conservation Commission hereby extends
Conservation Order No. 95 until 7:00 am ADST July 1, 1991.
Sip,,, erely,
Lonnie Smith
Commissioner
BY ORDER OF THE COMMISS10N
jo/3.AA95
Telecopy No.
(907) 276-7542
,Tune 21, 1989
ADMINISTRATIVE APPROVAL NO. 95.19
Re: Extension of Conservation Order No. 95, McArthur
River Field, middle Kenai Gas Pool.
Robert. T Anderson
District Land Manager
Unocal Corporation
P 0 Box 190247
Anchorage, AK 99519-0247
Dear Mr Anderson:
On. June 4, 1989 an application was received from Unocal Corp-
oration stating that all measures incorporated in past years to
minimize ,gas flaring are still in effect.
We have also reviewed testimony relevant to this matter submitted
as part of Conservation Order No. 95-A.
Pursuant to Rule 8 of Conservation Order No. 95, the Alaska Oil
and Gas Con.s+ervation. Commission hereby extends Conservation Order
No. 95 until 7 : 00 am AD T July 1, 1990.
Sincerely'.
4,''
Lonnie C M"Ith
Commissioner
BY ORDER OF THE COMMISSION
jo/'3.AA95
Telecopy No.
(907) 276-7542
June 3, 1988
ADMIN ISTRAT IVE APPROVAL NO. 95-18
Re: Extension of Conservation Order No. 95, McArthur
River Field, Middle Kenai Gas Pool.
Robert T. Anderson
District Land Manager
Unocal Corporation
P. 0. Box 190247
Anchorage, AK 99519-0247
Dear Mr. Anderson:
On June 1, 1988 an application was received from Unocal
Corporation stating that all measures incorporated in past years
to minimize gas flaring are still in effect.
We have also reviewed testimony relevant to this matter submitted
as part of Conservation Order. No. 95-A.
Pursuant to Rule 8 of Conservation Order No. 95, the Alaska Oil
and Gas Conservation Commission hereby extends Conservation Order
No. 95 until 7:00 a.m. ADST, July 1, 1989.
Sincerely,
"'tonnie C.(mith
Commissioner
BY ORDER OF THE COMMISSION
dlf/3.AA95
June 16, 1987
Telecopy No.
k '907) 276 -7542
A D M I N I S T R A T I V E A P P R 0 V A L NO. 95.17
Re: Extension of Conservation Order No. 95, McArthur
River Field, Middle Kenai Gas Pool.
Robert T. Anderson
District Land Manager
Unocal Corporation
P. 0. Box 190247
Anchorage, AK 99519-0247
Dear Mr. Anderson. -
On June 15, 1987 an application was received from Unocal
Corporation stating that all measures incorporated in past years
to minimize gas flaring are still in effect.
We have also reviewed testimony relevant to this matter submitted
as part of Conservation Order. No. 95-A.
Pursuant to Rule 8 of Conservation Order No. 95, the Alaska Oil
and Gas Conservation Commission hereby extends Conservation Order
No. 95 until 7:00 a.m. ADST, July 1, 1988.
Sinc,erely,,
Lonnie C. Smith
Commissioner
BY ORDER OF THE C014MISSION
jo/3.AA95
June 5, 1986
TELECOPY NO.
(907) 276-7542
A D M I N I S T R A T I V E A P P R 0 V A L NO. 95.16
Re: Extension of Conservation Order No. 95, McArthur River Field
Diddle Kenai Gas Pool.
Mr. Robert T. Anderson
District Land Manager
Union Oil Company of California
P. 0. Box 1.06247
Anchorage, Alaska 99502
Dear Mr. Anderson:
On June 4, 1986 an application was received from Union tail
Company of California. stating that all measures incorporated in
past gears to minimize gas flaring are still in effect.
We have also reviewed testimony relevant to this matter submitted
as part of Conservation Order.No. 95-A.
Pursuant to Rule 8 of Conservation Order No. 95, the Alaska Oil.
and Gas Conservation Commission hereby extends Conservation Order
No. 95 until 7:00 AM A.D.S.T., July 1, 1987.
Yours very tr'�-Y,
Lonnie C. S-mi.th,
Commissioner.
BY ORDER. OF THE COMMISSI0N
d1f:3.AA95
July 1, 1985
A D M I N I S T R A T I V E A P P R 0 V A L NO. 95.15
Re: Extension of Conservation Order No. 95, McArthur River Field
Middle Kenai Gas Pool.
Mr. Robert T. Anderson
District Land Manager
Union Oil Company of California
P. 0. Box 106247
Anchorage, Alaska 99502
Dear Mr. Anderson:
On June 28, 1985 an application was received. from Union Oil
Company of California stating that all measures incorporated in
past years to minimize gas flaring are still in effect.
We have also reviewed testimony relevant to this matter submitted
as part of Conservation Order No. 95-A.
Pursuant to Rule 8 of Conservation Order No. 95, the Alaska Oil
and Gas Conservation Commission, hereby extends Conservation Order
No. 95 until 7:00 MI A.D.S.T., July, 1, 1986.
Yours very truly,
Harry W. Kugler,, 1,7
Commissioner
BY ORDER OF THE COMISSION
be: 3. AA95
June 6, 1984
ADMINISTRATIVE A P P R 0 V A L NO. 95.14
Ret Extension of Conservation Order No. 95, McArthur River
Field Middle Kenai Gas Pool.
Mr. Robert T. Anderson
District Land Manager
Union Oil Company of California
P. 0. Box 6247
Anchorage, Alaska 99502
Dear Mr. Anderson:
On June 6, 1984 an application was received from Union Oil
Company of California stating that all measures incorporated in
past years to minimize gas flaring are still in ef fect.
lie have also reviewed testimony relevant to this matter sub-
mitted as part of Conservation Order No. 95-A.
Pursuant to Rule 8 of Conservation Order No. 95, the Alaska Oil
and Gas Conservation Commission hereby extends the Conservation
Order No. 95 until 7:00 AM A.D.S.T., July 1, 1985.
Yours very truly,
Harry J. Kugler
Commissioner
BY ORDER OF THE COMMISSION
Ture 20,r 19P3 V U
A D M I N I S T R A T I V E A F P IZ 0, V A L N. 95
"i it I i M _.M .213
Re:.E3it—ension of Conservation Order Vo. 95t McArthur River
Field MUddle Fenai Cas Pool.
Mro Robert T. Anderson
District Land Manager
Union Oil Company of California
Pw 0, Box 6247
Anchorage, Alaska 99502
Dear Mr. Andersont
On June 20, 1983 an application was received from Union Oil
Cowpary of California stating that all measures incorporated
in past years to minimize gas flaring are still in effect.
We have also reviewed testimony relevant to this matter sub-
mitted as part of Conservation Order No. 95-A.
Pursuant to Rule 6 of Conservation Order No. 95t the Alaska Cil
and Gas Conservation Commission hereby extends the Conservation
Order No. 95 "ntil 7:00 AN A.D.S*T,o July 11 1964,
Yonirs very truly..
Farry T.T. Fugler,,,
Ccamissioner
BY ORDER OF THE COMMISSION
be
June 23, 1982
ADN'l N I STRAT I VE APPROVAL NO. 95.12
Re: ftctenslon of Conservation Order 95,, LICArthur River field,
lkliddle Kenai Gas Pool*
Mr. Robert T. Anderson
District Land Managex
Union Oil Conripany of California
P. 0. Pox 6247
Anchorage, Alaska 99502
Dear 10r. Anderson:
On June 22, 1982 an application was recokived from Union Oil
Corz)pany- of California stating that all measures Incorporated in
past years to mli4�,Imlzo as flaring are still in effect.,
Vise have also reviewed testimony relevant to this matter submitted
as part of Conservation Order Yo. 95-A.
Pursuant to Rule 8 of Conservation Order No. 95,, the Alaska Oil
and Gas Conservation Corzimission hereby extends Conservation
Order No. 95 until 7:00 AM, A.D.S.T.0 July ll 1983,
Yours very truly,
Harry W. Xugle r.
Cocunissloner
BY ORDER OF TBIE CViM11$S10N
BAIR :lit
June 10, 1981
ADM I N I S T P A T IVE APPROVAL NO. 95. 11
Re: Extension of Conservation Order 95, McArthur River Field,
Middle Kenai Gas Pool.
Mr. Robert T.,Anderson
District Land Manager
Union Oil Company of California
P. 0. Box 6247
Anchorage, Alaska 99502
Dear Fr, Anderson;
On June 8, 1981 an application was received from Union Oil
Company of California detailing recent and ongoing efforts to
minimize gas well qas flaring from the McArthur River Field.
We have also reviewed testimony relevant to this matter,
submitted as part of Conservation Order No. 95-A.
Pursuant to Rule 8 of Conservation Order Ho. 95, the Alaska Oil
and Gas Conservation Commission hereby extends Conservation
Order No. 95 until 1:00 AlN A.D,S.T., July 1, 1982.
Yours very truly,
Harry W. Kuqler"
Commissioner
BY THE ORDER. OF THE COMMISSION
11WK: be
June 6, 1980
ADMINI STRAT IVE APPROVAL N 0 1 (-fs- -0
Re: Extension of Consfrvation Order 95, McArthur River Field,
Middle Kenai Gas Pool,
Mr. Robert T. Anderson
District Land Manager
Union Oil Company of California
P. O. tax 6247
Anchorage, Alaska 99502
Dear Mr, Anderson:
On June 4, 1980 an application was received from Union Oil'
Company of California detailing recent and ongoing efforts to
minimize gas well gas flaring from the McArthur River Middle
Kenai Gas Pool*
vie have also reviewed testimony relevant to this matter
submitted as part of Conservation Order No. 95-AS
Pursuant to Rule 8 of Conservation Order No, 95, the Alaska Oil
'and Gas Conservation Commission hereby extends Conservation
Order No. 95 until 7:00 AM A.D.S.T., July 1. 1981.
Yours very truly,
Harry W, Kugler
Commissioner
BY THE ORDER OF THE COMMISSION
VWXtbe
August 20, 1979
A D M I N I S T R A T I V E A P P R 0 V A It No. 95.9
Re: Extension of Conservation order No. 95 McArthur River Field,
middle' Kenai Gas Pool.'
Mr, Wayne Rod ges
Landman
Union Oil Company of California
P. 0. Box 6247
Anchorage, Alaska 99502
Dear Mr. Rod ges.:
On August 20, 1979 an application was received from Union oil
Company of California detailing recent and ongoing efforts to
minimize gas well gas flaring from the McArthur River Middle
Kenai Gas Pool.
we have also reviewed testimony relevant to this matter submitted
as part of Conservation Order No. 95-Ao
Pursuant to Rule 8 of conservation Order No. 950 the Alaska oil
and Gas Conservation Committee -hereby extends Conservation Orde'r
No. 95 until 7:00 AM A.D.S.,T.,, July 1,, 1980.
Yours very truly,
Harry W. Kugler
Commissioner
BY THE ORDER OF THE COMMISSION
111";X: be
_.:*
June 27, 1978
ADMINISTRATIVE .APPROVAL N 5.��'`
Re r ion of Conservati x Order N. 95
Nit l= River Field, Middle Xemi Gas Pool
Mr. P4bert T. Anderson
District Land Mnager
Wm ailOmpany of California
Anchorage, Alaska 9950
Dead" Mr. Anderson:
On J'mie 20, 1978, an applicatim mas received fran ttdm Oil Caq=y
of California detailing remit and cngoing effcrts to odnize gas
ll gas flaring frcm the McArthur River Wdle Kenai cvas Pool.
We ba-ve also reviwed testUmmy relamt to this matter . rated
as part of Ctmservation Order No. 95-A.
Pursuant to lb� 8 of Cmservatim Order No. 9 , the Alaska Oil and
Gas Conservatim Camdttee hereby wMends Cmsermatim Order No. 95
until 7:00 AEI A.D.S„T.., July 1, 1979.
Very tnily yours,
nzas R. Marshall, Jr.
Fbow*iVe Secretary
l �
�;� 4r 1rl ��� ►`11,17
DEPARTMENT O NATURAL RESOUIMES
DIVISION Of OIL AND GAS
Conservation
July 1, 1977
JAYS. HAMMOND, GOVERNOR
3001 PORCUPINE DRIVE -ANCHORAGE 99501
ADMINISTRATIVE APPROVAL NO. 95.7
Re: Extension of Conservation Order No. 95
McArthur River Field, Middle Kenai Gas Pool
Mr. Robert T. Anderson
District Land Manager
Union Oil Company of California
Box 6247
Anchorage, Alaska 99502
Dear. ,11r . Anderson:
On June 29, 1977, an application was received from Union Oil Company
of California detailing recent effort to minimize gas well gas flaring
from the McArthur River Middle Kenai Gas Pool.
We have also reviewed testimony relevant to this matter submitted as
part of Conservation Order No. 95-A.
Pursuant to Rule 8 of Conservation Order No. 95, the Alaska Oil and
Gas Conservation Committee hereby extends Conservation Order No. 95
until 7:00 AM A.D.S.T., July 1, 1978.
Very truly yours,
Thcuis R. Marshall, Jr.
Executive Secretary
i
ALASKA OIL AND CAS CONSERVATION COMMITTEE
Y
January 28, 1975
A D M I It I S T R A T I V E A P P R 0 V A L H 0. 95.6
Re: Extension of Conservation Order No. 95
McArthur (liver Field, 11iddle Kenai Gas Pool
1+3r, Robert T. Anderson
District Band Manager
Union Oil Company of California
Box 6247
Anchorage, Alaska 99502
Dear Mr. Anderson:
Pursuant to Rule O of Conservation Order No. 95, the Alaska Oil and Gas
Conservation Committee hereby extends Conservation Order No. 95 until
7:00 AM A.DrS.T., July 19 1977.
Vile have reviewed testimony relevant to this ,utter submitted as part of
Conservation Order No. 95-A.
Very truly yours,
Thomas R. Marshall , Jr.
Executive Secretary
TRM b Jr
V
ALUU OIL AND GAS COISUVATWN II
Jme 17 o 1974
A 1 I TEA I $ APPRO AL log,21.22
i of Cotmrvotlan Order No. 95
c. Rabort T, Aud+soe
4otrut x=AV
Um Oil Owpany of California.
Sm 6247
aU " `
peace W . I
a erva tUm Ow"t-too Roby exteads, ZmeezvatUn "ft. 95 Until
We 'hen reviewed, tostimay relevant, to this matter omitted as part of
fiery truly, Vie,:
TWOS* C
h
1
wArlea1.l, it
'S�Mutive Secretary
liftebt
ALASM 01 L Pif) GAS CCONSEVAT I C04A 171 EE
cj
J tj.qe 21, 1,173
AD*4 I tl I STPRAT I VE APPROVAL ?40. 05.4
Re: ExIlentka of OmservatIon Order �Io. 95
McArthur River Ffald7r Middle Kbr al Gas Pool
%bert T. Andarsm
District Land Mmaqer
t J"n I on 0 11 Company of' Ca I I f0m I a
ROq W. 9th Avenuo
Anc%horoiga, Alaska 99501
Car PAr. Andersm,
Pursuant to Ru I a 8 crf C xmservat i on Order �Io. 95 the A Lask-a 1011 and (�&s
Cz-Asorvatlbn Ca", lti*o he o-xfpnds Conservation Order �Io. 95 untf 1
Is have rowlawed tastImony relevant -to this matter submitted as part of
0onservation Order No.. 95-A.
Very truly yours,
Thcms R. Marsha I I Jr.
FxS"tive Secretary
T PII -., J h
February 24, 1972
Re: Administrative Approval 95.3
A A qs. 3
Mr., Robert T. Anderson
Union Oil Company of California
909 W. 9th Avenue
Anchorage, Alaska 09501
Dear Mr. Anderson:
We have rec4fved your letter of February 23, 1972, with table and exhibits,
setting forth the emergency situation on the King Salmon Platform and your
request for a five (5) day extension of the provisions of Conservation
Order #95, Rule 7, during the current quarterly calendar period.
The 15-4ay period during which gas from the Middle Kenai Gas Pool may be
utilized to lift oil and escape, into the air is hereby extended five (5)
days, as, to the King Salmon platform., during the quarter calendar period
ending March 31, 1972.
Rule 7 is hereby extended for five (5) days for the King Salmn Platform
during the quarter c6leadar -period endIng Harch 31, 1972.
Sincerely,
Thomas R. Marshall, Jr.
Executive Secretary
Alaska Oil and Gas Conservation Committee.
04tw6w 19, -&971
Res xxte As ion of CoUM"ra1L i-en Order No, 95,
Y
AA
Mr.. wade S. Mcnis ter
Union Oil Company of Cali lnit
909 We 9th Avenues
Anchorage„ Alaska 99501
Dear Mr. McAlister t
P'tirsi3 mt to Rule S of Conner,,,,: r..ion Ordor Mom 93, the Alaska Oil, snd
Gas Conservation C+a wdttea b�,"-r rby extends Conservation Order No, 95
until July 1, 1973.
We have received and considered your application dated October 7, 1971
Including attached Exhibits 1 through 3 and your letter datad Octabor
120 1971 with aattactLed additle cal t .6
.. Sit�ex's1y.
Thom & 1. Marshall, .fat.
Exacw►tiv�a$►!!CrltadZ'y '
°n and ;'ii m , �Y�►�t�
'lhC J *•
1
w+�'1'11
H '�'�'�' � `�' ° Yl •' �' � ' �+' � � ' JN.'w;. ��' ...wa i, .ti �:'' F rn. ,�k. '. h„
r.u. �'. _,.�" �',. .,. ..+.. 9 N:'e4 Y. w _ .. !�- . , "`••• x1`.N,rJ4irl3.1W w :. � . J�`LJl:'�." ' � 0i1'Y+"i�s�Y�li'lry'�M .1ib.�,�IJ� u _ � ..,....w.�J , � .r!a. .. ''iJ� � ��i�2 y. �uINiYF� 'M d .. �.�. w '.�wlu+�.J wr
;:.� , � �,:. rti. ,, ,.YhaYiY, � V
�+=a 4P,. .�►u .rY�W9'y.
Robert T. Anderson
Manager, Lands
Alaska Region
Gentlemen:
Unocal North Americ-
E Oil & Gas Division
Unocal Corporation
P.O. Box 190247
Anchorage, Alaska 99519-0247
Telephone (907) 276-7600
June 1, 1990
Alaska Oil and Gas
Conservation Commission
3001 Porcupine Drive
Anchorage, AK 99501-1433
MCARTHUR RIVER FIELD
State of Alaska
Conservation Order 95
Application for Extension
Union Oil Company of California, as Operator of the Trading Bay Unit, hereby makes
application for extension until July 1, 1991, of Conservation Order 95, amending
Conservation Order 80, permitting gas well gas to escape into the air 15 days per
calendar quarter because of operations necessity.
The testimony presented by Mr. Gary Way in support of extension of this order on June
162 1972, is still valid. Well performance continues to show that shut-ins for even short
periods have the effect of reducing production rate and ultimate recovery.
The preventative maintenance measures incorporated in past years to minimize gas flaring
are still in affect. Although we are Continually making efforts to reduce dry gas flare by
improving our mechanical equipment operations, we will continue to have emergencies
when excess flaring is required, thereby necessitating the extension of this order.
Very truly yours,
Robert T. A derson
RTA: rms
REcEIVED
F4sk oil & Gas cons. Commission
Anchorap
Robert T. Anderson
District Land Manager
Alaska District
Gentlemen:
A.
Unocal Oil A Gas lion
Unocal Corporatiol
P.O. Box 190247
; u �,� ��
-
Anchorage, Alaska 99519-0247 %
C�k.'
Telephone (907)•276-77600 r,�
CC?�;�i]
fvR
UNOCAL �6 �s
Elyi�
:0000"'4'*
��,�-��s _
je
—cc, 3
ASS i
June 14, 1989
I_
FILE
Alaska Oil and Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, Alaska 99501-1433
McARTHUR RIVER FIELD
State of Alaska
Conservation Order 95
Application for Extension
Union Oil Company of California, as Operator of the Trading Bay Unit, hereby
makes application for extension until July 1, 1990, of Conservation Order 95,
amending Conservation Order 80, permitting gas well gas to escape into the air
15 days per calender quarter because of operations necessity.
The testimony presented by Mr. Gary Way in support of extension of this order
on June 16, 1972, is still valid. Well performance continues to show that
shut-ins for even short periods have the effect of reducing production rate
and ultimate recovery.
The preventative maintenance measures incorporated in past years to minimize
gas flaring are still in effect. Although we are continually making efforts
to reduce dry gas flare by .improving our mechanical equipment operations, we
will continue to have emergencies when excess flaring is required thereby
necessitating the extension of this order.
Very truly yours,
��"
Robert T. Anderson
04491/12 RECEIVED
JUN 15 19
Alaska Oil & Gas Cons. Commission
Anchorage
Robert T. Anderson
District Land Manager
Alaska District
Gentlemen:
Unocal Oil & Gas
Unocal Corporation
P.O. Box 190247
Anchorage, Alaska 99519-0247 01
Telephone (907) 276-7600 — �f�19—
GS
UNOCAL
June 1, 1988
Alaska Oil and Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, Alaska 99501-1433
McARTHUR RIVER FIELD
State of Alaska
Conservation Order 95
Application for Extension
61
Union Oil Company of California, as Operator of the Trading Bay Unit, hereby
makes application for extension until July 1, 1989, of Conservation Order 95,
amending Conservation Order 80, permitting gas well gas to escape into the air
15 days per calender quarter because of operations necessity.
The testimony presented by Mr. Gary Way in support of extension of this order
on June 16, 1972, is still valid. Well performance continues to show that
shut-ins for even short periods have the effect of reducing production rate
and ultimate recovery.
The preventative maintenance measures incorporated in past years to minimize
gas flaring are still in effect. Although we are continually making efforts
to reduce dry gas flare by improving our mechanical equipment operations, we
will continue to have emergencies when excess flaring is required thereby
necessitating the extension of this order.
04491
Very truly yours,
Robert T. Anderson
KE ""FIVE'
&W
Robert T. Anderson
District Land Manager
Alaska District
Gentlemen:
Unocal Oil & G Sion
Unocal Corporatioi i
P.O. Box 190247
Anchorage, Alaska 99519-0247
----'-- t
Telephone (907) 276-7600
UNOCAL19
_.i
June 12, 1987
Alaska Oil and Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, Alaska 99501-1433
McARTHUR RIVER FIELD
State of Alaska
Conservation Order 95
Application for Extension
Union Oil Company of California, as Operator of the Trading Bay Unit, hereby
makes application for extension until July 1, 1988, of Conservation Order 95,
amending Conservation Order 80, permitting gas well gas to escape into the air
15 days per calender quarter because of operations necessity.
The testimony presented by Mr. Gary Way in support of extension of this order
on June 16, 1972, is still valid. Well performance continues to show that
shut-ins for even short periods have the effect of reducing production rate
and ultimate recovery.
The preventative maintenance measures incorporated in past years to minimize
gas flaring are still in effect. Although we are continually making efforts
to reduce dry gas flare by improving our mechanical equipment operations, we
will continue to have emergencies when excess flaring is required thereby
necessitating the extension of this order.
Very truly yours,
Rober T. Anderson
.'nit ��,•%;!��,�� ^� V ",.i ^!��
Robert T. Anderson
District Land Manager
Alaska District
Gentlemen:
Unocal Oil & Gas Divil
Unocal Corporation
P.O. Box 190247
Anchorage, Alaska 99519-0247
Telephone (907) 276-7600
76
UNOCAL19
1 _
June 3. 1986
Alaska Oil and Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, Alaska 99504
McARTHUR RIVER FIELD
,-
State of Alask
f/
'
Conservation Order 95
Application for Extension
Union Oil Company of California, as Operator of the Trading Bay Unit, hereby
makes application for extension until July 1, 1987, of Conservation Order 95,
amending Conservation Order 80, permitting gas well gas to escape into the air
15 days per calender quarter because of operations necessity,
The testimony presented by Mr. Gary Way in support of extension of this order
on June 16, 1972, is still valid. Well performance continues to show that
shut-ins for even short periods have the effect of reducing production rate
and ultimate recovery.
The preventative maintenance measures incorporated in past years to minimize
gas flaring are still in effect. Although we are continually making efforts
to reduce dry gas flare by improving our mechanical equipment operations, we
will continue to have emergencies when excess flaring is required thereby
necessitating the extension of this order.
Very truly yours,
A
Robert T. nderson
R E C E IN! E D
JUNK 4 1986
Alaska Oil & Gas G11 s, Oc�,rraissiQr�
Robert T. Anderson
District Land Manager
A PC el
9
Gentlemen:
Union Oil and Gash_ ion: Western Region
Union Oil Company of California
P.O. Box 6247, Anchorage, Alaska 99502
Telephone: (907) 276-7600
L
union
June 27, 1985
Alaska Oil and Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, Alaska 99504
McARTHUR RIVER FIELD
State of Alaska
onserva ion r er 95
Application for Extension
Union Oil Company of California, as Operator of the Trading Bay Unit, hereby
makes application for extension until July 1, 1986, of Conservation Order 95,
amending Conservation Order 80, permitting gas well gas to escape into the air
15 days per calender quarter because of operations necessity.
The testimony presented by Mr. Gary Way in support of extension of this order
on June 16, 1972, is still valid. Well performance continues to show that
shut-ins for even short periods have the effect of reducing production rate
and ultimate recovery.
The preventative maintenance measures incorporated in past years to minimize
gas flaring are still in effect. Although we are continually making efforts
to reduce dry gas flare by improving our mechanical equipment operations, we
will continue to have emergencies when excess flaring is required thereby
necessitating the extension of this order.
Very truly yours,
Robert T. An erson
& Gas Gory
Union Oil and GaA -on: Western Regio
Union Oil Company of California
P.O. Box 6247, Anchorage, Alaska 99502
Telephone: (907) 276-7600�_;,.i:',�.� -
union
Robert T. Anderson
District Land Manager
_
I. 5� ; `Vr TEC -
Alaska Oil and Gas Conservation I CONFLER:
Commission '_FILF: - �-
3001 Porcupine Drive
Anchorage, Alaska 99504
June 17, 1983
McARTHUR RIVER FIELD
State of Alaska
Conservation Order 95
Application for Extension
Gentlemen:
Union Oil Company of California, as Operator of the Trading Bay Unit, hereby
makes application for extension until July 1, 1984, of Conservation Order,:95,
amending Conservation Order 80, permitting gas well gas to escape into th Fair
15 days per calender quarter because of operations necessity.
The testimony presented by Mr. Gary Way in support of extension of this order
on June 16, 1972, is still valid. Well performance continues to show that
shut-ins for even short periods have the effect of reducing production rate
and ultimate recovery.
The preventative maintenance measures incorporated in past years to minimize
gas flaring are still in effect. Although we are continually making efforts
to reduce dry gas flare by improving our mechanical equipment operations, we
will continue to have emergencies when excess flaring is required thereby
necessitating the extension of this order.
Very truly yours,
obert T. Anderson
RECF.IVEG
JU 1,111111,11 '111'�'111� 0 19�8'0
Alaska Oil u0tiWOs sl:,
A➢uchoi"age
/ "(: - -I, le C/, 0
r
Robert T. Anderson
District Land Manager
Gentlemen:
Union Oil and Gas 'ison: Western Region
r"
Union Oil Company of California
P.O. Box 6247, Anchorage, Alaska 99502
Telephone: (907) 276-7600
union
June 21, 1982
Alaska Oil and Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, Alaska 99504
McARTHUR RIVER FIELD
State of Alaska
Conservation Order 95
Application for Extension
Union Oil Company of California, as Operator of the Trading Bay Unit, hereby
makes application for extension until July 1, 1983, of Conservation Order 95,
amending Conservation Order 80, permitting gas well gas to escape into the air
15 days per calender quarter because of operations necessity.
The testimony presented by Mr. Gary Way in support of extension of this order
on June 16, 1972, is still valid. Well performance continues to show that
shut-ins for even short periods have the effect of reducing production rate
and ultimate recovery.
The preventative maintenance measures incorporated in past years to minimize
gas flaring are still in effect. Although we are continually making efforts
to reduce dry gas flare by improving our mechanical equipment operations, we
will continue to have emergencies when excess flaring is required thereby
necessitating the extension of this order.
Very truly yours,
r
Robert nderson
RECEIVED
',-1s1ca Oil & Gas Cons. C jn.
,��?0oj-a( () Jon
Robert T. Anderson
District Land Manager
Gentlemen:
Union Oil and Gas G" �ison: Western Region
Union Oil Company of California
P.O. Box 6247, Anchorage, Alaska 99502
Telephone: (907) 276-7600
union
'June 8, 1981
Alaska Oil and Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, Alaska 99504
McARTHUR RIVER FIELD
State of Alaska
Conservation Order 95
Application for Extension
_ COMNI _�I
_ Comm
'IEN^
2 ENG
-3
4 FNG
-1 Gc0L
2 GEOL
3 GEOL
STAT T^C
STAT TF-C
- - _j
CONFER:
Union Oil Company of California, as Operator of the Trading Bay Unit,
hereby makes application for extension until July 1, 1982, of Conservation
Order 95, amending Conservation Order 80, permitting gas well gas to
escape into the air 15 days per calender quarter because of operations
necessity.
The testimony presented by Mr. Gary Way in support of extension of this
order on June 16, 1972, is still valid. Well performance continues to
show that shut-ins for even short periods have the effect of reducing
production rate and ultimate recovery.
The preventative maintenance measures incorporated in past years to
minimize gas flaring are still in effect. Although we are continually
making efforts to reduce dry gas flare by improving our mechanical
equipment operations, we will continue to have emergencies when excess
flaring is required thereby necessitating the extension of this order.
Very truly yours,
Robert Anderson
q
RE
4.
�
0,/ & Gas
Union Oil and Gas +ison: Western Region�,�,
I Union Oil Coma -of California
P.O. Box 6247, Anchorage, Alaska 99502
�
o Telephone: (907) 276-7600
to -
rig
unin Yoe
J.
Robert T. Anderson June 3, 1980
District Land Manager
Alaska Oil and Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, Alaska 99504
McARTHUR RIVER FIELD. ;
State of Alaska
Conservation Order 95
Application for Extension
Gentlemen:
Union Oil Company of California, as Operator of the Trading Bay Unit,
hereby makes application for extension until July 1, 1981, of Conservation
Order 95, amending Conservation Order 80, permitting gas well gas to
escape into the air 15 days per calender quarter because of operations
necessity.
The testimony presented by Mr. Gary Way in support of extension of this
order on June 16, 1972,-is still valid. Well performance continues to
show that shut-ins for even short periods have the effect of reducing
production. rate and ultimate recovery.
The preventative maintenance measures incorporated in past years to
minimize gas flaring are still in effect. Although we are continually
making efforts to reduce dry gas flare by improving our mechanical
equipment operations, we will continue to have emergencies when excess
flaring is required thereby necessitating the extension of this order.
Very truly yours,
G
Robe t T. Anderson
.; .,
4tV
Q�i
Robert T. Anderson
District Land Manager
Gentlemen:
Union Oil and GaS �on: Western Region
Union Oil Company of California
/
P.O. Box 6247, Anchorage, Alaska 99502
Telephone: (907) 276-7600
Telex: 90-25188
union
August 20, 1979
Alaska Oil and Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, Alaska 99504
McARTHUR RIVER FIELD
State of Alaska
Conservation Order 95
Application for Extension
Union Oil Company of California, as Operator of the Trading Bay Unit,
hereby makes application for extension until July 1, 1980, of Conservation
Order 95, amending Conservation Order 80, permitting gas well gas to
escape into the air 15 days per calender quarter because of operations
necessity.
The testimony presented by Mr. Gary Way in support of extension of this
order on June 16, 1972, is still valid. Well performance continues to
show that shut-ins for even short periods have the effect of reducing
production rate and ultimate recovery.
The preventative maintenance measures incorporated in past years to
minimize gas f laring are still in of f ect. Recently we have been experiencing
ever increasing delays in receiving major parts for our gas compressors.
To alleviate the problem we are reviewing our existing large spare parts
inventory and will make the necessary orders for additional standby
equipment.
Although we are continually making efforts to reduce dry gas flare by
improving our mechanical equipment operations, we will continue to have
emergencies when excess flaring is required thereby necessitating,the
extension of this order.
Very truly yours,',
ne Rodgesz,�,
ndman
W
ion: Western Region
Union Oil and Gas E(
00 Union Oil Company of California
1
Cow of, P.O. Box 6247, Anchorage, Alaska 99502
/�j e, Telephone: (907) 276-7600
Telex: 90-25188
union
3
V
Robert T. Anderson Kr_
District Land Manager June 19, 1978 , FT
r
-----------
""" c
State of Alaska
Oil & Gas Conservation Committee
3001 Porcupine Drive
Anchorage, Alaska 99504
McARTHUR RIVER FIELD
State, of Alaska
Uons&Vatidh Order . 95
Application for Extension
Gentlemen:
Union Oil Company of California, as operator of the TradingBay Unit, hereby
makes application for extension until July l.. 1979, of Conservation Order 95,
amending Conservation Order 80, permitting gas well gas to escape into the
air 15 days per calender quarter because of operations necessity.
The testimony presented by Mr. Gary Way in support of extension of this order
on June 16, 1972, is still valid. Well performance continues to show that
shut-ins for even short periods have the effect of reducing production rate
and ultimate recovery.
Specific preventative measures incorporated to minimize gas well gas flaring
are:
(1) Continuation of the preventative maintenance programs which
includes vibration monitoring and analysis of critical high
speed equipment, lube oil analysis, scheduled periodic shut
down inspections of gas turbines and annual inspection of
water/gas heat exchangers.
(2) Increase the compressor spare parts inventory on each plat-
form, to reduce lost time due to shipping problems. A spare
gas turbine was also purchased for the Grayling to decrease
compressor down time.
(3) Improved training programs. Operators and mechanics are
sent to technical schools and also receive on board train-
ing with slide -tape programs. A change in the King Salmon's
organization was made with the addition of a maintenance
supervisor to better coordinate maintenance activities. R E C E I V E
jUN 2 01978
D;N isioll of ou anfj C�Aas uonserv;
Anchorage
State of Alaska -2-
Oil & Gas Conservation Committee
June 19, 1978
The effect of the programs discussed has been improved gas compressor operations.
This is evidenced by the Grayling and Dolly Varden Platform records for the past
three years where on time records varied between 97% and 98.90.
Although we are continually making efforts to reduce dry gas flare by improving
our mechanical equipment operations, we will continue to have emergencies when
excess flaring is required thereby necessitating the extension of this order.
DEVARTMENT O NATURAL REISOURCES
DIVISION Of OIL AND GAS
Conservation
July 1, 19 7.7
JAY S. HAMMOND, GOVERNOR
3001 PORCUPINE DRIVE -ANCHORAGE 99501
ADMINISTRATIVE APPROVAL NO. 95.7
Re: Extension of Conservation Order No. 95
McArthur River Field, Middle Kenai Gas Pool
Mr. Robert T. Anderson
District Land Manager
Union Oil Company of California
Box 6247
Anchorage, Alaska 99502
Dear. • M r . Anderson:
On June 29, 1977, an application was received from. Union Oil Company
of California detailing recent effort to minimize gas well gas flaring
from the McArthur River Middle Kenai Gas Pool.
We have also reviewed testimony relevant to this matter submitted as
part of Conservation Order No. 95-A.
Pursuant to Rule 8 of Conservation Order No. 95, the Alaska Oil and
Gas Conservation Committee hereby extends Conservation Order No. 95
until 7:00 AM A.D.S.T., July 1, 1978.
Very truly yours,
Lam`
Thcmtiis R. Marshall, Jr.
Executive Secretary
Union Oil and Gas D on: Western Region
Union Oil Company of California
P.O. Box 6247, Anchorage, Alaska 99502
Telephone: (907) 276-7600
I DIR l���. -�
Telex: 90-25188
C. GFCL /44
C. ERG
I 1 ENGunio-
n
Robert T. Anderson June 29 1977
District Land Manager
I 2 GE`-)L
Ail I n . i
F
1
!EV i
State of Alaska
DRAFT __
Oil & Gas Conservation Committee
SAC �___
3001 Porcupine Drive CONFER:
FILE:f-'() c� r
Anchorage, Alaska 99504
McARTHUR RIVER FIELD ` �"``��' ��r'
�� ��'� r'"
State of Alaska
Conservation Order 95
Application for Extension
Gentlemen:
Union Oil Company of California, as Operator of the Trading Bay Unit,
hereby makes application for extension until July 1, 1978, of Conservation
Order 95, amending Conservation Order 80, permitting gas well gas to
escape into the air 15 days per calendar quarter because of operations
necessity.
The testimony presented by Mr. Gary Way in support of extension of this
order on June 16, 1972, is still valid. Well performance continues to
show that shut-ins for even short periods have the effect of reducing
production rate and ultimate recovery.
There have been accomplishments made to improve on time of equipment
thus reducing the frequency of emergency situations when gas well gas is
required. Within the past two years each platform of the T.B.U. has
increased its gas handling capacity by about 3,900 HP. This was necessi-
tated by the increasing gas lift requirements as water cuts increased.
Where gas well gas was used to maintain production rates, the increased
compressor capacity allowed a subsequent reduction in its use.
The installation of a standby vapor compressor on the Grayling two years
ago also reduced downtime on the rich gas system.
Other efforts made to minimize gas well gas flaring are:
(1) Improvements in preventative maintenance programs which include
vibration monitoring and analysis of critical high speed
equipment, lube oil analysis, scheduled periodic shut down
inspections of gas turbins and annual inspection of water/gas
heat exchangers.
t
t
..,'W
State of Alaska - 2 - June 29, 1977
Oil & Gas Conservation Committee
(2) Increase the compressor spare parts inventory on each platform
to reduce lost time due to shipping problems. A spare gas
turbine was also purchased for the Grayling to decrease compressor
d own - t ime .
(3) Improved training programs. Operators and mechanics are sent
to technical schools and also receive on board training with
slide -tape programs. A change in the King Salmon's organization
was made with the addition of a maintenance supervisor to
better coordinate maintenance activities.
The effect of the programs discussed has been improved gas compressor
operations. This is evidenced by the Grayling and Dolly Varden Platform
records for the past two years where on time records varied between 97%
and 98.9%.
Although we are continually making efforts to reduce dry gas flare by
improving our mechanical equipment operations, we will continue to have
emergencies when excess flaring is required thereby necessitating the
extension of this order.
Very truly yours.
e
Robert T. An erson
C. 0. 95
2/4/76 10:00 AM
The Oil and Gas Conservation Committee met to discuss Union Oil Company's
request for AA 95.6.
Total dry gas flared for 1975 from the MacArthur River Middle Kenai Gas
pool was 539 mmcfg/year. This is about 1.6 mmcfg/day. Monthly flaring
figures inidate flaring of some amount of gas each month with some months
flaring many times the average monthly rate. It was agreed that a letter
should be sent to the operator requesting plans of how flaring due to
equipment failure could be minimized.
Union Oil and Gas :ion: Western Region
Union Oil Company of California
P.O. Box 6247, Anchorage, Alaska 99502 _
I D1R
Telephone: (907) 279-7681
C. GEOL
_ -�
C. ENG,,
February 27, 1976
ENG
1 2 _,N
I 3
nion
.NG -
_
I 4 FNG
5 ENG-i--
IK
Mr. Thomas R. Marshall` Jr.
!I 2 GrcL IL
Eugene F. Griffin District Operations Manager State of Alaska,, Dept. of Natural Res °t
Alaska District Oil and Gas Conservation Committee-1
REV I
3001 Porcupine Drive
I DRAFT
I s:
Anchorage, Alaska 99501 g ;:
4-0 {
c4D&
Dear Mr. Marshall: `' > 3401`sl
DRY GAS FLARING
co
McArthur River Field,, Cook Inlet, Alaska
This is in response to your letter of February 4 concerning flaring of dry gas from the
McArthur River Field. We are also concerned when gas flaring is necessary and have
taken definite action that should reduce future occurrences.
A large partion. of the,, flare. that has occurred during 1975 res,ulte:d primarily from ,mach,.
apical problems with gas lift compressors. Additional compressors have been in-
stalled durin the
g year on the: three McArthur River platforms. These installations
increase the; available gas lift horsepower and results in additional capacity to be
utilized during mechanical equipment maintenance and malfunctions.
The new 4,000 HP Rustin-»York compressor on the King Salmon was operational last
August, but has had some startup problems. It is now considered fully operational.
It also has the adaptability to compress additional gas to the onshore site when
needed, The new 3 , 800 HP Solar -Centaur gas lift compressor on the Dolly Varden
platform was completed and fully operational by February, 1975, and the new 3,800 HP
Solars»Centaur compressor installed aboard the Grayling was in service last December.
The Trading Bay Production facility experienced considerable compressor problems in
heat exchangers. The result of this problem also increased the gas flare. Recent
successful steps have been taken to greatly reduce the corrosion problem and should
result in a much lower flare in the future.
The programs discussed have been costly, but are affording a more efficient overall
operation. The end result is continued normal oil production rate with lower total
gas flare.
MAN 11976
DIVISION OF OIL AND GAS
E FG: nnb ANCHORA t
Ve truly xre%iira
uge e
February 4, 1976
Mr. R. E. Anderson
Union Oil Company of California
Box 624.7
Anchorage, Alaska 99502
Dear Mr. Anderson:
The Oil and Gas Conservation Committee is particularly concerned with the
flaring of dry gas from the McArthur River 14iddle Kenai Gas Field durinq
periods of equipment failure. Flaring is currently permitted for up to
15 days per quarter under Conservation Order No. 95, principally because
of the indications that oil recovery may be reduced if oil wells are shut
in during times when compressors are nonoperable.
We would be interested in any short or long range programs your company
may have which could reduce the amount of dry gas flared.
Sincerely,
Thomas R. Marshall, Jr.
Executive Secretary
Oil and Gas Conservation Committee
T R PI - b j m,
Union Oil and Gas 171 'sion: Western Region
Union Oil Company of California
P.O. Box 6247, Anchorage, Alaska 99502
Telephone: (907) 279-7681
r�"
union
) n
Robert T. Anderson January13, 1976
District Land Manager
State of Alaska j
Oil -and Gas Conservation Committe
3001 Porcupine Drive �;�::
Anchorage, Alaska 99504
McARTHUR RIVER FIELD
State of Alaska
Conservation Order 95
Application for Extension
Gentlemen:
Union Oil Company of California, as Operator of the Trading Bay Unit,
hereby makes application for extension until July 1, 1977 of Conservation
Order 95, amending Conservation Order 80, permitting gas well gas to
escape into the air 15 days per calendar quarter because of operational
necessity.
Reference i,s made to the testimony and Exhibits previously submitted in
support of extension of this Order on June 16, 1972.
The same technical and mechanical conditions exist in the Field today
that existed at that time, therefore, necessitating the extension of
this Order.
We respectfully request approval of this application.
AN 14 1979
G AS
Very truly yours,
UNION OIL COMPANY OF CALIFORNIA
Operator
Union Oil and Gas D Jsion: Western Region
Union Oil Company . California
P.O. Box 6247, Anchorage, Alaska 99502
Telephone: (907) 279-7681
union
Robert T. Anderson
District Land Manager June 13, 1974
State of .Alaska
Oil and Gas Conservation Committee
3001 Porcupine Drive
Anchorage, Alaska 99504
bbAFdHUR RIVER FIELD
State of Alaska
Conservation Order 95
Applicatio for Extension
Gentlemexi : � . c' �..�i f K 4 A -
Union Oil Company of California, as Operator of the Trading Bay Unit,
hereby makes application for extension until July 1, 1975 of Conservation
Order 95, amnendi.ng Conservation Order 80, permitting gas well gas to
escape into the air 15 days per calendar quarter because of operational
necessity.
Reference is made to the testimrony and Exhibits previously submitted in
support of extension of this Order on June 16, 1972.
The same technical and mechanical conditions exist in the Field today
that existed at that time, therefore, necessitating the extention of this
Order.
We respectfully request approval of this application.
very truly yours,
UNION OIL COMPANY OF CALIFORNIA
Operator
D I R �1
G
-G�CL-
�C -ENG I-
�- �N-
2 1�1 G--�--
3 ENG j
Ll�
^ _ `�.
1. L
---I 3 'GEOL I.
DRAFT {
SEC
COt\3F—ER �
----
/ 7�/'
By < .
Dr nr
Er-n
J U N 7 1974
_ AND ��:�
Robert T. Anderson
District Land Manager
Gentlemen:
DIR
Union Oil and Gas Dl• � is Western Region
C. �EOL
G
C. ENG
Union Oil Company of California
---�_.- -
ENG
909 W. 9th Avenue, Anchorage, Alaska 99501
ENS
Telephone: (907) 279-7681
PENG
E,E*
5 ENf3
union
1 f EOL
2 GE0!
13 GEOL
I REV
f DRAPf
June 29, 1973
SEC
CONFER,
44/ eV 4 O . / 1 FILE: CG.
Alt IfCacTjjjl�b 6Ifn
�+
State of Alaska
Oil and Gas Conservation Committee
3 001 Porcupine Drive
Anchorage, Alaska 99504
Re: McARTHUR RIVER FIELD
STATE OF ALASKA
Conservation Order 95
Application for Extension
Union Oil Company of California, as Operator of the Trading Bay Unit,
hereby makes application for extension until July 1, 1974 of Conserva-
tion Order 95, amending Conservation Order 80, permitting gas well gas
'to escape into the air 15 days per calendar quarter because of operational
necessity.
Reference is made to the testimony and Exhibits previously submitted in
support of extension of this Order on June 16, 1972.
The same technical and mechanical conditions exist in the Field today
that existed at that time, therefore, necessitating the extention of this
Order.
We respectfully request approval of this application.
RJUN 2 91973 ID
DIVISION OF OIL AND GAS
ANCHORAOF,
Very truly yours,
UNION OIL COMPANY OF CALIFORNIA
Operator
By:
f
Robert T. Anderson
District Land Manager
c
�� of
Union Oil and Gas lion: Western Region
Union Oil Company of California
909 W. 9th Avenue, Anchorage, Alaska 99501
Telephone: (907) 279-7681
union
February 23, 1972
State of Alaska
Oil & Gas Conservation Committe
3001 Porcupine Drive
Anchorage, Alaska 99504
SIR 1
C. GEOL
-1 ENG---
- 2 ENG
3 ENG
- `---
4 ENG
5 ENG
-; i GEOL
—� 2 GEOL
3 GEOL
J—REV
`— pRAFi
SEC
CONEER�
McARTHUR R I VE.R FIELD
-- STATE OF ALAS KA
Conservation Order #95 .
Gentlemen:
Union Oil Company of California, as Operator of the Trading Bay Unit,
requests an emergency order to allow the provisions of Conservation
Order #95, Rule 7, to be extended for an additional five (5) days for
the King Salmon Platform during the current calendar quarter.
The gas lift compressor on King Salmon Platform was scheduled for its
annual overhaul on February 9, 1972. The manufacturer's recommended spare
parts inventory proved to be inadequate to rebuild the turbo charger,
which was found to have suffered considerable wear and damage since
installation. Additional parts were air freighted to Kenai by the
manufacturer and the overhaul was completed on February 16, 1972.
Subsequent operation revealed the turbo charger was not functioning
properly. It was necessary to air freight i t to Houston, Texas, where it
was determined by the manufacturer that they had shipped a bent shaft. The
manufacturer has since rebuilt the rotating element and air shippedtit to
Kenai. The requested extension should allow sufficient time to reassemble
the compressor and insure it is operational. In the meantime however, the
K-20 gas well must continue to be utilized to provide gas lift gas.
Platform shut downs have historically resulted in a loss of productive
potential in oil wells in the McArthur River Field. This is true particu-
larly, though not exclusively, in wells with water cuts. Recent severe
icing conditions in the Cook Inlet prevented tankers from loading oil at
the Drift River terminal thereby creating a shortage in storage capacity
resulting in a curtailment of McArthur River oil production. Grayling
platform wells were shut in for periods ranging from 20 hours to a
week. After all wells had been returned to production the Grayling
d����i'�Iro',eESw�l� 1..�n"` '1.,�';�.� d'�ro.'i`•��� �.'GodrR��'e
State of Alaska l
McArthur River F!,-.id
Conservation Order #95• -2- February 23, 1972
platform had lost over 2,000 net BOPD. A list of Grayling wells showing
an oil production loss subsequent to the curtailment period is attached
as Table I. Also attached are the daily oil production test curves
which graphically illustrate the production loss incurred for each well.
To prevent risking a reduction of productivity by shutting in wells, it
is necessary for gas well gas to be utilized for lifting purposes until
the temporary compressor difficulties can be remedied.
Very truly yours,
UNION OIL COMPANY OF CALIFORNIA
BY,......;.._..�.
ms,. Attorney- i n-Fact''
., .. •2o F
e �• � � <PAoo. I►IsT. � , , ;.•, ..DAILY TEST RATES i . ....,.
NO,
7-'TRADING BAY U:\iie iT i
!ELD LEASE '
1 7 D NE WELL No. G-Z
16 - ... i ! I I r . i j : i . ' 1 ! ', !' i ; � T ' I. I i' • ��� 1 _...., ...�., L 'Y"i'•'; "`�^' M
•-w_ 7 �,
` i
1 f.
i. •I' 1 r r
ti I I.
� •1• L I , I
.i.
,
1
,
t
t
i
_:,............ ... it )
{
r i• i
i . i..
.I. I 4
1. 1
,
- i i 1. I
t t
r.
,
t7
( , i , , I � � j,.
, I 1 `` � 'I• i� t i 1 ,
-i
i
►
1
)
i , f
t
't
z
.,,,) .«.... ... ...... I..
„
f t , ..: jt �� ,. .�f .�'". I ,�• :1-i -�� ix
_.ice
f
f I 1
1
a.. !r
j 1
,
, •; i'• t 1-
t:
t
"{ i
, ! I
I .
I } i.
1 I I .I ', • .Y,. I. .3 j
I
, I
, r
1_
r r '
1^- 't• .!_ .. q.. 1- .,_ .. ... .... ....... ... V , 1 1 .. ... .. _ t .t..• .,... i .).
W+, •-•-�.1,• 'L._:........ ... .. .... ....... ...._.._.. _........
..... ..--�.w.. .�•.-r 4, I •.le ei��'Y_..I - 'Y _..I r �••,- :,,...a
.._. ...-i.... ..... _.....,...
,. -...
S �
I
:
I
.. tb. .1. , ,I- � .1. I { i t , j 'j j•� .y. _�: .L �,:: a_ ..#l« y. ••. r -r•- ... r ....... .. ..
I t
------ -- - - ------- . .......
j.
-77
- r
'71C`
.. .. : t" •1 vl Li
ict 17�.t.+a:,...........,._....`......_.
�I, V � � I ,,,): ) .. � � , 1 .. ' .. , .... .. I ..! 1 ,:<,«' ((' i , ' I � I. �• I ,. a t. [ t
arm...._ � .. ..... .. .. ... . ._...._ ....... ............._... _............ _ .._. , _. .. - • - --.._... __ .. ,.._.{•! ; ,;M L 'I i _
,r. ._ .. ._. . _. ..
1. ,
f
.j
, a
s
1.
{
�I
I f
CC ... .. ..
-
1_. _.. --
._..--............._.....�.. -- -
,
_.. _ ...•.+.w.a+nrc.ti,hi. _ .... r_—. .. • n. c . . r . o. ....... r..a...._ _._ *^'..^^^A•...°,•,,.n*.md,� `ms.. .. 1 _ .
, •w++rrrA. _ w�i,a,a.:,,:..�.,.�,,.,,�.«++.xti�l�is"".iir.,►W::;,u:,..�....,::� ,.f., rr.'w�?�,••;r .�.
PROD: INT, DAILY TEST RATES
TRADING
BAY UNI1FIELO LEASE
, „
r •- 'pis-* ..
i
ZONE WELL No. G-p
li j: I,—,--"�---1--."_1f— -_.-- —•- .:..,-�- ��-r• i• , •r-•- T^•-T^^----•- ! .i, :. ,
( i �I' 1 I •j • r,.i it �li , f. ,. : i.. 'S'- i 't j •} }, , .�.. i i;
I ! i. L.L. =n.,. 1
1
'A
I. .r.. ,
I t ,t '� {' .I� 1 1• 'i: i '! -! I . I. f . ? � i i i. r.:.,, _ ,.
L-q—
if Z
I�. �,
r''•' . A.
71
a......_.. ....:............._....__._... ._. ......_+ ..._._...._._. ..............._......_............._....._....._.......__._....._......._ ._.......... �':I. 2'11' S .. Rfh y�•u'.
'f r •. •. J NH : - DULY UuU •••... 9:FYT P+if .«A C?'TOa! t Nb'i It m u k:R• ?S'.,:CI.I I±ER•.. Arl`A+iY I•1•. r.. •.e
JAKGA t. Y?_V.Fit! FtY: fR AR:.H AF. R,L t
` ''. 4c.�.;.ye ..,1_..... .+w;..,..,..G..,..wa........r.�....,v_.rr..,-..,.......u,,.u..-.........�.. .....,..,�..»...1.,....'.... �..�...,,..... w.n.+'Iw.F.....,«gn�u,.w,: ,Mn+n.n�.w�r•M.n•�r,.n..+.wnAnn,ne+.wwn�•w.:r.�,wr,M�v�w�..f
Y�!11P"`a"" wmnipq.�+.. ...n�m*mn?n".�.,.,..smmw. ..,:.. ,�, mmr.�m•mom+aa.,nww_rvknw+nn�m,a,rmm�rtrvm-uerenm�mm.'.+.^�^•..w�!�•mmMf^'x+.:�.+^.^Awn . ^+m-^mmnm*m.-+n ',m••*_•�,.,...m,,.n•*.�++.,.*nm_a*m,�,.w,m-�m•�.,�....mm_mn.n„n mn-._.*..-.+,...m*n-.-,.., «-�,, . :. - ,o., ,.,� _ S r7 :. 1 H .. .>.. i.. l! 7 f ' ' _. .
�ilic#aJa w1�a�iy4MYiY%•SnW�!YJSW'r1�Rnn.w .� '. � � ...'..� 1 ., v , .?.
i hMIW AY+dYl�M4T:Ii�L/W�i}?Y?�IWN.�kMJdtW41�,�."'��y,���� � �. . . ��..;' ,. � 'r�. ��. � .... 4 a...� � ., ....... .. . r.
., Now�?�+b.�i14"�R� .�+Yai4i+.�}w�7 ,'�M+aa'�!w�*Gwpv. kaaal.. . ;. � r,,, .
,.. ,.- wY.itYiaJwlauk�w.�.'e¢ .:�, :�.:.. .. .„ : .:' :: !'.4 � '�'�.� ' ' ,; :�. 4rd'i� �..r'��....ti '" P.na+�
.. ._ - ; ._
- � � - .. � -
.. � � •. ,
•-•
-{ •'•r i i �� y r ..i ! 1 . ' � ;:. �. L �.: � ,..� � 1.,. it .+1 �_ = i.
F{ 1 � •� # .�. (+ t,. 1F i..1 J 7. r��'jjj a r-�—t f i ��
Is !
1A
y� tf t i•
�,
• .i. ,.. ! ? .�.. f...! is .�..�.� 1 ;+.'_,_•t�t��_ � � �' � l ? r
Grayling Test Information
Table I
2/2 3/7 2
Test Before
Shut In
Test After Shut In
Difference Lost
Well
Date
Gross
Net
Water
Date
Gross
Net
Water
Gross
Net
G-2
1/3/72
4486
4441
45
2/8/72
4338
4292
48
148
149
G-4
1/17/72
5405
5000
405
2/14/72
5236
4796
440
169
204
G-6
1/16/72
4709
3814
895
1/30/72
4153
3322
831
556
492
G-8
1/13/72
1988
1312
676
2/10/72
1832
1136
696
156
176
G-11
1/9/72
4981
4975
6
1/30/72
4482
4478
4
499
497
G-15
1/15/72
4420
4327
93
1/25/72
4320
4212
108
100
115
G-32S
1/14/72
2623
2618
5
1/30/72
2361.
2359
2
262
259
G-33L
1/11/72
2747
2744
3
2/8/72
2485
2483
2
262
261
nl'
Robert T. Anderson
District Land Manager
Union Oil and Gas D on: Western Region
Union Oil Company of California
909 W. 9th Avenue, Anchorage, Alaska 99501
DIR�'p',:�
L_.
Telephone: (907) 279-7681
C. GEOL'
I C. ENG
I 1 ENG I
I 2 ENG
n
` 3 ENG
uni ,6
I 4 ENG
I 5 ENG
I 1 GEOL I
October 12, 1971
2 GEOL
3 GECL
REV
of AlaskaOil
L—T-'—D-�R�AFT-
SCState
and Gas Conservation Committee
3001 Porcupine Drive
FILE:
Anchorage, Alaska 99504
Re: MCARTHUR RIVER FIELD
STATE OF ALASKA
Conservation Order No. 95
Gentlemen:
Enclosed is additional engineering information in support of the
application of Union Oil Company of California for extension of
Conservation Order No. 95.
Very ru 11-y yours,
Wade S. McAlister
Landman
WSM/sk
Enclosure
C., ,.
cc: Working Interest Owners
Trading Bay Un i t w/Enclosures
TRAD i NG BAY UNIT
COOK INLET, ALASKA
CHAIRMEN SUBCOMMITTEES
ENGINEERING & PLANNING
Mr. C. J. Diver
Marathon Oil Company --
P. 0. Box 2380
Anchorage, Alaska 99501
rani nr_ i rni
Mr. H. C. Lee
Union Oil Company of California
909 W. 9th Avenue
Anchorage, Alaska 99501
LAND -LEGAL
Mr. R. T. Anderson
Union Oil Company of California
909 W. 9th Avenue
Anchorage, Alaska 99501
ArrniIHTI nir_
M r . C. E . Newg reen
Union Oil Company of California
P. 0. Box 7600
Los Angeles, California 90054
OPERATION
Mr. E. F. Griffin
Union Oil Company of California
905 W. 9th Avenue
Anchorage, Alaska 99501
MANAGEMENT
Mr. W. C. Barton, Jr.
Union Oil Company of California
P. 0. Box 7600
Los angeles, California 90054
TRADING BAY UNIT
COOK INLET, ALASKA
MANAGEMENT COMMITTEE
Mr. B. G. Howard
Marathon Oil Company
P. 0. Box 2380
Anc!-io rage , Alaska 99501
Mr. 'I C. Doughty
PI-1 i 1 1 i ps Pet rol eum Company
1300 Security Life Building
Denver, Colorado 80202
Mr. W. C. Barton, Jr.
Union Oil Company of California
P. 0. box 7600
Los Angeles, California 90054
Mr. C. V. Chatterton c
Standard Oil Company of California
P. 0. Box 7- 839
Anchorage, Alaska 99501
Mr. H. A. Slack
Atlantic Richfield Company
P. 0. Box 360
Anchorage, Alaska 99501
Mr. W. M. Jones
Amoco Production Company
Security Life Building
Denver, Colorado 80202
Mr. F. L. Franz
Skelly Oil Company
1860 Lincoln Street
Denver, Colorado 80203
ENGINEERING REPORT IN SUPPORT OF THE APPLICATION OF
UNION 01L COMPANY OF CALIFORNIA FOR EXTENSION OF
CONSERVATION ORDER NO. 95
BY
GARY S. WAY
The Trading Bay Unit is producing above bubble point with pressure main-
tenance by natural water influx and water injection. As a result, the
number of wells producing water has steadily increased and will continue
to do so throughout the project life. In addition, the volume of water
production can be expected to increase as more wells produce with in-
creasing water cuts. The attached Exhibit I depicts the following:
1. total completions with dual producers counted as two
completions,
2. the number of completions producing in excess of one
percent water and
3. the percent of total completions making in excess of one
percent water.
This graph clearly illustrates the trend toward greater water production
which the Operator believes is also a trend toward greater potential
damage from drowning of oil productive sands during shut in of water cut
wells.
The justification for including wells -with only one percent water cut as
water productive is two fold. First, history has shown that shortly after
cuts reach approximately one percent, there is a rapid rise in water cut.
Second, production profile logs and pressure surveys have indicated that
water tends to accumulate in the casing opposite the producing formation
even for low cut wells. The amount of this accumulation is a complex
function of fluid production rates, produced fluid densities and casing size.
Exhibits II and III are similar sets of working graphs on wells Trading
Bay Unit State G-? End G-8, both on the Grayling Platform. These graphs
are plotted routinely by Union's reservoir engineering technicians for
us by engineers when analyzing field and well performance. Both are
broken line graphs of actual well test data dating back to initial comple-
tion of the wells. On those graphs are noted the occurrence of shut ins
and their duration beginning shortly before the wells began producing
water. Both show the detrimental effect on production when water
cut wells are shut in. It is Operator's belief that loss of productivity
resulting from shutting in such wells cannot be helpful and could contribute
to reduced ultimate recovery.
Engineering Report
Conservation Order No. 95 2. October 13, 1971
Exhibit If shows that Trading Bay Unit State G-2 began producing approximately
one percent cut in the second quarter of 1970 and this began to increase
rapidly in the last half of that year. A 15 hour shut in on March 18, 1970
and a 13 hour shut in on May 22, 1970 had little effect, if any, on
productivity as evidenced by tests immediately before and after the shut ins.
This well was making approximately one percent water at the time. An 18 hour
shut in on July 14, 1970 appears to have caused a reduction in productivity,
at which time G-2 was producing with 6 percent cut. The 25 hour shut in on Septembe
16, 1971 definitely caused a reduction in productivity. At that time, G-2 was
producing with approximately 11 percent cut.
Exhibit III illustrates behavior in Trading Bay Unit State G-8 similar to
that seen in G-2 above. Shut in periods during July, October and December 1969
appear to have resulted in definite losses in productivity. This is also true
for a shut in in March 1970. Subsequent short term shut ins had 1 i the per-
manent effect suggesting that the first few times drowning occurs is when
the majority of damage is done to the,wellbore; however, later longer shut in
periods increase the radius of damage. Note that damage to G-8 occurred at
cuts below 5 percent.
6(
Dg 5(
z
0
u
C
z
0 Z
d
3(
u
X
2(
H
1: Y W I PZ I T I
__Hl
STOR-Y--OF, WATER.LG U T--W Ell-
-------------
BAY
-McARTHUR:RIVER :HIELD-'
_ __,___
_. _
__ ._
__
G K —1 N E E T SK A
L
_-A-
----G S-
E�F_ 10 7
1.
---- —
------
F_
_.T7.
......
IiJ_
I- J
—I--
_J
............ . ..
4
=T
IL
.... . . ....
0
ph i:,-,i -n El-
d e _S_ 14
------
.......... —
o n
we I I
J
4
.-H
=4
L
-7-t-
al nu
r o-r
b e►^
-O.t
e
-0 rFS7
...... ....
...--C()M
1.
7
77
ce- n
t --- a c
rn
. _4 1
4
-producing
...... .
............
M
. .. .......
I
0 s.
.. .... .. .
r6duc )a.
-ter
<
W 0 7- C
19 67
19 68
1969 __—F
19 70
19
FIEL
IWIL
.04017- zr,
100 T —.r.- — --r.
--,F-: I
T
vi ri.l.
-A F
to... ... .... .. . .... .... .... 7
..... .. .. ........ .. . .. ..... ............. .....
..... .. ..... .
........... .... .. ... ..
A
9560 9G85
LEASE ilm P1 u'-.x- A,-I,—J.T
'a�j�UR RIVER
-7
4 v L L o G 2
.. ... .... ..
L
4' CL
E.... ...... l
�7
T.
. . . . . . . . . . . . . . . . . . . . . . . .
- - - - - - - - - - - -- - -
r
... . . .......
[7.7
J
::A
a
I
F7
. ... ... ...
....... ..... .... a
.0
'o
ac:o
7000
fl3co
5000
40i3 .
.J
C2
rt
O
5000
Boo 0
1
700 CA
600
'Da
-1Z CIO
. . . . ........
........... .... 100
........ 20 25 5 10 15 20 25 5 10 15 20 25 5 10 15 20 25 5 lu 13 ;0 zs ; �1013
25 5 .:, 1!, 20 25 5 10 15 k.0 25 5 10 15 20 25 5 0 15 20 23 5 to 15 zo Z5 to J ; ULY AUGUST SEF'YErABER OCTOBER NOvEMBER DECE&-VER__
i—"O. ,us "2ROY FEUPI;Any MARCH APRIL MAY JUNE I
F014M 79DO IFkXV A/671
1967 -
W,11 T.sLs
NkUU. INT.
• e THUR RIVER `�-� U�• ^ � )' � � t
FIELD _MCAR 9705 LEASE RADII: A: UI::IT. _ 100 Li;^.E %
_1'GMLUC:K
----r••-'1- '!-'-j- r ..{,.._,.,, ,., t„•,•t .., rrtLL NJ. V � � 3;�'�`
t
{TR, I�t Rr�> rai n1-1 T rr :rat,.-i, ..� ..(- , 1,.,,ai...I,.,al. I .,.. ,!rlla.,.•..!. .la I: L. ,. t ^�t
M '
W _1 -I i i - .} .�.....{_... _Ai
I .I• - -- - -�• �- 1- - •{:-- 1i _ .I i-• I , I. I t
�.: I I I. If }....� I 1'
,.,CL
t . ; I - I ' I.: .( i I I I 1 ! I I i' ! �' , ! ! + I t• , I ... , .1. , ! W
- � --io G. I1 � I / . � � � ? I i I � , .{ I .��•' i ' I I .� .� (. ; , I ! i .. i , . I .. .i a
of—
cr
F,�tOU> ' �~`'�jN'I.: i�} •�j .I- ,. :1, (.. ;I ,.:.,'^ �tT 1_ •.,-�T�,�•�; --
r -r- .I.., ' , I.: is
1'
.1
1
f•
I
I' ►:
I10
•'( I .:. �. .,.. -
-I !
4000
C — - ! I r ! 1 - y0
-..I-. .�-..:I..:..
1 i ; ; ; �• .I { ., ; , !- ; -I -I I ! ! ! I�_ ! '- :I , �; - ���• !' _ �! I I ( 1 i .. 2000 V
_ i ,
Z -i ! ' - I _1 �._I, 17, ,-' I i i_ -' ' ' i• ` .-�_--' I I i--^1'-• ' ' ._..,._.. I .ate. —I_ I_i_ ! _i-._r_... ... 1
- � ' I ! i � ! � I � ! ' ! !: I. t i� I 1 i I 1 i. � �� I I• I I' -I I i I I � �_ i 1' ' ' 1 I 1 I. o
Q� IOC _._. - - , ;. I. ,. .!. I ! - , I I• I ( I !- - ! ! I ' ' , i 1.. .� ! , I ! ! ' ( I r
V l�ilC - -- __ - .- _--h—_r _.»_ tY-•.±_-.., I:• . 1 I ' '�_ _ I _ ' , I _i ' .I —' 1 - 1 I r tcr
I
AL e i— 1 - r--' - --
ec _ _ __ __ , 1 � -- i � i ;�i I:... f � --r--- I I j —!- ! I � r-- •f i-----�--r—T_""'__ __.. � � --- - 7co v,
i
t—
•-!--
a
• --
..-4-
q i
I CIO
-
-� -• - �- •._-..__,.._r _ _ ;._ _� _.; I !. I - I.
I I I ti
I' 1
iG - --- - ! ! ! ! r I I I ! I• -� ' - ( ' -- ! 1 �_. — _�__
S 10 15 20 25 S 10 15 20 .5 S +O 15 20 25 S 10 IS 20 25 •_1 -'--- ---A-- ' - -_---- !OJ
- 70 2S S 10 IS 2J 25 S 10 15 20 25 S 10 15 20 25 b 10 15 20 25 6 10 15 20 25 5 10 15 JG 26 5 10 IS 2C 25
JAMUARY FEffn UwnY MARCH APRIL 'MAY DUNE DULY AU6U5T C.EP:fMBER
OCTObER NOVEMBER OECEMOER
- FORM 79>lO IRlV 2/97)
- i9 68 - W:.11 is sts
l' I UMcArthur River
. D
100 ........
t F!"T
13RAVJTY
LE -SE lr3a-:,c nay Unit
A
.. ... .... ... .........•...
.. .... ..... .. . ...... .. ...
' t ' - i i, I 1 I ! ' I .I I i I ; j I I ' I -�� '' I' -i-•' r 't r" f '- j f -� t - ---
- - - - - - - - - - - -
.......... ..
40
- )3b
34
A
7 77;
T':'�7 7.T. ... .... j. ... .. . .........
........ ..
t 600
20000
w. a .. .....
... .... . .. ..... ...... .......
%6 . . . . . . . . . . . . . .
I. I i I .j .- I ., .I. , 1 !- y ! ; 1 1 I I 1 ,- •, i .(...L. i -
..... .... . ... ....
. ... .. ..... .............
......... i—A -j .. ... ....
7
too, (a f Q, ... . .. 000
... ...... 71 m
--------- -----
- --- - ------- scoo
a V,
7000
70C, ------ ...... ...... ..... ... .......
d. 1 1 V
. ...... Scott
Goc .....
A
J—*
5,
soc
-7
4
...... .. . .. ...... . ... ...
a
In
5 coo
7-
A.... .... 1.
jjp�l U.
1101
200o---------------
2OC9
+
f.. .. .. .... .... ..
loet
Oct .. . ..... ...... . .... ...
0
------------- ....... 600
700
r
TCA
600
.7.
..........
r
j-
......... . .... ------
a
&0
t
17
m
2CA
7. CIO
7
... . ......
-4
.. ........
. .... .... ..
v
5 10 IS 20
2 -A 5 10 1- 2 C, 2 r 5 2to 6 10 15 20 25 5 10 15 20 25 5 10 IS 20 25 5 10 15 zn 25 5 10 I'S 2U 25 5 10 15 IU Z5 5 10 is 20 25 S tU Idj ?o 23 -0 25
JAMUARY MAkCF4 APRIL MAY Jl,ho JULY AU:I,-ST III '- Ill L, U E R OCT03LA NOVEMBER DLI:E)ACE.q
N
PRODUCTION RATE - B/D PER CENT CUT
P 0_0.1^,
cc
i t 1• 1 '��
y
-i- -
-- - -. t- ---�
I 1
7 7-
_
p-- - - - - --.. T_ I .. __..1--• t--7..... !__
1 ; ..
=3
me sr
_
1
, !
4.7
T .',
I.._
} I
As. µeSit".::-
77.
> O t I
74 1,
f
,
1
-
V 7-7
-
ff
O O O 4 O p O O it AO
GAS - OIL RATIO - CU. FT. / BDL.
PER CENT CUT
I
c._
PRODUCTION RATE -B/D PER CENT CUT
w
M V + u • V • tl 0 _
M u ♦ a • V • tl O C, J O 1 O n
I
� '
1_ .i. .7
A 17
;-- —
__
:_.. I
A« I --�' .--—
I i
-- — - - - -
--�
I
I
- ---
--- -
is
-
- f- ---
:l
1 I
771
17
4+91
-•I - # f..1 1 1. --
1
N I— i 1 .
1
1 , 1! i,--i- 3 1
�._: ,
� I I � }
177.
7. — = ` — — 17-7
--
I i.
. ii
-- -- . _ --- -- _ is i _:1 , — -:� �� . —= �3
1 ,
{{
-
t
• ' 1
•1- r
I
I
'
,
}
I � i i•
I
7.
_
c
:
U y,I • N _.• M_�
O p O �
0^ 0 0 o L o ti c> o o c; .� o 0N
v o o u o J
' v
GAS - OIL RATIO - CU. FT. / 1IBL. PER CENT GUT
z
Li
IY
ui
0.
FHOU IN(.
'RAD"',3 -'A" UNU
McArthur Rivor r A � -C
ALLL No
too
1 171
14 A,
i i i ` i I 1 ! I t i+ ' ( { I l I.• � j j t i j, i , I i , j l I � I i i � j , i .. j1 �
i p
1 I i i ' i I I'I I i l ii I! I , I R i I 0:
i 1 , .I , i I ! I ! I., 1 �,...I. ... ... Ea.
a
CT
j .......
0 ......
- ----------- --- ... .... 7. ........ ....... F:77-f.: :-"7717T... F. T. . ......
... ......... . .... .
a
...... ..... .
.... .... . .. . .. 1.7
4 L
. .. . -: "-: -: --i --- ------------
d A
- - - - t- - �_ , ! ,
14 ......
...... .. ... ..... ... . .... . 14
to
0000
8000
7r
T 00
rT:
m
:7!
�7.
7—, f-
...... .. .... ... ... ..........
403-0
... ....... - ------
-7.
m
-7— -- ------
3, ...... -- -------
t 3000
m I i.
...................... ...... I.: . ...... -------
L
i
20010
V;
+
4i
'COO
5:0
A
... . .......
. . ....... . .. 0
a
j
T—r- t ......
A :I . a
A
7—....... ...... ........ . ......
':' 7'7—'
.....`. ' ,. ' .' _ i. .; i ; f
2C COR
V: T
...........
.. ..... ... . 7 717 t r
-7
a
I ! i ; :� ;a
10 100
f5 20 3 �) 15 20 t; 5 10 i2o 25 5 to 15 20 25 5 10 IS 20 25 a IQ Is zo 25 5 to Is zo 25 5 to 15 20 25 5 to 15 20 25 --57-10 15 20 25 3 IS ?o 25 5 23 25
o 5 1r ;.014JAn#' MAUCH AFRIL MAY Jullf; JULY AUGUST SEPTLMSER OCTODIEA NOVEMBER DLCr)-azA
19__o
WELL TESTIS
McArthur Viver 1rddim, any'Lt..[Fi E 1. 1) LEASE
H.
t J
too .......... r-1 -.1
...... .. !.,T[llr T11, 11- -111 . -:1 " �] - -.1 1-- - v - r
740
-IT171
GRAVITY .
::�: ; � . 1iI 1 ; � I! 41 � {.. 11II( I � I i ! � 1111 � ►�. ( . � ; ,. �. � .�. ' .,. ; .., , .j
. .......... ..... 77-7
........ ...
. ........ ...... . . .. ... . ...... ......
. . .. . ........ .... . ... T:.
2o030
. ... .. ..... ......... .
... ......... 7. . ....... .... ...
..... ...... .. ... ..
Jw
............ ........ ....... .......
. ... .... ...
...... ....
100110*' —------ ...... - ------
... . ........ . .
7000
ol: m i A.
m
5000
A.
..........
4CCC
J
-4
B/D . .. . . . .
........... - - ---- -- 3000
A.... ..............
L6
Cm
2 01:4 ....... z C-1 0 :3
w
'�1.,.
.. .... 4--4-
........... . ... ...... .... .. . i.
0
0 A .
+
Cr
030
lCil
0
- — -------- - - -
In
q
r. 00 . ......... ....... --'-7r7
- ----------
.. .........
F
4 f 4 - ......... ......
... 1-7
lCO
2C4 -
... —L-4—
lit I
10 -•5 io Is 20 25--1 3 JU 25 5-10 ir do 25 5 10 15 20 25 5 10 15 20 25 5 10 is 20 25 5 to 20 To 20 25 5 TO 15 20 25 5 10 15 WO 25 5 to is 20
JAN�AAY FLU�,,AFIY APRIL MAY JUNE JULY AUGUST S-EPYEMBER OCT08ER NOVIEMBEF
naIu/ rseT nxrux
rmxo/wmm«v Mr
too
40
�
"
^
"
�
^
�
. ^^—�^—�--^—�'^�—���--�c��� �� 200(0
| Li
20000
14
7000
�
� �
° ~
. .~
� z000
cc
loce
8 �
cc �
. �
�
C)
3C4 A.
\�~
T RA D 1; 4 "'3 --AY UNIT
7r-r—
]IT.
a ....
ii 3b
a
Ip
u S= �--�• :....� � Ii Ii�►':��� � ���iilI��1ii,,�;���;.;�Ii�� f � '�
. . .... ..--. ....•
.... .... --- -.. .... ..
f i28
cWi
ELI .. .. ... . .. .. .... ... .
I L I. .
.... ... ...
............... . i ..... .. . . . . . .
t
. . ... ..... ...... .. .....
... ..........
......... .... .... ........
... TV . . .............
..... 20OW
. .... .....
......... . . .. ........
. .... ...
.... ..........
QQ t
............
r. T. f
100
qv
0000 A
----- - -----
8 01
9000
7000
a
ficco f 7
77-
... .......... 7-
.400t
.... ..... -
000
------ ......
1za
--
F
N.
50-:-0
I
61
MT . :p
..........
.. .. ... .....
I
0
.................. ...... . .
D 10C - - _ - - - ' - I I ! ' 1 -,+-j i '_ _L. •� ' ' ..._1..._1 - - 1 -- - - I I , j I i ! i ; ;. •-1.- .i.: I i .i I . l I .��
-7 '000
a
goo
c ----- ------ -)00
-
•
700 to
r-7:• ------- - 60.0
500
4' .. ....
t Do
. ......... — ------------- ....... —
....................... . . .............. 1.
!C0
.. .. .........
. ....... .. .
7 all
.... .. . ....... ... .........
. . ... .. . .....
200
"7 ...
A
Ic
5 10 i5 20 25 5 10 15 ?a 255 to 15 20 25 •5 10 in 20 25 5 to 15 20 25 6 10 15 20 25 Z 10 Ib 20 25 51 10 15 ko 25 5 10 Is 20 25 & IV le .15 �Oo
0
JANUARY MARCH APRIL MAY JUNK DULY AUGUST 6LPTE14SER OCTOaCR NO,EMDLR CLCIII.M&ER
FORM 71,30 Imav 3/47)
19. '71
Union Oil and Gas [ ;ion: Western Region
Robert T. Anderson
District Land Manager
F1
D!R � ;�
C. GEOL
C. ENG
1 ENG
2 ENG
3 ENG
4 ENG
5 ENG _i_
1 GEOL
3 GEOL�I—
REV
DRAFT
SEC
FER,
Union Oil Company of California
909 W. 9th Avenue, Anchorage, Alaska 99501
Telephone: (907) 279-7681
union
Application for Extension
of Conservation Order No. 95
Gentlemen:
October 7, 1971
A � /A L76.�
State of Alaska
Oil and Gas Conservation Committee
3001 Porcupine Drive
Anchorage, Alaska 99504
Union Oil Company of California as Operator of the Trading Bay Unit,
requests extension of Conservation Order No. 95 in accordance with Rule
8 thereof.
It is a widely accepted fact in the petroleum industry that drowning of
oil productive intervals by either formation or injected water can cause
wellbore damage with resultant loss in productivity and potential loss
in reserves. Such damage is impossible to prevent but it can be
minimized by minimizing downtime and operating fluid levels. Many Trading
Bay Unit wells now produce water due to natural water encroachment and
water injection and several have sustained water damage due to unavoid-
able drowning. This problem can be expected to increase with time as
both the number of wells producing water and the volume of water produced
will increase. To reduce potential wellbore damage the Trading Bay Unit
sub -operators have sought to use gas well gas for gas lift on an
emergency basis in event of gas lift equipment downtime.
Exhibits 1 through 3 are tabulations of occurrences when gas well gas was
utilized for lift purposes pursuant to Conservation Order 95 on the
Dolly Varden, Grayling and King Salmon platforms, respectively. These
tabulations show by date the amount of such usage and the reason a
compressor or compressors was inoperative and unable to supply 1 i ft
gas on the platforms. Exhibits 4 through 6 are plots of the cumulative
hours per month that the gas wells were utilized for lift purposes on
each of the platforms. Exhibits 7 through :9 show this same information
with the hours cumulated by quarters. Conservation Order 95 provides gas
well gas may be utilized for lift purposes up to 15 days or 360 hours
per quarter. These exhibits show only one instance in the past year,
while operating under the provisions of this Order, that necessitated
approval of the Conservation Committee to exceed the allowed number of
hours. Had the FiEld been operating under the provisions of Section 2158
(b) (3) of the Conservation Regulations, there would have been 6 months
which would have required Committee approval to continue the use of gas
well gas.
The total amount of time during the year which required the use of gas
well gas for lift purposes can be seen from the exhibits to be relatively
small. In reviewing the tabulated information, it is apparent that most
instances during which a compressor has been inoperative have been completely
nonpredictable. Scheduled maintenance and overhaul time is a relatively
minor portion of the total compressor downtime in practically every month.
This indicates that the use of these gas wells for lift purposes is being
held to an absolute minimum by the operators.
For operational flexibility the tabulated and graphical information
attached indicate the desirability of continued operation under
Conservation Order 95. There has been very little use of the wells over
the amount provided by Regulation; however, the ability to cumulate hours
has reduced significantly the number of instances during which adminis-
trative approval would have been required. This serves to reduce the
burden placed on both the operators and the Conservation Committee for
consideration of individual occurrences without risking waste or damage
to natural resources.
Technical information and exhibits submitted in this application were
prepared by the Trading Bay Unit Engineering and Planning Group. Members
of this Group are available to answer questions upon request.
Your approval of this application is respectfully requested.
Very truly yours,
UNION OIL COMPANY OF CALIFORNIA
Un i t ,Operator
B
Wade . McAlister
WSM/s k
Enclosure
cc: Working Interest Owners
Trading Bay Unit w/Enclosures
M
MARATHON
MARATHON OIL COMPANY
PRODUCTION —UNITED STATES AND CANADA
December 31, 1970
Mr. Homer Burrell
Department of Natural Resources
Division of Mines & Minerals
3001 Porcupine Street
Anchorage, Alaska
Dear Mr. Burrell:
P.O. BOX 2380
ANCHORAGE, ALASKA
DIRif
IC.GEOL�
C. cN1G-��
—I- i- rNG
—i
`I\i-J
v
Ji C
CCi�rE�;:
--F (LE: ----
`
This letter confirms the telephone conversation between C. J. Diver and
you'December 30, 1970, during which Mr. Diver requested that an emergency
order be granted allowing an extension of the time allocated for usage of
gas well gas for lift purposes to prevent possible well bore damage.
During production operations on the Dolly Varden Platform in this quarter,
the gas well (D-18) has been utilized for gas lift purposes a total of 357
hours as of midnight December 30, 1970. Since this quarter ends at mid-
night December 31, 1970, this emergency extension would be of a 21 hour
duration. This extension is necessary so that gas from 0-18 can be used
to supplement the gas lift system until repairs to Compressor Unit 1 are
completed. Mechanical di f fi cut ti es with this unit were experienced early
on December 28, and a diligent effort has been made to expedite the repairs.
Parts necessary to complete the repairs were ordered by telephone December
28 and shipped by air freight. However, the parts were lost in transit
delaying the work for approximately 36 hours. The necessary parts have
now been received and a factory representative is currently completing
the repairs.
Attached is a summary of the gas usage for this quarter prior to the
compressor failure on December 28, 1970.�"
attachment
Yours very truly, ,.
9: G. Howard
District Operations Manager
R Ii
Ay '
04V11b1+,-;N OF ()iL A al.) GAS
ANCHQRAr*
04V11b1+,-;N OF ()iL A al.) GAS
ANCHQRAr*
GAS WELL GAS USAGE
Third Quarter - 1970
60 hours During this period Compressor Unit 2 was down to install
anodes in the heat exchangers on the cooling skid. Anodes
are necessary to prevent excessive corrosion in the sea
water to gas heat exchangers.
46-1/2 hours Revisions to the platform cooling water system and the
installation of a 400 HQ booster oil shipping pump re-
quired the gas lift compressors to be shut down during
this period. D-18 gas -was utilized to lift several wells
while these modifications were being completed.
30 hours A gasket on the fuel line to Compressor Unit 1 failed
allowing gas to escape into the room. The gas ignited
and was subsequently extinguished by an automatic dry
chemical and water system. It was necessary to change
spark plugs, ignition transformers and thoroughly clean
the engine prior to restarting. The gas well was utilized
to supplement the gas lift system during this period.
172 hours During the past quarter, gas from the gas well was utilized
for lift purposes 172 hours while performing minor repairs
and routine maintenance on both compressor units. These
repairs include changing spark plugs, ignition transformers,
suction and discharge valves, pistons, gaskets, etc.
23-3/4 hours The gas well was utilized to supplement the lift system
for an additional 23-3/4 hours. During this time either
one or both compressors was down for miscellaneous reasons
which include power failures, high or low levels, and high
or low pressures.
r .wwr
DOLLY VARDEN PLATFORM
GAS WELL UTILIZATION FOR GAS LIFT
EXHIBIT ]
DATE
HOURS
REASON
1970
Oct. 1
1-1/2
Electrical malfunction in emergency control panel.
2
7-1/2
High liquid level in fuel system, and repair compressor
cylinder valves.
3
12-1 /2
Mechanical repairs on C/B #1 .
7
3
High liquid level in separator, and production shut
down for construction on shipping line.
9
13-1/4
installing shipping pump, and broken starter on C/B #2.
10
4
Repairing starter, and tightening gas leak on lst stage
suction valve.
11
2-1/4
t
Power failure, and work to stop gas leaks on compressor
cylinder.
.12
1-1/2
Taking web deflections on C/B #2.
13
4
Power failure, and repair gas leaks on C/B #2 compressor
cylinder.
18
4
Power failure, and because of malfunction in scam panel
throwing emergency breaker.
20
2-1/2
Repair water leaks and change spark plugs on C/B #2.
23
5
Replacing valves in compressor cylinders on C/B #1, and
high explosive atmosphere in shipping room.
25
3
Replacing compressor cylinder valves.
26
1-1/2
Replacing head gasket on #1L power cylinder on C/B #i.
27
3-1/2
Replacing C/B #1 head gasket, low lst stage suction on
C/B #1, and high level in suction scrubber.
29
1/2
C/B #1 down on high pressure shut-in.
31
3-1/2
Changing plugs, fuel and start-up problems.
Nov. 2
2-1/2
Power failure, and starter repair.
3
7
Numerous no -indication shut dol'Ins on C/B ;!l and to fix
gas leak on lst stage after cooler, C/B #2 down to
change plugs and low tube oil pressure.
DOLLY VARDEN PLATFOR14
GAS WELL UTILIZATION FOR GAS LIFT
DATE
HOURS
REASON
970
Nov. 4
6
Construction to tie in sand filters, repairing compressor
#1 engine.
5
1
Repair 1st stage blow down valve.
7
6-3/4
Tie in compressor cooling water lines, and high jacket
water temeprature.
9
1/2
C/B #2 down to hook up torque limiter.
14
7
C/B #2 down - ignition problems, and high 1st stage
discharge pressure.
15
1
Ignition problems on C/B #2.
16
5-1/2
Replacing compressor valves on C/B #2.
18
1-1/2
Replacing ignition transformer on C/B #1.
21
11-3/4
Construction - connecting salt water cooling lines to
system, repair gas leaks, and high jacket water temperature.
22
2
Construction - connecting salt water cooling lines to
system, repair gas leaks, and high jacket water temperature.
23
10
Construction - weld-10" water line, starting engine, blown
gasket on manifold feedinq gas valve on #3L power cylinder
which ignited causing Fire Boss system to activate.
24
20
Cleaning C/B #1 of Ansul powder, replacing ignition
transformers and plugs. ,
25
3
J
Changing out C/B #1 ignition transformer.
26
12
C/B #1 down 3 times on No -indication shut downs and shut
•
down because of knock in cylinder #5 left.
27
9
C/B #1 down to check knock in #5 cylinder.
28
14
Replacing gas injection valve, head gaskets, and exhaust
gaskets.
29
1-1/2
Change spark plugs.
30
4
Repair Turbo assist, high pressure in vent scrubber, and
repair lst stage discharge regulator.
_2-
DOLLY VARDEN PLATFORM
GAS WELL UTILIZATION FOR GAS LIFT
DATE
HOURS
REASON '
1970
Dec. 1
2
Change spark plugs.
2
4
High lst stage discharge pressure, and low lst stage
discharge pressure.
3
15
Replace head and Exhaust gaskets, plugs, and unloader
valve, low lst stage suction pressure, relay failure in
Scam panel.,
4
3-1/4
Change spark plugs and 3rd N-Ldge unloader valve, low lst
stage discharge pressure.
5
3-1/2
Weld collars i n- glycol lines and high 1st stage discharge
pressure.
7
7-1/2
Low lst stage discharge pressure and starting problems,
power failure.
8
2-1/2
Changing ignition transformer and gas valve.
11
71
Welding glycol unit, change spark plugs and starting fuel
valve, repair gas leaks on compressor cylinders.
12
7-3/4
14
1/2
Power failure.
15
6
Construction - installing anodes in cooling skid exchangers.
High jacket water temperature and valve repair.
16
12
Working on cooling skid exchangers.
.17
24
Installing anodes on cooling water skid.
18
18
Installing anodes on cooling water skid.
.22
11
Repair suction unloader valve and explosive atmosphere in.
#1 compressor room.
24
3-1/2
Faulty governor and low 1st stage discharge pressure.
26
2
Low 1st stage and low 3rd stage discharge pressure shut-
down.
27
17.
Bendix out of Turbo and broken piston.
DOLLY VARDLEN PLATFORM
GAS WELL UTILIZATION FOR GAS LIFT
DATE HOURS REASON
1970
Dec.28 5 Power failure to control panel.
30 10 Repairing Turbo assist.
31 24 Repairing Turbo assist. .
1971
Jan. 1
24
Repairing Turbo assist.
2
24
Repairing Turbo assist.
3
9
Repairing Turbo assist.
5
1
Power failure.
6
8-3/4
Power failure 1 hr. , repair gas leaks and replace head
gaskets 7-3/4 hrs.
7
7
Changing plugs and transformer on C/B -#29 and high
pressures and levels in separators.
9
16
Power failures, repairing fuel gas valves.
11
3-1/4
High jacket water temperature.
12
3
Replace head gasket, high jacket water temperature.
13
8
Break in water injection line caused short in gas and
fire detection systems. Change spark plugs and
transformer.
14
2
Repair line on water injection system.
17
10
Contaminated .ai r in fuel gas regul ator ' caused low fuel
pressure causing load shed. Repair leaks in compressor
cylinders.
18
5
Repair 1" bypass line from 3rd stage discharge to 1st
stage suction.
19
6
Loose piston rod on.#3 compressor cylinder on C/B #l.
. 20
4.
Replace valves on 3rd stage compressor cylinder.
21
13
Repair gas leaks and replace #1 compressor cylinder valves.
r
4
I
DOLLY VARDEN PLATFORM
GAS WELL UTILIZATION FOR GAS LIFT
DATE
HOURS
REASON
1971
Jan.22
4
Power failure.
23
2
Low lst stage suction. pressure.
26
2
Low lst stage discharge pressure and replace gas
injection valve. ,
27
7
High liquid level in 2nd interstage scrubber, frozen
drain line, and replacing valves s 1st stage compressor
cylinders..
28
2
Power failure, and low suction pressure.
29
4-1/2
Repairing fuel gas regulator.
30
4
Down 3 times due to low suction pressure and once due
to low fuel pressure.
31
2
Low suction pressure.
Feb. 1
3
High temperature in #4 compressor cylinder, and low
suction pressure.
2
6-1/.2
3
9
Power failure caused by malfunction of control valve on
D-18, low 1st stage suction pressure.
5
11-1/2
Repair valve in #5 separator, replace 3rd stage discharge
valve, repair starter, and electrical malfunction.
6
18
Repair compressor valves, low suction pressure, replace
plugs, transformers, and dry out engine after fire water
'
deluge.
w
7
4
Repair Traban unit, high temperature on 7#4 compressor
cylinder, and high discharge pressure.
8 `
9
Repair compressor valves.
9
3
Change spark plugs.
10
.2
Change plugs and fuel gas valve.
11
9
Repair Traban oiler, low 3rd stage discharge pressure.
DOLLY VARDEN PLATFORM
GAS WELL UTILIZATION FOR GAS LIFT
DATE
HOURS
REASON
1971
Feb.16
6
Low instrument air causing power failure.
19
4
Recalibrate pressure shut down switches.
20
1-1/2
Change plugs and service pulse generator.
21
1
Power failure.
22
3-3/4
Explosive atmosphere alarm, and construction in
compressor room.
23
4
Change plugs and clean air intake filter.
24
5-1/4
Construction in compressor room.
25
10-3/4
Explosive atmosphere alarm, construction in compressor
room, high jacket water temperature, and low lst stage
discharge pressure.
26
5
Replace head and fuel gas valve.
March
5
20
Replacing cracked pourer cylinder.
6
19
Replacing cracked power cylinder, also controller on
sensing line to the flare scrubber froze.
8
8
Change compressor valves and repair leaking valve caps.
.Knock in compressor cylinder on C/B #1.
12
2
19
1-1/2
Plug change and compressor valve.repair.
25
10
C/B #2 down to repair lst stage discharge bottle.
29
1
Installing repaired lst stage discharge bottle.
30
5
Replace exhaust gasket and adjust ignition system.
April
1
3
Replace head gasket on power cylinder.
3
11-1/2
Change plugs, balance engine, and replace piston.
4
22-1/2
Replacing cracked power cylinder.
6
DOLLY VARDEN PLATFORM
GAS WELL UTILIZATION'FOR GAS LIFT
DATE
HOURS
REASON
1971
April
5
24
Replacing cracked power cylinder.
6
24
Replacing cracked power cylinder.
7
24
Replacing cracked power cylinder.
8
13
Complete repairs and inspection.
.9
4
Repair temperature on jacket water system and repair fuF-1
gas regulator.
10
7
Installed new fuel air ratio controller, reset engine
timing, repair torque limiter.
15
9
Construction - start up problems after platform shut
down.
16
8-1/2
Replace power piston and 9 cracked heads.
17
1/2
Two power failures.
18
22
Replacing power cylinder heads.
19
24
Replacing power cylinder heads.
20
8
Complete repairs on C/B ni.
23
1
High jacket water temperature and start up problems.
28
1-3/4
Change spark plugs.
May 1
2-1/4
Change leaking compressor valves.
5
1
Repair gas leak in compressor #2.
6
1
,Checked high pressure shut downs on shipping lines and
on vessels in production -room, and change plugs.
7
7
Down numerous times while welder worked to change out
„cooling water pump beneath C/B nl.
8
8
Replaced head gasket, spark plugs, and made other
adjustments because of 3 no -indication shut downs.
DOLLY VARDEN PLATFORM
GAS WELL UTILIZATION FOR GAS LIFT
DATE
HOURS
REASON
1971
May 10
2
Replaced compressor valve and electrical problems.
15
3
Changed spark plugs on C/B #1.
16
2-1/2
Replaced exhaust gasket on C/B 7171.
17
7
Replaced 0-rings and gaskets on C/B #1 compressor
cylinder.
21
3
Replace transformer and exhaust gasket.
24
1-1/2
Power failure.
25
-1/2
Low 1st stage discharge pressure.
26
3-3/4
Repairing and synchronizing generators.
27
3
Replacing compressor valves.
28
1/2
Accidental shut down while repairing gas detector.
31
1-1/4
Changed spark plugs on C/B #l.
June 1
1
Changed spark plugs on C/B #2.
10
1/2
Repaired leaking gas valve on C/B #1.
12
5-1/4
Installed exhaust fan in compressor room.
16
10
Changed lube oil on C/B #1.
18
1
Repair leak in 3rd stage cylinder cap.
22
4
Check and adjust piston clearance on #3 compressor
.
cylinder on C/B #1.
24
1-1/2
Changed spark plugs.
26
24
Major overhaul of C/B #2.
27
24
Major overhaul of C/B #2.
28
24
Major overhaul of C/B 1#2.
29
24
Major overhaul of C/B #2.
8
DOLLY VARDEN PLATFORM
GAS WELL UTILIZATION FOR GAS LIFT
DATE
HOURS
REASON
1971
June
30
24
Major overhaul of C/B r2.
July 1
15
Major overhaul of C/B n2.
2
8
Fuel gas problems.
3
3
Balance engine and repair oil leaks.
4
1-1/4
High temperature in 1st stA..up compressor cylinder.
5
3
Repaired discharge valves and adjust high temperature
shut downs on compressor cylinders.
6
7
Welded on air intake filter, replaced fuel gas
injection valve and tightened all injection valves.
7
1
High level in 1st interstage scrubber.
9
3'
Electrical short in Sol ar' i n jecti on panel, fuel
regulator problem, and high jacket water temperature.
10
)3/4
Repair broken sight glass on 1st stage suction drain.
11
2
False fire alarm, change ignition transformer.
13
2-1/4
Installed air tugger, high temperature in compressor
cylinder.
14
1-1/2
High jacket water temperature caused by two cooling
water pumps off at same time.
15
1-1/2
Replaced suction valve.
16'
4-1/4
Change plugs, check out fuel regulators, tighten push
rods.
17
3-1/2
Welder worked on water. filter.
20
1
Change spark plugs.
22
2
Replaced gas valve, spark plug, and ignition wire.
28
6
Replaced fuel gas valve, repair suction valve.
DATE HOURS
1971
Aug. 2 6
5 3-1/2
6 1/2
7 1
9 1
12 1/4
16 3-1/2
18 4-1/4
20 4-1/2
21 3/4
22 1-3/4
23 2-3/4
26 3/4
31 1/2
Sept.
2 1/2
3 11
4 6
7 1-1/2
8 1/2
11 1/2
r
DOLLY VARDEN PLATFORM
GAS WELL UTILIZATION FOR GAS LIFT
REASON
Repaired Traban oiler, fuel gas regulator and change
plugs.
High jacket water temperature, and welding in
compressor room.
Change several spark plugs.
Change spark plugs.
Power failure, low 1st stage suction.
Change spark. plugs in 2 cylinders..
Change valves in compressor cylinder.
Changed valves in compressor cylinder, high level in
2nd stage scrubber.
Replace starter, high jacket water temperature, and high
vent scrubber pressure.
No -indication shut down.
Changed spark plugs.
Changed manifold gasket.
Changed spark plugs.
Changed plugs and wiring on 43L.
Electrical problem showing low level in W1 separator.
Replaced manifold gaskets, crankcase door gaskets, and
change seals in fuel gas valves.
Construction in C/B #1 room.
High jacket water temperature twice.
Change spark plugs.
Change spark plugs .
- 10 -
DOLLY VARDEN PLATFORM
GAS WELL UTILIZATION FOR GAS LIFT
DATE HOURS REASO`1
1971
Sept.
14 1 Change spark plugs and transformer.
15 4 Sand blasting near air intake.
GRAYLING PLATFORM
GAS WELL UTILIZATION FOR GAS LIFT
EXH 1 T 2
DATE
HOURS
REASON
1970.
Oct.
1
5
Clean engine on Guy T. Martin
6
2
Oil filter change, Guy T. I"arti n
8
16
Gas cooler inspection, Guy T. Martin
30
4
!uel control valve failure, Guy T. Martin
Nov.
4
5
G-36 watered up
5
6
Fuel control valve failure, Guy T. Martin
8
3.5
Clean engine on Guy T. Martin
9
1
#1 York overhaul, Guy T. Martin, replace seals
10
18
#1 York Overhaul, Guy T. Martin
16
2.5
Pre -Post Lubricator pump failure, Guy T. Martin
17
7
#1 Routine maintenance, Guy T. Martin
18
3
#3 Compressor seal oil system maintenance, Guy T. Martin
19
2.5
Cooling water pump failure
20
1
Scrubber drain lines frozen, Hutchinson Hayes
21
0.5
Scrubber drain lines frozen, Hutchinson Hayes
23
1
Engine over speed, Guy T. Martin
24
3
Cooling water pump failure, Guy T. Martin
29
15
Clean engine, Guy T. Martin
30
24
#3 Compressor failure, Guy T. Martin, replace seals
Dec.
1
14
#3 Compres.sor failure, Guy T. Martin, replace seals
2
15
#3 Compressor failure, Guy T. Martin, replace seals
4
6
Fuel control valve failure, Guy T. Martin
DATE
1970
Dec. 9
10
11
12
13
17
21
GRAYLING PLATFORM
GAS WELL UTILIZATION FOR GAS LIFT
HOURS REASON
7
2
2.5
1
4.5
4
24
22 24
30 6
31 1
1971
Jan. 1
3
4
16
26
28
29
Feb. 9
16
1
12
18
1
10
3
4
9
9
#2 accessory drive failure, Guy T. Martin
Split flare lines, Guy T. Martin, Hutchinson Hayes
Split flare lines, Guy T. Martin, Hutchinson Hayes
Battery charger failure, Guy T. Martin
Routine maintenance (Lifting G-34), evaluate and
D-Oubleshoot G/L valves
Engine surge troubleshooting, Guy T. Martin #3
Lifting G-34 and G-36, evaluate and troubleshoot
G/L valves
Lifting G-34'and G-36, evaluate and troubleshoot
G/L valves
Safety shutdown inspection, Guy T. Martin (installa-
tion of new instrument panel control room)
Safety shutdown inspection, Guy T. Martin (air inlet
icing)
Fire eye failure, Guy T. Martin
Compressor overhaul, H. Stage, Guy T. Martin
Compressor overhaul, H. Stage, Guy T. Martin
Limit switch failure (Yorks), Guy T. Martin
Seal bearing failure #4 Guy T. Martin
Seal gas modification #3/4 Guy T. Martin
4,000-hour inspection, Guy T. Martin
#2 engine change, Guy T. Martin
#4 Compressor failure, Guy T. Martin
-2-
GRAYLING PLATFORM
GAS WELL UTILIZATION FOR GAS LIFT
DATE
HOURS
REASON
1971
Feb.
17
20
#4 Compressor failure, Guy T. Martin
18
24
#4 Compressor failure, Guy T. Martin
19
24
#4 Compressor failure/engine failed #1, Guy T. Martin
20
24
#4 Compressor failure/engine failed #1, Guy T. Martin
26
1
7#4 Compressor seal failed (Guy T. Martin), #1 Compres-
sor failed (Hutchinson Hayes)
27
0.5
#4 engine failed, Guy T. Martin
Apr.
13
20
#2 engine failure, Guy T. Martin
.16
9
#2 engine failure/1,000-hours #1, Guy T. Martin
May
13
18
Fuel regulator and manifold modification, Hutchinson
Hayes
14
24
#2 Compressor failure, Hutchinson Hayes
15
19
#2 Compressor failure, Hutchinson Hayes
25
1
Relay failure, #1 Hutchinson Hayes
26
1
Over speed, Hutchinson Hayes
28
9
Clean engine, all Guy T. i'larti n
Jun.
3
0.5
#3 Seal oil malfunction, Guy T. Martin
7
16.5
#1 York failure, Guy T. Martin
8
5
#1 York failure, Guy T. Martin
9
0.5
#1 York failure/DC power malfunction, Guy T. Martin
13
6
Clean engine, all Hutchinson Hayes
17
1
Low oil pressure shutdown, Hutchinson Hayes
20
4
Clean engine, Guy T. Martin
- 3-
GRAYLING PLATFORM,
GAS �IELL UTILIZATION FOR GAS LIFT
DATE
HOURS
REASON
1971
Jun.
21
4
High oil temperature shutdown, Hutchinson Hayes
23
1
Sequence failure #1, Hutchinson Haves
Jul.
2
18
#4 Compressor failure, Guy T. Martin
3
8
#4 Compressor failure, Guy T. Martin
4
2.5
Tach. generator failure, Hutchinson Hayes
5
0.5
Seal oil modification routine maintenance #4
Guy T. Martin
9
3
#3 Compressor failure, Guy T. Martin
10
24
#3 Compressor failure, Guy T. Martin
11
24
#3 Compressor failure, Guy T. Martin
12
24
#3 Compressor failure, Guy T. Martin
13
24
#3 Compressor failure, Guy T. Martin
14
24
#3 Compressor failure, Guy T. Martin
15
24
Modify York lub. system, Hutchinson Hayes
16
7
Modify York lub. system, Hutchinson Hayes
28
1
High oil temperature shutdown, Hutchinson Hayes
Aug.
2
11.5
Clean engine, Guy T. Martin
6
1
York heat exchanger repair (lub. oil), Guy T. Martin
7
5
#1 engine failure, Hutchinson Hayes
8
2
#1 engine failure, Hutchinson Hayes
16
0.5
Lost inst. air wellhead room #2
24
4
Clean engine, Hutchinson Hayes
-4-
• w
King Salmon Platform
GAS WELL UTILIZATION FOR GAS LIFT
EXHIBIT 3
DATE
HOURS
REASON
1970
Oct .
2
19
Monthly service - #1 Gas Lift Compressor (GLC)
Oct.
3
12
Monthly service - #2 GLC
Nov.
3
2-3/4
High level shutdown - both GLCs
Nov.
20
24
Replace valves in 2nd stage - both
GLCs down for repair
Nov.
21
24
Replace GLC valves - #2 GLC
Nov.
22
24
Replace GLC valves - #2 GLC
Nov.
23
24
Replace GLC valves - #2 GLC
Nov.
24
24
Replace GLC valves - #2 GLC
Nov.
28
24
Compressor down - waiting on parts
- replacing compressor
valve
Nov.
29
24
Compressor down - waiting on parts
- replacing compressor
valve
Nov.
30
24
Compressor down - waiting on parts
- replacing compressor
valve
Dec.
1
24
Received parts - replacedbad valve
Dec.
4
24
GLC down
1971
Jan.
9
5.
Repaired air leak in air chest - #2
GLC down for repair
Jan.
13
22
Major overhaul on #2 GLC
Jan.
14
24
Major overhaul on #2 GLC
Jan.
15
24
Major overhaul on #2 GLC
Jan.'16
24
Major overhaul on #2 GLC
Jan.
17
24
Major overhaul on #2 GLC
Feb.
0
Used only fuel gas for the month of.
February
Mar.
23
24
Major overhaul GLC
Mar.
24
24
Major overhaul GLC
Kinq Salmon Platfor f.
GAS WELL UTILIZATION FOR GAI LIFT
DATE
HOURS
REASON
1971
Mar.
25
24
Major overhaul GLC
Mar.
26
24
Major overhaul GLC
Mar.
27
24
Major overhaul GLC
Mar.
30
24
Replaced studs on 3rd stage #2 GLC
Mar.
3!
24
Replaced studs on 3rd stage #2 GLC
Apr.
1
24
Overhaul GLC
Apr.
2
14
Overhaul #1 GLC
Apr.
3
12
Completed overhaul #1 GLC
Apr.
7
12
Installed new piston rings GLC
Apr.
27
24
Repacked pocket clearance on 3rd Stage GLC
1
Apr.
28
24
Repacked pocket clearance on 3rd Stage GLC
Apr.
29
12
Changing #1 and 7#6 liner and piston GLC
May
'0
Used only fuel gas for the month of May
June
4
20
Repair knock in 3rd stage GLC
July
15
12
Replacing valves in compressor•
July
16
12
Working on lubricator on GLC engine
Aug.
16
19
Monthly service - GLC
Aug.
19
18
Replaced rings on #6 cylinder GLC
Aug.
20
24
Replaced liner on piston in #1 GLC
•Aug.
21
15
Completed replacing piston in #1 GLC
✓1
EXHIBIT 4
EXH I B I•T 5
• 1, to It in III 2n 77 S 10 111 t0 25 •s in iS ;-o 7s S 10 Is 2n 25 a 10 11.1 ?o 29 I'l to ,5 20 23 1% 10 11. 20 25 5 to 17 20 2e s 10 11% If ; S In 11 to .'t
350
300
250
90
�_-•----.i ..._.�-�---j.
'�-�--
171
:
..
i
I I I
�..._ .. I
I
:�
IPLATFORM.
_�GAS_.WEI.L.UTILIZATION
GRAYLING---- ------ . -__
TFO
FOR GAS.LIF'T _
•
-
-- - --
- -
- - - I
-- -- - --
-
_ -� -�-
M,ULATIVE HOURS PER MONTH
i- --.. SEPTEMBE R_ t971.- - --- - - - . - --
—
i
I i I
_._._-----•-- -�- -._ �. _ ... ...
__ �._.;-;--L _
I�
_.�-; .�
�• I , ,1,
--r--;--
�C �f
- �---�-�
i I� j
------;---ram
.._ _ � __
-i. _:__-�-�-- =- - - - --- - :_ ;
� I
:I.mJL
I i 1 •L.
�j I I I
I j � i
I i �, �
_� 1 i� I � � —_ �• ^----i
{ j
I
1 It
. IJ.
__ I•�
t— !-- ----- -- — +
� �:_ • - I
- ---------------
_
1
I
1 I I i
! -- - -
I
-._._. _. _-�._..
, !
f
I 'III I.
-- -
- - -
I :I I
L�
--
� I
_4
I ' :I
! ! f- -
-
I !� � I ►,--____ ' � i ': ` ' '
--1--- L ' _�_
_�_
�
ALLOWED
�
l:�._-I
H1,
.�
i -I•
I..)
i
1 I
i—i_;.
---� �---'-_.t__�
.� -
1 ,
1
:
I
1
,
l i
I l i
I
I •]
I
1
I I
t
i
I
;
1
0 —
6 to to du 26 6 to 15 20 26 6 10 to 20 as
0 10 t0 20 to
a 10 10 20 is 6 10 15 20 20 6 10 la 20 20 6 10 to IIo 20 0 10 la 20 26 a 10 16 20 25 6 10 Is 20 25 6 to is 20 as
OCT.
NOV. DEC.
JAN.
FEB. MARCH APRIL MAY JUNE JULY AUG. SEPT.
1970
1971
EXHIBIT 6
EXHi3iT 7
OGTOl1[R NOVEMBER OECEMBER JANUARY FEBRUARY
_ -
S 10 15 20 27 a 10 15 20 25 -
a f0 13 ^(+ PRIL MAY
to A 15 20 23 3 10 15 20 25 5 10J I5 E20 25 3 1 V` AUGUST SEPT-3 20
0 - - 0•t 15 Y20 25 5 10 t)iS 20 25 5 10 15
?� 3 10 13 20 23
f 3 10 15 z{o 25 3 10 15C
23
-� s t T.
i
DOLLY_ VARDEN'- _
-- I k4E
�---'PLATFORM'
-•--'j-- ,—'—�— I ! I .t� ,. , . ' .I� , �: 1 ! ! � i _ — 1 !- i- ! r__—�—F __ --'t- � VA1.J�-rT ' �Y 1
ELL -U ILIZATION FOR GAG
I - I (" - -�- _-UM ULATjVE___HOURS.__PER QUARTER - -
4 00 -- - - j_ ' _� I - _ -I___ I ! f -1 1 , -�-
-.. _ _i— _ --I SEPTEMBER 197! I _!
! I
ALLOWED ORDER 95 - j -1 i_ -- - - -- i
j ` - -
•
J1----
`-' -j
300 --
-�= - -3
---'
200 ' ! _. ' ! i ; ! 1 1 .' ! i- I !- _ - - --,
M; t i i f i l- r - l__ !._ 1= l— '_ j
I
I --- — —1� j
U 100 1 — — I I — —
t ; t --L-
-i J
i A
Q .:1
[ 10 1a 20 2■ a to 13 20 25 a 10 15 20. 25 a •10 is 20 25
OCTOMCR N0V[MB[R 0[CEMa[R JANUARY
1970
I
-- -
_�- I -
'_i __►
a to to zo 25 a to t3 zo zs
r[BRUARY MARCH
a l0 1e zo 2a a 10 1a 20 as
APRIL MAY
a a• zo as a to fa zo 25
J. N[
I
a to fa zo :a a to 15 zo 23
-
JULY
AUGUST G[PTEMB[q - -
1971
f
EXHIBIT $
,t 70 25 5 10 15 20 23 5 10 Is 20 25 5 10 15 20 25 5 10 15 20 25 5 10 15 20 25 5 10 15 20 25 5 10 15 20 25 5 10 15 20 25 5 to 45 20 25 5 10 it 20 25 5 -_ 15 20 25
:W.
r
i ii'_ • GRAYLING PLATFLRM
a00;- 'ATION FOF GAS LIFTGAS. WELL UTi
-
i
! ! ! '
1HOURS-PER- -- - ----- '
CUMULATIVE QUAR T E - R ,
- - - -
ALL
- ORDER 95 SEPTEMBER 1971 A
I f
(• i 1 , I I I _rt .�j- .; { j I i I ! i , ?" I t. I- :1 —' � — I — �----i
_ -____—
LJ
:
- --- - -
;
--- -- -- -
D 0 ooi
. I
—'—�—
t
. 1 - i. I I i
j _—__— _—.I.--.--•---- 1 i ? I I I
• . i _ 1: -
17
J h i; t I ; j. i_ I; ;
_ I!
100
T
I
------------
Fj
1
I
t I I =44_11
I
3 ,O is 20 23 5 10 15 20 25 6 10 15 20 25 0 10 15 20 25 5 10 15 20 25 5 10 15 20 23 'J-It; '"+ 20 25 6 10 15 20 256 10 15 20 25 5 10 15 20 25 5 10 :3 20 23 5 10 13 20 25
OCT. NOV. DEC. JAN. FEB. MARCH APRIL MAY JUNE JULY AUG. SEPT.
1970 1971
r $ 0,
200
0
••
0
r' `I rn N••. ••
1970
1971
Alaska Oil and Gas Conservation Committee
November 29, 1970
Res, Conservat.im Orders 95 and VV
McArthur River Field
McArthur River Middle Kenai. Qw Pool
U0104,011 Company of California
909 West Ninth AVIMUO.
eberaw * Alaska 99501
Attention: Robert T. Anderson
cent.lema.»
Co"ervation Order kbo 95,* dated October 8., 1970, amended Coaservati.on
Order Mu, 80 by addisS Rules 7 and 8 thereto. Rule 7 is hereby
clarified and. Interproted to me= that the *wdmaperted o1 15 days
,per calendar u arter durUS wbich the escape of Vw is permitted without
Comdttee apprav&l a"lies separately and individnaUy to each of the
three platform ;in the Arthur River Fleld
vary tr17 yonn,
Thy .w Marshall.,. Jr. �, �:euti Secretary
Alaska 011, and Can Cdaservation Committee
Conurrence.
Alaska Oil. and Gas Couservati4m, Comittee
etu
Alaska Oil and Gas C=servatien Comittee
RM,SUS z Is
Union Oil and Gas F"vision: Western Region
Union Oil Company y of California
P
909 W. 9th Avenue, Anchorage, Alaska 99501
Telephone: (907) 279-7681
unia"'O'n
Robert T. Anderson
District Land Manager September 9 , 1 970
State of Alaska
Oil and Gas Conservation Committee
3001 Porcupine Drive
Anchorage, Alaska 99504
APPLICATION FOR EXCEPTION TO
SECTION 2158(b) OIL AND GAS
CONSERVATION REGULATIONS
TRADING BAY UNIT STATE K-20
AND FOR AMENDMENT OF CONSERVATION
Gentlemen:
In compliance with your request of August 31, 1970, enclosed
is additional information provided by Mr. C. J. Diver.
Please enter Mr. Diver's letter into the record of the
hearing for Conservation Order #95 .
Very truly yours, ;
Wade S. McAlister
Landman
Enclosure
' DIR
C. GEOL
C. ENG
1 ENG
i 2 ENG I
3 ENG -
4 ENG
5 EN G
1 GEOL I
2 GFOL I
3 GEOL
�_ REV _..
DRAFT -
�f SEC
CONFER:
FILE:
MARATHON
MARATHON OIL COMPANY
PRODUCTION -UNITED STATES AND CANADA
TRADING BAY UNIT
ENGINEERING & PLANNING GROUP
Alaska Oil and Gas Conservation Committee
3001 Porcupine Drive
Anchorage, Alaska 99504
Attention: Mr. 0. K. Gi 1 breth , Jr.
Acting Director
Gentlemen:
P.O. BOX 2380
ANCHORAGE. ALASKA S9501
September 4, 1970
Conservation File No. 95
It is noted that the curves attached to your letter of August 31, 1970,
are plots of monthly production. Since these values are a function of
several variables, among which are the number of days per month the well
is on production, the distribution of available lift gas and mechanical
malfunctions on the platform, they are not a very accurate gauge of well
bore capacity. Production test data rather than monthly production is
generally used as a gauge of well capacity.
Reviewing the data presented you on well K-4 in Milay 1970, measured values
of producing bottom hole pressure were submitted along with the reservoir
pressure. This data, with the measured producing rate on test, indicated
to us that a productivity index decrease had occurred in this well. The
only reason that we could ascribe to this chance was a shut-in period
which occurred between measurements. The actual measured efficiency of
the gas lift system had increased, therefore giving a deceptive result
if one only analyzed the monthly production rate. To reiterate once more,
the productivity index, or the measure of the formation capacity to pro-
duce fluid, had shown a decrease between the two surveys.
Attached is a plot of the production test information on well G-16 and a
copy of the raw test data from which this plot was made. You will note
the performance in mid-1969 reflects the decline resulting from pressure
depletion. As was reported in the "Third Semi -Annual Report" on this
field, the pressure has essentially stabilized as a result of water
I DIR
C. GEOL
C. ENG
I ENG
I 2 ENG f
I 3_ENG II
4F.
ENG.... `--
5 ENG I_
1 GEOL
_L 2 GEOL
3 GEOL
3 REV.... -I_.
DRA_Ff
J SEC
CONrE�::
F I LE--�'�
Alaska Oil and Gas -?- Sertember 4, 1970
Conservation Committee
i n,jecti on . Therefore, a stabilization of nroduci ro rate Would F.e expected
and well G-16 t,;as i ndi cati no in late 1969 this performance. In December
the well ��aas shut-in for a number of days and v,hen returned to nroducti on
tested at considerably lot,rer rates. This abrupt change in producing ability
appears to be directly related to the shut-in.. Since December, you will
note the producing rate has stabilized which is to be expected. Unfor-
tunately, it has stabilized at a rate several hundred barrels per day
lower than would have been expected.
In summary, endi neeri ng data exists on only one v!e.l l to date 11.►here we feel
a shut-in has caused damage do to a,.,ater production. Nowever, we are injec-
ting %,rater in this reservoir for pressure maintenance and feel that, in the
future, similar results can be expected on wells which are produci nc! tgater
such as G-16. Our application is asking for the operational flexibility
to forestall such an occurrance. Past experience has shown that the cur-
rent rule allowing five days use of gas well gas for artificial lift purposes
is insufficient because compressor malfunctions usually persist longer than
five days. We feel we would be lax in our responsibility not to drav:i the
potential dander of these shut-in periods to the Committee's attention before
the damage happens rather than substantiate a loss in reserves after the
occurrance.
Very truly yours,
TRADING PAY UNIT
ENGINEERING & PLANNING GROUP
C. J. Diver, Chairman
CJD:ea
Enclosures
)_7= y YEARS' i3'I MONTHS` di6- 3i2t)0
F logo-__C -6X 100 BTWSIONS
KEUF'FET- & €5S€R CO,
OIL RATE 1,000 BOPU
WATER CUT % o — roCD
w
Jan. i ' 1 I !
I i � j !
Feb.
'vay
i0
Jul': I �- '------ --I
Aus (( ♦:
.1 4VJ
O,t.
. I -
I
.0 I Dec
0 Jan.---
Z I I Feb.-
G7 `
Fri - - --- t—_ ' - -- -- - -
i a
ca Apr.-
D
C 'p I June
n `
I-
Z July
_
--I-- - -'---J--- -- -- -- - �- - - - -
D e r:
I
� I I Feb.
,
II Apr.------
�c f;9 a y-
! 'June
Nov. j-- I -�-- - -- --- -- -- - j
oec, i - - - -- - -
Aj OD
O O' O O O O O O 0 CD
0 0
O O O O 0
O
GLR -CFPB
AeL 1:3L%[l a'�;t7 i sr.:1 1,I1��%vS [i LJ O CUT n�;, i3 :J t�i��:l t i:t�J i i:.i1 1� xl\J S)J,.7 i�l" ;J C1Q1� �r. r �+r �c ,- I
t7 i / / /• LR GIZAV ► i3(V-SG .,..� OUT
-��._T��
'`�
_ ''v
`
c>-
i - -�--off-
4 y� . �_I �� 1, i
"if
j,
".'►_'_'_'' i i ,{ r--"-•------.�
e
/1,
! �� • f lit.
i
_. -
��`�
�1 �,_,i �_.---------i,.�..J
F
f\. >-` 17)^ i St��`� f ;
� _ i_�i �. I f `� j `-1 1 � i
!•�) `'/ i�({J
�1,�L.�.�t-.�
[�)�(�\. (
� ;J E
1 �; �• i1 �r (,,� i�� �- i j� •ice` �• 1yT .1
j / � � ✓ � '� •. f / , �} :.) L '�
`J. a'i ) I i
/_•_�� •
I __ s' S7 I1 , }d
f i V � ! � � �'1i._.i f r��t`L
JQ- 1
• � i 7
� ._ ~+
'� ��1 �
j L 1 ��. _+- � "� �_ �� � 1 � �
50
�� "^� �` � f ��
va
�_ - r'�
�
� � �..o�x�-�...�
•
f �J :✓ ' � i. i c �!
�h.��ic �
9 , i � �,.�5i,-��
I f 1 I .�_(I
� i�l � .�i�-
�---v'il
cl
l
' ��
- -Y��
-�
�. � � >=•-
� f
E ���-��
I J � '� � 1 � ' ' I
t
! l �f t _�_ � i =.� � Cyr-�l� �_
ram! `�
; �'�
�
J - � ��
i � `-•r-ttYrr
j 1 1
I � �'� ��i� �_� `� �_,
�1 /,
I)
� � , u.��
" A
L # � � � \i � r •� 1
r
1 j � 1 r � • J � / � ',��/ ✓i C
� ��
i.
WELL TESTS
rF F
t � u'z��i'JS,il�c ;T!!np TESTED GROSS !3%I; n CUT NET B/D PROD (-,AS\MCF'lD I`J GAS �sCr/D GOR GLR GRAY Ti�G/C.SG ClIQKRwQi.iT
471
IM
qU
gL
-LIza�1.����
t
Q�L?
t
�.
�.
......� ..e-.b.--'Ire-.s,.•"".�.�....�
.'�-��-! •tee-n• E a.. -
}..
i
,
LZ
'� yf
1
71 0
'
� 1
•
`�
F�
j
1 i ,
j� Ie-`,- F
F
t�
+
4
1j�'�
i==•,. �',....-.: y i % -
I f��`Y �i..v.... j j`� - - - -�• I
cf
f I
,
14.
�Gil 1)
or's
yo
�, �r i
It"'ELL TESTS
K ELL NO. �? �__i_CIA-PUS./M.ETNOD T-FX,7al GROSS B/11' 010- CUT NET B/D PROD CAS -IMCF/D INNJ GAS MCF/D GOR CUR GRPV TBC;/(,,SC, CIIOKI:-o!,I'F
U4L
)
-,VS-
lqc, wn
6 vl-21fi-f
F7 7
41-
�eu
te, C,
r_i o
WrT T 'rrCrC
-0
I 1,1E L L N,
V-"
010- CUT - NET B/D PROD (-,AS MCF/D
1909 STA7,JSAMETHOD 1"E"ISTED - GROSS BID
INJ GAS MCF/D GOR GLIR GRAV Til)l(',/CS(', CHOKIE-OW
Lj C
Lj
C/
LIE
k-
to
ifCD __ _-- �' , _ -i
1 � I I+ r
r)
`
� y
t
L
0
i
L1�C%
ZJ
f
CIL
C)
L
TA r T- 7 T Ir T_ 0 Ir 47
:FELL Nn
1 L ✓ STAT"'S"TEMOD Tr_
R
G'OSS P,/TD 0' CUr NET B/11) '-AS C p T GAS MCF/D GOR C L! GRAV TII.C,/CS(7, ci,!n;(E-o,JT
7>
'jL
7�7
Ll
I
(J
i
ell
U,
LY—L
1v
!Li
Zj
J if6l J_ Lc 6
)4111
C>j Po
ID
L
kj
_Y-L16;
la,
NA
Yd
-7
c
Atlantic RichfieldCompany North American Producing Division
Alaska Dis("
Post Office oox 360
Anchorage, Alaska 99501
Telephone 907 277 5637
September 3, 1970
4J -A-
C, �.
State of Alaska
Department of Natural Resources
Division of Oil and Gas
3001 Porcupine Drive
Anchorage, Alaska 99504
Attention: Mr. Homer Burrell
Gentlemen:
DIR 11~
C. GEOL
C. ENG I-
1 ENG
I. 2 ENG
3 Ef�'G I_
4 ENG
i
L 5 ENG �-
-� 1 CECL)
2 GEOL
` 3 GECL I,
i
REV
bRAFT
sEc- �
CONFER:
FILE:-
_
In view of the hearing on Thursday, August 27, I would like
to inform you that we got our second compressor in operation
August 29. The piston rod which we had manufactured in Kenai
is apparently doing the job and our mechanics were able to get
it installed before Monday, the date I had given to you at the
hearing.
I want to express my sincere appreciation of the way the Division
of Oil and Gas has worked with us on this particular problem.
As I said at the hearing, we do have difficulty at times with
various suppliers and your Department's cooperation is greatly
appreciated.
Very truly yours,
4�/Ao
K. W. S1epr
District Production Supervisor
KWS:pa
ALASKA OIL MD GAS CONSERVATION COW. ITTEE
Septe"er 3,, 1970
U.- Cmservation Order 95
unioa 011 Co"y of Call forals
90.9 West #Intb A"mme
Aachorage, Alaska 99501
Atteation: Wade ftAlester
-
goat I *mn
The red of Ow boarlag of Ca"orvation Order 95 will reaslow
,co" throuo Sit 100 19,70 to view of the necessity to
submit additimal s-upportiag %documm-ts.
Ury truly yours,,
Thams A. Marshall, Jr.
ExecmrlSecmtM, ,
T Int, im
west 31, 1970
r' J1Re: Cmwervalon File No. 95
'U"im Oil Cry o 'aliforala
2$05 90"11 Stv"'t
"wage o lm9,9503
comt1
and smaysing the, wt"tp'ovinox "'mites on Tradlog
Say U141t ft1 No. -4, thwe to ^ question . to ttee *
Wit + Atch wAght have ocerre 4 : to U l" shut-in.
Sftm the pwo4vetlea data presonted to not upo date t ve
Ow 111wrty to plot cev from the wouthly Veil, e -
t10 rests and these data Indleate to ua that productioa rates
are back 1 dim ,,* W are amble to soe 1vdtrA-
timo that lrmparsbU, damSe Us, oocumd to voll productivity;or to 14"ft ems. o these u� is Icing per:"
VITOMICY
t 'ou vftlt ass Oat you eowmt or fa=1mb any mWitional
181a "MUee rm any haw vhltb Indicates Parmaent 4MRASO boo.
acewrod,
00% OW *WiXOL Aieh WOUU hOlp tko C ute, le r4mdexUW a
degulon 06 this Witter
Sineetwxy �e .
14
9
8
7,
: i
. . . . . . . . . . .
7
7:
1t:
'
.
77
I , 1 �_
r . _ I 1 � ' I
I
�. ;.
-
1
,
T
I
77
. �- -r' -- •- - I--i� - I I I_I I I- � I-;. [ �� III.
j
' i I ' ' III 1 I � I I � I I_I � I I I •I l� i I ram_ - _. �. � �I.. - I I � I .
-i- -i
I
I III I I ( I � II ' II ilj I III 11 I �II'I III III I I i II (I{ !4 II it i I I II I
_l __I. ,IIII I_ .! ri i. _I_ I ..I_ I. Ti_i i-I. _! I ! 'i
lil jII II IIII ! 1 li .l r..�1 VIA ICI II I �1 1i ;I.I_!- I II it II I I I i. II
I.., r,.f~'ti•\ ._....i .I.I ._ i..i 1. ._I I._ _,_...,.. .. - {_- 9 -� -- l I"_.... _ ,..L�
111 ; I IIII III III I�.. f j __I
_I I ', I� I I; I 1 I. III I I I
., ..I _;t 1' :i L_.I . ;_. ,_-
1� I 1 1!� �I
-
li;ll i_ I I _ Ilil ill IIII Illi I i!l i�' Ilii iIII !i i
PAN
I N - A,i -'� -. I I I � !I I I �'I I
1
- I I. _ I. ( i.. I I I I i l I I I'I, i �!L.' I I I- I I� I i I i i I I
ilk
f
it
f l l _ , I ± I.: i I !:I 1 I- I I' ;.'I I 'I -I .I -I' j I I-� i� ,. I ;
1
�
I
L, ,..I .I .; .i
.,_i.(l Aid
1-I-1-,
....-._Li L_,_ ,
, I
I I I
i_�
.! I I
..I i I .. I.�. I I_,�-OEM
RRIM
I...'..I..III..I .I..... I�.l I_.._- _ I�II I1I, I �Illl11 �.II II I III III �II�I IIII I I � I II I�I I II
K
Z4
�y;
P[ISLTC 1JE-ARING
TESTIMONY G1-'
STATE O aLAU��t
I a or
t, Q + ov
DEt ARTINIENT OF ti'!l`I (.,P,1%1, RESOURCL5:
r.T,1.7T Q,Tn„ T nr,r,
l,\ �✓ � ./ 1 L . 1. � L' \? � '\'.�'
LASKA M, ANC! GAS COI,dSI.R.�l�-'1TIC�N COi�1�tI
CM,TTEF::
CONSI]RVAT"ION F TI,E' NO. 95
AUGUST � 7 , 1970
INTRODUCTION
On August 12, 1970, Union Oil Company of California, Operator of. the
Trading Bay Unit, requested the State of Alaska Oil and ;Ias Conservation
Committee amend the A(cArthur River Field Rules, Conservation Order Number
80, to include the following rule:
rule:
"Gas from a gas well may be permitted -to escape into
the air without Committee approval when such gas is
used to artificially lift oil from a pool in cases of
operational necessity, provided no such escape be for
more than 30 days in each such case."
I request the following sentence be added to the originali.y proposed
.-llpon request, C!le Culm i u.eC
a longer period of time."
Operational experience has shown the rigid provision of Section
2158(b)(3) of the Conservation Regulations to be inadequate for the proper
conservation of natural resources in the McArthur River Field by not allowing
use of gas well gas in lieu of compressed casinghead gas for artificial
lifting for a sufficient time for repairs and for scheduled preventive
maintenance of compression equipment. Evidence exists which shows permanent -
damage may have been suffered by McArthur River Field wells when shut in for
varying; periods of time. Such well damage, when caused by being shut in
during repairs and ;maintenance of compression equipment, can be minimized
if gas well gas is available for lifting on a flexible basis. The proposed
rule offers the necessary flexibility while at the same tir:;e limiting the
period during .diicii Oas well gas ;?,ay be uti lizod for a single operat icn���.
necessity before, rurther Committee approval ,,�ould be rcqu:ired.
2
Mr. C. J. Diver and Mr. Kenneth 11. Slepr will present testimony in
support of the proposed rule. I will read the qualifications of both
these men into the record since neither have previously been established
as expert witnesses by the Conservation Committee.
Mr. Diver graduated from Colorado School of Mines in 1952 with a
degree in Petroleum Engineering. Following two years with the U. S. Army
Corps of Engineers, he went to work for Marathon. Oi 1 Company in Wyoming
as a Production Engineer in 1954. From Wyoming, he went to Tulsa, Oklahoma
as a reservoir engineer in 1957 until 1963 when he moved to Denver, Colorado
where he worked as a reservoir engineer in Marathon's research laboratory.
In 1965 lie was transferred to Robinson, Illinois as the District Reservoir
Engineer. From 1965 through 1969 Mr. Diver was Marathons Division Reservoir
Engineer in Los Angeles, California. In January 1970 he moved to Anchorage,
Alaska where he is the Chairman of the Trading Pay Unit Engineering and
Planning Group. Mr. Diver previously served as the Chairman of the District
Three of the Conservation Committee of the California Oil. Producers. H
presently is serving on the API Reserve Subcommittee for Alaska.. Mr. Diver
is a member of. the Society of Petroleum Engineers of AIMF and is a Registered
Professional Engineer in Oklahoma.
Mr. Slepr graduated from. Georgia Institute of Technology in 1953 with
a Bacliel.or of Mechanical Engineering Degree. He has worked over seventeen
years. for Atlantic Richfield Company at various levels of responsibility
in the Engineering Section. Mr. Slepr came to Alaska in December 1968 as
Special Projects Engineer - Cook Inlet. He has been District Production
Supervisor. since February 1969. He is a Registered Professional Engineer
in Texas and a member of. the Society of Petroleum Engineers of RIME. In
196$ and 1969.i1e served as chairman of. the Production. Operations Committee,
RIME.
I request lair. Diver and' INir. Slepr be established as expert witnesses
and be sworn for this hearing.
(Oath administered)
E�;GIf.'.Ef_PIf G TESTIl"O Y
TO SUPPORT THE APPLICATION FOR APPROVAL OF
AN APPLICATION FOR EXCEPTIO11 TO
SECTION 2158(b)
OIL AND GAS CONSERVATION REGULATIONS
TRADING DAY UNIT STATE K-20
AND FOR
AMENDMENT OF CONISERVATION ORDER NO. 80
PRESENTED BY
C. J., DIVER, CHAIMAN - ENGINEERING & PLANNING GROUP
TRADING BAY UNIT
AT A
PUBLIC HEARING - AUGUST 27, 1970 - ANCHO..F'I\GE., ALASKA
r
IHT[ZODU' CTI011
IN testimony Sri 1 i slhov; that the use of c?as t,"e11 nas for nas lift purposes
is an operational necessity. The fol 1 of !i nq '111 he discussed: r o . 1 -
Uti l i zati on of c:as as a lift m`c'.ani sm on the pl atfori-ns , rNlo. 2 - The historical
summary of operation of compressors on the pl atforins , iIo. 3 -- The near term
effects of. a lack of avai 1 able lift oas and 111o. n - The lone► ter,i effects of
a lack of lift -aas .
In the 1,11cArthur River Field, the pressure in the Hemlock reservoir has de-
.cl i ned to the point where most wells have ceased to flow; therefore, artificial
lift of some type must be used to sustain oil production. 1,,,►e are employing
gas lift for this mechanism. Gas lift operations are conducted by compressing .
low pressure gas and circulating this now high pressure aas into the annulus
of a well and returni na it to the surface through the tubing i�ii th the oil and
water,- Under normal operating conditions, our source of gas for gas lift.
purposes is that evolved from the crude oil in the producing stream.
Gas compression equipment has been installed on all platforms in the ticArthur
River Field. When this compression equipment is inoperable, the oil production
ceases.
HISTORICAL DOWNTIIE
Exhibits A, a and C are historical summaries of the operation of compressors
on each of the three platforms in the Trading .Day Unit. This information
indicates that the frequency and duration of compressor dovintime is not
predictable. The compression equipment is massive, intricate and very
specialized, Exhibit A for the King Salmon platform shows three major
periods during which lift gas from a compressor was; not available. Mr. S1 epr
will testify in detail concerni nn the doti.rnti r,e start-i no in July 1970. In
riarch , flay and July a compressor v.as dorm for consi dera�)l e periods of time
for repairs.
on the Grayl i nn platform, in Jani, ary, February and (--'arch of 1970, a compressor
was ft,ln for several days.
The 13 month period tabulated on Exhibit C for tho Dolly Varden platform shol.!!s
.several months, i ndl uci ng December of 1969 and lMarch of 1970, when a com-
pressor t%yas inoperable.
Every effort is being made by the Operators to improve on this performance.
For example, spare parts inventories for all compressors on the platforms are
maintained by the Operators. Those inventories are a part of the original
compressor package and include those parts which are expected (through operat-
ing experience) to need replacement. As more experience is gained in the
operation of these machines, we expect future performance will be better.
However, we can never hope to achieve an'operating efficiency which is equal
to that of a land operation. This is do in part to the amount of vibration
which occurs in a platform installation as compared to that vrhen the same
machine is operated on a golid foundation. Also, the location on platforms
demands far more safety devices than would be necessary elsewhere. These
can automatically stop the compressor yet no hazard would exist if production
were continued., Space limitations on the platforms create problems in
delaying repairs.
In addition
to the non-scheduled
downtime as
shown on
these exhibits, other
periods of
downtime are expected.
These will
result
from required annual
-2-
Y
preventive maintenance on the various pieces of in0chi nery. Ile estimate this
t,.i l l amount to al -Tut 20 days a year, i t r platform.
NEAR TEIRI EFFtCTS
I?Jhen one r�achi ne or half the coi:'.pression is lost on a platform, we lose about
35 percent of the production rate from the Hemlock. At the current level of
production- for the three pl atfori>>s , this loss in production amounts to about
9,000 barrels per day on the King Salmon, 13,000 Barrels per day on the Graylinq
and 15,000 barrels per day on the Dolly Varden. eased on the royalty and the
severance tax currently -payable, the State of Alaska's loss of daily income
'attributable to this loss in production will be $4,400, $6,300 and $7,300,
respectively. These losses assume a price of ;2.78 per barrel which is the
posted price of the Unit Operator.
When both compressors are inoperative, platform production is essentially zero.
It remains so until lift facilities are once more available. At that time,
production resumes but at a reduced rate. Experience. has shown that it takes
about 72 hours to approach normal production rates. Exhibit D illustrates
thi.s typical rate performance after a platform shutdown. from this curve,
it can be seen that when a platform is completely shutdown and then restarted,
an equivalent day and a half of production is lost after startup. When there
is a platform shutdown on the King Salmon, -the revenue loss to the State of
Alaska will be $12 ,000 per day of shutdown plus an additional '$10,300 while
the production is returning to the pre --shutdown rate. On the Grayl i np, this
loss will be $17 ,500 a day plus an additional . $26,300, for the Dolly Darden
$20,500 a day plus $30,700.
-3-
I
There are other potential losses when a well is shuti n . Typical pas lift
i nstal 1 atl on s cnnsi st of ten to fourteen (,,(,s 1 i 'It vaI ve s . It, 1'1F_'.r1 a s
in normal operation, only one of these valves is operati r;q. After a ,;ell
is shuti n , liquid r i ses in the tUhi nn. In or-cier to return a to normal
o��c'rati nc status most cf the v, �i ves i n the syster', must onerate . Tl�i s
creates thy, pos si bi 1 i tv of a r;al functi or, . ! +hen this occurs, it is so,Yreti rocs
necessary to kill t!F,,_,- V;el l and pall the tuhli nro. This is a probable har}peni nq,
the frequency of tilhi ch cannot h,e predicted. The result is a further delay
in production and more importantly, exposes the �.,,el l to fluids which could
result in long term losses in productivity.
LONG TERM EFFECTS
There is concern about the effect of a shut in on the long, term productivity
of a well. Laboratory data on Vleml ock cores from the Mc' Arthur River Field
indicate that water introduced into the rock causes'a reduction in flow
capacity. Measurements of this have been made utilizing both pseudo -Hemlock
formation water and filtered Cook Inlet water. The results of these studies
are.documented in a report titled "Water Sensitivity Evaluation Hemlock
Reservoir", dated April 1969 by Mr. J. T. Morgan, Senior Geologist of 1,111arathon
Research. This report is marked Exhibit E.
When a well which is producing some water -is shut i n , the liquid rises in the
well bore and along with fluid segregation, will expose oft bearing sandstone
to water. Thi s 'porti on of the reservoir is then free to imbibe water and
cause a reduction in flow capacity through increased water saturation and
through particle dislocation. This 'problem is more severe where there are
different pressure systems in the various layers as is the case in this field.
In addition, it is an accepted fact of reservoir behavior that with increased
-4-
�rt
!{rater saturation, the relative permeability to oil decreases . In the ''cArthur
River Field, many t,-ells currentl\� produce some water. Also, we are injecting
v!ater for pressure mai nten-nce and', in ti r;e , all � lel l s in the field v?i l l
produce ti;ater in increasing amounts.
The Committee ti,fas previously given data on Piay 25, i°I _,, concerning the per-
formance of !-!ell K-4. Prel i rni nary data on at least one other well in the
McArthur River Field, that is G-16 , indicates a' productivity loss i�Ih-i ch tine
believe to have been caused by a shut in. Since subsurface pressure data
was not gathered before and after the shutin, the evidence is not entirely
conclusive on this ivel 1 ; ho�,rever, production performance did indicate a loss
of productivity, We plan to observe individual well performance and to monitor
losses in productivity resulting from unavoidable shutins. The loss in well
productivity that vie have been discussing has been measured on at least one
other platform producing from the Hemlock reservoir in the Cook Inlet. This
is the Spark platform operated by Atlantic Richfield where this has been a
major operating problem.
Mr. Chairman, this concludes our direct testimony. I request
Exhibits A through E referred to in the testimony be entered into the
record of this hearing.
(Question & Answer)
Conclusion
From the testimony presented, it is obvious an artificial lifting
mechanism is mandatory for the Hemlock Pool of the McArthur River Field.
It can be seen from an historical viewpoint that considerable compressor
down time has been suffered for periods ranging upward from one hour. An
immediate result of losing gas lift capability is a loss of the Sta.te's
royalty and tax income. Permanent damage of a well is highly possible
following its being shut in. To avoid adverse effects from shutting in
wells when comnressed gas is unavailable -for art1 fi -i --l1 l i ifting ??s well
gas must be made available for this purpose as allowed by the proposed
rule.
:, B I A
KING PLAT M r;
COI-TF.ESSOP D0!-NN T T, "�
Date
er:s.
Jan.
9
20
firs .
Install new overSr!V.
nod swi l-ch .
18
10
"
Adjust ermine.
19
12
" At
25
la
f°
2e
14
r
It
a It
Feb.
iQ
a
hrs.
Change fuel regulator.
15
3itChance
plugs.
25
10
Adjust empi ne (both units).
March
3
lr,
Adjust engine.
1$
l t
i'ai ntenance .
2G
3:
:.�ays
Unit N�o. 2 dorm for overhaul.
26
2
hrs.
Change plugs.
AP .
15
G
hrs.
High liquid level in scrubbers.
flay
13
12
days
Unit Nlo. 1 dovrn for overh�.&ul.
June
1
12
hrs.
Repair broken gas line.
4
12
It 11 of it
24
11")
Repair e; haust coup -line.
July
14
12
1hr5 ,
Replace f,Io . 1 compressor valves.
24
34
das
Comnresso,, P' o. 1 d e}t-:r. f ol- rer ai rs .
15-
3
Compresscr f!o. 2 do►in for ret-4air,s.
Aua.
2
hy-s .
Chancre n1 ups .
11
2
Repair Beat exch(--mner.
Date
Jain.
1
6
7
8
.9
10
10
1.1.
1.4
20
Feb.
3
March,
1.3
14
1.6
18
24
April
22
27
May
3
3
7
20
23
25
Dou-ntimie
6 days
LZ I)rs
16 hrs.
4 -r s .
�.6 hr r s .
8 h s.
? day
4 hrs,
4 days
4 hrs.
2-1/2 dati;-s
Lk:ITB-TT B
GRAYLING PLATF� RIN-1
COMPRESSOR DOW",'" rI�,IL
R.emarI,s
Unit
B
down
due
to
condensate i.n
lube
oi-I ,
Uni t
A
dozen
due
to
conc:eiisate i._i
itii;,e
of i
Unit
A
dov.,n
due
to
condensate in
1u1)f,
,
of 1 ,
'unit
A
down
due
to
condensate in
lul)e
oi.1.
Unit
A
dovin
due
Lo
clonC1eiiSa.te in
labc,
oil. ,
'Unit
B
down
due
to
conclensa.te in
lu.be
oil.
Unit
A
doi n
due
to
scrubber drains and.
air
inlet
filters
freezing.
Unit
B
down
due
to
scrubber drains
and
air
inlet
filters
f'reezin^.
Unit
A
doWn
du.o
- o
cc -.dens ate in
lub eY
of 1. .
Unit
B
down
due
to
condensate in
i..ue,
ol.l ,
Unit
A
down
-�o
replace
seals i.l
low :> �..zZ>e
.
''( .1i 7. .., N V'/!. A. 4 ,(\ U.V YY♦• �.V A ♦'.�Aa+\. •, „7Vf4 ./. �) J. .1a 3!ilj..,,lA
6-1./4 days Unit B dowel to replace seals ..ri hikyl, S%o.go
3-1.12 days Unit A down to replace seals in hista gse .
5-1/2 days Unit B down to lepla.ce seals in high stage.
4 hrs. Unit A down to replace seals in hiph stage.
4 hrs. Unit A down to replace seals in high t;tago.
1.6 hrs, Unit A down to replace seals :i.n ILi.gh stage.
8 Ilrs . Minor adjustments.
4 hrs. Minor repairs on low stage.
16 hrs. Minor repairs on control air.
4
:hrs .
Unit
A down due to minor hi gh stage
repairs .
4
hrs .
Unit
B down due to minor hligh stage,
r e"I�G 1T-5 .
3-1/2 days
Unit
B dowl—L to replace bearings and
seals
.in
high stage.
12
his.
Unit
B down to .replace bearings and
seal s
in
high stage.
10
Iirs ,
Minor
repairs ,
4.
hrs .
! (I jesting
control system.
12
Uzrs .
114in.or
repairs.
Date
3u:1c
12
29
29
jul s
7
ov nt i m c
4 hrs ,
4 nrs .
4 hrs .
F.%I I� B I `I B
(Cojitinued)
Rema : 1::7
Unit
A
down
due
to minor hi crh
stage
repairs.
Unit
A
doi,m
due
to minor iig.'r.
stag:;
r. fairs
Unit
B
down
duv
to minor higli
stage
repairs,
8 hrs . Both units do,..n for electrical repairs c.,--n
low stage,
r Beth units down for ea.ectz• ica.I rei3iI-s On
low stage.
4 hrs. Both units down for electrical_ repairs on
high stage
Da to
July - 1 9�5t
3
4
7
t5
15
19
Oct
12
25
NIOV .
7
8
10
13
18
20
27
29
Dec.
3
5
9
10
12
26
Sian. - 1970
2
3
28
Fe
2
Down t i rT:e
18 hrs.
1-1/2 firs.
1 d a 4,
J
9-1/2 hrs.
E) HiBiT C
0 LY f :., ,T
CONTRESSOR DUIT'iTI, IE
Inspecting corrr)ressor.
Replaced nush rod.
Chance suction valve.
Repair broken piston.
Rema rl s
5 firs. - Kenai r rnan i fc,l d .
10_1/2 tars. install fuel injection valve.
4-1/2 Change discharge valve.
9--3/4 firs. Installing di sCharge valve.
AA
10 hrs. itechani cal repair.
14 " Change nluc,s and head gasl'et.
1-1/2 hrs. Chancre plugs.
2 hrs. Charing of 1 f i 1 ters .
Chance plugs.
2-1/2 hrs. Change di scharre valve.
2 4rrs.
Chancre
spark plugs and adjust air controller.
2-1/2
hrs.
Chance
r1 ucs .
7--1/2
hrs.
Chance
valves.
2 hrs.
Chance
plugs.
18
Change
ni ston and cylinder.
1 hr.
Chance
t,l u n s .
7 hrs.
Chance
head.
6-1/2
hrs,
Chance
hoad
4 days
Inspection
and mWai nt:enance .
6--1/4
firs.
P.enai r
,)acker arm.
1 hr.
Chan,-ie
snarl: 01 uc s .
3--1 /2
days
Pen",'Ice
craci:ed h--ads .
12 sirs.
P%djus1--
clearance.
2--1/4 firs. C'l.anne valve.
3 hrs . lonai r valves.
3 C:oripressor piston hack rod.
8-1/2 hrs. P..djUst engine.
It
Ca to
Feb. 1070
8
21
Ma r.
15
23
24
22,
29
30
i
r
J
26
3
r, rt
r_
June
17
25
July
1
4
7
8
16
2.1
24
���•:nti r�:e
5 ti rs .
2 days
* / � 1 B 1 . %C
(Conti nueu j
Repairing ccMrressor.
tepai rs.
Pena rk s
1 fir.
Chance
valve .
1
Repair
ignition.
2 days
Chancled
piston.
22 hrs.
Changing
cylinder mead oaskets .
24 hrs.
Replace
piston arida rod.
4-1/2 hrs.
it
It"
2-3/4 hrs.
Chance
suction valve.
1-3/4 ;ors.
Chance
three discharge valves.
c) hrs.
Completi
nd rAriai rs .
1-3/4 firs.
Engine
oversreed .
I hr.
Install
ncw transformer.
1 hr. Repair scavenger air.
2 days Replace head.
1 hr. Repair.
7 hrs. Peoai r.
14 hrs. Adjustment - engine No. 2.
10 hrs. Repair enni ne No. 2.
1 ter. Flaintenance chec,:.
5--1/2 hrs . Replace suction valves.
8-1/2 " ,•jai ritenance .
EXFilBIT D
�-1 DAY -�
TIME
S -7 IRV I C E _? "Ic 0
7\7,a T
ATER SENSITIVITY HEMLOCK RESER%70'.,rR
UAT i 0 NT
J. T. MorCD-,C--.n
'S? 04 04 008 08 was authorized at the r%aC.uas_L 0. :.ncnora e
District O-oc-rations Vanac7er. A water sensitivity evalu-a-cLon of core
Cal
material from the D-2 Trading Bay Unit well was requested.
An interiT,,; repo-rt dated July, 1.968, re -ported the results of: 1
licuid permeability data performed by Core Laboratories, inc., of Dal"A_,!:S,
Texas, and (2) permeabilities to Cook Inlet water which was performed at
DRC. A copy of the intarii-ii report is attached (in Docket). The interim
report concluded that the Hemlock sand could he flooded at a uniform rate
with filtered Cook Inlet water. That conclusion was IDased on tests which
were performed in the presence of water alone. Emulsion problems, etc.,
were not evaluated.
We helped coordinate some of the special analyses run by Core La' -,-;-
oratories, Inc., Dallas, Texas. That work has not been completed. To
aid in the interpretation of the special analyses Ap L pend-Ix I, J_L n. pocket,
was prepared. Appendix I contains photographs of: (1) plug ends at one
magnification, and (2) thin sections of the plug ends at 30 magnifica-`ions.
Examples of pores, quartz, feldspar, clay and mica are labeled. The -Door
sorting of grains and consequently of pores, and grains with large surface
areas, such as clay grains, suggest the connate water saturations of 30-40%
reported by Core Laboratories, Inc. are reasonable. Regardin7 the photo-
micrographs, in general, those with the larger and more abundant- pores will
have the lower connate water saturations and more favorable relative
ability curves.
All of t--he plugs contain approximately the same complex mineralogy.
They are composed of subangular grains of quartz, chert, mica, feldspar,
and rock 447ragments. The rock fragments have the following variety in
origin: igneous, metamorphic, volcanic, and sedimentary. Clays are
kaollnite, chlorite, sericite, illi-Le, montmorillonite, and mixed !ayer"71'.
clays. X-ray diffraction indicates the presence of swelling clays in al'i
the Hemlock samples. The amount of swelling clay varies considerably.
r.mounts 'Large enough to be detected by swelling tests (see Table I) ocC,,_,--
e---ratically distributed t-hrough the reservoir interval. Amount of
smaller than 0.016 mm are shown on Table II.
Recon.'Iniendations remain the same as those given in the attached intar-ILm
ner It is further recommended that, if special analyses of Core 1,a:b-
Inc. of the " congloir,,e rates" show any differences fro7t*-Ie 1� S
anlalvzed, the "con.2-lo-m.era Les" he sent here for a lithologic study to define
Me reasonS far those variations.
C.D. 9s
j� /�
�il:�lji nO�T\T O T .� Tl.1C:rY�A:u
I� D-2 r:"i"\I�l ING BAY U.,," STAVE
Deg
1157271-11,728'
115798`-115799'
11,894'-11,895'
11,901'-11,900'
115902'-11,903'
ll,9061-112907'
119912'-115913'
11, 918' -119 919'
11,921'-11,922'
115923'-11,924'
11,931'-115932'
112933'-11,934'
11.,934'-11,935'
112972'
12,122'
12,205'
122208'
125398'-12,399'
Swelli n? Value-
98.1
100.0
112.0
102.0
106.2
105.0
100.0
105.0
102.0
100.0
100.0
100.0
102.0
122.0
100.0
100.0
104.0
96.0
SwelLing value over 105 indicates the presence
of swelling clay.
TABLE II
CLAY SEPARATIONS
MARATHON OIL COMPANY
#D-2 TRADING BAY UNIT STATE
Depth
11,798.7-99.2'
11,894.0-95.0'
115906.0-07.01
119918.0-19.0'
111,921.0-22.01
11.1972. 01
12,122.O'
12,205.0'
125208.5-09.5°
finery than
0.0-6
6.7
4.8
9.7
3.9
2.9
6.7
2.3
3.5
4.3
TECHNICAL SERVICE PROJECT 04 04 08
INTERIM REPORT
July, 1968
J. T. Morgan
Reported here are (1) liquid permeability data performed by Core
Laboratories, Inc., of Dallas, Texas, and (2) permeabilities to Cook
Inlet water, which was performed at DRC.
CONCLUSIONS
These conclusions are based on a very limited amount of evidence.
More core material would need to be studied to characterize the reservoir.
It is concluded:
1. The Hemlock is slightly to moderately sensitive to brine.
This sensitivity increases with decreasing salinity,
with the rocks being strongly sensitive to fresh water.
2. Any fresh water, including fresh water based drilling muds,
will damage the Hemlock reservoir, as well as some sands
above the Hemlock.
3. Cook Inlet water is apparently compatible with Hemlock brine.
4. Permeability to Cook Inlet water ranges from about 40 to 70
percent of Klinkenberg or air permeability.
5. The Hemlock can be flooded with filtered or filtered and treated
Cook Inlet water at a uniform rate.
RECOMMENDATIONS
It is recommended that:
1. No fresh water be introduced into the Hemlock reservoir.
2. Consideration be given to avoiding the use of fresh water
drilling fluids in future wells in the area.
3. Additional liquid permeabilities be performed to confirm con-
clusions and the above recommendations that are related to
water sensitivity.
4. Cook Inlet injection water be both treated and filtered.
More complete recommendations were made under TSP 04 04 07.
TSP 04 04 08
July, 1968
CORE LABORATORIES, INC. LIQUID PERMEABILITIES
Results of liquid permeability measurements performed by Core
Laboratories, Inc., Dallas, Texas, are listed on Table I. Because of
core breakage and shortage of core samples along with numerous other types
of tests to be performed, samples from only two depths were analyzed.
Those data show the Hemlock to be moderately sensitive to brines and Cook
Inlet water and strongly sensitive to fresh water. The sensitivity to
fresh water can be caused by either or both particle movement and swelling
clays. Incomplete data indicates montmorillonite occurs scattered through
the reservoir.
This strong sensitivity to fresh water indicates that any fresh water,
including fresh water based drilling muds will damage the reservoir. Study
(TSP 04 04 01 letter report by Hewitt and Morgan, April, 1967) of the sands
above the Hemlock in the Trading Bay #A-2 well showed those sands to be
strongly sensitive to fresh water. So all data indicate that a fresh water
based drilling mud probably results in bore hole damage.
Permeabilities to Cook Inlet water are similar in both plugs initially
saturated with formation brine, and in plugs saturated with Cook Inlet
water. This data suggests that the formation water and Cook Inlet water
are compatible.
DRC PERMEABILITIES TO COOK INLET WATER
To support Technical Service Project 04 04 07 (Water Treatment,
Hemlock Reservoir, McArthur River Field, Cook Inlet), a series of perme-
abilities to Cook Inlet surface water was performed. Results of these
measurements are shown on Figures 1-13, which are plots of permeability
variation as a function of cumulative water injected.
BEREA CORES
Because of a small amount of available Hemlock core, Berea core
(Figures 1-6) was used to help evaluate selected treatments of Cook Inlet
surface water. The Berea cores had been fired, which broke down clay
structures. This minimized clay dispersion problems, and allowed an
evaluation of treated Cook Inlet water in a 'anon -sensitive" rock.
Figures 1-3 show there is little permeability reduction with large
amounts of throughput for filtered (0.45 microns) Cook Inlet water, filtered
Cook Inlet water +3 ppm ARCO 901, or filtered Cook Inlet water +3 ppm
Cla-Perm A-34. Of the three solutions, filtered Cook Inlet water shows
the least reduction.
. Figure 4 shows that unfiltered, settled one hour, Cook Inlet water
caused severe permeability reduction. Figures 5 and 6 show that treatment
of the unfiltered water with ARCO 901 or Cla-Perm A-34 causes the perme-
ability reduction to be much less severe.
-2-
TSP 04 04 08
July, 1968
HEMLOCK CORES
Having established a basis for comparison, with the Berea, the
same measurements were performed on Hemlock cores. Those results are
shown on Figures 7-13. Figures 7-11 show that there is basically no
difference between filtered Cook Inlet water and treated (ARCO 901 or
Cla-Perm A-34) and filtered Cook Inlet water. All show a 5-10 percent
of Klinkenberg drop from the initial permeability to the solution to its
last permeability value. All of that reduction takes place in the first
50 pore volumes of throughput and probably is caused by particle movement.
This suggests that the Hemlock can be flooded at a uniform rate once this
small amount of initial permeability reduction has taken place. Further
permeability reduction would be caused by material injected rather than
because of a rock property.
Figures 12 and 13 indicate that unfiltered, settled one hour, and
treated Cook Inlet water has a continuing permeability reduction, but
that a considerable number of pore volumes can be injected through a
sample without completely plugging the rock. The sharp permeability
reduction at 300 cc. cumulative throughput on Figure 13 is unreal. It
is actually a relative permeability effect caused by air entering the
system.
The above data suggest that it would be desirable to both treat and
filter Cook Inlet water. If a filter failed, the temporary injection of
treated, but unfiltered water, would cause much less damage than an un-
filtered untreated water.
The initial permeability to Cook Inlet water varied from 46 to 71
percent of Klinkenberg on the Hemlock plugs (Figures 7-13). Similar
results were obtained by Core, Laboratories, Inc. (see Table I). All
liquid permeabilities (including Kro at Swi) in the Hemlock should be
expected to fall in about the same ranget
-3-
TABLE I
LIQUID PERMEABILITIES
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
Depth Koo K ( % K ) K (% K ) K A K ) K (% KW)
30,000 � 25,000 � 10 000 � w m
119794-169795' 63.0 24.0 (39.2) 23.0 (36.5) 19.0 (30.2) 0.80 (1.2)
129395-129396' 10.0 4.2 (42.0) 4.2 (42.0) 3.4 (34.0) 0.65 (6.5)
Depth Koo KC.I. (% KOO) Kw (% Koo)
11,794-11,7951 71.0 31.0 (43.6) 12.0 (16.9)
119794-115795' 16.0 7.1**(44.3) 1.8 (11.2)
129395-129396 10.0 4.2 (42.0) 2.6 (26.0)
129395-129396 11.0 4.8" (43.6) 2.4 (21.8)
All measurements in millidarcys
Plugs saturated with formation brine prior to
measurement of permeability to Cook Inlet water
KC0 Klinkenberg Permeability
K30,000 Permeability to 30,000 mg/liter NaCl
K25,000 Permeability to 25,000 mg/liter NaCl
K10,000 Permeability to 10,000 mg/liter NaCl
Kw Permeability to fresh water
KC.I. Permeability to Cook Inlet Sea water
loo
90
�- e0
_J
m
Q
W 70
c
W
d 60
0
!Y
m 30
Z
W
]L
Z_ 40
J
]C
H- 30
Z
W
U
20
W
a
10
F
K co 365md.
I
i
I
i
I
i
50 Pore
Vo/umes
/00
100 200 300 400 500 600 700 Boo 900 1000 1100 1200
LIQUID THROUGHPUT (CC.)
FIGURE 1
PERMEABILITY VARIATION AS A FUNCTION OF CUMULATIVE WATER INJECTED
(FILTERED COOK INLET WATER)
BEREA SANDSTONE SAMPLE T-10
100
90
F- 30
DIN
EGN
K cc 391md.
150
Volumes
50 Pore
/00
200
100 200 300 400 500 Goo 700 Soo 900 1000 1100 1200
LIQUID THROUGHPUT (CC.)
FIGURE 2
PERMEABILITY VARIATION AS A FUNCTION OF CUMULATIVE WATER INJECTED
(FILTERED COOK INLET WATER + 3 ppm ARCO 901)
BEREA SANDSTONE SAMPLE T-27
100
90
}
_J
m
a
LLJ 70
cr
W
0- so
ac
aWo 50
z
w
]c
Z_ 40
J
]C
1- 30
Z
W
v
cr 20
w
a
10
0
V co 348md.
f
I
50 Pore Volumes /00
100 200 300 400 500 Coo 700 Soo 900
LIQUID THROUGHPUT (CC.)
FIGURE 3
PERMEABILITY VARIATION AS A FUNCTION OF CUMULATIVE WATER INJECTED
(FILTERED COOK INLET WATER + 3 ppm CLA-PERM A-34)
BEREA SANDSTONE SAMPLE T-12
1000 1100 1200
M
90
so
CD
LLJ 70
2
cr
LLJ
CL so
�— 30
z
Uj
U
w 20
w
CL
it]
0
K co 393md.
4-
41.3
Pore
Volumes
100 200 300 400 500 600 700 Soo 900 1000 1100 1200
LIQUID THROUGHPUT (CC.)
FIGURE 4
PERMEABILITY VARIATION AS A FUNCTION OF CUMULATIVE WATER INJECTED
(UNFILTERED COOK INLET WATER, SETTLED ONE HOUR)
BEREA SANDSTONE SAMPLE T-7
100
so
F- so
-j
cc
4%
W 70
2
cr-
w
0- so
(D
cr_
mLL)
50
z
LLj
le
z 40
F- 30
10
0
K co 427md.
50 Volumes /00 /50 200'
100 200 300 400 500 Goo 700 Soo 900
LIQUID THROUGHPUT (CC.)
FIGURE 5
PERMEABILITY VARIATION AS A FUNCTION OF CUMULATIVE WATER INJECTED
(UNFILTERED COOK INLET WATER + 3 ppm ARCO 901, SETTLED ONE HOUR)
BEREA SANDSTONE SAMPLE T-19
1000 1100 1200
loo
90
d Go
CD
cr-
w
co 50
z
LLJ
Y
Z 40
F- 30
z
ui
u
at 20
w
0-
10
0
X co 408 md
yy
-4
- - - -- -
200
/00
Pore
Vo/ames
100 200 300 400 500 600 700 Boo 900 1000 1100 1200
LIQUID THROUGHPUT (CC.) ,
FIGURE 6
PERMEABILITY VARIATION ASA FUNCTION OF CUMULATIVE WATER INJECTED
(UNFILTERED COOK INLET WATER + 3 ppm CLA-PERM A-34., SETTLED ONE HOUR)
BEREA SANDSTONE SAMPLE T-18
100
90
r
~ 80
J_
m
Q
W 70
arc
w
CL so
c�
a`
m 50
z
w
]G
z 40
J
]C
H- 30
Z
w
U
20
W
a
10
0
K co 134 md.
I
1 �
I �
I i
i
...............
I
I
50 Pore Volumes /00 /50
100 200 300 400 500 Goo 700 Soo 900 1000 1100
LIQUID THROUGHPUT (CC.)
FIGURE 7
PERMEABILITY VARIATION AS A FUNCTION OF CUMULATIVE WATER INJECTED
(FILTERED COOK INLET WATER)
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,921-22 FEET
HEMLOCK FORMATION
1200
EXHIBIT "E"
o�
K co //.Omd.
+Oa
90
a ao
CD
a`
m 50
z
w
]G
z_ 40
J
X
30
z
W
cr 20
w
!1
10
n
/OO Pore Volumes
I 1
100 200 300 400 500 Goo 700 Soo 900
LIQUID THROUGHPUT (CC.)
FIGURE 8
PERMEABILITY VARIATION AS A FUNCTION OF CUMULATIVE WATER INJECTED
(FILTERED COOK INLET WATER + 25 ppm HgC12)
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 12,395-96 FEET
HEMLOCK FORMATION
1000 1100 1200
K co /6md.
100
90
r
~ 90
_J
m
Q
W 70
ME
Qr
W
a so
cD
cc
co so
z
w
]C
z 40
J
]C
H— 30
Z
W
V
cr LO
W
a
10
RE
/00 Pore do/umes
100 zoo 300 400 300 Goo 700 Goo 900
LIQUID THROUGHPUT (CC.)
FIGURE 9
PERMEABILITY VARIATION AS A FUNCTION OF CUMULATIVE WATER INJECTED
(FILTERED COOK INLET WATER + 25 ppm H9C12)
MARATHON OIL COMPANY
TRADING BAY UNIT. STATE HD-2
DEPTH 11,794.95 FEET
HEMLOCK FORMATION
1000 1100 1e00
100
90
~ so
J
a
W 70
a
1Y
w
60
t9'
0`
m 50
z
W
Y.
2 40
J
Y
H- 30
Z
W
U
0: 20
W
a
10
0
C co 102 md.
3
� 1 �
i I 1
1
j
1
I
1
50 Pore Volumes t00 150
100 200 300 400 500 Goo 700 Soo 900 1000 1100 1200
LIQUID THROUGHPUT (CC.)
FIGURE 10
PERMEABILITY VARIATION AS A FUNCTION OF CUMULATIVE WATER INJECTED
(FILTERED COOK INLET WATER + 3 ppm ARCO 901)
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,921-22 FEET
HEMLOCK FORMATION
loo
90
�= 90
m
a
W 70
a
O`
W
d 60
C'3
Z
m 50
2
W
]C
Z_ 40
J
Y
30
Z
W
U
1r Ito
W
a
10
0
as 60.2 md.
50 Pore Volumes /00
100 200 300 400 500 50o 700 Boo 900 1000 1100 1200
LIQUID THROUGHPUT (CC.)
FIGURE 11
PERMEABILITY VARIATION AS A FUNCTION OF CUMULATIVE WATER INJECTED
(FILTERED COOK INLET WATER + 3 ppm CLA-PERM A-34)
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-Z
DEPTH 11,906-07 FEET
HEMLOCK FORMATION
100
90
~ BO
J
m
Q
W TO
a
0:
W
C- 60
0
m 50
Z
W
]e
Z_ 40
J
Y
30
Z
W
U
O` 20
W
a
10
0
K co /9/ md.
I i
i
1
fI
I
i
i
50 Pore Volumes /00 /50 200 250
100 200 300 400 500 600 700 Soo 900
LIQUID THROUGHPUT (CC.)
FIGURE 12
PERMEABILITY VARIATION AS A FUNCTION OF CUMULATIVE WATER INJECTED
(UNFILTERED COOK INLET WATER + 3 pPM CLA-PERM A-34, SETTLED ONE HOUR)
MARATHON OIL COMPANY
TRADING BAY UNIT STATE HD-2
DEPTH 11,921-22 FEET
HEMLOCK FORMATION
1000 1100 1200
loo
90
�= 00
CD
J_
Q
W 70
la1
d 60
tr
m 50
z
Uj
Y
z 40
J
Y
30
z
W
U
1r 20
W
iZ
10
0
K cc 60.7 md.
i
I I i
vIr bubbles
i
Ii -
1
i
I
50 Pore Volumes /00
100 too 300 400 500 COO 700 a00 900 1000 1100 1200
LIQUID THROUGHPUT (CC.)
FIGURE 13
PERMEABILITY VARIATION AS A FUNCTION OF CUMULATIVE WATER INJECTED
(UNFILTERED COOK INLET WATER + 3 ppm ARCO 901, SETTLED ONE HOUR)
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,906-07- FEET
HEMLOCK FORMATION
APPENDIX I
PHOTOMICROGRAPHS OF
HEMLOCK SAND ON WHICH
MEASUREMENTS WERE PERFORMED
BY CORE LABORATORIES, INC.
Legend
Q quartz
F feldspar
C clay
m mica
p pore
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 12,395-96 FEET
PLUG #1
'r1TT+= y
i
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 12,395-96 FEET
PLUG #2
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 12,395-96 FEET
PLUG #2A
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2*
DEPTH 12,395-96 FEET
PLUG #3
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,717-18 FEET
PLUG #4
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE ##D-2
DEPTH 11,717--18 FEET
PLUG ##5
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,824-25 FEET
PLUG #7
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,824-25 FEET
PLUG #8
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,794-95 FEET
PLUG #10
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 119794-95 FEET
PLUG #l0A
1X
g'
so
i
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH ll,794-95 FEET
PLUG #11
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,794-95 FEET
PLUG #11A
1pn
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 119794-95 FEET
PLUG #12
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,894-95 FEET
PLUG #13
14
L C,
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,903 FEET
PLUG #17
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,903 FEET
PLUG #18
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,907 FEET
PLUG #19
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,907 FEET
PLUG #20
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,907 FEET
PLUG #21
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 111911 FEET
PLUG #22
1X
x
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,911 FEET
PLUG #23
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,911 FEET
PLUG #24
'p��q� fin.. ;•r%�+ + r'„1'. #1
'9'� >
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,915 FEET
PLUG #27
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 115918 FEET
PLUG #28
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,918 FEET
PLUG #29
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 119918 FEET
PLUG #30
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 115925 FEET
PLUG #31
1X
11 r �y rXN
0.0
.•� � y
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 119925 FEET
PLUG #32
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,925 FEET
PLUG #33
SW.
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,930 FEET
PLUG #35
w,
t
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,935 FEET
PLUG #37
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 119935 FEET
PLUG #38
kip.
,30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,967 FEET
PLUG #40
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,972 FEET
PLUG #43
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,972 FEET
PLUG #44
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 11,976 FEET
PLUG #46
WA
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 12,193-94 FEET
PLUG #49
1X
i
A
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 12,199-200 FEET
PLUG #52
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 129199-200 FEET
PLUG #53
ix
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 12,199-200 FEET
PLUG #54
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 129397-98 FEET
PLUG #55
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 1231397-98 FEET
PLUG #56
.".,r "'r. } � ,
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 12,389 FEET
PLUG #58
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 12 089 FEET
PLUG #60
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 125400-01 FEET
PLUG #61
1X
'117
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 129400-.01 FEET
PLUG #62
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 12,400-01 FEET
PLUG #63
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE #D-2
DEPTH 129410-11 FEET
PLUG #64
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNITS STATE #D-2
DEPTH 12,410-11 FEET
PLUG #65
1X
30X
MARATHON OIL COMPANY
TRADING BAY UNIT STATE ##D-2
DEPTH 125410-11 FEET
PLUG ##66
AFFIDAVIT OF PUBLICATION
STATE OF ALASK.A, )
THIRD JMC1AL DISTRICT,) ss.
-- _
being first duly sworn on oath
deposes and says that
is the- _"^'-= of the
Anchorage mews, a daily news-
paper. That said newspaper has
been approved as a legal news-
paper by the Third Judicial Court,
Anchorage, Alaska, and it is now
acid has been published in the
English ianguage continually as
a daily newspaper in Anchorage,
Alaska, and it is now and during
all of said time was printed in an
office maintained at the aforesaid
place of publication of said news-
paper, That the annexed is a true
.
copyof a - ---------------------------------
as it was published in regular
issues (arid not in supplemental
form) of said newspaper for a
period of __ _one __ insertions,
commencing on the `� - -- day
r�
i U f"'"71 t "%
of `�
-------®� 9 - -- - , and
ending on the ------ I ------- day of
o6
gg ------------ , --
both dates inclusive, and that
such newspaper was regularly
distributed to its subscribers dur-
ing all of said period. That the
full amount of the fee charged
for the foregoing publication is
the sum of 12 . C'0 which
arriount has been paid in full at
the rate of 25¢ per line; Mini-
rnum charge $7.50.
Subscribed � dsworn to before
22 "7 St
me this --____-- day of--------------------,
1 9----
Notary Public in and for'
the State of Alaska,
Third Division,
Anchorage, Alaska
MY COMMISSiC N EXPIRES
i NOTICE OF PUBLIC HEARING
STATE OF ALASKA
DEPARTMENT OF NATURAL
RESOURCES
DIVISION OF OIL AND GAS
Alaska Oil and Gas Conservation i
Committee
Conservation File No. 95
Joint Resolution No. 11.
Re: The Application of Union Oil
Company of California for mod
ification of Conservation Order
No. 80 to include the following
pool rule:
Gas from a gas well may be per.
witted to escape, into the air with-
out Committee approval when such
gas is used to artificially lift oil
from a pool in cases of operational
necessity provided no such escape
be for more than 30 days in each
such case.
Notice is herebygiven that the,
Union Oil Company of California has
petitioned the Alaska Oil and Gas
Conservation Committee for an or-
der which would make the above
referenced addition to the McArthur'
River pool rules. A public hearing
on this matter will be held on
August 27, 1970 in the Ben Craw-
ford Memorial Building, Third Ave-
nue and Eagle. Street, Anchorage,
Alaska, at 9:30 a.m., at which time
affected and interested parties will
be heard.
THOMAS R. MARSHALL, JR.
Executive Secretary
Alaska Oil and Gas
Conservation Committee
3001 Porcupine Dr.
Anchorage, Alaska 99504
'Pub.: August 15, 1970
Legal Notice No. 3063
5
NOTICE OF PUBLIC HEARING
STATE OF ALASKA
DEPARTMENT OF NATURAL RESOURCES
DIVISION OF OIL AND GAS
Alaska Oil and Gas Conservation Committee
Conservation File No. 95
Re: The application of Union Oil Company of California for modification
of Conservation Order No. 80 to include the following pool rule:
Gas from a gas well may be permitted to escape into the
air without Committee approval when such gas is used to
artificially lift oil from a pool in cases of operational
necessity provided no such escape be for more than 30
days in each such case.
Notice is hereby given that the Union Oil Company of California has
petitioned the Alaska Oil and Gas Conservation Committee for an order
which would make the above referenced addition to the McArthur River
pool rules. A public hearing on this matter will be held on August 27,
1970 in the Ben Crawford Memorial Building, Third Avenue and Eagle Street,
Anchorage, Alaska, at 9:30 a.m., at which time affected and interested
parties will be heard.
Thomas R. Marshall, Jr. v
Executive Secretary
Alaska Oil and Gas Conservation Committee
Anchorage, Alaska 99504
Publish August 15, 1970
Union Oil and Gas D', ;ion: Western Region
Union Oil Company of California
2805 Denali Street, Anchorage, Alaska 99503
Telephone (907) 277-1481
August 12, 1970
I . 3
41Y L; I.af ir.r
Alaska Oil and Gas Conservation Committee
3001 Porcupine Drive
Anchorage, Alaska e°;SO4
APPLICATION FOR EXCEPTION TO
SECTI OI'v 2158(b) OIL AND GAS
CONSERVATION REGULATIONS
TRADING BAY UNIT STATE K-20
AND FOR AMENDMENT OF CONSERVATION
ORDER NO.'80
Gentlemen.:
Reference is made to Conservation File No. 94, Emergency Order, dated
July 23, 1970.
Circumstances beyond the control of Union Oil Company of California, operator
of the Trading Bay Unit, and Atlantic Richfield Company, sub -operator of the
King Salmon Platform, have prevented the repair of the damaged compressor
creating the emergency requiring the above Emergency Order. A part necessary
for such repair was not available and had to be manufactured thus causing an
unforeseeable delay in the repair. It is anticipated the compressor will not
be operational' until approximately August 26, 1970. Unless gas from the
Trading Bay Unit State K-20 well can be utilized for gas lifting operations,
production from some wells will have to be curtailed and other wells will
have -to be shut in. The Engineering Report referred to in Union's application
for exception to Section 2158(b) dated August 3, 1970 contains information
presenting strong evidence of the likelihood of well bore damage to wells
shut in for an extended period of time. Unio,-., therefo;rve respectfully requests
an Emergency Order be issued allowing,exception to S ctic;% 2158(b) of the Oil
and Gas Conservation Regulations to permit the escape into the air of gas from
Trading Bay Unit State K-20 well after being utilized for lifting oil for the y .
period August 13, 1970 through August 27, 1970 inclusive or until the damaged
_i_ _..._._._.._.�....
compressor is again operational, whichever first occurs. It s.. also requested
that the McArthur.._......_.._._.........._.__._.......... _........ �..
include that
following
Order No. 80 be amended to
_... ,,...._._..., .
Gas from a gus well may be permitted to escape into the air without
Committee approval when such gas is used to artificially lift oil
from a pool in cases of operational necessity provided no such escape
be for more than 30 days in each such case.
'V
DO
Pku
pwVj,,ijuN OF OIL AND GAS
�•,�*1C li �l�AG �
Alaska Oil and Gas Coi�.servat i on Committee
Page 2
August 12, 1970
It is requested a hearing be held on August 27, 1970 at which testimony may be
presented to support this request for Field Rule Amendment.
Very truly yours,
UNION OIL COMPANY OF CALIFORNIA
Unit Operator
By
Robert T. Anderson ��
