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Alaska Oil and Gas Conservation Commission
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From:NSK DHD Field Supervisor
To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC)
Cc:Well Integrity Specialist CPF1 & CPF3
Subject:3N-03,04,05 and 10 10-426 forms from 8-17-24
Date:Sunday, August 18, 2024 11:54:55 AM
Attachments:image001.png
MIT KRU 3N-03,04,05 and 10 SI TESTS 08-17-24.xlsx
Please see the attached 10-426 form for the shut in MITIA’s from 3N-03,04,05 and 10 that were
conducted on 8-17-24. If you have any questions please let me know.
Bruce Richwine/Matt Miller
DHD Field Supervisor
KOC F-wing 2-14
(907) 659-7022 Office
(907) 943-0167 Cell
N2238@COP.com
.581
37'
Submit to:
OOPERATOR:
FIELDD // UNITT // PAD:
DATE:
OPERATORR REP:
AOGCCC REP:
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 1860160 Type Inj N Tubing 1050 1250 1275 1275 Type Test P
Packer TVD 6146 BBL Pump 2.0 IA 400 2100 2010 1990 Interval 4
Test psi 1537 BBL Return 2.0 OA 100 110 105 105 Result P
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 1860170 Type Inj N Tubing 2000 2010 2010 2010 Type Test P
Packer TVD 6157 BBL Pump 2.0 IA 120 2700 2610 2600 Interval 4
Test psi 1539 BBL Return 2.0 OA 100 100 100 100 Result P
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 1860260 Type Inj N Tubing 2060 2080 2080 2080 Type Test P
Packer TVD 6041 BBL Pump 2.0 IA 320 2830 2770 2760 Interval 4
Test psi 1510 BBL Return 2.0 OA 60 60 60 60 Result P
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 1860720 Type Inj N Tubing 1860 1875 1875 1875 Type Test P
Packer TVD 6303 BBL Pump 3.2 IA 210 2700 2580 2550 Interval 4
Test psi 1576 BBL Return 3.2 OA 35 45 40 40 Result 3
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
TYPE INJ Codes TYPE TEST Codes
INTERVAL Codes Result Codes
W = Water P = Pressure Test I = Initial Test P = Pass
G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail
S = Slurry V = Required by Variance I = Inconclusive
I = Industrial Wastewater O = Other (describe in notes)
N = Not Injecting
ConocoPhillips Alaska Inc,
Kuparuk / KRU / 3N Pad
Arend / Richwine
08/17/24
Notes:
Notes:
3N-03
3N-04
3N-10
Notes:
3N-05
Notes:
Notes:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
MMechanicall Integrityy Test
jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov
Form 10-426 (Revised 01/2017)2024-0817_MIT_KRU_3N-pad_4wells
999
9
9
9
9
9
-5HJJ
3N-10
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg n DATE: Tuesday, August 18, 2020
P.I. Supervisor I`� ��i �(S I SUBJECT: Mechanical Integrity Tests
6 ConocoPhillips Alaska, Inc.
3N-10
FROM: Brian Bixby KUPARUK R1V UNIT 3N-10
Petroleum Inspector
Sre: Inspector
Reviewed By:
P.I. Supry
NON -CONFIDENTIAL Comm
Well Name KUPARUK RIV UNIT 3N-10
Insp Num: mitBDB200816081716
Rel Insp Num:
API Well Number 50-029-21576-00-00 Inspector Name: Brian Bixby
Permit Number: 186-072-0 Inspection Date: 8/15/2020
Packer
Well 1 3N-10
Type Inj w -'TVD
PTD 1860720
Type Test'; SPT,
,Test psi
BBL Pumped: I
1.9 BBL Returned:
Interval
4YRTST _jP/F
Notes:
Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
6303
Tubing I
2970 -
2970
2970 '
2970
1576
IA480
1900
1810
1790
1_7
OA
105 .
105
105
105 -
P
Tuesday, August 18, 2020 Page I of I
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• •
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Monday,August 08,2016
TO:
Jim Regg 7 c(tj/oi
P.I.Supervisor 1-71/ I SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
3N-10
FROM: Bob Noble KUPARUK RIV UNIT 3N-10
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I.Supry jGe
NON-CONFIDENTIAL Comm
Well Name KUPARUK RIV UNIT 3N-10 API Well Number 50-029-21576-00-00 Inspector Name: Bob Noble
Permit Number: 186-072-0 Inspection Date: 8/1/2016
Insp Num: mitRCN160801172918
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well 3N-10 - [Type Inj W'TVD 6303 . Tubing 2900 2900 - 2900 2900 .�
PTD 18607220 Type Test SPT Test psi 15P76 IA 430 2000 - 1920 _ 1890 .
'i
-r -
Interval 4PR0 P/F OA i 140 160 - 160 . 160 -
Notes:
SCANNED MAY 1 0 20I
Monday,August 08,2016 Page 1 of 1
•
~/ • •
ConocoPh i I I ~ ps
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
October 23, 2008
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West 7~' Avenue, Suite 100
Anchorage, AK 99501
Dear Mr. Maundcr:
•
~a~'~~°2
~o
~f'
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRiJ). Each of
these wells was found to have a void in the conductor. These voids were filled with cement if
needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As
per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that
the treatments took place and meets the requirements of form 10-404, Report of Sundry
Operations.
The cement was pumped October 19, 2008 and the corrosion inhibitor/sealant, was pumped
October 21, 2008. The attached spreadsheet presents the well name, top of cement depth prior to
filling, and volumes used on each conductor.
Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions.
Sincerely, ,~~
~~
~~ Gr~%
~`
MJ Lo eland
ConocoPhillips Well Integrity Projects Supervisor
• ~
ConocoPhillips Alaska Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations (10-404)
Kuparuk Field
n~+e 10/22/2008
Well Name
PTD #
Initial top of
cement
Vol. of cement
um ed
Final top of
cement
Cement top off
date
Corrosion
inhibitor Corrosion
inhibitor/
sealant date
ft bbls ft al
3N-01 185-313 32' 5.00 21" 10/19/2008 3.4 10/21/2008
3N-02A 186-032 66' 10.00 4" 2" 10/19/2008 10.2 10/21/2008
3N-03 186-016 43' 6.00 22" 10/19/2008 5.1 10/21/2008
3N-04 186-017 83' 9.00 24" 10/19/2008 10.2 10/21/2008
3N-05 186-026 21" NA 21" NA 2.55 10/21/2008
3N-07 186-028 20' 3.50 21" 10/19/2008 3.4 10/21/2008
3N-08A 186-068 8' 1.50 21" 10/19/2008 5.1 10/21/2008
3N-09 186-030 14' 2.50 21" 10/19/2008 4.25 10/21/2008
3N-10 186-072 9T 12.00 5'8" 10/19/2008 15.3 10/21/2008
3N-12 186-079 62' 9.50 4'7" 10/19/2008 17 10/21/2008
3N-13 186-081 17' 2.00 35" 10/19/2008 4.25 10/21/2008
3N-14A 207-119 21" NA 21" NA 3.4 10/21/2008
3N-15 186-090 64' 8.00 20" 10/19/2008 6.8 10/21/2008
3N-16 186-091 71' 8.50 30" 10/19/2008 3.75 10/21/2008
3N-17 186-092 59' 6.00 22" 10/19/2008 5.1 10/21/2008
3N-18 186-093 49' 6.40 28" 10/19/2008 5.95 10/21/2008
3N-19 201-225 16" NA 16" NA 3.4 10/21/2008
MEMORANDUM
To: Jim Regg '~~~ l ~ C.,~r (~~
P.I. Supervisor
FROM: $ob Noble
Petroleum Inspector
State of Alaska •
Alaska Oil and Gas Conservation Commission
DATE: Wednesday, October O1, 2008
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA PVC
3N-10
KUPARUK RIV iTiVIT 3N-10
Src: Inspector
NON-CONFIDENTIAL
Reviewed By•
P.I. Suprv ~3(=
Comm
Well Name: KUPARUK RIV UNIT 3N-10 API Well Number: 50-029-21576-00-00 Inspector Name: Bob Noble
Insp Num: mitRCN080930092947 Permit Number: 186-072-0 °' Inspection Date: 9/28/2008
Rel Insp Num:
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well 3N-]0Type Inj. W TVD 6303 ~ ; IA I 1000 1970 1940 ~ 1930 ~
P.T. 1860720 iTypCTeSt SPT i TCSt pSl 1970 QA ', 220 270 270 270
Interval aYRTST p~F P J Tubing ~ z7oo i z7oo ~ z7oo ~ z7oo
Notes:
Wednesday, October Ol, 2008 Page 1 of t
MEMORANDUM
State of Alaska
Alaska Oil and Gas Conservation Commission
TO:
Jim Regg r;/ ß(Z4JO-f-
P.I. Supervisor Î')~f I
DATE: Thursday, August 19,2004
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
3N-10
KUPARUK RIV UNIT 3N-10
FROM:
Jeff Jones
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I.Suprv Sf312--
Comm
NON-CONFIDENTIAL
Well Name: KUPARUK RIV UNIT 3N-10 API Well Number: 50-029-21576-00-00 Inspector Name: Jeff Jones
Insp Num: mitJJO4081810 1409 Permit Number: 186-072-0 Inspection Date: 8/15/2004
Rei Insp Num:
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well 3N-10 Type Inj. S TVD 6744 IA 940 1970 1930 1930
P.T. 1860720 TypeTest SPT Test psi 1575.75 OA 220 330 340 340
Interval 4YRTST PIF P Tubing 2980 2980 2980 2980
Notes: .6 BBLS diesel pumped.
Thursday, August 19,2004
Page 1 of 1
MICROFILMED
9/11/00
DO NOT PLACE
ANY NEW MATERIAL
.UNDER THIS PAGE
· UN 16
1. Type of Request:
'9S 04: ;:'4PH ,~_.P,X.~,E~DJ, C~O~'[',~,~,.,~,~ ~C~~/"~'~ON COMMISSIOI~,~
APPLICA'Ir N FOR SUNDRY APP VALS
m.i _ ii ~ .,,
Abandon __ Suspend _. Opera, on Shutdown __ Re-enter suspeneled well
Alter ca~ing Repair weft ~ Plugging Time extension b"limulale _..
Change approved program ~ Pull tubing ~ Variance ~ Perforate Other
._. ii
5. Type of Well:
Develppment _.
b"tratlgraphlo . Serdoe X
..- i
2. Name of Operator
'.....B,,,P, ExOIoration (Aiae _i~, ), lnc.
3. Address
P. O, Box 196~12, Anchora.qe, Alaska 9g~19~$12
, 4. Location of well at surface
1989' SNL, 2256' WEL, Sec. 38, T12N, R16E
At top of productive interval
222' SNL, 3716' WEL, SEC,. 38, T12N, R16E
At effective depth
$0' SNL, 3823' WEL, Sec. 38, T'/£N, R16E
At total depth
24' SNL. 3858' WEL, Seo: 36. T12N, R76E
12. present well condition summary
Total depth: measured
true vertical
Effective depth: meas. ured
true vertical
11242 feet
10587 BKB feet
11160 feet
10511 BKB feet
Plugs (measured)
Junk (measured)
P.16719
6. Datum elevation (DF or KB)
.,, RT-
7. Unit or Properly name
Dusk Island Unit/Endicott
ii
8. Well number
2-34/P-14 MPI
9. Permit number
86-172
10. APl number
50-029-21.682
11. Field/Pool
Endicott Oil Pool
feet
ORIGINAL
Casing
Structural
Conductor
Surface
Intermediate
Production
Liner ·
Perforation depth:
Length Size Cemented Measured d~J~ True vedi~l depth
BKB
71' 30" Ddven 111' 111'
2442' 13 3/8" 2542 c.f. Permafrost '2482' 2482'
100F1' 95/8' 575c. f. Class G 10111' 9556'
1413' 7" 447o. f. Glass G 9827'. 11240' g308'. 10585'
measured 10634'- 10724', 10732'- 10760', 10795'- 10840', 10850'- 108g0', 10940'. 10980'
true vertical ($ubsea) 9972'- 10055', 10062'- I0088; 10119'. 10161'; 101~g'. 10206', 10252'- 10289'
Tubing (size, grade, and measured depth) 5 1/'2" 17# L-80 tubing to g590' MD; 4 1/2' 12.61f L-80 tubing to 10793' MD
Pa~kers and SSSV (type and measured depth) g ~/8" Baker $B-3 Packer at g616', 7 ' Baker SABL-$ Packer at 10781', $$$V at
._
1508' ._
J II I
:13. Attachments Description ~ummary of proposal :~._. Detailed operations program BOP sketch
-..,, .j, ,
14. Estin~ated date for commencing operation 15. Status of well =aasmca~on as:
June
'
16. If proposal was verbally approved Oil
Name of approver Date approved Service Water I.njector
17. I' here.by certify that the foregoing is true and correct to the best of my knowledge. ' ........
FOR COMMISSION USE ONLY
Conditions of approval: Notify Commission so representative may witness I [~pproval No. ~,~
Plug i~tegri~ BOP Test~ Location clea~nce ~
chani~l Integd~ Test ~ Subsequent form required 1
Approved ~y order ~ ~e Commission.
Form 10-403 Rev 06/1~/88 SUBMIT IN TRIPLICA~
ORIGINAL $1GI~IEu
:Robert N. ChdstensOn
17 1998
AlaskaOilaGasCms.
June 15,1998
Background
Originally completed as a zone 3A/2B producer, well 2-34/P- 14 was initially put on production in
April, 1988. After producing 3.36 million stock tank barrels, the well was convened to a water
injector in Sanuary, 1990. In November, 1993, a rig work over was completed on well 2-34/P-14
to replace a failed production packer. Since the 1993 work over, the well has been very necessary
to maintain zone 2B wservoir pressure via water injection. Tubing - inner annulus communication
was fu'st suspected in mid April with a injection profile log and confirmed with a leak detection
log (I;/11/98) and Kinley Caliper Survey (5/12/98). Both the leak detection log and Kinley Survey
verified the communication. The location of the leak was identified to be in the middle of a joint
of tubing at approximately 6,6.55' md. Overall, the existing leak is evidenced to be an isolated
hole in a single joint of tubing. ,
Remedial Actions
Since discovery of the leak, the well has discontinued water injection. Pending immediate
installation of a mechanical tubing patch, consideration of the observed con'osion in the tubing
around the identified leak justifies that continuation of water injection into the existing well
completion poses no significant risk of increased tubing damage. After evaluating all of the
remediation options, it was decided that the tubing patch was the most attractive technique
available to repair the leak.
Recommendation
We request well 2-34/P-14 be allowed to maintain water injection until a mechanical patch can be
instailed. Priority will be given to this job to ensure a prompt repair. Pending equipment and
material availability, the tubing patch should be installed before the end of July, 1998. During the
interim, the inner and outer annulus pressures will be monitored on a daily basis. BP believes the
well can remain in it's current state, pending remedial action, without compromising safety or the
environment. Your concurrence is requested.
DJ$/s~
ORIGINAL
JUN 17 1998
ila Oil & OasOons. Coneiaaion
A'RCO Alaska, Inc.
Post Office i~'/'"'~'~00360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
November 10, 1993
Mr. David W. Johnston, Chairman
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Dear Mr. Johnston:
Attached in duplicate are multiple Reports of Sundry Well Operations (Form
10-404) notices in the Kuparuk field. The wells are listed below.
WELL ACTION
3F-02 Stimulate
'' 3M'09 Stimulate
'"3M-09 Perforate
3N-10 Stimulate
3N-16 Stimulate
If you have any questions, please call me at 263-4241.
Sincerely,
P. S. White
Senior Engineer
Kuparuk Petroleum Engineering
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
AI~A OIL AND GAS CONSERVATION ~MIS,..
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Performed: Operation Shutdown Stimulate X Plugging Perforate
Pull tubing Alter casing Repair well O t h e r __ /
2. Name of Operator 15. Type of Well: 6. Datum elevation (DF or KB)
Development _
ARCO Alaska. Inc. Exploratory __ RKB 69' fee
3. Address ~ Stratigraphic __ 7. Unit or Property name
P. O. Box 100360, Anchorage, AK 99510I Service ;~ Kuparuk River Unit
4. Location of well at surface
1561' FSL, 179' FEL, SEC.29, T13N, R9E, UM
At top of productive interval
1650' FSL, 1785' FWL, SEC.33, T13N, R9E, UM
At effective depth
1547; FSKM 1725; FWL, SEC.33, T13N, R9E, UM
At total depth
1209' FSLr 1961' FWLr SEC.33r T13N~
12. Present well condition summary
Total Depth: measured
R9E, UM
9394' feet
true vertical 6744' feet
EffectiVe depth: measured 9 2 71 ' feet
true vertical 6 6 6 3' feet
Casing Length Size
Structural
Conductor 8 0' 1 6"
Surface 4533' 9 5/8"
Intermediate
Production 9 3 3 6' 9 5/8"
Liner
Perforation depth: measured
8860'-8898',
true vertical
6395'-6420',
9O26'-9O49',
6504'-6519',
Tubing (size, grade, and measured depth)
Plugs (measured)
Junk (measured)
8. Well number
3N-10
9.
Permit
numbe/Approv_.qJ,,Number
10. APl number
so-029-21 57600
11. Field/Pool Kuparuk River Field
Kuparuk River Oil Pool
Cemented Measured depth True vertical depth
247 Sx CS II 1 1 5' 1 1 5'
1400 Sx AS II & 4572' 3560'
315 Sx Class G
300 Sx Class G & 9375' 6732'
175 Sx AS I
9064'-9071'
6529'-6533'
RECEIVED
NOV 7 5 199
13.
2-7/8" 6.5# J-55 AMB @ 8956'
Packers and SSSV (type and measured depth)
SSSV: Baker FVL @ 1835'~ PACKERS: Brown HB-1 ~ 8703', Brown 1-B @ 8948'
Stimulation or cement squeeze summary
A SAND FRACTURE TREATMENT ON INJECTOR
Intervals treated (measured) ,.
9026'-9049', 9064'-9071 '
Treatment description including volumes Used and final pressure
SEE A'I-I'ACHED WELL SERVICE REPORT SUMMARY
14.
Representative Daily Average Production or Injection Data
OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure
Tubing Pressure
Prior to well operation 0 0 225 900 2800
Subsequent to operation
0 0 500 50
2800
15. Attachments
Copies of Logs and Surveys run
Daily Report of Well Operations X
16. Status of well classification as:
Oil __ Gas Suspended
Service WATER INJECTOR
17. I hereby,~<ertify that the foregoing is true and correct to the best of my knowledge.
Signed Title Sr. Petroleum Engineer
Form 10-404 Rev 09/12/90
SUBMIT IN DUPLICATE
MORNING REPORT SUMMARY
10/01/93 TO 10/01/93
CPF-3
DS-3N
3N-10
10/01/93 GSW DATAFRAC W/DOWELL. PUMP BD, PI's and DF's @ 15 BPM. DATA AS
FOLLOWS:
STAGE VOLUME FWHTP ISIP CLOS P FG PERF/XS FRIC
BD @23BPM 100 6880 3080 5400 .92 N/A
PI #1 25 5241 2966 5400 .90 125
PI $2 25 5250 2984 5500 .90 117
PI $3 25 5241 2938 5600 .89 152
FLUSH 51 5227 3154 5680 .93 ---
DF $1 150 5589 3250 NF .94 190
DF $2 80 5566 3236 NF .94 180
NO CLOSURE EVIDENT ON EITHER DF FOLLOWING 30 MIN & 25 MIN
SHUTDOWNS RESPECTIVELY. FLUID EFFICIENCY ESTIMATED AT BETTER THAN
60%. DECREASED PAD F/ 40-20 BBLS PER PROCEDURE. HAD TO CUT RATE
TO 13 BPM @ 10PPA STAGE DUE TO TBG FRIC, TREATING PRESSURE DROPPED
F/6500-5900 PSI. SCREENED OUT 13.3MLBS INTO 10 PPA STAGE, LAST
WHTP=6900 PSI. TOT PROP: DESIGN=99.7 MLBS, IN FORM=61.5 MLBS
W/10 PPA @ PERFS, 15.7 MLBS IN WELLBORE, EFF PAD/SLURRY = 5%. TOT
FLUIDS: WATER=788.5 BBL, DSL(FLA + FLUSH)=20 BBL, ADD'S=69 BBL.
ALL FLUIDS LOOKED GOOD. (GOLDEN/BOTELLO/HARVEY)
RECEIVED
Alaska Oil & f~as Cor~. Co~p~ni~km
ARCO Alaska, Inc.
Subsidiary of Atlantic Richfield Company
WELL SERVICE REPORT
WELL
CONTRACTOR
REMARKS
FIELD- DISTRICT- STATE DAYS J DATE
OPERATION AT REPORT TIME
I~¢~
0 / o,_~, ~..o '
R ECELV_E.B
r,~ov i 5 i9~,~
Alaslca Uii & Gas Co~. ~:llflmJl~on
I-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK
Weath.
Report
REMARKS CONTINUED:
DESCRIPTION DAILY ACCUM.
TOTAL
CAMCO
,
OTIS
SCHLUMBERGER ~,
DRESSER-ATLAS ~ . ..
,
DOWELL ~/Z y
HALLIBURTON
, ,,
ARCTIC COIL tUBING
FRACMASTER
,,
B. J. HUGHES
.
·
Roustabouts ~' ~ <'" ~ /Z. ,, ~
Diesel ,~
Methanol
Supervision_~ -- . .....
~'~o ~,,~,~ . .. ~ ~ o o ..
Pre-Job Safety"-' -'-Meeting .,.
AFE
,
..
-.
·
......
.. , ,
TOTAL FIELD ESTIMATE ~07,~ ~
I Sign.~~~
ARCO Alaska, Inc.
Date: February 23, 1989
Transmittal #: 7432
RETURN TO:
Transmitted herewith are the following items.
one signed copy of this transmittal.
3F-15
3N-18
3F-01
3F-02
3F-09
3F-06
3F-10
3F-11
3F-15
3F-14
3N-10
3N-06
3N-09
31-01
3N-11
3N-14
3F-08
3N-01
3N-14
3F-15
3F.-15
3F-13
3F-15
1B-'05
1E-25
3B-11
3A-03
3H-01
2Z-19
31-12
1E-08
3M-18
ARCO Alaska, Inc.
Attn: Brenda K. Miernyk
Kuparuk Records Clerk
ATO-1119
P.O. Box 100360
Anchorage, AK 99510-0360
Please acknowledge receipt and return
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
KuPaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
· Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kuparuk Well Pressure Report
Kuparuk Well Pressure Report
Bottom-Hole Pressure Survey
Kuapruk Well Pressure Report
Kuparuk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
12-03-87
12-18-87
8-29-87
8-29-87
8-29-87
8-29-87
8-29-87
8-29-87
8-29-87
8-29-87
5-18-87
5-22-87
5-21-87
4-24-87
4-15-87
4-13-87
4-14-87
4-20-87
12-04-87
2-02-89
8-27-87
8-27-87
8-25-87
2-20-89
2-19-89
2-20-89
2-21-89
2-21-89
2-20-89
2-20-89
2-19-89
2-15-89
Casing
Casing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Casing
Casing
Casing
Casing
Casing
Casing
Casing
Casing
Casing
Tubing
Sand 'C'
SandBHP 'C'
Amerada
Casing
Casing
Ca ing
Tubing
Tubin~'~l~
Casin~
Casin(;]-~
'cboraEe
3H-01
3B-13
1E-29
1C-05
3M- 1'7
2Z-20
30-10
31-12
3H-10
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
BHP Report
2-15-89 Casing
2-17-89 Casing
2-15-89 Casing
2-18-89 Casing/Tubing
2-16-89 Casing
2-18-89 Tubing
2-16-89 Casing
2-20-89 Tubing
2-13-89 BHP
Receipt Acknowledged'
-- Date' - ...........
DISTRIBUTION:
D&M State of Alaska SAPC Unocal Mobil Chevron
--:-~_ i _. ~: ,~. -~:~.: ~.-.~:~- :.. ~
ARCO Alaska, Inc.
Date: February 17, 1989
Transmittal #: 7429
RETURNTO:
ARCO Alaska, Inc.
Attn: Brenda K. Miernyk
Kuparuk Records Clerk
ATO-1119
P.O. Box 100360
Anchorage, AK 99510-0360
Transmitted herewith are the following items. Please acknowledge receipt and return
one signed copy of this transmittal.
3 F- 1 I Sub-Surface Pressure Survey 1 0- 0 6 - 8 8
3 H - 1 2 Kuparuk Well Pressure Report 8 - 2 9 - 8 8
30-07 Kuparuk Well Pressure Report I 2-20-88
3 F- 1 0 Kuparuk Well Pressure Report 8 - 2 9 - 8 7
3 F- 0 6 Kuparuk Well Pressure Report 8 - 2 9 - 8 7
3 F- 0 2 Kuparuk Well Pressure Report 8 - 2 9 - 8 9
3 F- 1 6 Kuparuk Well Pressure Report 8 - 1 7- 8 7
3 F- 1 6 Kuparuk Well Pressure Report 8 - 1 7- 8 7
3 F- 1 I Kuparuk Well Pressure Report 8 - 2 9 - 8 7
3 F ~ 0 4 Kuparuk Well Pressure Report 6 - 2 6 - 8 7
3 F- 0 5 Kuparuk Well Pressure Report 1 2-1 2 - 8 8
3 F- 1 3 Kuparuk Well Pressure Report I 2 - 3 1 - 8 8
3 N- 1 0 Kuparuk Well Pressure Report 6 - 1 1 - 8 7
3 N- 1 0 Kuparuk Well Pressure Report 6 - 1 1 - 8 7
3 N- 0 4 Kuparuk Well Pressure Report 9 - 01 - 8 7
3 N - 0 9 Kuapruk Fluid Level Report 5 - 0 4 - 8 7
30-1 4 Kuparuk Fluid Level Report 2 - 1 3 - 8 9
3 O- 14 Kuparuk Fluid Level Report 2 - 1 0 - 8 9
3 M - 1 8 Kuparuk Fluid Level Report 2 - 1 0 - 8 9
3 F- 1 6 Kuparuk Fluid Level Report 6 - 0 5 - 8 7
3 F- 1 3 Kuparuk Fluid Level Report 6 - 0 9 - 8 7
3 F- 1 3 Kuparuk Fluid Level Report 6 - 1 8 - 8 7
3 F ~ 1 3 Kuparuk Fluid Level Report 6 - 1 6 - 8 7
3 F- 1 3 Kuparuk Fluid Level Report 6 - 21 - 8 7
3 F - 0 8 Kuparuk Fluid Level Report 5 - 0 8 - 8 7
3 F- 1 6 Kuparuk Fluid Level Report 8 - 1 8 - 8 7
3 F- 1 6 Kuparuk Fluid Level Report 8 - 2 4 - 8 7
3 F- 1 3 Kuparuk Fluid Level Report 6 - 0 5 - 8 7
3 F- 1 6 Kuparuk Fluid Level Report 6 - 2 / 3 - 8 7
3 F- 1 6 Kuparuk Fluid Level Report 8 - 5 - 8 7
3 F- 1 6 Kuparuk Fluid Level Report 6 - 5 - 8 7
3 F- 1 4 Kuparuk Fluid Level Report 9 - 8 - 8 7
#7-889
Amerada
Sand 'A'
Amerada
Amerada
Amerada
Sand 'A'
Sand 'A'
Amerada
Sand 'A'
Both Sands
Both Sands
Sand 'A'
Casing
Casing
Casing
Casing
Tubing
Casing
Casing
cas? '7'
Casing
Tubing
Casing
Casing'
3F-14
3F-06
3F-14
3F-08
3F-14
3F-09
3F-05
3F-09
3F-06
3F-05
3N-10
3N-10
3N-11
3N-10
3N-05
3N-04
3N-13
3N-11
3N-18
3N-17
3N-07
3N-15
3N-05
3N-09
3N-04
3N-14
3N-08
3N-06
3N-02
3N-10
3N-10
3N-10
3N-10
3N-10
3N-10
3N-10
3N-07
3N-01
3N-04
3N-04
3N-09
3.N-1 0
Receipt
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Kuparuk Fluid
Acknowledged:
Level
Level
Level
Level
Level
Level
Level
Leyel
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Level
Report 9 - 1 I - 87
Report I 2 - 06 - 86
Report 9 - 1 I - 87
Report I 0- 1 I - 87
Report 9 - 1 6 - 87
Report 4 - 1 I - 88
Report 4 - 08 - 88
Report 4 - 01 - 88
Report 3 - 26 - 88
Report I - 3 0 - 88
Report I 0 - 1 2 - 87
Report 10 - 1 5 - 87
Report I 0 - 28 - 87
Report I 0 - 28 - 87
Report I 0 - 28 - 87
Report I 0 - 28 - 87
Report 3 - 1 9 - 87
Report 9- 1 2 - 87
Report 9 - 1 0 - 98
Report 9 - 1 0 - 87
Report 9 - 1 0 - 87
Report 9- 1 2 - 87
Report 9 - 08 - 87
Report 9 - 01 - 87
Report 9 - 01 - 87
Report 9 - 06 - 87
Report 9 - 06 - 87
Report 9 - 06 - 87
Report 9 - 06 - 87
Report 6 - 01 - 87
Report 5 - 31 - 87
Report 6 - 03 - 87
Report 6 - 06 - 87
Report .6 - 08 - 87
Report 6 - 09 - 87
Report 6 - 25 - 87
Report 4 - 1 7 - 87
Report 4 - 1 8 - 87
Report 6 - 1 7- 87
Report 6 - 20 - 87
Report 5 - 0 7 - 87
Report 8 - 24 - 87
........................... Date:
Casing
Tubing
Casing
Tubing
Casing
Casing
Casing
Casing
Casing
Casing
Casing
Casing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Casing
Casing
Casing
Casing
Casing
Casing
Casing
Casing
Casing
Alaska Oil & Gas Con,~. CommisS~or~
....... ~orage
DISTRIBUTION:
D&M State of Alaska ~.~ Mobil Chevron Unocal SAPC
ARCO Alaska, Inc. ~
Post Office Bo ..... 00360
Anchorage. Alaska 99510-0360
Telephone 907 276 1215
November 9, 1988
Mr. C. V. Chatterton, Chairman
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501 ·
Dear Mr. Chatterton:
Attached in duplicate are multiple Reports of Sundry Well Operations on the following
Kuparuk wells.
Conversions
3N-11, 3N-10, 3N-05, 3N-04, 3F-12, 3F-03, 3F-08, 3N-03, 3N-12, 3N-
13, 1E-21, 1E-19, 1E-23, 1E-lA, 1E-04, 1E-16 and1 E-27
Fractures and Stimulations
·
3K-14, 3C-16, 3K-17, 1E-14, 3N-17, 3F-16 and 2V-12
Perforations
3N-11, 3F-11
and 3N-8A
1E-30
Failed MIT
If you have any questions, please call me at 265-6840.
Sincerely,
Senior Operations Engineer
Attachments
cc: J. Gruber
M. L. H agood
S. P. Twiggs
KOE1.4-9
ATO 1478
ATO 1120
ATO 1130
RECEIVED
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
1. Type of Request:
-_ STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
Operation Shutdown__ Stimulate __ Plugging Perforate
Pull tubing Alter casing Repair well Pull tubing
Other
2. Name of Operator
ARCO Alaska. Inc.
3. Address
P. O. Box 100360, Anchorage, AK 99510
5. Type of Well:
Development X
Exploratory _
Stratigraphic _
Service
Location of well at surface
1561' FSL, 179' FEL, Sec. 29, T13N, R9E, UM
At top of productive interval
1650' FSL, 1785' FWL, Sec.'33, T13N, R9E, UM
At effective depth
1548' FSL, 1825' FWL, Sec. 33, T13N, R9E, UM
At total depth
1209' FSL, 1961' FWL, Sec. 33, T13N, RgE, UM
12, Present well condition summary
Total Depth: measured
true vertical
6. Datum elevation (DF or KB)
RKB 69
7. Unit or Property name
Kuparuk River Unit
8. Well number
3N-10 J,~ ~¢? ~",t)
9. Permit number/approval number
7-~61
10. APl number
5o-029-2157§
11. Field/Pool
Kuparuk River Oil Pool
9394' MD feet Plugs(measured) NONE
6744' MD feet
Effective depth: measured 9271' MD feet
true vertical 6663' MD feet
Junk (measured) NONE
Casing Length Size Cemented Measured depth
Structural
Conductor 80' 1 6" 247 Sx CSII 115' MD
Surface 4533' 9 5/8" 1400 Sx ASII 4572' MD
Intermediate & 315 SX Class G
Production 9336' 9 5/8" 300 SxClass G 9375' MD
Liner & 175 Sx ASI
Perforation depth: measured 8860'-8898', 9064'-9071', 9026'-9049'
True vertical depth
TVD
3560' TVD
6732' TVD
true vertical 6395'-6420', 6529'-6533', 6504'-6519'
13.
Tubing (size, grade, and measured depth)
2-7/8", 6.5#, 8971' MD
Packers and SSSV (type and measured depth)
Brown HB@ 8703' MD; Brown 1-B @ 8933' MD
Stimulation or cement squeeze summary
Intervals treated (measured)
Treatment description including volumes used and final pressure
14.
Reoresentative Daily Average Production or In!e(~tion Data
OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure
Tubing Pressure
Prior to well operation 129 111 0 700 123
Subsequent to operation 0 0 507 1 0 5 0 1 3 2 5
15. Attachments ~ 16. Status of well classification as:
Copies of Logs and Surveys run __
I
Daily Report of Well Operations X Oil Gas Suspended __Service Water In!ecti0n
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed //~ ~./~ f ./'~.'~/L-~[/~ ~/~/~ Title ~/~1, ~f~,-~t~,~.-~t...
Form 10~-404 Re~/ 06/15/88 SUBMIT IN DUPLICATE
feet
WELL SERVICE REPORT
ARCO Alaska,
Sui3~idiary of Atlantic Richfield Compan~
WELL I PBDT
..%~,1- ~ o
IFIELD - DISTRICT- STATE
OPERATION AT REPORT TIME
CONTRACTOR
~EMARKS
[-'1 CHECKTHIS BLOCK IF SUMMARY CONTINUED ON BACK
Weather ] Temp. Chill Factor I Visibility Wind Vel.
Report I °F °FI' miles ~
knotl
STATE OF ALASKA ~
ALA..,A OIL AND GAS CONSERVATION CO~, "SSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing []
Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other
,
Name of Operator
ARCO Alaska, Inc
3. Address
.
11.
PO Box 100360_. Anchnrage. AK
Location of well at surface
99510
t561' £SL, 1.79' FEL. Sec 29 T13N R9E UM
top or proouct~ve interval ' ' ' ~
5. Datum elevation (DF or KB)
RKB 69
6. Unit or Property name
Ku.naruk River liner
7. Well number
3N-10
8. Permit number
Permit #86-72
9. APl number
50-- 029-21576
1650' FSL, 1785'
At effective depth
1548' FSL, 1825'
At total depth
1209' FSL. 1961'
Present well condition summary
Total depth: measured 9394' MD
true vertical 6744' MD
FWL, Sec.33, T13N, R9E, UM
FWL, Sec. 33, T13N, R9E, UM
FWL. Sec.33~ T]3N~ RqE. IIM
10. Pool
KIJn~ruk River {lil Pnnl
!
feet
feet
Plugs (measured)None
feet
Effective depth:
measured 9271' MD
true vertical
6663' MD
Length
Casing
xxx~m,~kxxxx
Conductor 80 '
Surface
X X X ~'r~Rl~X(~i~te
Production
XXX kr xxxx
Perforation depth: measured
Size
16"
4533' 9-5/8"
4533'
9-5/8"
8860' -8898'
true vertical6395, -6420'
feet Junk (measured) None
feet
Cemented Measured depth
247 SX CSII 115' MD
1400 SX ASII & '4572' MD
315 SX Class G
300 SX Class G 9375' MD
& 175 SX ASI
, 9064'-9071', 9026'-9049'
, 6529'-6533' 6504'-6519'
Tubing (size, grade and measured depth)
2-7/8", 6.5#, 8971' MD
Packers and SSSV (type and measured depth)
Rrnwn HR 0 R7~l.~' Mrl~ Rrown !-B @ 8933' MD
12.Attachments Description summary of proposal []
Convert,ha a oroducer 1:o a wal:e~ ~n~Pcf. nr
- ~
13. Estimated date for commencing operation October 17, 1987
True Vertical depth
TVD
3560' TVD
6732' TVD
RECEIVED
OCT 0 1987
Alaska 0il & Gas Cons, C0mr
Anchorage
Detailed operations program [] BOP sketch []
14. If proposal was verbally approved
Name of approver L. Smith
Date approved 10/23/'87
15. I hereby certify that the foregoing is true and N"'~rrect to the best of my knowledge
Signed'/~(::~-J?2- /~ .q~,,~..~'~/'Title Sr. Operations Engineer
Commission Use Only
Conditions of approval
Approved by
Date10/23/87
Notify commission so representative may witness
[] Plug integrity [] BOP Test [] Location clearance
II]Ilt. Bi$
Commissioner
J Approval No..~ .- ~//
ssion
Form 10-403 Rev 12-1-85
by order of
the commission Date/(9 ,--.~ ,-~'~' I ~
Submit in tri~licat~
STATE OF ALASKA ~
ALA~ .~A OIL AND GAS CONSERVATION CO,. .;ISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: Operation shutdown [] StimUlate [] Plugging []
Alter Casing [] Other []
2. Name of Operator
ARCO Alaska, Inc
3. Address
PO Box 100360, Anchorage, AK 99510
4. Location of well at surface
1561' FSL, 179' FEL, Sec.29, T13N, ROE, UM
At top of productive interval
1650' FSL, 1785' FWL, Sec. 33, T13N, ROE, UM
At effective dep_th
1548' FSL, 1825' FWL, Sec.33,
~6~tFI ~t,h 1961' FWL, Sec.33,
T13N, R9E, UM
T13N, R9E, UM
11. Present well condition summarYcl ,
Total depth: measured ..394 MD feet
true vertical6744' TVD feet
Perforate [] Pull tubing []
5. Datum elevation (DF or KB)
RKB 69'
6. Unit or Property name
Kuparuk River Unit
7. Well number
IN-lO
8. Approval number
#86-72
9. APl number
50-- 029-21576
10. Pool
Kuparuk River 0il Pool
Plugs (measured~lOne
Effective depth: measured 9271' MD feet
true vertical6663' TVD feet
Junk (measured)None
Casing Length Size
Structural
Conductor 115 ' 16"
Surface 4533' 9-5/8"
XX x)4~te{:lx~j~te
Production 4533' 9-5/8"
xxxx~R~xxxx
Cemented Measured depth True Vertical depth
247 SX CSII 115' MD
1400 SX ASII 4572' MD
& 315 SX Class G
300 SX Class G 9375' MD
& 175 SX ASI
TVD
3560' TVD
6732' TVD
Perforation depth: measured 8860'-8898' MD, 9064'-9071' MD, 9043' MD, 9045' MD, 9047' MD
true vertica16395'-6420' TVD, 6529'-6533' TVD, 6515' TVD, 6516' TVD, 6518' TV[
Tubing (size, grade and measured depth)
2-7/8", 6.5#, 8971' MD
B Packer,s...an..d SS_SV_ ~tyD_e and measured depth)
rown HP Ld 8703 MD; Brown 1-B @ 8933' MD
RECEIVED
12. Stimulation or cement squeeze summary
Intervals treated (measured)
Treatment description including volumes used and final pressure
AUG 1 9 1987
Alaska 0il & Gas Cons. Commission
Anchorage
13.
Representative Daily Average Production or Injection Data
OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure
Tubing Pressure
Prior to well operation
150 BOPD 158 MCFPD 0 BWPD 850 psig
130 psig
Subsequent to operation
141BOPD 130 MCFPD 0 BWPD 850 psig
130 nsia
14. Attachments
Daily Report of Well Operations
Copies of Logs and Surveys Run []
15. I hereby certify that the foregoing is true and correct to the best of my knowledge
Form lO-3,0~"Rev. ¢-85 '
Title
Sr. Operations Engineer
Fee~
Date ~./~//'~/ ~ '7
Submit in B~plicate
ARCO Alaska Inc~,~
Subsidiary of Atlantic Richfield Compan;
WELL SERVICE REPORT
R,- .r,vED
AUG i 9 i'387 '"
AlasEa IJil & las Cons. Commlsslo~
~nchorao_,] , ,
[] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK
knots
,F-'", STATE OF ALASKA """-
ALA,-..A OIL AND GAS CONSERVATION CON .... ISSlON
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing []
Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate 2~, Other []
2. Name of Operator
ARCO Alaska, ;[nc
3. Address
PO Box 100360. Anchorage. AK 99510
4. Location of well at surface
1561' FSL. 179' FEL, Sec 29 T13N RgE UM
At top of productive interval
1650' FSL, 1785' FWL, Sec.33, T13N, RgE, UM
At effective depth
1548 FSL, 1825' F~L., Sec.33, T13N, RgE, UM
At total depth
1209' FSL, 1961' FWL, Sec.33. T13N? R9E. gM
11. Present well condition summary
Total depth: measured 9394' MD feet
true vertical 6744' MD feet
5. Datum elevation (DF or KB)
RKB 69
6. Unit or Property name
KuDaruk River Unit
7. Well number
3N-10
8. Permit number
Permit #86-72
9. APl number
5o-- 029-21576
10. Pool
Kunaruk River Oil Pnnl
Plugs (measured)None
feet
Effective depth: measured 9271' FID feet
true vertical 6663' FID feet
Casing Length Size
XXX$~gKKaLIXXXXX
Conductor 115 '
Surface 4533'
XX x;l~llllX~e~te
Production 4533 '
xxxk-~Zxxxx
Perforation depth: measured
Junk (measured) None
Cemented Measured depth True Vertical depth
16" 247 SX CSII 115' MD
9-5/8" 1400 SX ASII & 4572' MD
315 SX Class G
9-5/8" 300 SX Class G 9375' MD
& 175 SX ASI
8860'-8898', 9064'-9071', 9043', 9045', 9047'
true vertical6395,_6420, 6529'-6533' 6515' 6516' 6518'
Tubing (size, grade and measured depth)
2-7/8", 6.5#, 8971' FID
Packers and SSSV (type and measured depth)
Brown HB ~ 8703' MD; Brnwn 1-R 0 Rq23' Mn
12.Attachments Description summary of proposal []
TVD
3560' TVD
6732' TVD
Detailed operations program [] BOP sketch []
Adding perforations to a currentlv perforated interval
13, Estimated date for commencing operation
July 3, 1987
14. If proposal was verbally approved
Name of approver L. Smith
Date approved 6/29/87
15. I hereby certify that the fore_going is true and c...orrect to the best of my knowledge
Signed ,~~b.'l.~ ~¢'2/¢z4,,~.//.,,~Title Sr. Operations Engineer
Commission Use Only
Conditions of approval
Approved by
Date 7/16/87
Notify commission so representative may witness
[] Plug integrity
I Approval No.
[] BOP T~'st [] Location clearance q '~'/'-,-,~'-' '~
'~~''r' ~;ommissioner tbhYe°crdoernr m°~s s i o n/D a t e '~ ~ J~'_..,~
Form 10-403 Rev 12-1-85
Submit in triplicate
ARCO Alaska, Inc.'
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
April 30, L987
Transmittal # 5966
Return to:
ARCO Alaska, Inc.
Attn= Kuparuk Records Clerk
ATO-Ill9
P.O. Box 100360
Anchorage, AK 99510-0360
Transmitted herewith are the following items. Please acknowledge
receipt and retUrn one-signed copy of this transmittal.
3H-7
3H-6
3H-il
3H-12
3N-10
3J-16
3J-15
lA-8
2Z-7
2Z-7
2Z-7
2Z-7
CET 4-1-86 6202-7597
CET 4-/-86 606L-7583
CET 4-22-86 7600-8675
CET 4-29-86 6396-7965
CET 4-14-86 7462-9130
C£T 3-29-8G 7704-8727
C~T 3-29-86 7400-8398
CET I-5-86 5755-6154
CET 4-1&-87 8250-8491
CET 4-12-87 8246-8595
Squeeze & Retainer Record 4-15-87 8250-8491
Squeeze, BP & Retainer Record 4-12-87 8290-8588
Alaska Oil & Gas Cons. C0mmiss[0~
Anchorage
Receipt Acknowledged:
DISTRIBUTIOH:
HSK Drilling
Chevron Mobil
mmmmmmmmmm~mm
Date:
mmmmmmmmmm
BPAE
SAPC Unocal
VauLt (film)
ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany
-~--'t:,'~ ~ STATE OF ALASKA '-X
ALASKA UIL AND GAS CONSERVATION C~,VlMISSlON
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE []
2. Name of Operator 7. Permit Number
ARCO Alaska~ Inc. 86-72
3. Address 8. APl Number
P. 0. Box 100360, Anchorage~ AK 99510 50- 029-21576
4. Location of well at surface 9. Unit or Lease Name
1561' FSL, 179' FEL, 5ec.29, T13N, RgE, UN Kuparuk River Unit
At Top Producing Interval 10. Well Number
1650' FSL, 1785' FWL, Sec.33, T13N, RgE, UM 3N-lO
At Total Depth 11. Field and Pool
1209' FSL, 1961' FWL, Sec.33, T13N, R9E, UM Kuparuk River Field
5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool
RKB 69'I ADL 25520 ALK 2556
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions
03/28/86 04/03/86 08/15/86*I N/A feet MSL 1
17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+'rVD) 19. DirectionalSurvey I 20. Depth where SSSV set I21.Thickness°fPermafr°st
9394'MD, 6744'TVD 9271 'MD, 6663'TVD YES ~ NO [] 1851 feet MD 1700' (approx.)
22. Type Electric or Other Logs Run
DIL/SFL/SP/GR/CNL/FDC/Ca], CET/GR/CCL, Gyro (GCT)/CCL
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
16" 62.5# H-40 Surf 115' 24" 247 sx CS II
9-5/8" 36.0# J-55 Surf 4572' 12-1/4" 1400 sx AS III & 315 sx Class G
7" 26.0# J-55 Surf 9375' 8-1/2" 300 sx Class G & 17~ sx AS I
24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
2-7/8" 8(~71 ' 8719' & ~'
8860'-8898'MD 6395'-6420'TVD w/12 spf,120° phasing
9064'-9071 'ND 6529'-6533'TVD w/4 spf'90° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
9043'MD 6515'TVD w/4 spf, 90° phasing
DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED
9045'MD 6516'TVD w/4 spf, 90° phasing See attached Adden. lum, dated 03/24/87. for Fr~.~.,,r~ cl~l
9047'MD 6518'TVD w/4 spf, 90° Phasing -
_
27. N/A PRODUCTION TEST
Date First Production I Method of Operation (Flowing, gas lift, etc.)
I
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO
TEST PERIOD e
I
Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. 24-HOUR RATE ~
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
APR 2 2
/~l~s](a 0JJ & ~aS Cons. Commission
NOTE: Drilled RR 04/05/86. Perforated well & tubing run 07/19/86.
Form 10-407 WC2: 42: DAN I Submit in duplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE 0~
GEOLOGIC MAR K'Ei~'S . TESTS
,.
NAME InclUde interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
,
Top Kuparuk C 8766t 6332~ N/A
Base Kuparuk C 887~t
Top Kuparuk A 9011 ' 6~9~'
Base Kuparuk A 9125t 6568t
31. LIST OF ATTACHMENTS
Addendum (dated 03/2~,/87),
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed b/')~'7')~'~( ,/ ~ L~_~/_,\ ,, Title.i. Associate Engineer Date
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and log on
all types of lands and leases in Alaska.
Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt
water disposal, water supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements
given in other spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple
completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported
in item 27. Submit a separate form for each additional interval to be separately produced, showing the
data pertinent to such interval.
Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cement-
ing and the location of the cementing tool.
Item 27: Method of Operation: FloWing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none".
Form 10-407
ADDENDUM
WELL:
3N-lO
4/14/86
4/16/86
8/14/86
8/15/86
8/20/86
Arctic Pak w/175 sx AS I, followed by 60 bbls Arctic Pak.
RU Schl, rn 6-1/8" JB/gage ring to 9142', POOH. Rn
CET/GR/CCL f/9130'-7500' WLM. Rn gyro/CCL f/9104'-100',
RD Schl.
Press'd ann to 2660 psi w/diesel. Tst Ins to 12,500 psi;
OK.
Pmp'd frac per 7/28/86 procedure. Tree saver leaking &
Dowell did not have vlv open on tree saver body. Pmp'd
frac to flow back tanks as a result. Tree saver
completely failed. Flow back tank gained 100 bbls total.
Pulled tree saver; cups missing and mandrel severely
eroded. Reset new tree saver. Tst ins to 7000 psi.
Pmp'd 52 bbls gelled diesel to clear tbg vol & get
injection tst (Avg 6130 psi @ 19.4 BPM)
Frac'd Kuparuk "A" sand perfs 9043', 9045', 9047' &
9064'-9071' in 7 stages per 7/28/86 procedure using
gelled diesel, 100 mesh & 20/40 mesh sand. Press'd ann
to 2640 psi w/diesel. Tst lns to 8750 psi; OK.
Stage 1: Pmp'd 20 bbls gelled diesel pre-pad @ 5 BPM,
3930 psi
Stage 2: 10 bbls gelled diesel w/1 ppg, 100 mesh @ 5
BPM, 3850-3740 psi
Stage 3: 17 bbls gelled diesel pad @ 5 BPM, 3740-6100
psi
Stage 4: 50 bbls gelled diesel pad @ 20 BPM, 6100-6060
psi
Stage 5: 8 bbls gelled diesel w/3 ppg 20/40 mesh @ 20
BPM, 6060-6050 psi
Stage 6: 32 bbls gelled diesel w/8 ppg 20/40 mesh @ 18
BPM, 6050-6140 psi
Stage 7: 52 bbls gelled diesel flush @ 18 BPM, 6140-5440
psi (Job underflushed by 3 bbls per procedure)
Pmp'd 420# 100 mesh & 11,024 20/40 in formation leaving
735# 20/40 mesh sand above top perfs in csg.
Load to recover 189 bbls of diesel. Job complete at 0827
hrs, 8/15/86. Turn well over to Production. (Note:
Lost top cup off tree saver in hole.)
Set BPV, ND tree, NU new 2-9/16" tree & tst to 5000 psi;
OK.
ADDENDUM
WELL:
2/06/87
3N-10 (cont'd)
RU CTU, tst tbg & BOP to 4000 psi. RIH, break circ @
8500', wsh to tbg tail @ 9202' @ 1-3/4 BPM, 3600 psi.
Wsh'd 131' below lower perf, CBU. Displ CTU w/cln
diesel, POOH, displ'g well w/cln diesel. RD & secure
well. Used total 170 bbls gel diesel & 76 bbls diesel.
Turn well over to Production.
:" ~"~ STATE OF ALASKA "~' [~
ALASKA OIL AND GAS CONSERVATION C,~MMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOCI
1. Status of Well Classification of Service Well ~
OILY~ GAS [] SUSPENDED [] ABANDONED [] SERVICE []~
2. Name of Operator - : 7. Permit Number
ARCO Alaska, Inc. 86-72 '
3. Address 8. APl Number
P, 0, Box 100360, Anchorage, AK 99510 50- 029-21576
~'. Location of well at surface 9. Unit or Lease Name
1561' FSL, 179' FEL, 5ec.29, T13N, RgE, UM Kuparuk River Unit
At Top Producing Interval 10. Well Number
1650' FSL, 1785' FWL, Sec.33, T13N, RgE, UM 3N-10
At Total Depth 11. Field and Pool
1209' FSL, 1961' FWL, Sec.33, T13N, RgE, UM Kuparuk River Field
5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kupaurk River 0il Pool
69' RKBI ADL 25520 ALK 2556
12' Date SpUdded03/28/86 13. Date T.D. Reached04/03/86 14' Date C°mp" Susp' °r Aband'08/15/86* I15' water Depth' if OffshOreN/A feet MSL [ 16. No. of Completions1
17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost
9394 'MD ,6744 "TVD 9271 'MD,6663'TVD YEsX~] NO []I 1851 feet MD 1700' (approx)
·
22. Type Electric or Other Logs Run
DIL/SFL/SP/GR/CNL/FDC/CAL, CET/GR/CCL, Gyro (GCT)/CCL
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD . AMOUNT PULLED
·
i 6~ bZ.5~ H-~,U Surf 115' 24" 247 sx CS I I
9-5/8" $6.0# J-55 Surf 4572' 12-1/4" 1400 sx AS Ill & 315 sx Class G
7" 26.0# J-55 Surf 9375' 8-1/2" 300 sx Class G & 175 sx AS I
,..
,
24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
8860'-8898'MD 6395 '-6420 'TVD w/12 spf,120°PhaSing 2-7/8" 8971 ' 8719' & 8948'
9064'-9071 'MD 6529 '-6533 'TVD w/4 spf, 90° phasing
9043'MD 6515'TVD w/4 spf, 90° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETc.
9045'MD 6516'TVD w/4 spf, 90° phasing DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
9047'MD 6518'TVD w/4 spf, 90° phasing See attached addencum, dated 9/02/86, for fracture data
.
27. N/A PRODUcTIoN TEST
Date First Production I Method of Operation (FioWing, gas lift, etc.)
I
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-McF WATER-BBL CHOKE SIZE I GAS~OIL RATIO
TEsT pERIOD I~
I
Flow Tubing Casing Pressure CALCULATED ' OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-APl (Corr)
Press. 24-HOUR RATE ~
'2'8. CORE DATA
,
Brief description of l ithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
None k~C~IV~,0
S ~; P 1 9 1986
~l, SSk8 0il & Gas Gou~. ~ ...... .,~orl
Anchorage
,, .
Form 10-407 * NOTE: Drilled'RR 4/05/86, Perf'd well & ran tubing 7/19/86.
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
WCl/109
Submit in duplicate~
GE~0GiC;MARK' . ' .' "':'.. "; . · ...-~FORMATION TESTS
· ~ · . ! - ,', , ..,. -. - ~.. . ~,~ :.-
'NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR0 and time of each phase.
Top Kuparuk C 8766-~ 6332~ NA
·
Base Kupa¢uk C 887~w $~0~
Top Kuparuk A gQ1.1~ ~g~
Base Kuparuk A 9125~ ;5687
.
·
/: '.'
. .,
·
.
' i ' ' ~ ' ' '
.,.'~. f ; '
31, LIST OF ATTACHMENTS
Addendum (dated 9-02-86). '.':;
32. I hereby certify that the foregoing is true andcorrect tO the best of m.y. knowledge
.
Signed ~ ~ j ~/.~ Title ASSoc,ate EngineeF Date
/!
I NSTR UCTIONS
General: This form is designed for submitting a complete and correct well completion report and log on
all types of lands and leases in Alaska.
Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt
water disposal, water supply for injection, observation, injection for in-situ combustion.
Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements
given in other spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple
completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported
in item 27. Submit a separate form for each additional interval to be separately produced, showing the
data pertinent to such interval.
Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cement-
lng and the location of the cementing tool.
Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none".
Form 10~,07
ADDENDUM
WELL:
3N-lO
4/14/86
Arctic Pak w/175 sx AS I, followed by 60 bbls Arctic Pak.
4/16/86
RU Schl, rn 6-1/8" JB/gage ring to 9142', POOH. Rn
CET/GR/CCL f/9130'-7500' WLM. Rn gyro/CCL f/9104'-100',
RD Schl.
8/14/86
Press'd ann to 2660 psi w/diesel. Tst Ins to 12,500 psi;
OK.
Pmp'd frac per 7/28/86 procedure. Tree saver leaking &
Dowell did not have vlv open on tree saver body. Pmp'd
frac to flow back tanks as a result. Tree saver
completely failed. Flow back tank gained 100 bbls total.
Pulled tree saver; cups missing and mandrel severely
eroded. Reset new tree saver. Tst ins to 7000 psi.
Pmp'd 52 bbls gelled diesel to clear tbg vol & get
injection tst (Avg 6130 psi @ 19.4 BPM)
8/15/86
Frac'd Kuparuk "A" sand perfs 9043', 9045', 9047' &
9064'-9071' in 7 stages per 7/28/86 procedure using
gelled diesel, 100 mesh & 20/40 mesh sand. Press'd ann
to 2640 psi w/diesel. Tst lns to 8750 psi; OK.
Stage 1: Pmp'd 20 bbls gelled diesel pre-pad @ 5 BPM,
3930 psi
Stage 2: 10 bbls gelled diesel w/1 ppg, 100 mesh @ 5
BPM, 3850-3740 psi
Stage 3: 17 bbls gelled diesel pad @ 5 BPM, 3740-6100
psi
Stage 4: 50 bbls gelled diesel pad @ 20 BPM, 6100-6060
psi
Stage 5: 8 bbls gelled diesel w/3 ppg 20/40 mesh @ 20
BPM, 6060-6050 psi
Stage 6: 32 bbls gelled diesel w/8 ppg 20/40 mesh @ 18
BPM, 6050-6140 psi
Stage 7: 52 bbls gelled diesel flush @ 18 BPM, 6140-5440
psi (job underflushed by 3 bbls per procedure)
Pmp'd 420# 100 mesh & 11,024 20/40 in formation leaving
735# 20/40 mesh sand above top perfs in csg.
Load to recover 189 bbls of diesel. Job complete at 0827
hrs, 8/15/86. Turn well over to Production. (Note:
Lost top cup off tree saver in hole.)
8/20/86 Set BPV, ND tree, NU new 2-9/16" tree & tst to 5000 psi;
OK.
Drilling Supervisor k~CE~"~/~V~e $ ~
1986
Alaska Oil & Gas Cons.
Anchorage
DIRECTIONAL
$URVEY
r'~UIDANCE
[~ONTINUOUS
r'~OOL
RECEIVED
AUG- 5 1986
Alaska Oil & Gas Cons. Commission
Anchorage
Company
Well Name
Field/Location
ARCO ALASKA INCORPORATED
WELL 3N-10 (1561'FSL, 179'FEL, S29, T13N
KUPARUK, NORTH SLOPE, ALASKA
, R9E)
Job Reference No.
71436
Logam:l By:
FINNELL
Date
27-APRIL-1986
Computed By;
KRUWELL
GCT DiRECTIDN4L SURVzY
CUSTOMER LISTING
FOR
4L~SKA, INC.
3N-lO
KUo~qUK
NO~T~ SLOPE,~L4SK2
SURVEY DATE: i¢-APR-96
ENG~N::R'. .__ · =ZNNEL.
METHODS OF COmPUTaTION
TOOL LOCATION: T4NGENT!AL-. ~VERAGEO
INTERP~LATi]N: LINEAR
VERTICAL S~CT!DN: qORIZ. DIST. PRDJECT~O
O~VI.ATION &ND
O'~TO ~ T~SET
~ Z i ;~UT H
',1 Zi MLJTH
S~UTH
20 DES
37 MIN
EAST
COMPUTfiTION DATE: 27-4P~-86 P4$E 1
~RCO ALASKA, INC.
3N-10
KUPARUK
NORTH SLOPE,ALASKA
INT;RPOLATEO VALUES FOR EVEN 100 FEET
TRUE SJE-SEA
MEASURED VERTICAL V=RTI=AL
DEPTH DEPTq DEPTH
C2U~S~ V~TICAL DOGLEG
D~VIATION AZIMUTH SECTION SEV=RITY
3EG ~IN D:G MIN mEET DEG/IOO
0,00 0,00 -68,00
100,00 100,00 32,00
200,00 200,00 132,00
300,00 300,00 232,00
400.00 ~O0.O0 332.00
500.00 500.00 432.00
~00.00 599.97 531.97
700.00 699.83 531,~3
800,00 799,54 731.54
900.00 -89~.99 830.99
0 0 N 0 0 E 0,00 0,00
3 5 N 22 43 W -0,01 D,18
O 4 S 70 29 5 -0,05 O,lO
0 8 S 3~ 9 ; 0.I1 0.13
0 9 S 28 7 = 0 3= 0 17
0 22 S 61 28 c 0.63 3.91
2 13 S 29 39 E 2.5~ 1.96
3 54 $ 27 59 ~_ 7.84 1.lB
4 39 S 30 53 15.32 1.45
'8 4 S 29 5? E 25.53 5.55
1000.00 997.05 929.05
1100.00 1093.05 1025.06
1200,00 1188,72 1120,72
1300.00 1284.51 1216.5t
1400.00 1380.1~ 1312.18
1500.00 1474.57 1406.67
1500.00 1567.00 1499.00
1700.00 1654.96 1586.96
1800.00 1738.61 1670.61
1900.00 1820.~3 1752.53
14 12 S 24 7 E 44,72 5,04
: 7~. :9 0 2~
16 58 S 24 6 : ....
16 4~ S 24 6 c · 101,53 0,38
16 3~ S 2~ 31 E 130.33 0.29
17 38 S 25 14 =_ 159.35 2.52
20 31 S 25 59 = 191.93 2.93
25 10 S 23 ~9 ~ 229,95 6,30
31 11 S ?6 4 : 277 O0 5 47
~ ~ m .
34 28 S 23 30 = 331.62 1,45
35 !4 S 21 30 ~ 388.93 2.06
2000,00 1901.55 1833.55
2100,00 1979~,95 1911,95
ZZO0.O0 2055.20 1987.20
2300,00 2126,94 2058,94
2~00.00 2194.58 2126.58
0.00 2330,22 22.52,22
0,00 2396,49 2323,49
2800.00 2460.50 2392.50
2900,00 2524.96 2456.96
36 46 S 19 28 = 447 5~ 3 10
39 41 S 18 15 : 509.54 2.20
42 42 S 18 44 ~ .575.33 2.35
46'6 S 19 32 ~ 644.94 4.65
47 49 S 20 21 =_ 71~.58 0.31
47 14 S 19 59 ~ 792.39 0.7~
47 11 S 19 25 E 865.55 1.47
49 49 $ 19 51 ~ 940.40 1.74
50 4 $ 19 51 5 1017.21 0.74
49 :8 S 19 g~ E 109= 66 0.6~
3000.00 2590.10 2522.10
3100.00 2656.11 2588.11
3200.00 2722,93 2554.93
3300.00 2790.~3 2722.43
3400.00 2855.97 2727,97
3500.00 2917,58 2849,'68
3600,00 2976,05 2908,05
3700.00 3035.08 2967.08
3800.00 3095.16 3027.16
3900J00 3155.69 3-087.69
49 5 S I~ 55 E 1159.51 0.97
48 21 S 17 57 ' 1244.57 0.97
47 50 S 17 11 ~ 1318.~6 0.8l
47 39 S 16 30 E 1392.43 1.39
50 35 S 16 38 ~ 146'7.80 2.48
53 26 S 17 ~3 E 1546.32 3.34
54 18 S 1~ 41 E' 1.527.43 1.4~
53 19 S 18 43 E 170~,12 C.92
52 51 S 1~ 3 = i787.99 0.83
52 37 S 17 8 ~ iq67.48 0,77
DATE OF SURVEY: 14-~PR-B6
K~LLY BUSHING ELEVATION: 58.00 FT
ENGINEER: ~INN:L
MEASUR:_3 DEPTH
R:CTANSULAR CD]RDI~AT~S HDRIZ, DEPARTURE
NOqTH/SOOTH EAST/WEST DIST, AZIMUTH
FEET FEET F~T 3~S MIN
O.O0 ~ 0.00 ; 0.00 ~q 0 0 E
0.01 N 0.01 W 0.01 N 27 51 W
0.08 N 0.05 E 3.10 N 37 35 E
0,03 S 9,22 E 0,22 S 82 18 E
0.25 S 0,32 : 0,41 S 52 I E
0,45 S 0.60 ~ 0,75 S 52 54 =
2.0,3 S 1.83 E 2.77 S 41 21 E.
6.76 S 4.29 ~ ,~.O1 S 32 23 ~Z
13.36 S ~.00 E 15.57 $ 30 55 r-
--
~2._P7 S 13,~0~ :_ 25.94 .S 30 50 ~
39,54 S 21.91 E a5.20 S 28 59 E
65,05 S 33.24 E 73.05 S 27 3 :
91,65 S 45,12 E 102,17 S !6 12 ~
117.82 S 56.95 E 130.86 S 25 47 :
14~.22 S 69.20 E 159.96 S 25 37 =
173,72 S ,53,29 E 192,66 S 25 36 E
207.71 S 100.94 E 230.~4 S 25 55 ~
249.5~ S 123.26 E 278.35 S 26 17 E
299.46 S 145.81 E 333.07 S 25 57 E
352.32 S 16!3.05 = 390.35 S 25 2'9 E
407,29 S I~8,33 E 443,73 S 24 48 E
466,05 S 20~,27 E 510,47 S 24 4 E
528,.50 S 229.13 ~ 576.03 S 23 .26 ~
594.36 S 251.73 E 545.48 S 22 57 ~
553.50 S 277.12 E 71'9.04 S 22 40 E
732.75 S 302.54 E 792.79 S 22 26 E
801.64 S 327.29 = ~55.88 S 22 12 2
872.19 S 352.33 E 940.67 S 21 59 ~
944,40 S 378.55 5 1917.45 $ Z1 50 ~
1016.41 S 404.26 5 1093.~5 S 21 41 E
10~8.02 S 429,32 E 1169,66 S 21 32
II$9 28 S 453 OT E 1244.67 S ?1 20
1Z~0.21 S 475.53 ~ 1~18.9Z
1300.~5 S 496.84 5 1392.50 S ZO 54
1373.24 S 518.31 E 1467.~0 S
1448.43 S 541-45 E 1546.32 S 20 29
1525.58 S 566.75 E 1527.45 S gO 22
1601 93 S 592 '93 E 1708 14 S
1677.7~ S 61~.1~ E 178~.04 S 20 13
1753.66 S 642.22 E 1867.55 S gO 6 E
~RCO ~LASK~. I4C.
3N-lO
KUPARUK
NORTH SLOPE,ALASKA
COMPUTATION
DATE: 27-AD~-36
INTERPOLATED VALUES FOR EVEN 130 mi;T
TRUE SOB-SE6
MEASURED VERTICAL VERTiCEL
DEPTH DEPTH DEPTH
4000.00 3216.96 3145.96
4100o00 3279.47 3211.47
4200.00 3342.10 3274.10
4300.00 3405.93 3337.93
4400.00 3471,15 3403.15
~4500.00 3537.53 3469.53
500.00 3605.41 3537.41
.700.00 3674.07 3506.07
4800.00 3740.55 3672.65
4900.00 3806.98 3738.98
5000.00 3873.42 3805.42
5100.09 3940.39 3872.'39
5200.00 4007,54 3939.64
5300.00 4075.22 ~007.22
5400.00 4142,$8 4074.$~
5500.00 4210.01 4142.01
5600.00 4276.83 42~8.~3
5700.00 4343,40 4275.40
5800.00 4409,75 4341.7~
5900.00 4476.22 44~.22
6000.00 4543,00 4475.00
6100.00 4610.03 4542.03
6200.00 4676.96 460~.96
6300.00 4743.53 4675.53'
6400,00 4809.42 4741.42
6,,500.00 ~874.~3 4805.~3
L 00.00 4939.73 4571.73
~00.00 5004.~3 493~.43
6500.00 5069.12 5001.12
6900.00 5133.74 5065.74
COURSE VERTICAL 03GL
3EVICTION ~zIMUTH $~CTiDN SEV~
3EG MIN DES MIN ~EET
51 38 S 16 23 5 19~6.33
51 22 $ 16 50 E 2024.15
50 49 $ 20 3 E Z102.04
49 ~O S 20 10 E 2179.02
48 55 S 19 13 E 22~4.~1
4T 45 $ 18 3 = 2329.55
4~ ~3 $ 17 &l ~ 2402.39
~7 26 $ 18 43 ~ 2475.51
&:~ 27 S 20 20 ~ 2550.12
48 25 S 23 29 E 2624.95
48 10 S ZO 35 E 2699.68
47 4~ S 20 6 E 2773.95
47 35 S 19 50 £ 2347.95
47 29 S 19 5:~ = 'P9~1.66
47 37 S 20 14 ] !995.47
47 47 S 20 25 ~ 305'9.41
48 16 $ 20 34 : 3143.80
48 20 $ 21 3 ~ 3215.43
48 24 $ 21 7 ~ 3293.24
48 12 S 21 19 E 3367.95
47 59 S 21 26 E 3442.37
47 54 S 2t 35 E 3515.57
48 5 S Z1 53 J 35~0.~6
48 3I S 22 9 .~ 3565.46
48 57 S 22 16 ~ 3740.55
49 1'9 S 22 25 E 3~15.25
49 ~3 S 22 44 ~ 3892.29
49 39 S 22 53 E 396~.48
49 37 S 22 48 ~ 4044.68
49 54 S 23 10 E 4120.93
49 58 S 23 20 E 41'97.46
50 1 S 23 34 :~ ~273.88
50 29 S 23 4'3 E 4350.53
$0 50 S 22 57 ~ ~27.90
51 6 S 21 34 J 4505.66
50 55 S 2i ~g ~ ~5~3.36
50 57 S 21 53 ~ ~661.03
51 13 S 21 52 5 4738.76
51 15 S 21 39 E ~B16.80
50 39 S 21 16 E ~89~.52
7000.00 5198.01 5130.01
'7100.00 5262.40 519~.40
7200.00 5326.37 5258.37
7300.00 5389.71 5321.71
7400,00 5452,56 5384,56
7500.00 5515.50 5447.50
7600,03 5578.46 5510.46
7700.00 5641.35 5573.35
7800.00 5703.36 5635.86
7900'.00 5766.73 5693.78
3F
RITY
100
.4O
.82
.42
.25
.42
.51
.23
.58
.46
.35
.23
.25
.42
.51
.33
.19
.55
.41
.27
· 48
.69
.34
.3~
.27
.51
.35
.31
.42
.70
.25
.I1
· 2 O
.49
.42
.7~
.;4:ASIJ~=. ,_
R:CTAN
:~C RTH/
FEE
1,~2~.
1904.
1 973.
2050.
2121.
2192.
2262.
2331.
2~01.
2471.
2.541
2511
2681
2750
28I 9
2958
3025
3098
3167
P&G5 2
AT-= 3: SUQVEY: 14-APR-85
ELLY BUSHING =L:VATiON: 68.00 F'
ENGi?'~EER: =I~NEL
D 3EPTH
gULAR C03ROIN4TES HOR· -
-Z. DEP~RTUR-
S]UTH EaST/WEST DIST. ~ZiMUTH
T F~:T FEET O~G MIN
32 S 565.03 E 1945.45 S 19 58
30 S 586.73 ; 2024.34 S 19 49
37 S 711.36 E 2102.26 S 19'47
24 S 73:3.66 : 2179.24 S 1'9 48
58 S 7~4.26 ~ 2255.04 S 19 48
66 S 7~$.11 E 2329.81 S 19 46
40 S 810.~9 i 2&03.20 S 1~ 42
52 S 333.01 E 2475.36 S 19 39
78 $ 25~.12 5 2550.48 S 19 39
~7 S ~4.~3 3 2525.30 S 19 41
35 S 910.57 E 2700.02 S 19 42 ~
~,6 S 935.44 : 2774.29 S 19 43 :
03 S 961.57 ~ 2348.29 S 19 43 E
35 S 9:~.75 5 2922.00 $ 19 44 :
67 S 1012.11 ~ 2995.82 S 19 44 ~
30 ,S 1037.83 E 306~.76 S 19 45 E
70 S 1063.~3 ~ 3144.14 $ 19 46 E
44 S 1090.39 E 3218.76 S 19 48 E
£Z S 1117.36 ~ 3293.55 S 19 49 ~
39 S 1144.35 E 3368.24 S 19 51 ~
3237.18 S 1171.55
3306.21 S 119~.75
3375.25 S 1225.23
3444.41 S 1254.26
3514.04 S 1282.71
3584.01 S 1311.45
3554.24 S 1340.?0
3724.49 S 1370.33
3794.79 S 1399,89
3~65.05 S 1429
3442.65 S 19 53 =
3515.82 S 19 55 E
359'1.09 S 19 57 E
3665.67 S 20 0 ~
3740.83 S 20 3 ~
3816.¢1 S 20 5 ~
3892.42 S 20 8 ~
3.968,58 S 20 11 E
4044.77 S 20 14 E
· 69 ~ 4121.00 S ZO 17 ~
3-235.43 S 1459.96
4DOS.6Z S 1490.40
4375.02 S 1521.24
4146.9:3 S 1552.Z9
4219.07 S 1581.28
42'9'1.29 S 1609.97
4363,45 S 1638.74
4435.60 S 1667.72
450~.07 S 1695.73
4580.41 S 1725.14
E 4197.51 S 20 21 E
E 4273.91 S 20 24 ~]
E 4350.65 S 2'.3 2T E
E 4427.91 S 20 31 E
4505.66 S 20 32 E
4583.36 S 20 33 6
4561.03 S ZO 35 E
473.~.76 S 20 36 E
481,5.80 S 20 37 'E
4;39~+.52 .g 20 38 ,=
COMPUTATION DATE: 27-~P~-86 P~E 3
ARCO ~LASK~, INC.
3N-lO
KUPARUK
NORTH SLDPE,AL~SK~
ME~SU
OEP
iNTSqPgL4T=g V~LUES FOR EVEN lgO
TRUE SUB-SE~
RE9 V=RTIC&L VERTICAL
TH DEPTM ~EPTH
8000.00
8100.00
8200.00
8300.00
8400.00
,,8500.00
SO0.O0
?00.00
8800.00
8900.00
5830.5~ 5762.59
5895.01 5827,01
5959.50 5B91.50
5024.~5 5955.~5
5090,21 S022,21
5156,3B 50~8,38
6222,58 515~,6B
5288.82 6220.82
5354.~? 6285.~T
5420.~1 5352.81
D~TE OF SURVEY: 14-~R-86
'9000.00 6486.54 541~.54
9100.00 6552.12 6484.12
9200,00 $617,2~ 5549,24
9300.00 6682.3~ 6614.34
9394,00 5743,54 5575.5~
KELLY BUSHING ELEVATION: 5B,O0 F1
E~4'3INEER: :INN~L
FE:T 0= '~SU~6
COJRSE VErTICaL gOGLES RECT~N
2EVI&TION AZiVUTH SECTION SEVERITY NORTH/
DSG ~IN O=G~ MTN.. F~ET ~-~:~/109 FE'~
2.29 4652,
0,23 4722,
0.32 4794,
g.33 4~35.
0.52 5005.
0,40 5075.
0,2~ 5144.
0.39 5214.
'3.2~ 52~4,
0.13 5354,
1,32 5424.
O,O0 5~'~5.
O,OO 5565,
O,OO 5531,
50 4 S 21 13 E 4971,51
49 50 S 21 3 E 5047,99
49 47 S 21 9 ~ ~124,41
49 12 S 21 27 ~ 5200,45
4B 36 S 21 3~ ~ 5275,77
48 33 S 21 3~ = 5350.73
48 30 S Z1 23 ~ 5425.58
48 39 S 21 17 E 5500,39
4~ 41 S 21 35 E 5575,6~
43 ~5 S 21 44 'E 5650,~2
49 0 S 21 47 E 5726,18
49 4 S 21 56 ~ 5801,55
49 22 S 21 56 E 5877.52
4.) 22 S 21 56 ~ 5953,40
4~ 22 S 21 56 E 5024,73
~]UL~R COORDINATES HDRIZ, 9~P~RTURE
SOUTH ~ST/W6ST DIST, AZIMUTH
T FEST F:=T 2E~ MIN
13 S 1753.02 E 4~71.51 S 20 38 E
52 S 1780.50 E 5047.9'9 S 20 39 E
~4 S !.~03,05 : 5124,41 $ 20 39 E
69 S 1535.59 E 5200,45. S 20 40 6
72 S 1~63,44 E '5275,77 S 20 41 E
39 S 1~91,14 E 5350,74 S gO 41 ~
03 S 191B,62 ~ 5~25,59 S 20 42 E
92 S 1945,35 5 5500,50 S 20 43 E
Bi S 1973,~7 E 5575,57 S 20 43 E
57 S ZOCi.05 5 55~0.$3 S ZO 44 E
55 S 2029,04 E 5726,19 S 20 45 E
74 S 2057,08 ~ 5801,67 S 20 46 E
13 $ 20:35,44 ~ 5B77,54 S 20 46 ~
53 S 2113,~2 E 5953.43 S 20 47 '~
71 S 2140,49 E 602~,77 S 20 48 6
C3HPUT4TI3N
ARCO ~kL~SKA, INC.
3N-lO
KUPAROK
NORTH SLOPE,ALASK~
MEASU
DEP
INTEROOL&TED VALUES FOR =VEN
TRUE SUB-SE&
RED VERTICAL VERTICAL
TM DEPTH DEPTH
0.00 0.00 -68.00
lOOO.O0 997°05 929.05
2000.00 1901.55 1833.55
3000.00 2590.10 2522.10
40OO.OO 3216.~6 3148.96
5000.00 3573.42 3805.42
000.00 4543.D0 4475.00
,000.00 5195.01 5130.01
8000.00 5830.59 5762.5)
9000.00 54B6.54 5418.54
9394
27-AOR-'36
1000
CDURSE VeRTiCAL
DEVI~TIDN AZIMUTH SECTION
~G MiN DEG MI~ · FEET
0 0 N 0 0 E 0.00
14 12 S 24 ? : 44.72
35 46 S 1'9 28 E 447.53
49 5 S 1~ 55 E 1169,51
51 3;3 S 16 23 E 1946.33
4~ 10 S 20 35 ~ Z6~9.68
47 59 S 21 26 E 3442.37
49 58 S lB 20 ~ ~197.46
50 W S 21 13 'E ~971.51
49 0 $ 21 47 ~ 5725.15
· 00 6743.54 5675.54 49 ZZ S 21 56 E 5024.73
9,]GLEG
SEV:QITY
DES/lDO
0.00
6.0'4
3.10
0.97
1.40
0.EF~
0.41
0.31
0.2~
~,.13
ME~SJR
qECT~N
40~
lO~.
1323.
ZEal.
3237.
3~35.
4652.
5354.
~T= O: SURVEY: 1~-~;~q-86
ELLY 3USHiNG ELEVATION: 63.00
ENGINEER: FINN~L
GULAR C30ROINAT~S HDRiZ. DEPARTURE
SSUTH EAST/WEST DIST. ~ZI~UTM
T FEET FEET DES MIN
O0 N 0.00 E 0.00 N 0 0 E
5~ S 21.91 ~ 45.20 S 28 59 E
Z) S 188.33 E 445.73 S 24 48 E
02 S 429,32 E 1169,56 S 21 32 E
~2 S 665,03 E 1945,45 S 19 58
85 S 910.57 E 2700,02 S
18 S 1171.55 E 3442.65 S 19 53
~3 S 1459.96 E 4191.51 S 20 21
I$ $ 17:3.02 E 4:~71.51 S 20 33
65 S 2029.$4 E 5726.19 S
0.00 5531.71 S 2140.49 F_ 6,024.77 S 20 48 E
CgMOUTATIDN DATE: 27-.~P~-85 ~aDE 5
ARCO ALASKA, INC.
3N-10
KUPARUK
NORTH SLOPE,ALASKA
INT:RPOLATED VALgES FOR
TRUE SUE-SE4
MEASURED V~RTICAL VERTI~&L
DEPTH DfPTH DEPTH
0,00 0,00 -58.00
68,00 68.00 0.00
168,00 165.00 100.00
258.00 258.00 ZOD.O0
368,00 368,00 300,00
468,00 ~58,00 400,00
568,01 568,00 500.00
568,11 668.00 500.00
768,35 768.00 700,00
868.77 868,00 800.00
970,13 968,00
1073,80 1058.00
1178.35 1168.00
1282,77 1268,00
1387.24 1368.00
1492,89 1468.30
1601.10 1568.00
1715.28 1668.00
1~35,75 1768.00
1958.42 1~68.00
2086.50 1968.00
2217.48 2068.00
2350.41 2168.00
2508.76 2268.00
2656,2~ 2368,00
~,811.68 2468.00
66.16 2568.00
~17,85 2668,00
3256,B~ 2768,00
3419.08 2868,00
2968.00
3068,00
3168,00
3268,00
3368,00
3468,00
3568,00
3668,00
3768,00
3868,00
35B6,Z1
3754,92
3920,25
4081,64
42~0,85
4395,19
45~5'0~
4691.02
4841.23
4991;85
COORSE
DEVI~TICN AZIMgTH
DEG ~iN DCG
0 O N 0 0 .'_-
0 3 N 25 ~Z W
0 2 N 74 51 E
0 :3 S 56 5~. =
0 8 S 19 55 =
0 12 S 6~ 17 E
1 31 S 34 16 E
3 18 S 27 ZZ E
4 26 S 29 q. 6 'E
6 29 S 30 40 E
900,00 IZ
1000.00 16
1100.00 16
1200,00 16
1300,00 17
1400,00 ZO
1500,00 25
1600.00 31
1TO0.O0 3~
1800,00 35
21 S 25 15 E
S 24 3 E
53 S 24 2 E
38 S 24 26 ~
22 S 25 9 E
S 2'5 53 ~
14 .S 28 51 E.
55 S 25 22 ~
56 S 20 1 E
1900,00 39
2000.00 43
2100.00 47
2200,00' 47
2300.00 48
2~00.00 50
2500.00 a9
2600.00 43
2700.00 47
2300.00 51
Z1 S 1~ 18 E
8 S 18 46 E
S 20 !5 ~
10 S 1:.' 56 5
S 19 32 E
15 S 19 11 E
15 S !7 48 ~
26 S 16 39 E
t S 16 45 E
2900,00 54 Za S 13 30 E
3002.00 53 3 S 1~ 23' E
3100,00 52 30 S 15 59 E
3200,00 51 18 S 16 27 E
3300,00 50 26 S 20 ZZ 5
3400,00 48 5'9 S 19 15 E
3500.00 47 19 S 17 45 ~
3600.00 47 15 S lB 3~ ~
3'700.00 ~B 26 S gO 30 E
3800,00 48 12 S 20 35 E
EVEN I00
V~RTIC~L
SECTION
FEET
0,00
0.00
-0.07
0,04
0.27
0.52
1.55
5.84
12.~7
21,57
37,78
64.94
95.42
125.42
135.55
189.47
230,41
294.91
351.96
422,97
49 i. 68
537.23
559.24
79'B.B3
907.19
1026.17
1143,90
1257,~7
1368.12
!4'~2.57
1515.24
1732.03
1383.54
2009.85
2133.54
P~51.!8
2362.69
2468.90
2580.97
2693.61
DATE OF SURVEY: 14-AOR-86
KELLY BUSHING ELEVATION: 58.00 F1
5NSIN:E2: =INN=L
SUB-SEA D=PTH
C']GL=_G RECT&NSUL4R COOqDIN4TES
SeVeRITY NORTH/SOUTH =&ST/NEST
9EG/1 O0,=E ET F~__=T
0.00 0.00 N 0.00
0.00 0.00 '.J 0.00
0.25 O.O.B N 0.03
0.13 0.02 N 0,16
0.04 0.18 S 0.29
0.34 O.3-) S 0.46
2.37 1.1~ S 1.27
2.01 4.97 S 3.35
0.3~ I!.21 S 6.75
4.10 13,90 S 11.32
7,32
0.99
0.27
0.19
1
2.76
6.34
1.15
1,62
2.06
2,!9
0.93
0,73
3
0,72
O .72
O.~q9
0.55
2.14
1.74
0.65
0.91
1.71
!.12
I · 33
0.75
2..84
0.16
0.53
HORIZ. DEPARTURE
DIST. 4ZiMUTH
FEET OEG MIN
O,O0 N 0 0 E
0,00 i ']0 0 E
0.09 N 18 15 F_
0.17 Nt 82 3 ~
0 34 S 5° 45 ~-
0.60 S 49 55 E
!.7~+ S 47 5 E
6.00 S 33 58 E
13.08 3 31 2 E
22.03 S 30 55 E
33.20 S 19.34
53.06 3 30.11
35.93 S 42.57
113.34 S 54.91
140.7:~ S bT. 5,~
171.51 S 82.22
208.1! S 101.17
256.73 S 126.73
31~.15 $ 153.:39
384.18 S 180.05
3B.27 S 29 50 f
65,40 S 27 24 E
95.90 S 26 21 E
125,94 S 25 50 E
155.16 S 25 33 E
190.19 S 25 36 E
231.40 S 25 55 ~
286.30 S 25 i6 E
)53.41 S 25 48 E
424.28 S 25 6 E
456,58 S 205.20
539,76 S 232.96
635.99 S 256.91
733,80 S 304.35
3~0.93 S 341.14
952,82 S 381.59
1063.80 S 420.95
11.71.95 S 457.14
1277.44 $ 489.38
1387.42 S 522,56
500.65 S 26 11 ;~
58'7.59 S 23 20 E
589.73 S 22 45 E
79'9.22 S 22 25 E
907,49 S 22 ~ E
1025.~0 S 21 A9 ~
11~4.06 S 21 35 E
i237.~6 S 21 18 E
!36~.15 S 20 58 f
1~82.57 S 20 38 E
1314,97 S 563,15
15.43.51 S 606.92
1769.04 S 646.94
1890,53 S 682.74
2007.59 S 722,87
2118.15 S 763.05
222~,03 S 798.30
2325.25 S 830.88
2430.68 S 868,91
2536.16 S 908.43
1515.25 S 20 23 ~
1752.09 S ZO 16 E
1883,63 S 20 5 E
2010.03 S lg 51 f
2133.86 S 19 48 f
2251.41 S 1'9 48 E
2362.97 S 19 44 E
2~69.24 S 19 39 E
2531.32 S 19 40 :
259,3 95 S 19 42 :
ARCO ~L~SKA, INC.
3N-lO
KUPARUK
NORTH SLOPE,&L~SK~
COMPUT~TIg~J
INTERPOLATED V&
TRUE SJE-SEA
ME&SURED VERTICAL VERTICAL
g:PTH~ DEPTH D:PTH
5141,09 3968,00 3900,00
5289,33 4068,00 4000,00
5437.59 4168.00 ~lO0.OJ
5586.72 4268.00 4200.00
5737.04 4358.00 4300.00
. 5887,68 4~68,00 4400,00
'037,30 4568,00 4500,00
0186.50 4668.00 4500.00
6337,04 4768,00 4700,00
6489.52 4868.00 4800,00
6643.75 4968.00 4900.00
6798.28 5068.00 5000.00
6953.28 5168.00 510D.O0
710~.72 5268.00 5200.00
7255.5~ 5368,00 5300,00
7424.5~ 5468.00 5400.00
7583.~0 ~568.00 5500.00
7742.65 5663.00 5609.00
7901.93 5768.00 5700.00
8058.15 5868.00 5800.~0
8213.15 5968.00 5900.00
8366.37 6065.00 5009.00
8517.37 6168.00 6100.00
8668,50 6268,00 $20D,00
8819.89 6368.00 5300.00
.R971 73 6468.00 6400.00
oo.oo
-,~277.97 6668.00 5600.00
9394.00 6743.5~ ~675.54
COORS
D;VI~TION A
DEG qlN 9
47 45 S
47 28 S
47 39 S
48 13 S
48 25
48 14 S
47 54 S
48 44 S
49 17
49 41 S
4~ 37 S
50 1 S
50 3 S
50 44 S
51 3 S
5O 58 S
51 t9 S
50 38 S
~9 51 S
DATe:,. 27-~PR-86
LUgS FOR EVEN 1DO FEET
E V:tTIC~L DDGLEG
ZiMJTH SECTiSN SEV=~ZTY
=G MIH FEET D~G/IO0
19 57 E
20 19
20 31
21 7 E
21 17
21 30 '~
22 1~ -
22 .24 E
22 52 E
22 48 E
23 15 ~'
23 34 E
23 33 ~
21 35 E
21 4~ Z'
21 49 E
21 15 =
21 6 ~
49 42 S 21 11 E
48 44 S 21 39 E
4~ 31 S 21 37 =
48 36 S 21 15 5
~5 44 S 21 3~ ~
48 5~ S 21 48 E
49 22 S 21 56 E
49 22 S Z! 56 E
49 22 S 21 35 E
2804.37 0.27
2913.79 0.17
30Z3.26 0.19
3133.8~ 0.66
3246,12 0,35
335S,78 0.7~
3479.05 0.26
3530.90 0.35
3693.25 0.52
3808.31 D.41
3925,65 3,34
40~3,37 0,53
4161,70 2,25
4280,55 0,45
~401.36 0.~5
452~,79 0.35
~64~,14 0.36
&772.05 0.17
~$96.00 0.?1
5016.03 0.59
5134.46 0.63
5250,52 0.AB
5363.91 $.55
~476.95 0.10
55~0.60 13,36
3704.83 0.26
5~20.13 0.00
5936,69 0.00
5024.73 0.00
P~GE 6
DATE O~ SJRVEY: 14-~PR-86
KELLY ~USHI~G ELEVATION: 58.00 F
:N'31N65R: ;iNNEL
SU3-SE& DEPTH
RECTANGULAR CC3
NRRT~/SOUTH
FEET FE
ROINATES dDqIZ. DEPARTURE
T/WEST DIST. AZIMUTH
ET FE~T DEG MIN
25~0.05 S 946
2742.96 S '9B4
2945.7~ S 1021
2949.40 S 1060
3054.27 'S llO0
3159.35 S 1141
3262,~3 S llB1
3365.90 S 1222
3470.15 S 1264
3576.65 S 1303
,35 E 280W,71 S 19 43 E
,06 E 2914,14 S 1~ 44 E
,75 ~ 3023.51 S 19 45 M
· 36 E 3134,22 S 19 46 E
· 36 E 3246.44 $ 19 4~ E
· ~0 E 3359.07 $ 19 51 E
.67 E 3~70.31 S 19 54 5
.53 5 35~1.14 S 19 57 3
.75 ~ 3593.45 S 20 1 :
,~2 E 3B03,~7 S 20 5 E
3635.01 S 1353
3793.59 S 1399
3~02.54 S 1445
4011.74 S 1493
4122.52 S 1541
~23~.~5 S 158~
4351.49 S 1633
4466,50 S 16~0
4581.~0 S 1725
4593.70 S 1769
.54 E 392~.78 $ 20 10 ~
· 38 E 4043.46 S 20 14 ~E
.79 E 4151.75 S lO 19 E
,07 ~ 4280.58 S 20 24 E
· 71 E 4401,37 S ZO .30 ~
· 32 E 4524.7'9 S 20 33 E
· 9~ ; 4643.14 S 20 34 E
.12 E 4772.05 S 20 35 E
· 68 ~ 4896.01 S 20 3~ ~
· 11 E 50116.03 S 20 39 E
4804,22 S 1~1!.
~912,25 S 1854.
5017,64 S 1896,
5122.,~9 S 1937.
5228.70 S 1978.
53.34,83 S 2021,
5441.88 S 2063,
5550,02 S 2107,
5631,7! S 2140.
70 E 5134.47 S 20 39
12 E 5230 52 S ZO 40
'
Ol E 5363.91 S £0 41
28 E 5476.96 S 20 42 E
78 E 5590.61 S 20 43
11 5 5704,85 S 20 44
99 E 5820.15 S 20 46 E
57 E 5'936.71 S 20 47 E
49 ~ 6024.7'7 S gO 48 E
ARCO ALASKA, INC.
3N-10
KUP~RUK
NORTH SLOP;,AL&SK4
MARKER
TOP KUPARUK C
BASE KUDARUK
TOP KUDARUK A
BASE KUP4RUK
PBTD
TO
CO~PUT~TI3N
iNT:RPOL4TED VALOES FOR
M:ASJRED DEPTH
5ELOW KB.
8765.00
8874.00
9011.00
9125.00
9Z?l.O0
939a.00
DATE: 27-~PR-85
g~!GIN:
TV3
F~2~ K~
6332.40
6403.66
6493.76
6563.41
6653.46
D~TE DF SURVEY: 14-~0R-56
K~LLY 5USWI~3 EL~&TigN:
ENginEEr: ~INN~L
7
5~.00
1551 FSL, 179
5264.4~
6335.55
5425.76
6500.~1
6595.46
6575,5~
SJRF~CE LOC&T
F~L, 'SEC 29,T13M, R
R6CTSMGUL~R CO0~
N'SRTH/SOUTq EA
ION
OlN~TES
ST/W~ST
$191.07 S 1953.90
5255.52 S 1~93.32
5362.36 S 2032.13
$a42.32 S 2054.17
5545.11 S 2105.59
5631.71 S 2140.49
CgM~UT~TIgN OAT-: 27-APR-35 PaGE 8
ARCO ~L~SKA, INC.
3N-lO
KUPARUK
NORTH SLOPE,AL~SK~
MARKER
TOP KUP~RUK S
BASE KUPARUK C
TOP KUP~RUK ~
BASE KUPARUK ~
.PBTD
TD
.~.,.,. ,x STR~TISRAmgIC
~ASJ2Eg DEPTH
5mLOW KB
5766.00
88?4.00
9011.00
9125.00
9271.~0
9394.00
SUq~6RY
I]RZGIN:
TV]
FRCM K8
5332.&0
6403.65
b~93.76
6568.41
66~3.45
6743.54
PAT= OF SURV6Y: l~-&PR-85
KELLY BUSHi~UG ELE¢~TION: 68°00 Fi
ENGINEER: FI~NEL
1561 FSL~
SUS-SE~
179
SEC 2
RECTfiNG
ACE _]C~TIDN
~T
9,T13N, ~gE, JM
OLd2 CDORDIN~TES
S~UT~ E~ST/WEST
6264.~0
6335.66
5425.76
5500.~1
6675.54
51
91.
62.
4,2.
~5.
31.
07 S 1953.90
52 iS 1993.82
35 S 2032.13
32 S Z06~..1T
11 S 2105.5)
71 .S 2140.49
FINAL
MEASJRED
DEmTH
939~.00
T:RU~
VERTICAL
DEPTH
5743.54
aT 'TD:
SU~-S~
VmRTIC&L
~EPTH
567~.5~
H3RI'ZONT~L 9EO~RTURc
DISTANCE 6ZIqUTq
602~.7'7. S lO 48
SCHLUMBERGER
0 1 REC T I ONAL SURV E Y
COMPANY ARCO ALASKA INC
WELL 3N- 10
F I ELD KUPARUK
COUNTRY USA
RUN 1
DATE LOGGED 14-APRIL-1986
REFERENCE 00009]436
RECEIVED
AUG- 5 1986
Alaska 0il & 6as Cons, Commission
Anchorage
WELL 3N- 10
(1561'FSL, 179'FEL, S29, T13N, R9E)
HORIZONTAL PROJECTION
NORTH ZOO0 REF 000071436
lO00
-1000
-2000
. -9000
-4000
-~000
SOUTH -6000
-3000
WEST
SCALE = l/1000 IN/FT
-2000 -1000 0 1000 2000 3000 4000 SO00
EAST
WELL 3N-10
(1561'FSL, 179'FEL, S29, T13N, R9E) '
VERTICAL PROJECTION
-4000 -~OOO 0 0 ~000
4000 6000 8000 10000
]2000
159.
PROJECTION ON VERTICIqL PLF1NE 1S9. -
'"~'"~'"'~'"'~"'h"i'"~'"';'--
....~..-~....L..,:...,L.~....~....~ ...... !"'~--'-~'"-F---h.-~-..~.--
---~--.i----~----i i ...... ~ ....... ~--.~..-~---~---~---~--.~...
--;-.-.-i---:, .--~.--i.--~,....~ <
......... ~-..-;....~--. k.z...~.....i...~ · ' '
'--I'
::: :-'-!-+-.i.--~.-..i'-= '~ ~"?~'~ "!"'?'"-!::::'"r;;:::!:::'?.;::f;:!;::-!:"!:::-i;:: ...... =~....~....,,..: ......... ~ ....
?-....~----F-.~--. ~
:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~--~ r-
: ~--!....h4..i....!..-~.. i ..... :...i....~..i. !...!.:..}? iZi ?'"~ .i .~. i..+..~ ....
..... ~'"?""Y'"~ r--'F---?-..:..-.~ .................... ~ ...:...~ ' ....
.... :...;....~ 4...:....~....:.. .... ~.. :: 7: ~:' .~:::::,:..:!:. 'i"::',, '! '~ .... ~. !..-i..'- -~.- ~..-;---.i...i '!--'!' .!----i ...... !.. o
~' ?'"':'"~".": ..... ..... t ............ ,?i'"':"~ .......... ............ :--.~........+..~.-i....~...~
/
9~9. SCALEO IN VERTICAL DEPTHS HORIZ SCALE : 1/2000 IN/FT
RECEIVED
AUG- 5 1986
Naska Oil & Gas Cons. Commission
Anchorage
ARCO Alaska, Ir,
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
TO:
ARCO ALASKA, INC.
ATTN: Kuparuk Records Clerk
ATO 1119
P. O. Box 100360
Anchorage AK 99510-0360
DATE 08-21-86
TRANSMITTAL # 5746-B
Transmitted herewith are the following items. Please acknowledge receipt and
return one signed copy of this transmittal.
Final Prints' Schl' Open Hole' One. * of each
3N-8~5'' DIL/SFL-GR 03-19-86 Run #2A 3624-6859
2'.' DIL/SFL-GR 03-19-86 Run #2A 3624-6859
-5" Den/Neu-GR (poro) 03-19-86 Run #2A 6170-6834
-2" Den/Neu-GR (poro) 03-19-86 Run #2A 6170-6834
i~5" Den/Neu-GR (raw) 03-19-86 Run #2A 6170-6834
--~2" Den/Neu-GR (raw) 03-19-86 Run #2A 6170-6834
'~--Cyberlook 03-19-86 Run #2A 6170-6834
The following logs are Run #1 and 2 combined. They are listed
according to Run #2 to save space and time. (Only the DIL's)
3N-9 ......5" DIL/SFL 03-27-86 Run #2 4671-9376
2" DIL/SFL 03-27-86 Run #2 4671-9376
/ ~5" Den/Neu (poro) 03-27-86 Run #2 8300-9350
~2." Den/Neu (poro) 03-27-86 Run #2 8300-9350
q~,-5" Den/Neu (raw) 03-27-86 Run #2 8300-9350
.... ~ .... ~2" Den/Neu (raw) 03-27-86 Run #2 8300-9350
~C~erlook 03-27-86 Run #2 8700-9330
3N-10 ~,51,' DIL/SFL-GR 04-03-86 Run #1 0100-9379
....... ~" DIL/SFL-GR 04-03-86 Run #1 0100-9379
%?~?~ ~5~' Den/Neu-GR (poro) 04-03-86 Run #1 6880-9354
~ ~" Den/Neu-GR (poro) 04-03-86 Run #1 6880-9354
~ ~ ~ ~5" Den/Neu-GR (raw) 04-03-86 Run #1 6880-9354
fl" Den/Neu-GR (raw) 04-03-86 Run #1 6880-9354
~4~yberlook 04-03-86 Run #1 8650'9i75
Receipt Acknowledged:
~State Of AK*bl seJ_~~
Drilling*bi
Rathmell*bl
D&M *bl
ARCO Alaska. Inc. is · Subsidiary of AllanticRichfielclComplny
Date:
~AI~ 0ii & Gas Cons. Commission
Anchorage'
STATE OF ALASKA ~"x
ALAS..,4 OIL AND GAS CONSERVATION COM SSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate j~ Pull tubing []
Alter Casing [] Other [] Comp'lete
2. Name of Operator
ARCO A1 aska, Inc,
3. Address
P.O. Box 100360 Anchoraqe, AK 99510
4. Location of well at surface
1561'FSL, 179'FEL, Sec.29, T13N, RgE, UN
At top of productive interval
1650' FSL, 1785'FWL, Sec.33, T13N, R9E, UN
At effective depth
1296'FSL, 1927'FWL, Sec.33, T13N, RgE, UM
At total depth
1209'FSL, 1961'FWL, Sec,33, T13N, RgE, UM
5. Datum elevation (DF or KB)
RKB 68' Fee~
6. Unit or Property name
Kuparuk River Unit
7. Well number
3N-10
8. Approval number
59
9. APl number
50-- 029-21576
10. Pool
Kuparuk River O'Jl Pool
11. Present well condition summary
Total depth: measured 9394'
true vertical 6744'
Effective depth: measured
9271
true vertical
6663
Casing
Cono"ucto r
Surface
Length Size
80 ' 16"
4535 ' 9-5/8"
9353 ' 7"
Producti on
feet
feet
feet
feet
Plugs (measured) None
Junk(measured)
None
Cemented
247 sx CS II
1400 sx AS III &
315 sx Class C
300 sx Class G &
175 sx A5 I
Measured depth
ll5'MD
4572'MD
9353'ND
~ue Vertical depth
ll5'TVD
3586'TVD
6720'TVD
Perforation depth: measured 8860'-8898'MD
9064 ' -9071 ' MD
true vertical 6395'-6420'TVD
6529' -6533' TVD
Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail ~ 8971'
Packers and SSSV (type and measured depth)
HB pkr ~ 8719', lB pkr ~ 8948', & FVL SSSV ~ 1851'
9043'MD 9047'MD
9045'MD
6515'TVD 6518'TVD
6516'TVD
RECEIVED
AUG- 5 1986
Alaska Oil & Gas Cons, Commission
Anchorage
12. Stimulation or cement squeeze summary
N/A
Intervals treated (measured)
Treatment description including volumes used and final pressure
13.
N/A
Prior to well operation
Subsequent to operation
Representative Daily Average Production or Injection Data
OiI-Bbl GaS-Mcf Water-Bbl Casing Pressure Tubing Pressure
14. Attachments (Completion Well Hi story w/Addendum, dated 4/28/86)
Daily RepOrt of Well Operations ~ Copies of Logs and Surveys Run C~ Gyro
15. I hereby certify that the foregoing is true and correct to the best of my knowledge
Form 10-404 Rev. 12-1-85
Title Associ ate Engi neet
Date
Submit in Duplicate
(DAM) 5W0/081
ARCO Oil and Gas Company
Daily Well History-Final Report
Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold.
"Filial Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not
required upon completion, report completion and representative test data in blocks ~rovided. The "Final Report" form may be used for reporting the entire
operation if space is available.
Accounting cost center code
District ~County or Parish State
Alaska I North Slope Borough Alaska
Field ILease or Unit J Well no.
Kuparuk River ADL 25520 3N-10
Auth. or W.O. no. ~Title
AFE AKl177 I Completion
Nordic 4 API 50-029-21576
OperatorARCO Alaska, Inc. IA*R*C°' W'1'56 . 24% JabandonmentlC°strl'°tal number °f wells (active °r inactive) °n thisIcenter priOrof thist° pluggingwell and
Spudded or W.O, begun IDate IHour IPrlor status If a W.O.
Complete 7/17/86 ! 1800 hrs.
Date and depth Complete record for each day reported
as of 8:00 a.m.
7/18/86 7" @ 9353'
9.9 ppg NaC1/NaBr
Accept rig @ 1800 hfs, 7/17/86. ND tree, NU & tst BOPE. RU
DA, perf w/4" gun, 4 SPF f/9064'-9071', 9043~-9045', 9047' &
8878'-8898'. Perf w/5" gun, 12 SPF f/8860'-8878'. Make gage
ring/JB rn. Set lB pkr @ 8933'. RU & RIN w/2-7/8" compl.
7/19/86. 7" @ 9353'
9271' PBTD, RR
Diesel
Rn 226 its, 2-7/8", 6.5#, J-55 EUE 8RD tbg w/SSSV @ 1851', HB
pkr @ 8719', lB pkr @ 8948', TT @ 8971'. Tst ann, ND BOPE, NU
& tst tree; OK. Displ well w/diesel. RR @ 0430 hfs, 7/19/86.
RECEIVED
AUG- 5 1986 ,'
Alaska 0il & Gas Cons, Commission
Anchorage
Old TD J New TD Pa Depth 9271 '
PBTD
I
Released rig ~ Date ~ K nd of r g
0430 hrs. I ' 7/19/86 J Rotary
Classifications (oil, gas, etc.) ' I Type completion (single, dual,, etc.)
Oil I Single
Producing method I Official reservoir name(s)
Flowing I Kuparuk Sands
Potential test data
Well no. Date Reservoir Producing Interval Oil or gas Test time Production
Oil on test Gas per day
Pump size, gPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date
corrected
The above is correct
~"~ ' -
For fornp preparation and distribution,
see Procedures Manual, Section 10,
Drilling, Pages 86 and 87.
Drilling Supervisor
ADDENDUM
WELL:
3N-10
4/14/86
4/16/86
Arctic Pak w/175 sx AS I, followed by 60 bbls Arctic Pak.
RU Schl, rn 6-1/8" JB/gage ring to 9142', POOH. Rn
CET/GR/CCL f/9130'-7500' WLM. Rn gyro/CCL f/9104'-100',
RD Schl.
RECEIVED
AUG- 5 1986
Naslai Oil & Gas Cons. Commission
Anchorage
Drilling Supervisor
Date
STATE OF ALASKA
ALA~ .A OIL AND GAS CONSERVATION COl~. ,SSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Requests! Abandon [] Suspend [] Operation Shutdown ~ Re-enter suspended well [] Alter casing []
Time extension [] Change approved Program [] PlUgging [] Stimulate ~ Pull tubing [] Amend order [] Perforate ~i~ Other-,~-r-'
2. Name of Operator
ARCO Alaska, Inc
3. Address
P. O. Box 1QQ$60 Anchorage- AK c~(:JC~lO
4. Location of well at surface
1561'FSL, 179'FEL, 5.ec.29, T13N, RgE, UN .
· At top of productive interval
1381'FSL, 1825'FWL, 5ec.33~ T13N, RgE~ UN (ap. prox.)
At effective depth
1496'FSL, 1874'FWL, 5ec.33, T13N,- R9E, UM (approx.)
At total depth
1191'FSL, 1996'FWL, Sec.33, T13N, R9E, UM (approx.)
5. Datum elevation (DF or KB)
68 ' RKB feet
6. Unit or Property name
K_ u 7 _~ r'_' k R '.' ,.,e r Iff .~. ~ t
7. Well number
3N-lO
8. Permit number
86-72
9. APl number
50--029-21576
10. Pool
Kuparuk River 0il Pool
11. Present well condition summary
Total depth: measured
true vertical
9 3 9 4 ' feet
feet
6729'
Effective depth: measured
9271 '
true vertical
6440'
Casing Length
Conductor 80 '
Surface 4535'
feet
feet
Plugs (measured) None
Producti on 9365 ' y\,~
( IZ ' a~ve rotar
Perforation depth: measured None
true vertical None
Junk (measured)
None
Size Cemented Measured depth
16" Conductor report 115'
not available.
9-5/8,, 1400 sx AS Ill & 4572'
315 sx Class G
~ue Verticaldepth
115'
3567'
7" 300 sx Class G & 9353' 6702'
175 sx AS I
Tubing (size, grade and measured depth) None
Packers and SSSV (type and measured depth) Non e
12.Attachments
Oescril~tion summary of proposal [] Detailed operations program [] BOP sketch []
Well History
13. Estimated date for commencing operation
May, 1 986
14. If Proposal was verbally apProved
Name of approver
Date approved
15. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed ~ ~ ~ Title AssoCiate Engineer
Commission Use Only
Date
Conditions of approval
Approved by
(DAM) SA/012
Notify commission so representative may witness
Approval
No.
[] Plug integrity [] BOP Test [] Location clearanceI "'/
~:'~' :::;~ ~ ~'.~: :~ ~ .......... ~r~ ~ ~: by order of
,. ~,~,:T~ Commissioner the commission Date
Form 10-403 Rev 12-1-85 Submit in triplicate
· . . Well History Initial Report Dally
~ n~;~ : ·" Rel~Ol, t" on the fkst Wednesday alter a well is spudded or workover operations are started.
Daily work prior to spudding should be summarized on the form giving inclusive dates only.
Kuparuk River
Auth. or W.O. no.
AFE AK1177
District ]County. parish or borough IState
Alaska I North Slope Borough
I
Field ILea" orUnit
25520
I
]Title
] Drill
Doyen 9
API 50-029-21576
Operator [ARCO W.I.
ARCO Alaska, Inc.
Spudded 3/28/86 2130 hrs.
Date and depth
as of 8:00 a,m,
3/28/86
3/3:1/86
4/01/86
4/o2/86
4/o3/86
The above Is correct
Complete record for each day reported
Alaska
9-5/8"'@ 4572'
4593', (4478'), Prep to cmt
Wt. 9,5, PV 18, YP 17, PH 9.5, WL 13.6, Sol 8
(16" @ 115') Accept rig @ 1515 hrs~ 3/28/86'. 16" @ 115' NU
diverter sys. Spud well @ 2i30: hfs, 3/28/86. Drl & surv 12~'
hole to 4593', 35 std short trip, C&C, TOH.~ RU & rn 112 its,
9-5/8", 36# BTC csg w/FS @ 4572', FC@ 4482'. Prep to cmt.
633', 3.4°, S25.75E, 632.8 TVD, 3.9 VS, 3.5S, 1.7E
1097', 17.2°, S24.75E, 1088.6 TVD, 81.2 VS, 73.0S, 36.5g
1785', 34.9°,
2351', 48.1°,
2979', 49.1°,
3486', 53.7°,
S23.75E, 1720.3 TVD, 343.1VS, 310.6S, 148.7E
S18.75E, 2150.2 TVD, 708.8 VS, 655.6S, 270.5E
S18.75E, 2564.4 TVD, 1180.6 VS, 1101.5S, 425.0E
S17.75E, 2888 TVD, 1570.0 VS, 1474.3S, 539.8E
9-5/8" @ 4572'
5246', (653'), TOH
Wt. 8.9, PV 9, YP 5, PH 9.0, WL 16.4, Sol 4
Cmt .9-5/8" w/1400 sx AS III, followed by 315 sx C1 "~' w/2%
S-l, .2% D-46 & .2% D-13. Displ using rig pmps, bump plug.
CIP @ 1015 hfs, 3/31/86. ND diverter sys, NU & Cst BOPE.
RIH, DO flt equip i cat + 10' new hole. Conduct formation tst
to 12.1 ppg ENW. Drl & surv 8½" hole to 5246', TOH ck'g f/wsh
Out.
4747', 48.4°, $21.75E, 3684.6 TVD, 2545.8 VS, 2398.4S, 854.8
5122', 47.7°, S19.75E, 3935.2 TVD,,2824.7 VS, 2659.2S, 953.6
9-5/8" @ 4572'
7503', (2257'), Drlg
Wt. 9.4, PV 7, YP 4, PH 9.5, WL 8.6, Sol 9
Chg out Navi-Drl, RIH, drl & surv 8½" hole to 7503'.
5437', 47.7e, S20.75E, 4147.2 TVD, 3057.7 VS, 2877.8S, 1034.3E
6060', 47.8~, S21.75E, 4563.5 TVD, 3521.1VS, 3309.1S, 1204.1E
6687', 49.5°, S23.75E, 4977.1TVD, 3992.0 VS, 3743.6S, 1386.4~
9-5/8" @ 4572'
9098', (1595'), Drlg
Wt. 9.9, PV 15, YP 7, PH 9.0, WL 6.2, Sol 12
Drl & surv 8½" hole to 9098'.
7633', 51.1°, S22.75E, 5578 TVD, 4720.9 VS, 4412.5S, 1678.3E
8264', 49.2°, S21.75E, 5982 TVD, 5205.9 VS, 4862.4S, 1860.0E
IWell no.
3N-lO
56.24%
Signature
~or ~orm preperatlon an~ diatribution,
see Procedures Manual, Section 10,
Drilling, Pages 86 and 87.
I Date / [ Title
·
Drilling Superintendent
Atlant,cRiChfieldComPany' Daily Well History-Final Report
Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well Is Plugged, Abandoned, or Sold.
"Final Repe~' should be submitted also when operations are suspended f.or an in. definite or appreciable length of time. On workovers when an official test Is not
required upon completion, report completion and representative test data In blocK8 provided. The "Final Report" form may be used for reporting the entire
operation if space is available.
District
Field
J Accountlng coat center code
I County or Parish iState
Alaska North Slope Borough Alaska
I Lease or Unit IWell no.
Kuparuk River ADL 25520 3N-10
Auth, or W.O. no. ~ Title
AFE AK1177 I Drill
Doyon 9
Ol~r~or
ARCO Alaska, Inc.
AP1 50-029-21576
Spudded or W.O. begun
Spudded
IA.R.Co. W.I.
56.24%
IDate 3/28/86
4/04/86
Data and depth
as of 8:00 a.m.
4105186
4/13/86
Complete record for each day reported
I otal number of wells (active or Inactive) on this
cst center prior to plugging and
bandonment of this well
our I Prior status if a W,O.
2130 hrs.
9-5/8" @ 4572'
9394', (296'), C&C mud
Wt. 9.9, PV 15, YP 6, PH 9.0, WL 6.0, Sol 12
Drl to 9394', short trip, C&C, POOH. RU Schl, rn
DIL/SFL/SP f/9387'-to 4574', GR f/9150' surf. Rn CNL/FDC
f/9150'-8650' & 7050'-6890'. Rn CAL f/9150'-6890'.
8893', 48.5°, S21.75E, 6397.5 TVD, 5678.2 VS, 5301.1S, 2035.0E
9334', 48.7°, S21.75E, 6689.1TVD, 6008.9 VS, 5608.4S, 2157.6E
7" @ 9353'
9394' TD, RR
9.8 ppg NaCl
POH, LD DP. Chg out top rams & tst. RU & rn 229 its, 7", 26#,
K-55 BTC csg w/FC @ 9271', FS @ 9353' Cmt w/100 sx 50/50 C1
"G" w/8% D-20, .5% D-65, .5% D-112 & 12% D-46. Tail in w/200
sx C1 "G" w/.9% D-127, .3% D-46 & 3% KC1. Displ w/9.8 ppg
brine, bump plug. ND BOPE, NU & tst tbg head to 5000 psi. RR
@ 0430 hfs, 4/5/86.
Arctic pack well w/175 sx AS I.
Old TD New TD
9394' TD 9271' PBTD
Released rig Date
0430 hrs.
Classifications (oil, gas, etc.)
Oil
I PB Depth
Kind of dg
4/5/86 Rotary
I Ty~ completion (single, dual, etc,)
Single .
Official reservoir name(s)
Kuparuk Sands
Producing method
Flowing
Potential test data
Well no. Date Reservoir Producing Interval Oil or gas Test time Production
OII on test Gal per day
Pump size, SPM X length Choke size T.P. C.P. · Water % GOR Gravity Allowable Effective date
corrected
The above is correct
For form preparation ~ distribution,
see Procedures Manual, Section 10,
Drilling, Pages 86 and 87.
Drilling Superintendent
ARCO Alaska. In
Post Office Box 100360
Anchorage. Alasl<a 99510-0360
Telephone 907 276 1215
RETURN TO:
ARCO ALASKA, INC.
ATTN: Kuparuk Records Clerk
ATO 1119
P. O. Box 100360
Anchorage AK 99510-0360
DATE 04-15-86
TRANSMITTAL # 5628
Transmitted herewith are the following items. Please acknowledge receip= and
return one signed Copy of this transmittal.
Open Hole LIS Tapes plus Listings: Schl: One copy of each
- ~ ~. 0-~ ~. ~ ~ a~ ~ ?- 3 -~p~ ~, -/~- ~I
~31-15
~N-10
~N-9***
04-08-86
04-06-86
04-03-86
03-27-86
Run
Run #1
Run
~ #~ oo~.o-~.o~~ ~-$- ~/~ -?;-?~ 7~
***There was previously transmitted on transmittal %5613 a 3N-9 OH LIS tape ·
but it was for Run #1 only.
Receipt Acknowledged:
State of AK
·
March 26, 1986
Mr. J. B. Kewin
Regional Drilling Engimeer
ARCO Alaska, Inc.
P. O. Box I00360
Anchorage, Alaska 99510-0360
Re: 3N-10
ARCO Alaska, Inc.
Telecopy'.
(907) 276-7542
Permit No. 86-72
Sur. Loc. 156t'FSL, 179'FEL, Sec. 29, T13N, R9E, UM.
Btmhole Loc. lll9'FSL, 1924'FWL,'Sec. 33, T13N, RgE, UM.
Dear Mr. Kewin:
Enclosed is the approved application for permit to drill the
above referenced well.
The permit to drill does not indemnify you from the probable need
to obtain additional permits required by law from other
governmental agencies prior to commencing operations at the well
site.
To aid us in scheduling, field work, please, notify this office 24
hours prior to commencing installation of the blowout prevention
equipment~ so that a representative of the Commission may be
present to witness testing of the equipment before the surface
· casing shoe is drilled. Where a diverter system is required,
please also notify this office 24 hours prior to commencing
equipment installation so that the Commission may witness testing
before drilling below the shoe of the conductor pipe.
~ton
Chairman o f
Alaska Oil and Gas Conservation Commission
BY ORDER OF THE COMMISSION
dlf
Enclosure
CC'
Department of Fish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
Mr. Doug .L. Lowery
STATE OF ALASKA
ALASKA C,,,_ AND GAS CONSERVATION
PERMIT TO DRILL
20 AAC 25.005
,
la. Type of work. DRILL ~( lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC I--I"L:'
REDRILL [] DEVELOPMENTOIL)~] SINGLE ZONE [~X
DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE []
2. Name of operator
ARCO Alaska, Inc. _
3. Address
P. 0. Box 100360, Anchorage, Alaska 99510
4. Location of well at surface 9. Unit or lease name
1561' FSL, 179' FEL, Sec.29, T13N, R9E, UM Kuparuk River Unit
At top of proposed producing interval 10. Well number
1381' FSL, 1825' FWL, Sec.33, T13N, R9E, UM 3N-10
At total depth 11. Field and pool
1119' FSL, 1924' FWL, Sec.33, T13N, R9E, UM Kuparuk River Field
5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. Kuparuk River 0i 1 Pool
RKB 68' PAD 34'I ADL 25520 ALK 2556
,
12. Bond information (see 20 AAC 25.025) Federal Insurance Company
Type Statewide Surety and/or number #8088-26-27 Amount $500,000
13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or c°mpleted
30 mi. NW of Deadhorse miles 1119' @ TD feet 3N-9 well 25' (~ surface feet
--
16. Proposed depth (MD & TVD) 17. Numbe~ o~ acres in lease 18. Approximate spud date
9376'MD, 6704' TVD feet 2560 03/27/86
' I '
19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures 2947 psig@__80°F Surface
KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 49 o (see 20AAC25.035 (c) (2) 33~.3 psig@. 6572 ft. TD (TVD)
21
Proposed Casing, Liner and Cementing Program
SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEI~/IENT
Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data)
24" 16" 62.5# H-40 Weld 80' 35' I 35' 115' I 115' +200 cf
12-1/4" 9-5/8" '36.0# J-55 BTC 4586' 35' I 35' 4621, I
I I 3577' 1315 sx AS Ill &
HF-ERW ~ I 315 sx Class G blend
8-4/2" 7" 26.0# J-55 BTC 9342 ' 34 '
I 34' 9376' I 6704' 300 sx Class G
HF-ERW I I
~ I
22. Describe proposed program:
ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well. A 20", 2000 psi annular diverter
be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack
installed on the 9-5/8" surface casing will be tested to 3000 psig upon installation and weekly thereafter.
Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded
gas bubble at surface, including temperature effects. Production casing will be tested to 3500 psi prior to '
releasing the drilling rig. Reserve pit fluid will be disposed of by pumping them down the 7" x 9-5/8" annulus ol
this well. Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175
sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing.
Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A
subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has
i moved off location, this well will be fracture stimulated.
23. I hereby cert~at the foregoing is true aod correct to the best of my knowledge '
SIGNED /~___~~. ~ TITLE Regional Dri 1 Iing Engineer DATE ~.~~~.~
CONDITIONS OF APPROVAL
Samples required Mud log required Directional Survey required APl number
[~]YES z~-N.O [[]YES j~O ,:~ES [-INO 50- O~.
Approvai date
Permit number 1~(,'~7't.- /~ ~ 03/.26/86 I SEE COVER LETTER FOR OTHER REQUIREMENTS
APPROVED BY ~~,../~. , /~,~.- -- ~ ,COMMISSIONER DATE March
' L : .~-~ by order of the Commission
Form 10-401 (LWK)
/
Submit in triplicate
........... 1000~
PAD 3N, WELL NO~ 10 Pr~OPOSED
EASTHAN WHIPSTOCK. INC; ' .. , - ;-' - . · . ~..
.
. ;
. . ._ .
.
_ .
_
_ .
KOP _.?VD=500 TMD-500 'DEP"'O
3 '
9 -
;21 : PER 1 O0 ¢1' ........
_
.......
·
........................ .
3~ !BASE PERI'IAFROST--'TVD~1717' TMD=1819 DEP~4~8
...... 2,000_
.................. [ ......... . .....
.
' TOP UGNU SNDS TVD-245? THD~2918 DEP"1248
........
m ...... ~000 .................................................
'~ TOP W SAK SNDS TVD=3152 THD=3975 DEP=2044
m
::o K712 TVD=3377 TMD=4317' DEP=2302
o 9 5/8' CSO PT
>. TVD=3577 TMD=4621 DEP=2531
o 4000
AVERAGE ANGLE
...... 48 DE G 53 M IN ......
......... 5000 ............. - ..... L_ ....... i ............ &.] ............ _L_..._,.'_ ....... ~ - . ........................
K-5 TVD=54i 7 TMD=741 9 DEP=4639
................................................_ ~ ......................... i ......................
-.~,,,.,,.,u.---?n. nn-- .......... ! - '? - i .......
....... ........... TTtTONE'T'D~TVD=6T87-Tt1D=8590-DEP=5522'] .........
.......... T/ ZONE.C. TVD=6245 THD=8679 DEP=5588
........... T/ ZONE ;A'- TVD=6459 'THD=900.4 DEP=5833 ' .
..... ~ .......~ TA ~OET--CN TR--+TVD=65t 6-?MD=909 I-DEP=5899
_; -'-:-; - ' B/j KUP 'SNDS i TVD=6572 -T:HD=9176 DEP=5963
........ TDi-(LO0 'PT)- -TVD=6704 T;MD=9376- DEP=6114
............... I_ . ~ .... I I I I I
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............................................. i__HOR]:ZON T.~L ..... PR 0 J'E C_T__.[ONi.i ......... i_:_'''''~
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..... :. .... : ....... ~ ...................... .:' .......... ~ ............................. ' .......... ;. ............................
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'- PAD' 3N. ~/ELL" NO" 10'; PROP~3s~-D-iii: i' .; :-
KUPARUK FIELD,' NORTH:! SLOPE.-AL. ASEA .:..~-. j,)t,,: '~,~
- - ; i'.;: ...... ; EASTI"IAN.NH]:PSTOCK, ]:N0;-_'_.;"::¥.-¥: /.F.~." i:-:-
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. ~ 000 ~. 0._ :._:: ..... ! 000 ._ _ 2000 3000
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' 200 ~ ' ,100 0 100 200 ' ~00 400 500 600 , 700
I I : :
KUPARUK RI VER UNIT
20" DIVERTER SCHEMATIC
DE $CR I PT I ON
'i. tE,-
2. TAI~O STARTER HEAD.
3. T AI',a(O SAVER SUB.
4. TAI'~O LOWER. OUICK-COI',,t4ECT ASSY.
5. TAI'~O UPPER QU I CK-C~,NECT ASSY.
6'. 20' 2CX:X) PSI DRILLING SPCX:X.
W/I0' .OUTLETS.
7. I0' NCR BALL VALVES W/lO'
DIVERTER LINES° VALVES OPEN
AUTOMATICALLY UPON CLOSURE OF
Ah~AR PREVENTER.
8. 20" 2CX:XD PSI Ah~LAR PREVENTE~,
MA:[NTENANCE & OPERAT~IO~N
I. UP-C)N INITIAL INSTALLATION. CLOSE
PREVENTER AND VER.IFY THAT VALVES
HAVE OPENED' PROPERLY,
2, CLOSE ANINULAR PREVENTER AND BLOW
AIR .THROUGH DIVERTER LINES
EVERY 12 .HOURS,
3; 'CLOSE' AI~LAR PREVENTER 'IN THE
EVENT 'THAT AN IhI'LUX 'OF ~EiLLBORE
FLUIDS OR GAS IS DETECTED, IF
NECESSARY, . MAhaJALLY' OVERRIDE ANO
CLOSE APPROPR I ATE VALVE TO
ACHIEVE DOWNWIND DIVERSION,
DO NOT SHUT IN'
i
ANY CIRCUMSTANCES.
7
6
5
4
3
2
.::
"-'"~ DIAGRAM #1 c//~
13-5/5 ~300 PSI F~$RRA BCP STA~
4. ~8- - ~ ~z P~ ~
5. ~8" - ~ ~ ~~ ~ w/~ ~
KI~ LI~
'-:- ACCk/VULATOR CAPACITY TgST
I. Q-E~ AN:) FILL A~TCR RF_SE:RVOIR TO '~
LEVEL WITH HYDRALLIC FLUID.
2. ASS~ THAT A(~TC~ PRES.~ IS ~ PSI WITH
1500 PSI D~TREAM ~F TiE RE(AJ_ATCR.
3. C~VE TllvE, TI-F,N CLOS~ ALL UNITS SllvU. T~GJS. Y
AN:) A'ECO;~ ~ TI~E AN:) PRE$_~_.i~E ~4AININ~ AF'rER
ALL UNITS ARE O..OSED WITH CHAR~INS PLM~ (:FF.
4. RE~ ON NADC RF_PORT, TIE ACCEPT~E LONE~ LIMIT
IS 45 SECO',I3S O_OSINS TI~'E AN:) 1200 PSI RE)V~ININS
PRE~.
13-5/8" BCE:' STACK TEST
1. FILL BCP STACK AhD CHO~ MANIFOLD WITH ARCTIC
DIESEl..
2. Q-I~CK THAT ~ L~ ~ ~ IN ~~
~Y ~RA~. ~T ~T ~ IN
WI~ ~I~ ~ ~ ~ IN L~
LI~ V~V~ ~~ TO ~ STA~ ~L
P~~ ~ TO 2~~ F~ I0 MIN.
~ ~~ TO~ PS~ ~ F~ I0 MIN.
5. ~ ~ PR~~ ~ ~AL KI~ ~
LI~ VALVES, ~E T~ PIPE ~ ~ ~ V~VES
~ KILL ~ ~E
6. TEST TO 2~ PSI ~~ IN ST~ 4.
7. ~I~ TESTI~ ALL~ES, LI~$, ~
WITH A ~ PSI L~ ~ 3~ PSI HI~. T~T AS IN
ST~ 4. ~ ~T ~~ TE~T ~ ~ ~T
8. ~ T~ PI~ ~ ~ ~ ~~ PI~ R~.
TEST B~ PIPE ~ TO ~ ~I ~ ~ ~I.
9. ~ BO~ PIPE R~, ~ ~ ~I~ ~
.!0. ~ ~I~ ~ ~ TEST TO ~ ~I ~.~
PSI.
II. ~ ~I~ ~ ~ ~l~ TEST ~. ~
~IF~' ~ LI~S ~ ~L. ~ ~~I~'
~UID. ~ ~ VALVES IN ~I~l~ P~ITI~
I~ TEST ST~I~ VALVES, K~Y, ~Y ~S, ~'
PI~ S~ VALVE, ~ I~I~ B~ TO ~ PSI
5~ PSI.
13. RE~ TEST ~~T]~ ~ ~~ ~ TEST
F~, SI~, ~ ~ TO ~I~I~ ~I~.
14. P~~ ~~E B~ ~$T ~ NI~I~ ~
~Y T~~~ ~I~LY ~~ B~ ~ZLY,
!
I I I II I Ill III I I IIII I I I P I i'~ ~1 f'~t/~ I J;3 ~" ~
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
January 31, 1986
A/
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: Conductor As-Built Location Plat - 3N Pad
(Wells 1- 18)
Dear Mr. Chatterton-
Enclosed is an as-built location plat for the subject wells.
you have any questions, please call me at 263-4944.
Sincerely,
. Gruber
Associate Engineer
JG/tw
GRU13/L45
Enclosure
If
RECEIVED
FEB 0 5 iS.'8 '
Alaska Oil & Gas "~ ,-
ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany
i I i
. t LG'CATED IN PROTRACTED SEC',f 28 & 2, TI~ N, R 9E,U... -- 29(~,~28
LOCATED IN PROTRACTED LOCATED IN PROTRACTED
SEC. 29, TI3N~ R9E, U.M. SEC. Z9, TISN,R9E, U.M.
1 - Y = 6,013,799.67 LAT. 70~26'55.9615'' ~0 - Y = 6,013,799.37 LAT. 70~26'55.9519"
X = 517.946. ~9 LONG. 149~51' 12. 938'' X = 518.221.07 LONG. 149~51'04.865"
· : 454' FEL, 1562' FSL OG = 28.2 PAD = 33.7 179' FEL, 1561' FSL OG - 28.5 PAD = 34.0
2- Y - 6,013,799.65 LAT. 70026'55.9606" 11 - Y = 6,013,799.32 LAT. 70'26'55.9508"
X - 517,971.21 LONG. 149o51'12.203" X - 518,246.03 L~G.149o51'04.132"
429' FEL, 1562' FSL OG - 28.2 PAD - 33.8 155' FEL, 1561' FSL OG - 28.5 PAD - 33.8
3- Y - 6,013,799.54 LAT. 70~26'55.9590" 12 - Y ~ 6,013,799.45 LAT. 70°26'55.9515"
I X - 517,996.25 LONG. 149°51'11.468" X · 518,270.89 LONG. 149oSI'03.403"
404' FEL, 1562' FSL OG- 28.4 PAD - 33.9 130' FEL, 1561' FSL OG
4 - Y - 6,013,799.50 LAT. 70~26'55.9580'' 13 - Y = 6,D13,799.41 LAT. 70~26'55.9505"
. X - 518,021.16 CONG. 149051. 10.736" X - 518,295.97 LONG. 149~51'02.666"
379' FEL, 1562' FSL OG = 28.4 PAD = 33.7 ~ 105' FEL, 1561' FSL OG
.~
5 - Y = 6,013,799.~ LAT. 70°26'55.9572"
~ 14 - Y ' 6,013,799.33 LAT. 70*26'55.9491"
X = 518,046.1B LONG. 149~51'lO.O02" ' '~ X - 518,320.91 L~G.149~51'01.934"
354' FEL, 1562' FSL OG ~ 28.5 PAD = 33.7 ~ ~ 80' FEL, 1561' FSL OG = 28.5 PAD
6 - Y = 6,013,799.44 LAT. 70~26'55.9562" ~ ~ ~ 15 - Y : 6,013,799.28 LAT. 70~26'55.9480''
X = 518,071.24 LONG. 149051'09.266" ~ X = 518,345.77 LONG. 149~51'01.204"
329' FEL 1562' FSL OG = 28.5 PAD = 33.9 ~ ~ ~ ~
, ~ ~ 55' FEL, 1561' FSL OG = 2B.5 PAD = 34.0
)i 7 - Y = 6,013,799.44 LAT. 70'26'55.9556" ~ ~ ~ ~
. o 16 - Y = 6,013.799.25 LAT. 70~26'55.9471"
X : 518,096.21 LONG'149°51'08'533" ~ 0 ~ ~ X = 518,370.74 LONG. 149'51'O0.470"
( 304' FEL, 1561' FSL OG = 28.5 PAD = 33.9 ~ ~ 0 ~ 30' FEL, 1561' FSL OG ' 2B.5 PAD = 34.1
8 - Y = 6,013,799.45 LAT. 70~26'55.9551'' ~ ~ ~ 17 - Y = 6,013,799.26 LAT. 70~26'55.9466''
X = 518,121.15 LONG. 149°51'07.800" X = 518,395.63 LONG. 149~50' 59.739"
279' FEL, 1561' FSL OG = 28.6 PAD = 33.9 ~ ~ 0 5' FEL, 1561' FSL OG = 28.5 PAD = 34.1
~ 9 - Y = 6,013,799.42 LAT. 70~26'55.9542"
, X : 518,146.15 LONG. 149~51'07.066'' ~ SEC. 28,TI3N, R9E, U.M.
i ~.SECTION LINE DISTANCES ARE TRUE.
~ "
~ ~.HORIZONTAL POSITIONS BASED ON ON-PAD PILING CONTROL PER LHD ~ ASSOC.
~ 4. VERTICAL POSITIONS BASED ON MODULE PILES 5JOI-8 & 5JOI.-4~
5.0. G. ELEVATIONS INTERPOLATED FROM S/C DRAWING CED-RIXX-5090 rev.~.
CERTtFIC ~TE OF SURVEYOR: , ~E~EBY CERTIFY THAT I ~M PROPERLY
~) ~GISTEREO ~ND tIC~NSE~ TO ~R~CTIC~ ~ ~NO ~ A~ ~ .~%
~ ~_~ :-~' i ~,,m~v~n FnR ~ A~U AIOSKO, Inc.
~ ~ I ~u,~v~u '~, · ~ ~ ,~//.i ~'~' '"
, ~H --. , ~ ~.~.~ p~.,~T ~...~--------.--':-"~
i ~ass0~, ' "':~ .oo. ,., ,~6 AS-BUILT LOCATIONS
(4)
Oeolo
WVA
JAL
rev: 0S/1
6~011
(10 and 12)
(t3
(22 t~ru 26
-.
· -.
22.
23.
24.
25.
26.
· & Well No. ."
YES NO
2. ~ ~ell ~o be lo~ed' in a defined pool ........................ ~...~ ~
~IS ~well located p~)e~ist~nce..from other wells .................. ~ ~ ...
'5 Is Sufficient ~dediCat~:'acre~ ,~ailable in this pool ........... ~ ~
, · . , , . (~"~ ~, ,
~ well be deviated '~d.:,is~~bore plat included ................ ~ ~
'~',~: e onl affected ~y ..............................
be 'approved, before ten-day wait .. ~ ."'..: ................
...
have a bond in force ~
oes op , .~ .~ ..........
conse~ation order needed ' ~~"'-
Is a~nis~ra~ive approval needed
approP=~e ' ~
i2 Is the lease n~ber '
13 Is conductor s~r~ -
· ee ee eee e · · · · · · · · · · eae e e eeeeeee es ~ eel
· 14. I's enough cemen~ use~ ao' ~trc~a~e om conduc~or~d sur~.ace .' ........ ~
15'' ~Will cement tie in surface ~d inte~ediate °r ~r~d~ctiO~strings ~ ~~ ~'
16,J':Wiil cement cover al~ '~ productive horizons:~'~2 ...... -.,, ...... [ ~:~ ':%,'
.....~all casinE give adequate safety in co~apse,,, tensio~,.~d b~st..
Is ~;~this well to be kicked off from ~ existinE,~611bore ; ...... ~{~:~ .~i
I~?Old wellbore ab~do~ent procedure included~on 10-403 .' ...... ..."'~
. uate wellbore separation proposed'· .~ ...... ........ . ~...~.~ ~.~.
Are necessa~ ~tagr~s of diverter and B~P. equipment at--ed ~...~~
Does BOPE have sufficient pressure ratinE i Test to ~E .. ~ ~
Does the choke manifold comply w/AP1 RP-53 (Feb
Is the presence of H2S gas probable ......
Additional requirements ....................
Additional Remarks:
POOL CLASS STATUS
0
Well History File
APPENDIX
Information of detailed nature that is not
Particularly germane to the Well Permitting Process
but is part of the history, file.
To improve the readability of the Well History file and to
simplify finding information, information of this
nature is accumulated at the end of the file under APPENDIX.
No special effort has been made to chronologically
organize this category of information.
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e
Memory Multi-Finger Caliper
Log Results Summary
LJlG
Company:
Log Date:
Log No. :
Run No.:
Pipe1 Desc.:
Pipe1 Use:
ConocoPhillips Alaska, Inc.
September 24, 2005
6531
1
2 7/S" 6.5 lb. J-55 EUE
Tubing
Well: 3N-10
Field: Kuparuk
State: Alaska
API No.: 50-029-21576-00
Top Log IntvI1.: Suñace
Bot. Log Intvl1.: 8,971 Ft. (MD)
Inspection Type:
Co"osive & Mechanical Damage Inspection
COMMENTS:
This caliper data is tied into the Tubing Tail @ 8,971' (Driller's Depth).
This log was run to assess the condition of the 2 7/S" tubing with respect to corrosive and mechanical
damages. The 2 7/S" tubing appears to be in good condition with respect to corrosive damage, with no
significant wall penetrations recorded throughout the tubing logged. No significant areas of cross-sectional
wall loss or I.D. restrictions are recorded throughout the tubing logged.
Cross-sectional drawings of the most significant events recorded are included in this report. The distribution
of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report.
MAXIMUM RECORDED WALL PENETRATIONS:
No significant wall penetrations (> 17%) are recorded.
MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS:
No significant areas of cross-sectional wall loss (> 4%) are recorded.
MAXIMUM RECORDED ID RESTRICTIONS:
No significant I.D. restrictions are recorded.
SCANNED OCT 3 1 2005
I Field Engineer: N. Kesseru Analyst: M. Tahtouh Witness: C. Fitzpatrick I
ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497
Phone: (281) or (888) 565-9085 fax: (281) 565-1369 E-mail: PDS@memorylog.com
Prudhoe Bay field Office Phone: (907) 659-2307 fax: (907) 659-2314
I
Tubing: Nom.oD
2.875 ins
September 24, 2005
MFC 24 No. 00387
1.69
24
M. Tahtouh
Nom. Upset
2.875 ins
Wen:
Field:
Company:
Country:
Survey Date:
3N-1O
Kuparuk
ConocQPhillips
USA
Inc.
I
I
_ penetration body
250
200
150
100
50
body
o 0 to
1%
1 to
10%
10 to 20 to 40 to over
20"10 40% 85% 85%
GLM 1
o
o
Damage COl1figtJratiol1{ body)
GLM2
10
I
GLM4
GLM5
GLM6
GLM7
I
o
isolated general line ring hole I poss
pitting corrosion corrosion corrosion ible hole
1.2 ins
Damage Profile (°/" wall)
loss body
50
o
£""1...../;."1A
1'1 M 11
Bottom of Survey = 282.8
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An"dysisDverview page 2
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JOINT TABULATION
Pipe:
Body Wall:
Upset Wall:
Nominal 1.0.:
2.875 in 6.5 ppf
0.217 in
0.217 in
2.441 in
3N-l0
KUPiJruk
ConocoPhillips Alaska, Inc.
USA
September 24, 2005
Well:
Field:
Survey Date:
I Joint PelL Pen. ¡Vletal ---- n. .£:L
Jt. Depth Pen. Min. .,;;-"""
(Ft.) ¡~~~:L)I Body !.D. Comments 10f
I No. \ '" ""'''1
(Ins.) (Ins.) 0 100
.1 12 0.02 2.39 PUP
1 16 0.01 2.37
2 49 0.02 1 2.37
3 79 0.02 1 2.38
4 110 0.01 2.38
5 141 0.02 2.38
6 173 0.01 2.38
.~- 204 0.03 2.39
. 8 235 0.02 2
9 266 0.02 2
10 298 0.01 1
11 329 0.03 ') 1 ~
12 360 0.01 18
13 391 ( 0.02 0 18
14 423 0.01 6 2.18
15 454 0.02 10 2.37
16 486 0.02 11 2.38
17 517 HUi' 13 18 Lt.
18 548 0.03 12 18
19 579 0.02 11 19
20 611 0.01 7 17
21 642 ( 0.02 11 2.38
22 674 ( 0.02 11 1 2.37
23 705 ( 0.02 11 2 2.37
24 736 ( 0.02 .
25 767 II
26 799
----..lL... 830
28 862
29 893
30 924
31 955 ~.37 ~ ..
32 986 0.03
33 1018 0.03
34 1049 0.02 2.38
35 1080 0.02 2.39
36 1112 0.02 2.36
37 1143 0.03
38 1174 0.02
39 1206 0.02 I
40 1238 0 0.02 11 2
41 1269 0 0.01 5 1
_42 1300 0 0.01 5 1
43 1331 0 0.01 6 2
44 1363 0 0.03 13 I
45 1394 ~'0
46 1425 10
47 1456 11 ¿
_48 1488 o 9
49 1519 o 0.02 10 0- III
Page 1
Pipe: 2.875 in 6.5
Body Wall: 0.217 in
Upset Wall:
Nominal I.D.:
3N-10
Kuparuk
ConocoPhillipsAlaska, Inc.
USA
September 24, 2005
Date:
Joint Jt. Depth Plt'n. Pen. Pen. ¡Metal Min. :'fftìle
No. (Ft.) \~;~~~;t Comments ¡Of'
Ons.) (Ins.) 0 \i" '''''''! '00
50 1550 0 o~
51 0 O.
f--,,52 1609 0 0.02103 2.38 -
53 1641 () O. 10 H-f%.3~
54 1672 0 0.02 ~
55 1703 0 0.02 11 2 2.35 ~
56 1735 0 0.02 9 1 2.38
57 1766 0 0.02 11 1 2.38 11II
58 1797 ( 0.ü1 2.39
58.1 1829 ( 0.ü1 t 2.36 :)
58.2 1835 0 2.31 V
58.3 1838 0.ü1 2.36
58.4 1845 0.01 2.35
59 1846 0.02 1') 2.37 11II
60 1877 0.ü1 ~ .2.37 ~
61 1909 0.01 ill
62 1938 2.36 '"
63 1969 0.02 t¡ '"
64 2000 0.03 ~
65 2031 0.01 lit
66 2063 0.02 ') =
67 2094 0.03
68 2126 0.02 . I .
69 2157 0.01
70 2188 0.03 i2 '"
71 2219 0.02 10 iii
72 2250 0.02 II
73 2282 0.02 11 11II
74 2313
75 2344
76 2376 ( 1
77 2407 12
78 2438
79 2470 )
80 2501
81 253:1 ) I
82 2563 0.ü1 1 H Deposits. III
83 2595 0.02 I II
84 2626 0.03 Lt. II
85 2658 0.02 11II
86 2689 0.03 II
87 2720 0.03 II
88 2751 0.03 '"
89 2782 0.02 '"
90 2814 0.02 ~GiM HI III
91 2844 0.01
91.1 2876 C 0 (
92 2882 0 0.02 Lt. '"
93 2914 0 0.02 ill
94 2944 0 0.02 ) Lt. Deposits. ill
Page 2
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:1
I
II
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I
I
II
II
I
I
Pipe:
Body Wall:
Upset Wall:
Nominal LD.:
2.875 in 6.5 ppf J-55
0.21 7 in
0.217 in
2.441 in
Well:
Field:
Company:
Country:
3N.l0
Kuparuk
ConocoPhillips Alaska, Inc.
September 24, 2005
I Joint Jt Depth Pen. Pen. Pt:n. Met;~1 Min. n"m""" PrQfj ~
(Ft.) ~~~~~t;t Body 1M .11\
No. Comments \!<> 'Vª"¡ 100
(Ins.) (Ins.) 0
95 2976 0 0.02 11 3 2.32
96 3007 0 0.02 11 2.34
97 3038 0 0.02 11
98 3070 0 0.02 1
99 3101 0 0.03 'I
100 3133 0 0.03 t
101 3165 0 0.02
102 3196 0.02 ! t npoosits.
103 3227 0.02 J It.Bpoosits.
~
105 3289
106
1 3384
109 3415 0.02
110 3446 0.02
111 3476 0.02
112 3507 0.02
113 3539 0.03 9
114 3570 0.02 =+±~ 3
115 3601 0 0.D2 2.34
116 3634 () 0.02 2.34 ¡ t
117 3664 0 0.01 4 3 2.33
118 3696 --. 0 0.02 '7 :I 2.35
119 3727 0 0.02 7 4 2.31
120 3758 0 0.02 10 3 2.32
121 3790 0 0.02 '7 2 2.33
122 3821 0 0.D2 9 :I 2.35 -
123 3853 0.02 11 2.30
124 3883 0.03 1 2.33
.__ill_. 3914 0.01 :; 2.32
.-.
126 3946 0.03 2.29
127 3977 0.03 2.33 Lt Deposits.
128 4009 0.ü3 2.32
129 4041 0.03 2.32
130 4072 0.02 2.34
131 4103 0.02 233 Lt DéPosits.
132 4135 0.03 232
133 4165 0.03 2.34
134 4196 0.02 233
135 4228 0.01 233
136 4259 0.02 J 233
137 4289 0.03 2.32
138 4320 r 0.02 234 !t. Deoosits.
139 4351 ( 0.02 236
140 4382 ( 0.02 2.36
141 4413 0 0.02 ! 237
142 4443 0 0.01 6 I 235
143 4475 0 0.02 <) 2 234 Lt. Deposits.
144 4507 0 0.02 9 3 232
Page 3
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SH
Pipe:
Body Wall:
Upset Wall:
NominaII.D.:
2.875 in 6.5 ppf J·55
0.217 in
0.217 in
2.441 in
Well:
Field:
Company:
Country:
Survey Date:
3N-10
Kup,uuk
ConocoPhiliips Alaska, Inc.
USA
September 24, 2005
IJ~: Jt. Depth Pert Pen. Pen. Metal Min. ^" iProfii I
No. (Ft.) Body 1.0. Comments
(Ins.) (Ins.) (Ins.) 10 JOp
145 4538 0 3
Clli= 1 1---.
5
148
149
150 4695
151 4726
152 4758 0.03 Lt. Denosits
153 4789 0.03
154 4821 0.D1
155 4852 0.02 34
156 4884 0.û3 32 Lt. leoosits.
156.1 4914 0 ¡fA GL 2 (Latch 8:001
157 4921 0.02 32 Lt. leoosits.
158 4952 0.02 2.34
159 4986 0.02
160 5016 0.02
161 5047 0.02 It. Deoosits.
162 5078 m ¡
163 5109 J 0.03 2.33
164 5140 12 2 2.33
_J65. 5171 13 :2 2.33 Lt.
166 5204 0 0.02 9 :2 2.36
167 5234 0 0.02 11 3 2.35
168 j 526~ 0.02 9 2 2.37
169 0.02 9 :2 2.38
170 0.02 1 :2 2.36
171 0.03 P :2 2.35
172 5391 0.02 =Ht
173 5421 0.03 3
174 5453 0.D2
175 5484 0.03 J 2.38
176 0.03 4 2.36
177 0.02 2.35
178 5576 0.02 2.37
179 5608 0.02 ] 2.36
180 5638 0.02 2.35
181 5668 0.02 ] 2.35 Lt. Denosits.
182 5699 0.02 2.34
183 5731 0 0.03 3 2-
184 5763 0 0.03 1 2.
185 5795 0 0.02 10 2.
186 5826 0 O. 9 2.
187 5857 0 O. 2.
188 5889 0 o. :. 2.3 Lt. Deoosits.
189 5919 0 2.3.
1-. 190. 5951 0 2.3~
191 5983 0 4 2.35
192 6013 0 0.02 :2 2.36
193 6045 0 I 0.02 11cJ :2 2.34
4
Joint Jt Depth PC'!L Pen, f)en, Ivletal Min. Damage Profile
No. (Ft) \:;~:~~t I.D. Comments (% wall)
(Ins.) '7<) (Ins.) 0 50 100
194 6077 0.02 2.34 Lt Deoosits.
195 6108 0.02 2.37
196 6137 0.03 231: Shallow oittin\!.
197 6169 0.02
198 6200 0.01
199 6231 0.01
200 6263 0.02 Lt
201 6294 0.02 1
201.1 6325 0 \! GLM 3 (latcn @3:0Oì
1-202 6332 0.02 P) 'Hi LL Deoosits.
203 6363 0.02 !~
204 6393 0.02 II'be~'i"
205 6424 0.02
206 6457 0.02
207 6487 0.02
208 6519 0.03 F'
209 6551 0.02 WI
210 6582 0.02 Zj 2.38
211 6612 0.02 ¡if 2.36
--- 212 6642 0.02 ff 2.37 . Lt Denosits.
213 6675 0 0.02 q ±TIH
214 6706 0 0.02
215 6737 0 0.02
216 6768 0 0.01 · I L Denn"iK
_)17 6799 0 0.02 It Deno,Üt,,_
218 6831 0 0.02 11
219 6862 --- 0.01 I t. Denosits.
220 6893 0.03 )
- -
221 E HÆ=t It
222 E {
223 E 2.33 ' Lt. Deoosits.
224 0.01 I
225 7050 * I Lt. Deoosits.
226 7081
227 7110 U.
227.1 7141 0 . . ¡ A elM 4 · (Latcn@ 3:0Oì
228 7148 0.02
229 7180 0.02 n
230 7211 0.02 I
231 7243 0.02 I .34 U.
232 7273 n 0.02 I' '. ~;< I 2 2.36
233 7305 n 0.02 11 4 2.37
234 7336 n 0.03 12 PI 2.35 Lt. Deoosits,
235 7366 n 0.01 h i 2.35
236 7398 0 0.03 1', '{ 2.35
-- 237 7430 () 0.03 12 " 2.34 ---
238 7461 0 0.02 -~
239 7491 0 0.02
240 7524 0 0.02
240.1 7554 0 0 0 0 I N/A GLM 5 (Latch @7:3Oì
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Pipe:
Body Wall:
Upset Wall:
NominaII.D.:
2.875 in 6.5 ppf )-55
0.217 in
0.217 in
2.441 in
Well:
3N-l0
Kuparuk
ConocoPhillips Alaska, Inc.
USA
September 24, 2005
Company:
Country:
Survey Date:
I
Page 5
I
TABULATION
Pipe:
Body Wall:
Upset Wall:
Nominal I.D.:
2.875 in 6.5 ppf J-55
0.217 in
0.217 in
2.441 in
Well:
Cornpany:
Country:
Survey Date:
3N-10
K!jparuk
ConocoPhillips Alaska, Ine.
USA
September 24, 2005
I
~int Jt. Depth Perl, Pen. Pell. Metal Min. )"m""", Profile
No. (Ft.) \.:;~:t;t Body !.D. Comments "" .11\
\ 1<1 V,,,,Ii) 100
I (Ins.) (Ins.) 0 50
241 7561 0.03
242 7592 0.02
243 7623 0.03 )
244 7655 0.01 ¡ t
245 7686 0.02 -
7717 0.03
7750 0.02 ¡ t
7779 0.03 It ¡
~ 7812 0.02
250 7844 0.03
251 7873 0.02 2.33
252 7906 0.02 2.34 Lt. Deoosits.
253 7936 0.02 2. Lt. Deoosits.
253.1 7967 0 NJ GL M 6 lLatch3:00)
254 7974 0.03 2. 4 Lt. Deoosits.
255 8006 0.02 1 1 2. b
256 8037 0.03 1: 2 2.33 Lt. Deoosits.
257 8069 0.02 I 4 2.31
258 I 8101 0 0.02 l! 2 2.32 ,
259 8131 0 lIow oittinq.
260 8162 0
261 enosits.
262 0.02 11 2} 2.33
263 7 27
264 31
265 33
266 8349 Lt. O",nosits.
266.1 8382 0 () N/A r;t M 7 (Latch @ 12:0Oì -..
267 8387 0.03 2.34 Lt. Dennsits.
268 8420 0.02 2.31
c---1_69 8451 0.03 2.32 Lt. Deoosits.
270 8481 0.03 2.30 Lt Deoosits.
271 8514 0.02 0 Lt. Deoosits.
272 8545 0.02 2 Lt. Deoosits.
273 8576 0.03 2
274 8604 ( 0.03 3 It
275 8636 ( 0.02 t2 Lt. Deoosits.
275.1 8666 ( 0 ) o,J(A GLM8 (Latch@ 3:00) r
276 8674 0 0.03 .31 Lt. Deoosits.
276.1 8706 0 0.01 .42 PUP
276.2 8709 0 0 ) .44 PBR
276.3 8711 0 0.03 12 4 2.51 PUP II
]76.4_ 8720 0 0 0 0 ·3.00 HB PACKER
277 8730 0 0.02 11) 2 ;5 Lt. Deoosits. ~
277.1 8762 0 0 0 0 N(A GLM 9 (Latch @ 8:0Oì ~
278 8767 0.03 2 Lt. Deoosits.
279 8798 0.02 4-
279.1 8831 0 0 N, GLM 10 (Latch @ 2 :001 ~
280 8836 0.03 4
'-.281 8868 0.02 '$
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Page 6
I
JOINT TABULATION
Well:
Field:
Company:
Country:
Survey Date:
2.875 in 6.5 ppf J-55
0.217 in
0.217 in
2.441 in
3N-l0
Kuparuk
COlloCQPhillips Alaska,Jnc.
USA
September 24, 2005
Pipe:
Body Wall:
Upset Wall:
Nominal I.D.:
Jt. Depth
(Ft.)
Joint
No.
Comments
282
282.1
282.2
282.3
282.4
282.5
282.6
282.7
282.8
8897
8925
8934
8942
8951
8956
8967
8970
8971
Ie
Tail
Page 7
KRU
.1
~ 31'1I.10
~
SSSV Type: TROP 49 9394
sssv ---- Completion:
(1851-1852.
OD:2.875) Annular Fluid: ~ -..- -¡'fev Reason: UI-'UAlt:
·nn. Ref Loa . Last
I ",,,,t TO: 9394 ftKB
8/22/1997 Max Hole
SizE! Too Bottom
16.000 0 115 62.50 H-40 I
9.625 0 588 36.[]0 J·55 I
7.000 0 0 J-55
TOD I Bottom I TVD
I 8971 6469
I Tvoo
8860 - 8898 6396 - 6421 38 12 7/17/1986 IPERF 17n ..1"" pile","., '" ~~ ~
B
9026 - 9043 6505·6516 A-3 17 8 7/3/1987 RPERF 3~~:1etPhase; 2118"
9043 - 9043 6516 - 6516 A-3 0 9 7/3/1987 RPERF ~~~~~tPhase; 2 118"
9043 - 9045 6516 - 6518 A-3 2 8 7/3/1987 r\, -Lr\' ~~;J;;thase; 2 1/8"
9045 - 9045 6518 ·6518 A-3 0 9 7/3/1987 r\"en, n::r-:t phase; 2 118"
9045 - 9047 6518 ·6519 A-3 2 8 7/3/1987 ~;~~thaSe; 2 118"
9047 - 9047 6519 - 6519 A-3 0 9 7/3/1987 RPERF 3~~~~tPhase; 2118"
9047 - 9049 6519 - 6520 A-3 2 8 7/3/1987 r\! 'Lr\! 1~;j~tPhase; 2 1/8"
Ener J
9064 - 9071 6530 - 6535 A-2 7 2 7/17/1986 IPERF 120deg. phase; 4" Jumbo
PBR C~~t
(8707-8708. nf
OD:2.875) 1 2546 era 1.0 0.000
2 4891 era 1.0 '--- 0.000 I 0 ~0/25/1987
PKR 3 6297 ela 1.0 O.
(8719-8720. 4 7112 ela 1.0 '--- O.
OD:6.151)
5 7522 Merla TMPO DMY 1.0 0.000 0 "'01
6 7934 TMPD OMY 1.0 BK 0.000 0
DMY 1.0 BK 0.000 0 VII:';:),
1.5 DMY 1.5 RK 0.000 0 I\J!V/
St MD V C~~t
Mfr
Pelf 9 875616327 DMY
(8861J..8874) -. 10 88261 6374 DMY 1/26/1987
11 8930 6442 DMY
Pelf
(8874-8898)
2. to
8707 6295 PBR BroWil 2. t1
8719 . PKR 3. m
8948 PKR mown I-!:J 3.250
8964 NIP Cameo'D' Nir¡ple NO GO 2.250
PKR 8970 6469 SOS Brown 2.441
(8948-8949,
00:6.151) 8971 6469 TTL 2.441
NIP
(8964-8965.
OD:2.875)
TUBING
(0-8971,
OD:2.875.
ID:2.441)
Pelf - ~
(9026-9049) .-- -
~ § ~
Pelf -
(9043-9043) j t=
Pelf
(9064-9071 )
I
IqACRO :ILMED
~/~.¥~_ :,
LIS TAPE
VERIFICATION LISTING
.VP OIO.H02 VERIFICATION LISTIN~ PAtE 1
,-~- R:EL~ HE~DER
~ERVICE NAME :EDIT
)ATE :85/04/10
]R!GIN :
~EEL NAME :149415
]O~TINU~TIDN # :01
~REVIOUS REEL
~OMMENTS :LIBRARY T&PE
~ TAPE HEADER ~-~
~ERVICE NAME :EDIT
)ATE :85/04/10
]RI~IN :0000
rAPE N~ME :1393
~ONTINUATION' ~ :01
~REVIOUS TAPE :
SOMMENTS :LIBRARY T~PE
EOF
~ FILE HE~DER
=ILE N&ME :EDIT
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INFORMATION RECORDS
~NEM CONTENTS
~N : ARCO AL~SK~INC
~N : 3N-IO
:N : KUPARUK
~OWN: I3N
~ECT: 29
COUN: N,SLOPE
STAT: AL~SK~
CTRY: USA
MNEM CONTENTS
·
PRES: E
~ COMMENTS *'~
UNIT
TYPE
000
000
000
000
000
000
000
000
000
TYPE
000
C AT E
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015
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065
065
065
065
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065
065
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065
.VP OlO.H02 VERIFIC4TIDN LIST!N~ PAGE 2
~ SCHLUMBERGER
~ ALASKA COMPUTING CE4TER
.,. ~: .,.. ~ ~. ~: ~: ~: ~: ~ ~ ~ ,,,, ~ .,. ~ ~ ~.-'.,-'- -'., ~ -'- -'- -'- .'- -~. -',, -'- ,'--'- -'- -'. -'--'--'..'- ~ -'- ~--~ .- ~ ~- ~ .... ~..,..,..,..,..~ .,..,..,. ,,..,..,..,~ ~ .,..,,..,.
SOMPANY = ARCO ALASKA INC
4ELL = 3 N-1.D
mIELD = KUPARUK
SDUNTY = NORTq SLOPE BOROUGH
STATE : ALASKA
JOB NUMBER AT ACC: 71393
RUN al, DATE LOGGED: 3-~PR-86
LOP: L. B. CUDNEY
SASING
TYmE FLUID
DENSITY
VISCOSITY
~H
mLUID LOSS
: 9.625" @ 4572' - BIT SIZE = 8.5" TO 9394'
: LSND
= 9.go LS/S RM = 5.015 @ 50.0 DF
= 52.0 S RMF : 5.555 @ 50.0 OF
: g.o RMC = 4.190 @' 50.0 DF
: 5.0 C3 RM AT BHT, : 1.858 @ 14,6. D'F
MATRIX SANDSTONE
.VP 010.H02 VERIFICATION LISTIN~ PAGE 3
-~- THIS 2AT~ HAS NOT BEEN DEPTH SHIFTED OVERLAYS FI,'LD PRINTS
SCHLUMBER2ER LOGS INCLUDED WITH THIS MAGNETIC TAPE:
DJ~LINDUCTION SPHERICALLY FDCUSE2 LOG (OIL)
DATA AVAILABLE: 9200' TO 4650'
FORMATION DENSITY COMPENSATED LOG (FDN)
C~MPENSATED NEUTRON LOG (FDN)
DATA AVAILABLE: 9200' TO 6880°
GAMM~ RAY IN C~SING (GR.CNL)
DATA AVAILABLE: 4660° TO 88~
~ DAT~ FORMAT RECORD ~
~NTRY BLOCKS
TYPE SIZE REPR C02E ENTRY
2 ~ 65 0
~ I 66 I
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2.8381
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)EPT 4~00.0000 SFLJ
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)EPT 4300.0000 SFLU
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2H3B -999.2500 DRHD
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-999.2500 NR~T
-999.2500 FCNL
)EPT ~200.0000 SFLU
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2HDB -999.2500 DRHD
4PHI -999.2500 NCNL
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-999.2500 FCNL
3EPT 4100.0000 SFLU
5P -999.2500 SR
~HDB -999.2500 ORt'D
4PHI -999.2500 NCNL
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3EPT ~000.0000 SFLJ
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3EPT 3900.0000 SFLU
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.VP OlOoH02 VERIFICATION LISTING PAGE 10
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qPHI -999.2500 NCNL
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3EmT 3000.0000 SFLJ
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)EPT 2900.0000 SFL2
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)EPT 2800.0000 SFLiJ
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]EPT 2600.0000 SFLD
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66.2930
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30.0986
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45.4805
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.VP 010.H02 VERIFIC&TIDN LISTINS PAGE 11
~P -999.2500 GR
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.VD OlO.HO2 VERIFICATIDN LISTINS PAGE 12
)EPT
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~ FILE TRAILER ~
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SERVICE NAME :EDIT
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3RI~IN :0000
rAPE NAME :1.393
SONTINUATION ~ :01
4EXT T~PE NAME
SDMMENTS :LIBRARY T,~PE
~, REEL TRAILER ~-~
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),,ATE :B6/06/10
3RIGIN :
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COMMENTS :LIBRAR~ T'~PE
