Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout184-020127-D /8'�L—D20
Loepp, Victoria T (CED)
From: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty-
Sherrod@contractor.conocophillips.com>
Sent: Wednesday, September 11, 2019 6:48 AM
To: Loepp, Victoria T (CED)
Subject: RE: [EXTERNAL]Re: 2F-07 10-404
Follow Up Flag: Follow up
Flag Status: Flagged
Good morning,
I submitted yesterday (9/10/19)
Thanks,
r_m
From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>
Sent: Friday, September 06, 2019 3:51 PM
To: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty-Sherrod@contractor.conocophillips.com>
Subject: [EXTERNAL]Re: 2F-07 10-404
Please submit as soon as possible
Thx,
Victoria
Sent from my iPhone
On Sep 6, 2019, at 3:11 PM, Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty-
Sherrod(acontractor conocophillips com> wrote:
Victoria,
I have just been going over my wells completed in the last 90 days and discovered I have missed a 10-
404 for 217-07 for a Whipstock. The 10-407 for that completion was submitted 7/11/2019. 1 will che6
more on Monday but I don't think I submitted a completion for the whipstock.
I think somewhere along the job, we switched engineers due to a job change.
Thanks,
Ann
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑
Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑
Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: WHIPSTOCK
2. Operator
4. Well Class Before Work:
S. Permit to Drill Number:
Name: ConocoPhillips Alaska, Inc.
Development ❑ Exploratory ❑
Stratigraphic❑ Service ❑
184-020
3. Address: P. O. Box 100360, Anchorage,
6. API Number:
Alaska 99510
50-029-21076-00-00
7. Property Designation (Lease Number):
9. Well Name and Number: KRU 2F-07
ADL 25667
9. Logs (List logs and submit electronic and printed data per 20AAC25.071):
10. Field/Pool(s):
N/A
Kuparuk River Field / Kuparuk River Oil Pool
11. Present Well Condition Summary:
Total Depth measured 9,055 feet Plugs measured None feet
true vertical 6,254 feet Junk measured 8890, 8894 feet
Effective Depth measured 8,931 feet Packer measured 8,405 feet
true vertical 6,167 feet true vertical 5,812 feet
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 78 feet 16 109' MD 109' TVD
SURFACE 3,696 feet 9 5/8 " 3,727' MD 2889' TVD
PRODUCTION 9,025 feet 7 9,051' MD 6251' TVD
Perforation depth: Measured depth: 8554-8564. 8638-8657, 8674-8728, 8778-8784 feet
True vertical depth: 5912-5918. 5968-5981, 5992-6029, 6063-6067 at
Tubing (size, grade, measured and true vertical depth) 3.5 " J-55 8,433' MD 5,831' TVD
Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER FHL 8,405' MD 5,812' TVD
SSSV - OTIS QLP SSSV 1,953' MD 1,832' TVD
12. Stimulation or cement squeeze summary:
Intervals treated (measured): NIA
Treatment descriptions including volumes used and final pressure:
13. Representative Daily Average Production or Injection Data
Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation: SHUT-IN - - - -
Subsequent to operation: SHUT-IN - - - -
14. Attachments (required per 20 AAC 25.070, 25.071, s 25.20)
15. Well Class after work:
Daily Report of Well Operations CE
Exploratory ❑ Development El Service ❑ Stratigraphic ❑
Copies of Logs and Surveys Run ❑
16. Well Status after work: Oil Gas ❑ WDSPL ❑
Printed and Electronic Fracture Stimulation Data ❑
GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑
17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt:
319-227
Contact Name: Shane Germann
Authorized Name: Shane Germann
Contact Email: Shane.Germann@cop.com
Authorized Title: Staff CEngin r
Contact Phone: (907) 263-4597
Authorized Si �- I(S - I
natureDate:
Form 10-404 Revised 4/2017 ��y/,p RgDMS SEP 1 12019 Submit Original Only
KUP PROD WELLNAME 2F-07 WELLBORE 2F-07
C`%onoc��rrt)I'' n �' ' Well Attributes Mu Angle & MO TO
� Fla NNncco'1 M^nnB eaugreSUSAlaska. lied. oonACI BIm IhNB)
nnccn
OUT 175 112152016
31N.adddmm.`k5deM
Last Tag
Va'PSIatlIu,I+Oc (+cEaO
Mromen Dmah(M(B)Eam am. Vhliham, umumm, By
Last Tag: RKe 8795. 51162019 2F-0- Journal
IaNGER;as
Last Rev Reason
gnnolNenI End Oars
Wall Lael Moa ey
He, Eason:SET HIGH XPA I N WHI , NIPPLE MILLED 512312019
OUT, UPDATE TAG
2F -OJ conaijw
Casing Strings
caalne pescaptun OD he ID llnl TaPlh6a1 sememr(--) I ael DeAre(101-.iMlln p...rTopLGIE-d
CONDUCTOR 16 15.06 31.0 109.0 109.0 62.50 WELDED
CONDUCTOR 31 o10o
C mg uemlpaan im) mem, Top las.) Set Dep1111KKB) 9N OEM PVD1._ WULen (1... GuamTOp ID,va
SURFACE 9510 876 30.9 3,]26.8 2,8118.8 36W BTC
U>IIq OeFcnplbn OD lin) Wlinl TOP 1near 9--eam'--' Ser Oepq (rypl... WaLen TpTMeaaPRODUCTION - 6.28 26.0 90510 62508 26.00 BTC
waw WV', I'mme
Tubing Strings
moms Dexnpnon shto9 Ma_. tO lm) TOP IXN81 Sel Dep1n In.. sel prom OVDI 1... vn llNry Gmae Topconomron
TUBING 3112 2.99 236 8434.1 5,831.5 9.30 J-55 EUEBra
Completion Details
GPS UFT12LB5s
Top Here TOPtnd Nominal
Top (.a.) mKB) C hem dee Com ID (in)
236 23.6 007 HANGER FMC GEN II T -LI HANGER 3.500
1,953.0 1,832.1 4290 SAFETYVLV 1 LP 555VR_ UT1119 000)CL ACKTUBING .812
PRESSURE
8.391.0 5,8026 48.03 PBR BAKER PBR 3000
BURFACE.30.9aT89�
8,404.9 5812.0 48.03 PACKER BAKER FHL 3000
8421.3 5822.9 4801 NIPPLE- CAMCO D NIPPLE, MILLED OUT TO 280 "ON 5-1819 2.800
GASUFT: a T4a4
MILLED OUT
8.433.3 511 .9 4800 SOS AM HEA - L LMD 8249 PPROF 2.992
829/2004
Gas uFT;eem.4
Other In Hole (Wireline retrievable plugs,
valves, pumps, fish, etc.)
"'pmol
Top Incl
"haus)
(RKeI
1°1
Deo
Com Run Dela id lm)
Goa uFT, 8.4
6,645.0
5728
270
WHIPSTOCK
2. DNORTR LU N H H N 51232019 0.
WHIPSTOCK, TOW AT 8645, 0' ORIENTATION, TIED
INTO K1 MARKER AT 8428' MD
Pnrksm.
88900
6,140.2
46.57
FISH
TROT KICKSPRINGB LOST 5R" WIDE, 35" LONG 31232011 0000
8.894.0
6,142.9
d65J
FISH
Original Completion PKR Leh in hole during workover 101mrkel
PACKER;&4W.9
Perforations & Slots
sma
NIPPLE-MILLEDOUTAQ1e
Topharia
Simi
Topmo)
Mal
Blmmis
was
Wkaa2Pne
Doh
Dana
(shb/ft
i
Type
Com
L1-01 LATERAL: %414.8,
A�4
1
$554.0
8,5640
5,91.
5,918.5
-0,UNT B2
47
1221/198)
4.
(PERF
Deg. V' aslnp,
Em at
am: e.4sas
8,838.0
11,657 .0
, .
51
5,980.8
A-5, 2F -OJ
418/198/
4.0
IPERF
90 seg. asing, "
SCMum. Casing Gun
8674.0
8.728.0
5,OFT
6,028.9
747-07
4211984
40
IPERF
90aeg. hasmg,
Schlum. Casing Gun
msaF;ess4.pa.x4.G�
8778.0
8.7840
6, .1
6,06).2
A -3,2F -O7
41311984
4.0
IPERF
seg. hasmg,
Schlum. Casing Gun
Mantlrel Inserts
m
N Top m01 V+Ive All Pads- TRORun
Tep(N(9) MW Make all 013(Sary Typ Type (In) (pel) Run Mh Com
,065.5 1,912.1 IMMH FMHO 1 GAS LIFT GLV BK 0.188 1,256.0 19
2 4,-494 3,520. MMH FMHO 1 GAS LIFT OV BK 0250 001302019
3 ,eC4 4,803.1 IMMIA FMHO 1 GASLIPT OMY BK 0.000 0.0 21172019
IPERF; essa04a5TG
WHIPSTOCKa94a.GL�
4 8374.4 5)91.8 MMH FMHO 1 GAS LIFT DMY 00 11282019 mt'a
soon
g Pkr
repair
Notes: Generel & Safety
Eua 0.
Annoturnn
722019
NOTE. View Schematicwl Alaska SCnemalic10.0
IFERF; &81906,TA,G�
I
IPERF; B,PBPB,TaaO�
FISK;a60A
FISR;B.YrA
PROCUCTIOKM"Mr.rl
Operations Summary (with Timelog Depths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
De
Stan Time
End Time
Dur h
( r)
Phase
Op CaEa
Activity Code
Time P -T -X
Operation
("
End Depth (ftKB)
6/1/2019
6/1/2019
8.80
MIRU
MOVE
MOB
P
Trucks here @ 15:00. Pull off well,
0.0
0.0
14:00
22:48
Jeep up, rig down cellar. MOB to 2F
6/1/2019
6/12019
0.50
MIRU
MOVE
MOB
P
Arrive at 2F -Pad, drop jeeps
0.0
0.0
22:48
23:18
6/1/2019
62/2019
0.70
MIRU
MOVE
MOB
P
Begin spotting sub
0.0
0.0
23:18
00:00
6/2/2019
6/2/2019
2.80
MIRU
MOVE
MOB
P
Complete spotting sub & pits, lay
0.0
0.0
00:00
02:48
plywood for sow (in front of pits), lay
mats
6/2/2019
6/2/2019
2.20
MIRU
MOVE
RURD
P
Begin RU check list, drop stairs,
0.0
0.0
02:48
05:00
secure landings, MU hard-line, begin
moving shop & 1/2 -Way House
6/2/2019
6/2/2019
4.50
MIRU
WHDBOP
NUND
P
Begin NU BOP, continue RU checklist.
0.0
0.0
05:00
09:30
RIG ACCEPT @ 05:00, Run BOP
BORE scope. Check tree bolts. two
loose bolts on each lower flange
6/2/2019
612/2019
1.00
MIRU
WHDBOP
BOPE
P
Get shell test, Valve cm here service
0.0
0.0
09:30
10:30
tree
6/2/2019
6/2/2019
4.00
MIRU
WHDBOP
BOPE
P
Start full initial BOPE test. Test
0.0
0.0
10:30
14:30
witness waived by Jeff Jones,
AOGCC. Test complete. No fail /
passes
6/212019
6/2/2019
1.20
MIRU
WHDBOP
PRTS
P
Make up nozzle. stab on injector.
0.0
0.0
14:30
15:42
Circulate coil. Line up and test inner
reel valve, inner reel iron, and packoff
6/22019
6/2/2019
0.30
MIRU
WHDBOP
PULD
P
Unstab injector. Pull apart UQC and
0.0
0.0
15:42
16:00
install floats. Check motor high side
and houseing bend @ 1°
612/2019
6/22019
1.30
MIRU
WHDBOP
PRTS
P
PT Tiger tank & PDL's to 2500 PSI,
0.0
0.0
16:00
17:18
clear floor, PJSM
61212019
6122019
1.70
PROD1
WHPST
PULD
P
Crew change, PJSM PD BHA#1
0.0
77.0
17:18
19:00
Window Assembly (1.0"AKO
Weatherford motor, NS 2.80" String
Reamer, & 2.80" NS Long Shank Mill),
check pack -offs, MU to coil, tag up,
set counters
6/212019
6/212019
1.70
PROD1
WHPST
TRIP
P
RIH w/ BHA #1, holding 1 -for -1 returns
77.0
8,425.0
19:00
20:42
6212019
6/2/2019
0.30
PROD1
WHPST
DLOG
P
Difficulty logging K1, very eratic, pull
8,425.0
8,230.0
20:42
21:00
up to log HRZ, PUW = 39K,
6/22019
6/22019
0.20
PROD1
WHPST
CLOG
P
Log HRZ far+23'comection
8,230.0
8,285.0
21:00
21:12
6/2/2019
6/2/2019
1.30
PROD1
WHPST
DISP
P
Continue RIH, flush well -bore w/
8,285.0
8,600.0
21:12
22:30
seawater, displace to milling fluid,
close EDC
6212019
6122019
0.20
PROD?
WHPST
DLOG
P
Obtain SBHP: MID bit = 8600,
8,600.0
8,600.0
22:30
22:42
TVD sensor = 5910.9', pressure =
3802 psi, EMW = 12.37 ppg
6/2/2019
6122019
0.10
PRODt
WHPST
TRIP
P
Continue RIH, RIW = 12K, dry tag WS
8,600.0
8,645.6
22:42
22:48
pinch point at 8645.4' (TOWS -8641),
PUW = 38K, bring up pumps, RBIH
6/2/2019
6/3/2019
1.20
PROD1
WHPST
WPST
P
Milling from 8645.6', FS = 766 psi @
8,645.6
8,647.3
22:48
00:00
1.9 bpm, CWT = 10K, WOB =.6K,
annular = 3808 psi, WHP = 482 psi
Rertums fell off to 1.7 bpm out at
8646.2', began holding 1 -for -1
Page 1113 ReportPrinted: 911012019
Operations Summary (with Timelog Depths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
Stan Time
End Time
our (no
Please
Op bode
Activity Code
Time P -T4
Operation
(ftKB)
End Depth (ftKB)
6/3/2019
6/3/2019
2.40
PRODt
WHPST
WPST
P
Milling from 8647.3', CWT = 12.2K,
8,645.6
8,647.3
00:00
02:24
WOB = 2.2K, annular = 3815 psi,
W HP = 454 psi, pump = 4616 psi,
BOW called at 8648.7'
Continue control milling, CWT 12.7K,
WOB = 0.2K, pump = 4522 psi
6/3/2019
6/3/2019
2.40
PROD1
WHPST
MILL
P
String reamer eixts window, begin
8,647.3
8,670.0
02:24
0448
pushing on it milling rat -hole, CWT
=10K, WOB = 3.2K
6/3/2019
6/3/2019
1.10
PROD1
WHPST
REAM
P
Perform reaming passes, HS X 2,
8,670.0
8,670.0
04:48
0554
30R, 30L, & LS, Dry drift looks good.
RIH tag TO
Service ODS PDL swivel
6/3/2019
6/3/2019
1.40
PROD1
WHPST
TRIP
P
POOH, PUW=29K. Stop @ 8627 open
8,670.0
65.0
05:54
07:18
EDC
6/3/2019
6/3/2019
1.40
PRODi
WHPST
PULD
P
Tag up and space out. PUD BHA#1.
65.0
0.0
07:18
08:42
Lay down tools. Mill out @ 2.79 no go.
String reamer out @ 2.80
6/3/2019
6/3/2019
0.70
PROD1
DRILL
CTOP
P
M/U Nozzle. Flush stack and dg. Blow
0.0
0.0
08:42
09:24
down Mico Motion
6/3/2019
6/3/2019
1.20
PROD1
DRILL
PULD
P
PJSM. PD BHA#2 from pre loaded
0.0
72.1
09:24
10:36
PDL. Make up to coil trek and surface
test. Check pack offs. Tag up and set
counters
6/3/2019
6/3/2019
1.50
PROD1
DRILL
TRIP
P
RIH BHA#2, EDC open
72.1
8,225.0
10:36
12:06
6/3/2019
6/3/2019
0.30
PROD1
DRILL
DLOG
P
Log formation tie in for -11.5'
8,225.0
8,280.0
12:06
12:24
6/3/2019
6/3/2019
0.30
PROD1
DRILL
TRIP
P
Continue in hole. Stop @ 8627 shut
8,280.0
8,671.0
12:24
12:42
EDC, PUW=33K. Continue in. Clean
pass through window tag up @ 8671
6/3/2019
6/3/2019
1.60
PRODt
DRILL
DRLG
P
8671', Drill ahead, 1.8 BPM @ 4014
8,671.0
8,760.0
12:42
14:18
PSI FS, BHP=3856. Couple of hard
spots in build. Do not have surveys.
Estimate AVG DLS @ 49°
6/3/2019
6/3/2019
1.70
PROD1
DRILL
TRIP
P
Call EOB, Pump 5 X 5 sweeps. Trip
8,760.0
64.5
14:18
16:00
out. Slow down and jet 7"
6/3/2019
6/3/2019
1.00
PRODt
DRILL
PULD
P
Tag up and space out. PJSM PUD
64.5
0.0
16:00
17:00
1
1
IBHA#2
6/3/2019
6/3/2019
1.00
PROD1
DRILL
PULD
P
Late decision to run Ironside motor
0.0
0.0
17:00
18:00
since we would not be kicking off
billet. Lay down Inteq motor. Ironside
motors delivered one is at .03°
basically straight. Motor we picked up
is .8"
6/3/2019
6/3/2019
1.60
PROD1
DRILL
PULD
P
PD BHA#3 with .8' Ironside motor,
0.0
80.0
18:00
19:36
agitator, and RB HYC A#3. Make up to
coil and surface test. Complete
stripping on. DO confering with Geo
on plan. Might need to change angle.
Plan worked out. Tag up and space
out
6/3/2019
6/3/2019
2.80
PROD1
DRILL
TRIP
P
Trip in hole. A 500'shallow test
80.0
8,220.0
19:36
2224
agitator. Pressures high 1.9 BPM @
5490 PSI pump pressure. Diff @
1815. New agitator is in string. Consult
town Trip back to surface. Prep to
PUD. Do some research on previous
Irondide motor runs. Within 350 PSI of
noted pressures on 3M-26. Suspend
PUD. Trip in well
Page 2/13 ReportPrinted: 9/10/2019
. Operations Summary (with Timelog Depths)
2F-07
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Time
ESMTime
our (mi
Phase
op Code
Activity CMe
h
Time P -T -X
Operation
Sten Depth
n DO
EM Depth (flKB)
6/3/2019
6/3/2019
0.10
PROD1
DRILL
DLOG
P
Log formation for -11.5'
8,220.0
8,299.0
22:24
22:30
6/3/2019
6/3/2019
0.30
PROD1
DRILL
TRIP
P
Continue in well, 8585 PUW=35K
8,299.0
8,670.0
22:30
22:48
6/3/2019
6/3/2019
0.10
PRODi
DRILL
DLOG
P
Log RA marker in @ 8649,
8,670.0
8,685.0
22:48
22:54
TOWS=6642.2, BOW=8648.7
6/3/2019
6/3/2019
0.10
PROM
DRILL
TRIP
P
Continue in well
8,685.0
8,760.0
22:54
23:00
6/3/2019
6/4/2019
1.00
PROM
DRILL
DRLG
P
6760', Drill, 1.9 BPM @ 5400 PSI FS,
8,760.0
8,922.0
23:00
00:00
BHP=3877. Differential 1730 PSI off
bottom, RIW=9.5K, DHWOB=1.9K,
swap to new mud system (at bit at
8862')drill to 8922', avg ROP = 162
fph
Slow drilling beginning at -9404', ...
6/4/2019
6/4/2019
2.10
PROD1
DRILL
DRLG
P
Drilling from 8922', CWT = 8.9K, WOB
8,922.0
9,203.0
00:00
02:06
= 1.9K, annular = 3907', WHP = 460
psi, pump = 5603' psi, stall at 9002',
PUW = 35K, pump 5 x 5 sweeps
Oscillate drill when possible (limit to
-160 fph)
Lost communication w/ HOT (at
9170'), PU off bottom, PUW = 41 K,
trouble shoot & reset tool, go back to
drilling
6/4/2019
6/4/2019
0.20
PROD1
DRILL
WPRT
P
Wiper up -hole to EOB, PUW = 39K
9,203.0
8,760.0
02:06
02:18
6/4/2019
6/4/2019
0.20
PROD1
DRILL
WPRT
P
Wiper in-hole, RIW = 10.6K
8,760.0
9,203.0
02:16
0230
6/4/2019
6/4/2019
2.00
PRODi
DRILL
DREG
P
Drilling from 9203', FS = 1720 psi @
9,203.0
9,425.0
02:30
0430
1.9 bpm, CWT = 8.9K, WOB = 1.6K,
annular= 3889 psi, WHP= 561 psi,
pump = 5803 psi, gamma wrapped at
9255', stall at 9266', lower ROP
beginning at 9404'w/ Ankerite in
samples, PUW = 38K
Continued issue w/ HOT, losing
gamma, pump 5x5 sweeps, drill to
9425', PUW = 38K
6/4/2019
6/4/2019
2.60
PROM
DRILL
TRIP
T
POOH to swap out tools, grab missed
9,425.0
80.0
04:30
07:06
surveys, pull through window at 10 fph
& 0.5 bpm, jog 7" casing, open EDC
*Pre -load DS PDL w/ drilling BHA
6/4/2019
6/4/2019
0.90
PROD1
DRILL
PULD
T
PJSM, PUD BHA#3, inspect injector,
80.0
0.0
07:06
08:00
motor looked & blew down good
visually, bit came out a 2-1
6/4/2019
6/4/2019
1.20
PROD1
DRILL
PULD
T
PD BHA #4 L1 Drill Assembly #2 (new
0.0
80.0
08:00
09:12
Inteq tools, same agitator, same
motor, & RB A3 bit)
6/4/2019
6/4/2019
1.60
PROD1
DRILL
TRIP
T
RIH w/ BHA#4, shallow test tools,
80.0
8,225.0
09:12
10:48
pumping 1.84 bpm, dp = 1450 psi,
pump = 4980 psi
6/4/2019
6/4/2019
0.30
PROD1
DRILL
DLOG
T
Log HRZ for -11'correction
8,225.0
8,273.0
10:48
11:06
6/4/2019
6/4/2019
0.60
PROM
DRILL
TRIP
T
Continue RIH
8,273.0
9,425.0
11:06
11:42
Page 3113 ReportPrinted: 9110/2019
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
� I bi
':li (i ) �nfn
- I - —u1J
1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate
Performed E] Pull Tubing E] 0 -
shutdown L]Suspend ❑ Perforate E]Other Stimulate ❑ Alter Casing
E] Change Approved Plug for Redrill ❑ erforate New Pool ElRePair Well ❑ Re-enter Susp Well El Other: Cement Resin Packern
Ej
2. Operator 4. Well Class Before Work: El
Name: ConOCOPhillipS Alaska, Inc. 5. Permit to Drill Number:
Development O Exploratory E]184-020
3. Address: P. O. Box 100360, Anchorage, Alaska Stratigraphic❑ Service ❑ 6. API Number:
99510
7. 50-029-21076-00-00
Property Designation (Lease Number):
e. Well Name and Number:
ADL 25657 KRU 2F-07
9. Logs (List logs and submh electronic antl printed data per 20AAC25.071): 10. Field/Pool(s):
N/A Kuparuk River Field / Kuparuk River Oil Pool
FDepth
n Summary:
measured feet
9,055 Plugs measured 8417 feet
true vertical 6,254 feet Junk measured
8890/8894 feet
measured 8,417 feet Packer measured
8,405 feet
true vertical
5,820 feet true vertical
5,812 feet
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 78 feet 16 109' MD 109' TVD
SURFACE 3,696 feet 9 5/8 " 3,727' MD 2889' TVD
PRODUCTION 9,025 feet 7 9,051' MD 6251' TVD
Perforation depth: Measured depth: 8554-8564 8638-8657 8674-8728 8778-8784 feet
True Vertical depth: 5911-5919 5968-5981 5992-6029 6063-6067 feet
Tubing (size, grade, measured and true vertical depth) 3.5"— J-55
8,434' MD 5,831' TVD
Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER FHL
8,405' MD 5,812' TVD
SAFETY VLV - OTIS OLP SSSV 1,953' MD 1,832' TVD
12. Stimulation or cement squeeze summary:
Intervals treated (measured): N/A
Treatment descriptions including volumes used and final pressure:
2AA
Representative Daily Average Production or Injection Data
Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation: 45 41 566 1200 154
Subsequent to opera0on: 45 41 566 1200 154
hments (requires Per zo nAc zs.o7o, z5.o71, a zs.29a) 15. Well Class after work:
ort of Well Operations O Exploratory ❑ Development 2 Service ❑ Stratigraphic ❑ Logs and Surveys Run ❑ 16. Well Status after work:Oil OGas ❑ WDSPL ❑nd Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑eby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
318-571
d Name: Steve Drake Contact Name: Steve Drake
Title: Sr. Wells En sneer Contact Email: Steve.G.Drake@cop.corn
Authorized Signature: DateContact Phone: (907) 263-4062
: /
L 9 �! q
Form 10-404 Revised 4/2017 /J Q//B D M Si ✓
�L JUL 0 0 2019 Submit Original Only
2F-07
CEMENT RESIN PACKER
DTTMSTJOBTYP SUMMARYOPS
4/2/19 ANNCOMM RECOVERED BTM PORTION OF CEMENT RETAINER (PICTURE IN
ATTACHMENTS) IN TOP OF AVA CATCHER @ 8414' RKB; PULLED AVA
CATCHER AT SAME; EQUALIZED AND ATTEMPT TO PULL RBP @
8417' RKB (UNABLE TO LATCH UP). JOB SUSPENDED DUE TO
HIGHER PRIORITY WORK.
4/6/19 DRILLING (PRE -CTD) : TREE VALVE TESTS: SV, SSV, MV POSTIVE & NEGATIVE
SUPPORT- PRESSURE TESTS (ALL PASSED)
CAPITAL
4/18/19 ANNCOMM BAILED FILL FROM AND PULLED RBP @ 8417' RKB. JOB COMPLETE.
5/3/19 DRILLING TAGGED TD @ 8779' RKB (EST. 60F FILL); MEASURED BHP @ 8854'
SUPPORT- RKB (3748 PSI); DRIFT W/ 17' DMY BAKER WHIPSTOCK DOWN TO
CAPITAL 8773' RKB. JOB COMPLETE & READY FOR E -LINE.
5/9/19 DRILLING RIG UP ELINE. RIH WITH CALIPER. TOOL SHORT DOWNHOLE. POOH
SUPPORT- INVESTIGATE. LAY DOWN FOR THE NIGHT. JOB CONTINUED ON
CAPITAL 05/10/2019.
5/10/19 DRILLING RIG UP ELINE. LOG CALIPER FROM 8750' TO SURFACE. JOB
SUPPORT-
COMPLETE.
CAPITAL
5/11/19 DRILLING
RIH WITH LEFT HAND 2.80" (GR CONFIRMED NOGG) TAPERED MM
SUPPORT-
MILL AND MOTOR BHA TO 8392' CTMD TAG. MILL ON NIPPLE FOR 6
CAPITAL
HOURS WITH 35 STALLS AND 25K - 28K OVERPULLS ON PIPE
5/12/19 DRILLING
DRY TAG AT 8393' CTMD WITH LH 2.795" ROUND NOSE MM MILL AND
SUPPORT-
MOTOR BHA. MILL AT 8388'- 8390' CTMD CONSISTENTLY WITH PR =
CAPITAL
1.40 TO 1.65 BPM, UNABLE TO MILL PAST NIPPLE. PUMPED 580 BBLS
SSW AND 340 BBL S. DIESEL WHILE MILLING AN ADDITIONAL 8.90
5/14/19 DRILLING
RIG UP ELINE. LOG PDS MEMORY CALIPER FROM 8765' TO
SUPPORT-
SURFACE.RIG DOWN ELINE. JOB COMPLETE.
CAPITAL
5/16/19 DRILLING
STALL TAG 2.75" D -NIPPLE AT 8417.9' CTMD. START MILLING WITH 7
SUPPORT-
STALLS THEN MILL NIPPLE WITH 2.80" PARABOLIC MILL PUMPING
CAPITAL
1.60 BPM SSW. RIH TO DRY TAG IN 7" AT 8791' CTMD. POOH FREEZE
PROTECTING COIL AND TUBING FROM 3100'. MILL GR 2.801" GO AND
2.79" NOGG ON RETURN TO SURFACE. JOB COMPLETE.
5/23/19 ANNCOMM
RAN 2.63" OD NS HIGH EXPANSION WHIPSTOCK. TIE INTO K1
MARKER AT 8426' MD. SET TOP OF WHIPSTOCK AT 8645' MD AT 0°
ORIENTATION.
KUP PROD WELLNAME 2F-07 WELLBORE 2F-07
r..'
Ctl''i
Well Attributes Max Angle & MD TD
MaSka, InC.
tlName Wall re PYUWI WeIIWreSUIus [I ) MDIXXB) A[ran�IM1RB)
KUPARUK RIVER UNIT 50029210.600 PROD 5.88 2,400.00 9,055.0
Comment X]$(Ppmt DWe Annotation
SSSV: LOCKED OUT JS 12/92016 Last WO'.
Fno Gale NBGrd IXI Rp Rekase Dare
91)011984 2900 31]/1984
3.OFFCV6.Ue.a2PM
Last Tag
Veadess em0[Ismal)
AnnabOon I DepMaid(B)EnOpah Welbore East MM By
Last Tag'. RKS 8,)95. DU.19 2F-0] conarw
__. ____........._.................
XPNGER: Y.B
_.
Last Rev Reason
AnnolNbn
Entl 00M
Wellaore CalW By
Rev Reason: SET HIGH EXPASI N WHIPSTOCK, NIPPLE MILLED
5/23/2019
2F-0] D.nd,
OUT, UPDATE TAG
Casing Strings
Casing Des[ripson ODlin) IDUnl TaPaMBI Sat Deptnlln(B) SN gaiOVOL_ WVL ll_. Greas Top Tnreatl
CONDUCTOR 16 1506 31.0 1090 109.0 62.50 H40 WELDED
..�� CONDUCTORI31Otrfl0
Casing DescriptionOO (in)IG(inl Top ad(BI aeL Gepin lnRB) SN Deprn INOL_ WULan ll_. Gratle Tap e.
SURFACE 958 8)6 30.9 3,]268 ?888.8 3600 J-55 BTC
18TC
Casing Description oD On) rD(m) TopM1 see cepm(lntal sn ceptn,WDL.... p_-GrWe Top I.
PRODUCTION 7 6.28 26.0 8 9,051.0 6,250.8 2600 J-55
Tubing Strings
sAFETrav; l,eao
rnLlne Deserbnon svl,p Ma... IDant Top ryG(at see cepin m.. set Daptn IND11...W10WM GrWe TOPCon oecaan
TUBING 3112 2.99 235 8434.1 S,BJ1.5 9.30 J-55 EUEBrU
Completion Details
GIS LIFT ', 2,CC.5
TTop MD) Too- NoWna
op an(BI (PIKE) I, Xam Des Co. 10 (In) l
236 236 OD] HANGER FMCGEN IITUBINGHANGER 3.500
1,953.0 1.832.1 4290 SAFETPVLV GLPSSSV(LOGKED U / w)CL TRA KTU 2.812
PRESSURE
8,391.0 5,8026 48.03 PBR BAKER PER 3.000
SURFACE; a0.e3,72s8-
8404.9 5,812.0 48.03 PACKER BAKER FHL 3.000
8,421.3 5,822.9 48.01 WFIRILE- CAMEO D NIPPLE, MILLED OUT TO 2.80' ON S-16-19 2.800
GIS UFT: a,]aea
MILLED OUT
8,433.3 5,830.9 48.00 T69_ CANICO SHEAR OUT - TTL ELMD @ U46 ON SWS PPROF 2.992
829/2004
OaS LIFi:8.91]<
Other In Hole (Wireline retrievable plugs,
valves, pumps, fish, etc.)
Top InKBI
Top(TVD)
(.B)
Topincl
r)
Des
Co.
Run Gale
ID lin)
86450
5,9728
4]]0
WHIPSTOCK
N HERN BOLUTI NS, HI H ANSION
92312019
0000
Gas LIFT. a3]a4
WHIPSTOCK, TOW AT 8645, 0° ORIENTATION, TIED
INTO Kt MARKER AT 8426 MD
PaRawn a
--8-87-0
. 40 2
4657 1
FISH
12 KOT KICK SPRING LOST 518" WIDE, 3.5" LONG
32312011
1].000
8.8940
6,142.9
4657 IFISH
100gual Completion PKR Leftin hole during workover
1012/1984
PRCKE0.;a101.9
Perforations 8 Slots
sone
Dens
mpmG)
BrMI (rvD)
(aoaMm
NIPPLE -MILLED OUT', 8.4213
uau a.41a4++,9504
_
Top IXKBt
BM("'Kin
VDDR
MIKE)LinMtl
Zone
Ding
)
TateCom
8,5540
8564.0
5,9118
5,9185
C4,UNITB,
-07
12f22119O
4D IPERF
JU aeg.'V'Phasing,
EnerJel
sos. e.4».3
8,638.0
8, 7.0
5,9fi8.i
5,980.8
A-5 2F-07
4/3/1984
4.0 IPERF
ag, Phasing, '
Schlum. Casing Gun
8,6740
8,728.0
5,9923
6,028.
RF -07
4/3/1984
4.0 I -P
-ERF-
UrNg Phasing, "
Schian. Casing Gun
PERF, a551,09,5i
gp80
8,784.0
Q063.1
6,06)2
A-,2FAJ
V311984
4.0 IPERF
eg. hasing, "
Schlum. Casing Gun
Mandrel Inserts
St
ad
NTOP Tag)Wive Latch PMS. TRORun
TaPMKB) ME) MMe MCMI OD IIn) sery Type Type (In) (psit Run OaY Com
2.065.5 1,912.1 MMH FMHO 1 GAS LIFT GLV BK 0188 1, 56. 31302019
2 4,)484 3,520.1 MMM FMHO 1 GAS LIFT OV BK 0.250 313012019
3 7.4 4.803.1 MMH FMHO 1 GAS LIFT DMV BK 0000 .0 2/1)2019
,.aF; BECE.'50
4 8,3)4.4 5,)91.6 MMH FMH 1 GAS LIFT DMV .01282019 =toWXIPSiOCK
B,Gso
LI
tlurin
g pkr
repair
IPERF;aB]apa]200�
IPERF', 9.TI86a,]B1.0
FISH:88ECC
FISH', a... -
...
PRODUCTRW: at O9,re10J
PRODUCTION.
Originated:
Schlumberger
PTS- PRINT CENTER
6411 A Street
Anchorage, AK 99518
(907)273-1700 main (907)273-4760fax
Delivered to:
11 AOGCC
� ATTN: Natural Resources Technician 11
Alaska Oil & Gas Conservation Commision
333 W. 7th Ave, Suite 100
-41k Anchorage, AK 99501
18 40 20
is
TRANSMITTAL DATE
TRANSMITTAL#
Schlumberger -Private
VS -11.
PRoAcTivE DiAgnostic SERVICES, INC.
WELL LOG
TRANSMITTAL
To: AOGCC
Natural Resources Technician
333 West 7th Avenue
Suite 100
Anchorage, Alaska 99501
(907) 793-1225
RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection (Caliper / MTT)
The technical data listed below is being submitted herewith. Please acknowledge receipt by
returning a signed copy of this transmittal letter to the attention of :
1) Caliper Report
2)
Signed
Print Name:
ProActive Diagnostic Services, Inc.
Attn: Diane Williams
130 West International Airport Road
Suite C
Anchorage, AK 99518
Ddsan choraae(&memorvloa.com
14 -May -19 2F-07
1 Report / CD
0c.% ._. -
. „=%.*rIVE p
MAY 21 2019
AOGCC
50-029-21076-00
Date: (rj2j/iq
PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518
PHONE: (907)245-8951 FAX: (907)245-8952
E-MAIL: PDSANCHORAGE(&MEMORYLOGCOM WEBSITE: WWW.MEMORYLOG.COM
18 40 20
30 82 6
D:!\cLves\Mesta TftmplatePilce,Templates\Df tibuton,Trm@mItINShE2ts\CnnocoPhillips_Tie itdocx
am
Memory Multi -Finger Caliper
Log Results Summary
Company:
ConocoPhillips Alaska, Inc.
Well:
2F-07
Log Date:
May 14, 2019
Field:
Kuparuk
Log No.:
14379
State:
Alaska
Run No.:
1
API No.
50-029-21076-00
Pipe Description:
3.5 inch 9.3 Ib. J-55 EUE 8RD
Top Log Interval:
Surface
Pipe Use:
Tubing
Bottom Log Interval:
8,420 Ft. (MD)
Pipe Description:
7 inch 26 Ib. J-55 EUE
Top Log Interval:
8,420 Ft. (MD)
Pipe Use:
Casing
Bottom Log Interval:
8,751 Ft. (MD)
Inspection Type: Corrosive and Mechanical Damage Inspection
COMMENTS:
This caliper data is correlated using Gamma Ray referencing a Gearhart Cement Bond Log
This log was run to assess the condition of the tubing and casing with respect to internal corrosive and
mechanical damage, particularly around the Camco D Nipple following milling operations. The caliper
recordings indicate apparent mill damage from -8,248 feet to -8,250 feet where a 32% wall penetration is
recorded. A 3-D log plot of the caliper recordings from 8,200 feet to 8,420 feet, which highlights the
apparent mill damage and the Camco D Nipple is included in this report.
The caliper recordings indicate the remainder of the 3.5 inch tubing appears to range from good to fair
condition, with wall penetrations between 20% and 21 % wall thickness recorded in 4 of the 270 joints logged.
No significant areas of cross-sectional wall loss or I.D. restrictions are recorded.
The caliper recordings indicate the 7 inch casing appears to range from fair to poor condition with respect to
internal corrosive and mechanical damage, with wall penetrations between 23% and 81 % wall thickness
recorded outside of the perforation intervals throughout the casing logged. Maximum cross-sectional wall
loss of 23% metal volume is recorded outside of the perforation intervals in joint 7 (8,614 ft). Light to Heavy
Deposits are recorded throughout the casing logged, restricting the LD, to 5.49 inches at 8,559 feet. A graph
illustrating minimum recorded diameters on a joint -by -joint basis across the casing logged is included in this
report.
3,5 INCH TUBING - MAXIMUM RECORDED WALL PENETRATIONS:
Description
Percent Wall Penetratlor�
do i,r,.
Apparent Mill Damage
32
260
8,250 Ft. (MD)
Line Corrosion
21
216
6,846 Ft. (MD)
Line Corrosion
20
252
7,990 Ft. (MD)
Line Corrosion
20
249
7,906 Ft. (MD)
Line Corrosion
20
245
7,764 Ft. (MD)
3.5 INCH TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS:
No significant areas of cross-sectional wall loss (> 11 %) are recorded.
3.5 INCH TUBING - MAXIMUM RECORDED ID RESTRICTIONS:
No significant I.D. restrictions are recorded.
ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497
Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalvsis(a)memorvloo com
Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314
7 INCH CASING - MAXIMUM RECORDED WALL PENETRATIONS:
I),,., i t>>n
Percent Walt Penetration
,, l
Corrosion
81
5
8,590 Ft. (MD)
Corrosion
79
6
8,598 Ft. (MD)
Corrosion
74
7
8,614 Ft. (MD)
Line Corrosion
43
4
8,551 Ft. (MD)
Line Corrosion
36
3
8,476 Ft. (MD)
7 INCH CASING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS:
Corrosion 24 7 8,614 Ft. (MD)
Corrosion 23 5 8,590 Ft. (MD)
Corrosion 22 6 8,599 Ft. (MD)
No other significant areas of cross-sectional wall loss (> 6%) are recorded outside of the perforation intervals
throughout the casing logged.
7 INCH CASING - MAXIMUM RECORDED ID RESTRICTIONS:
I� r,:inu Minimum Recoided Diameter I:)int
Heavy Deposits 5.49 5 8,559 Ft. (MD)
Heavy Deposits 5.54 4 8,519 Ft. (MD)
Heavy Deposits 5.74 3 8,497 Ft. (MD)
No other significant I.D. restrictions are recorded throughout the casing logged.
C. Goerdt C. Waldrop J. Fama
„t
ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497
Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalvsis(a)memorvloo com
Prudhoe Bay Feld Office Phone: (907) 659-2307 Fax: (907) 659-2314
r�
E
L
a
ro
...5.... ._ �N�
_-_ . R�.•� C. -Y_..-_ __
Correlation of Recorded Damage to Borehole Profile
Pipe 1 3.5 in (18.5'-8,420.0') Well: 2F-07
Pipe 7. in (8,420.0'-8,751.0') Field: Kuparuk
Company: ConocoPhillips Alaska, Inc.
Country: USA
Survey Date: May 14, 2019
1
■
Approx.
Tool Deviation
■ Approx.
Borehole
Profile
23
11
775
1,565
GLM 1
75
�
t
2,378
3,168
�1
125
3,957
�
i
GLM 2150
4,744 °-
O
175
5,532
11
6,321
GLM 3
7,118
7,908
GLM 4
8,420
10
8,715
0
50
100
Damage
Profile
(%
wall) /
Tool Deviation
(degrees)
Bottom of Survey =
10
■ Perforations
1
11
�
t
�1
�
i
Pipe Nom.OD Weight Grade &Thread Nom.ID Top Depth Bottom Depth
3.5 in. 9.3 ppf 1-55 EUE 8RD 2.992 in 19 ft 8,420 ft
Damage Profile (% wall)
Penetration body Metal loss body
0 50 100
GLM 1 (3:00)
GLM 2 (2:00)
GLM 3 (4:00)
GLM 4 (9:00)
Bottom of Survey = 263.9
PDS Report Overview
S
Body Region Analysis
Well:
2F-07
Survey Date: May 14, 2019
Field:
Kuparuk
Tool Type: UW MFC 24 Ext. No. 10011398
Company:
ConocoPhillips Alaska, Inc
Tool Size: 1.69 inches
Country:
USA
No. of Fingers: 24
Pipe
3.5 in. 9.3 plof -55 EUE 8RD
Analyst: Waldro
Pipe Nom.OD Weight Grade &Thread Nom.ID Top Depth Bottom Depth
3.5 in. 9.3 ppf 1-55 EUE 8RD 2.992 in 19 ft 8,420 ft
Damage Profile (% wall)
Penetration body Metal loss body
0 50 100
GLM 1 (3:00)
GLM 2 (2:00)
GLM 3 (4:00)
GLM 4 (9:00)
Bottom of Survey = 263.9
ii4-s
Well: 217-07
Field: Kuparuk
Company: ConocoPhillips Alaska, Inc.
PDS
Report Joint Tabulation
Survey Date: May 14, 2019
Analyst: Waldrop
Sheet
Pipe Description
3.5 in. 9.3 ppf J-55 EUE BIRD Tubing
Nom. ID Body Wall Top Depth Bottom Depth
2.992 in. 0.254 in. 19 ft 8,420 ft.
Joint Jt. Depth
No. (Ft.)
Pen.
Upset
(in.)
Pen.
Body
(in.)
Pen.
%
Metal
Loss
%
Min.
I.D.
(in.)
Comments
Damage Profile
(% wall)
0 50 100
.1 7
0
3
1
7
.9
Pu
1 23
0
0.03
11
.97
2 54
0
0.-3
11
4
2.95
3 86
0
00.
11
5
2.95
4 118
0
0.03
10
4
2 9
5 149
1 0
0.04
15
4
2.96
Shallow -:,I--
itfin
6
6 187
1 0
0.03
1
3
2.98
7 211
1 0
1 0 0
4
2. 6
8 243
0
0.03
73
6
2.98
9 275
0
0.04
14
7
10 306
0
0.03
10
3
2.98
11 337
0
0. 2
4
96
12 368
2
2
13 400
0
0.03
10
2
2.96
4 429
0
1
4
2 8
15 459
0
0 OA
14.3
2.
16 490
0
0.02
7
3
2.98
17 5 2
0
0. 3
11
4
2.
5
0
0.03
10
19 585
0
0.04
15
4
2.96
Shallow Pitfin .
17
0
0.0
11
2 64
0
0.03
11
7
22 680
0
0.02
9
4
2.97
3 71
0.0
10
4
2.97
4 74
0
0.03
1 t
4
.98
25 775
0
0.02
9
4
2.96
8
0
0.03
10
2.96
27 838
0
0.03
12
5
2.96
28 70
0.0
10
3
2:97
2 901
0
.03
11
30 933
0
0.03
12
2
2.98
31 6
0
0.0
13
996
0
0 04
14
33 1028
0
0.03
12
4
2.95
3 3060.0
12
4
2.9
35 7091
0
0.03
11
4
.96
36 1123
0
0.02
9
4
2.96
37 11
0
0.03
1
4
2.98
1186
0
0. 3
10
2,98
39 1217
0
0.02
9
3
2.96
40 1 4-
0
0.03
10
3
2.99
11281
0
.03
11
8
42 1312
0
0.04
16
4
2.98
Shallow Line of Pits.
43 1344
0
0.02
9
5
.95
44 1375
0
0.02
9
2
2.97
45 1 07
0
0.
1
3
2.
46 14
0.03
13
3
2 9
47 1470
0
0.03
11
4
2.96
48 1 1502
0. 2
9
4
2. 7
49 1 4
0
0.
8
3
2.9
Penetration Body
Metal Loss Body
Page 1
ii4-s
Well: 2F-07
Field: Kuparuk
Company: ConoccPhillips Alaska, Inc.
PDS
Report Joint Tabulation Sheet
Survey Date: May 14, 2019
Analyst: Waldrop
Pipe Description
3.5 in. 9.3 ppf
J-55 EUE 8RD
Tubing
Nom. ID
2.992 in.
Body Wall Top Depth Bottom Depth
0.254 in. 19 ft 8,420 ft.
Joint Jt Depth
No. (Ft.)
Pen.
Upset
(in.)
Pen.
Body
(in.)
Pen.
%
Metal
Loss
%
Min.
I.D.
(in.)
Damage Profile
Comments (% wall)
0 50 100
50 1565
0
0.036
51 159 7
0
0.03
11
5
2.96
52 1629
0
0.03
10
4
2.96
3 1660
0
0.02
8
q
2.96
54 2
0
0.03
12
2
2.97
55 1724
0
0.03
11
5
2.97
1
0.
13
1 2
2.9
57 1787
0
.03
1
4
.96
58 1819
0
0.02
9
3
2.96
185
0
.04
16
.96
Shall
60 1882
0
0.03
11
3
2.96
61 1
0
0.0
11
2
2.91
Lt. osits
61.1 194
0
0.02
8
.99
Pu
61.2 1946
0
0
0
0
2.79
OTIS LP SSSV
61. 196
0
0.02
9
.99
P
6 1963
02
2
De Its
631993
0
0.02
9
4
2.96
6 025
0
.04
15
9
hallow ittin
64.1 2Q56
0I
Q0
0
GI kA i 11 AT11
1,0I
65 2063
0
0.02
9
4
2.93
Lt. osits.
66 94
0
.0
4
96
67 1 2126
1 0 1
0.03
13
3
2.
68 21 8
0
0.02
8
4
2.96
69 2189
0
9
4
2 7
70 1 2221
1 0
0.
9
3
2.9
712252
0
0.03
11
2
2.96
72 2 4
0 0
11
3
2.
73 1 2316
1 0
0.02
9
5
2.94
74 1 2347
1 n
0
9
2
2
23 8
0
0.0
13
4
2. OR
76 2410
0
0.03
13
4
2.98
7 1 2441
0
0.
11
5
2. 6
8 2473
0
o.04
15
4
2.97
Sha 11 wPit'
79 2505
0 1
0.03
12
4
2.97
W25 6
0.
11
2
2.
1 2
0.n
13
4
2.9
82 2600
0 1
0.03
11
4
2.97
8331
0
11
5
2.
84
0
0.0
12
4
2.97
85 2694
0
0.04
15
8
2.95
Shallow Pittin .
86 611
4
2. 7
87 27
1
0.03
11
.96
88 2789
0
0.03
12
3
2.96
89 821
0.
12
4
2.
90 2852
0
0.03
11
4
2.98
1 1 2884 1
0 1
n 04
7
allow i of 't
.
9216
1
4
2,
93 2947
0
0.03
13
5
2.96
24 979
0
.03
11
.92
Lt. De sits.
95 3010
03
11
5
Penetration Body
Metal Loss Body
Page 2
ii S,
Well: 2F-07
Field: Kuparuk
Company: ConocoPhillips Alaska, Inc.
PDS
Report Joint Tabulation
Survey Date: May 14, 2019
Analyst: Waldrop
Sheet
Pipe Description
3.5 in. 9.3 ppf J-55 EUE
8RD Tubing
Nom. ID Body Wall Top Depth Bottom Depth
2.992 in. 0.254 in. 19 ft 8,420 ft.
Joint Jt. Depth
No. (Ft)
Pen.
Upset
Pen.
Body
Pen.
%
Metal
Loss
%
Min.
I.D.
(in.)
Comments
Damage Profile
(% wall)
0 50 100
6 04
8
2
2.9897
0731
2
2.97
98 3105
10
4
2.97
9 313 7
A(in.)(in.)
2
2.96100
16811
2
.96
101 3200
11
2
2.95102
3 3212
3
.96
103
1
95
104 3295
0
0.02
8
2
2.96
OS 3327
0
0.03
11
.96
106 3358
0
0.02
9
4
2.93
107 39
.0
9
2
2.95
108
0
0.03
4
.96
109 3453
0
0.03
12
3
2.98
110 5
0
0.02
9
4
8
3516
0
.03
1
2
112 3548
0
0.03
11
4
2.95
113 3
0
.03
11
2. 5
17 3611
1 0 1
O.03
1
2.
115 36430
1
0.04
6
2
2.95
ShallowPittin .
1 3674
00.031
2.
717 1 3706
0
11
3
.91
Lt. its.
118 1 3738
0
0.03
12
3
2.96
11 376
0
2
2.
120 38 1
0.
0
2.95
1213832
0
0.03
11
4
2.94
1 865n
I
0 2
9
3
2.9
123 3893
0
0.02
9
3
2.94
124 3925
0 1
0,028
3
2.
125 3957
0 1
nn4
6
2.95
hallo ine of its.
726 32 86
0
0.03
13
4
2.94
4018
4
14
2
2.
Lt. osits.
128 1 4049 1
0 1
0
13
4
2.95
129 4081
0
0.03
13
4
2.95
1 4113
0
3
12
3
2
131 144
0.
12
2
2.96
132 4176
0
0.03
10
2
2.96
1 4207
0
10
2
2.9
4 39
0.
12
3
.96
135 4271
0
0.05
18
3
2.95
Shallow Pittin .
1 4302
0
10
3
2.95
137 1 4334 1
0
0.
11
.93
0
0.02
9
3
2.96
0
9
3
2.9
0
0.03
11
3
2.96
V1434521
0
0
2
2 6
0
03
1
2
2
0
0.02
9
2
2.93
0
0.02
4
0
02
2
2.
Penetration Body
Metal Loss Body
Page 3
iias,
Well: 2F07
Field: Kuparuk
Company: ConocoPhillips Alaska, Inc.
PDS
Report Joint Tabulation
Survey Date: May 14, 2019
Analyst: Waldrop
Sheet
Pipe Description
3.5 in. 9.3 ppf
J-55 EUE
8RD Tubing
Nom. ID Body Wall Top Depth Bottom Depth
2.992 in. 0.254 in. 19 ft 8,420 ft.
Joint Jt. Depth
No. (Ft.)
Pen.
Upset
(in.)
Pen.
Body
(in.)
Pen.
%
Metal
Loss
%
Min.
I.D.
(in.)
Comments
Damage Profile
(%wall)
0 50 100
1 6 461 1
0
2
147 4643
3
12
3
2.96
148 4675
0
0.02
9
4
2.96
149 4706
0
0.04
17
=
2.92
Shallow Pitting. I t. Der)Qsits.
149.1 4738
0
0
0
0
2.91
Q LLA 2 (LATCH @ 2 :0
150 4744
0
0.02
9
1 2
2.96
151 47760
0.0
11
4
.95
152 4
0
0.03
11
1 2
5
153 4839
0
0.04
15
1 4
2.94
Shallow Pitlin .
154 4871
0
0.02
9
9
155 4902
0
1 0.03
10
3
.94
156 1 4934ino.
10
157 4
2
2.
158 4997
9
2
2.96
159
2
0 5060
5
2.
161 5092
12
2
2.96
6 5124
10
3
2. 5
1 5155
17
364
5187
10
36
5 1
12
4
2.
Lt.DeoosiN.
166 5250
0
0.02
9
4
2.91
1 Lt. De its.
1675282
0
0.03
12
3
2.92
Lt. De osits.
1 531 3
0
3
2.9
169 1 5345
1 0 1
0.03
11
4
.92
t. De o its.
1705377
0
0.04
17
9
2.89
Shallow Pittin . Lt. De osit
171 5408
00.
13
1
2.88
t. De it .
172 5438
0
0.03
13 1
2.90
Lt. De osits.
173 1 469 1
0 1
ftQ4
16
3
2.87
Shall w ine f . Lt. e osi
174 1 5501
0 1
0.
13
3
. 5
175 5532
0
0.03
12
1
2.86
Lt. De osits.
17 5563
0
14
3
28
Lt. De sits.
17 5595
0. 3
11
9
. De osis.
178 5626
0
0.03
13
5
2.92
Lt. De osits.
7 5657
0
Q.04
15
3
2.86
hall w ittin . De 'fs.
180 1 5689
0
0.05
19
4
.88
allow Pit'n e osi
181 1 5720 1
0 1
0.04
14
2
2.86
Lt. De osits.
182 1 5752 1
0
0.
11
4
.91
t. De 'ts.
1 783
0.
9
.92
1845815
0
0.04
14
4
2.91
Lt. De osits.
1 155 47
0
0.
11
2. 2
t. Denosits.
186 5878
0.03
11
6
2.92 1
Lt. Denosits.
187 5910
0
0.04
14
6
2.91
Lt. De osits.
88 5941
0
3
2.92
Lt. De s' s.
189 5973
0
0.04
15
4
2.90
Shallow Pitt-
itti
190
190 6
0
.03
11
4
2.
Lt. sits.
191 6036
0
0.03
11
2
2.9
t. De its.
192 6068
0
0.02
9
3
2.92
Lt. Deposits.
193 61 QQ
0
0.03
12
4
2.b2
Lt. Deposits.
1 4 61 1
00,03
10
3
2.21 1
It. DepQsils.
Penetration Body
Metal Loss Body
Page 4
ji-�S,
Well:
Field:
Company:
217-07
Kuparuk
ConocoPhillips Alaska, Inc.
PDS
Report Joint Tabulation
Survey Date: May 14, 2019
Analyst: Waldrop
Sheet
Pipe
Description
3.5 in. 9.3 ppf
J-55 EUE 8RD
Tubing
Nom. ID Body Wall Top Depth Bottom Depth
2.992 in. 0.254 in. 19 ft 8,420 ft.
Joint
No.
Jt. Depth Pen.
(Ft.) Upset
(in.)
Pen.
Body
(in.)
Pen.
%
Metal
Loss
%
Min.
I.D.
(in.)
Comments
Damage Profile
(% wall)
0 50 100
195
0
603
11
5
2.89
Lt. De its.
196
6194
0
0.03
11
9
Lt. Qeuosits.
197
6226
0
0.04
17
4
2.86
Shallow Line of Pits. Lt. Deposits.
198
6258
0
0.03
10
4
2.91
U Q-Qi2osiI5.
199
289
0
0.03
13
5
2.91
Lt. Devosits,
200
6321
0
0.03
12
4
2.89
Lt. De osits.
2
6353
0
1
2
Lt. sit .
202
6384
0
1 0.03
13
7
2 AS
Lt. Deposits.
203
6416Q
0.03
12
5
2.90
Lt. De osits.
204
4 8
0
13
5
2.87
Lt. Deposits.
205
64747n
0.03
11
5
2.90
Lt. Deposits.
65
1
4
2.8
Lt its.
207
40.
9
3
.90
t. sits.
208
6570.03
10
4
2.89
Lt. Deposits.
209
600.
11
5
2.8
t. i s.
10
6 30.04
14
8
2.90
De
211
6669
1 0
0.03
10
4
2.87
Lt. De osits.
212
6700
1 0 1
0.03
11
3
.88
t. 'ts.
13
6732
0
0. 33
4
.88
o i .
214 1
6764
1 0
0.03
11
4
2.91
Lt. De osits.
14.1 1
6796
1 0
0
0
.87
3 TCH n,4:00
215
6802
1 0 1
0.04
16
4
1
Sh w Li of Pi Lt. De its.
216 1
6834
1 0.04
0.05
21
5
2.92
Line Corrosion. Lt. De osits.
17 1
6866
1 0
0.04
17
3
Sh low i of Pi . Lt. D osits.
218 1
897
1 0
04
17
2.9
f Pits.
Sh I w Lin23
219
6928
0
0.03
11
4
2.95
0
696
00.04
15
4
2. 4
S l w Lin of Pits.
221 1
6992
1 0
0.04
14
3
2.94
2
7023
0
1
0.03
12
4
o is.
223
7055
-Q
0.05
IS
6
2.
Shall w Lin Pits. t. D its.
224
7086
1 0
0.04
16
5
2.89
Shallow Line of Pits. Lt. De osits.
25
711
0
0.0
14
De o
26
7149
1 0 1
0
15
6
2.
Shall wPit' . L. osits.
227 1
7181
1 0
0.04
14
4
2.94
28 1
7213
0
0.03
12
4
2.
osi
9 1
7244
li 0
0.04
14
6
2. 1
Lt. osits
230 1
7276
0
0.03
13
6
2.90
Lt. De osits.
31 1
7307
0
0.04
1
2.
Sh w Lin QQ12Qsits.
232 1
7339
0
13
4
2.9
L. De osits.
233 1
7371
0
0.05
19
4
2.93
Shallow Line of Pits. Lt. Deposits.
234 1
7402
0
0.04
4
4
. 1
Lt. ----
25 1
7434
0
17
6
Shall Lin f Pits. Lt. Deposits.
236 1
7465
0
0.04
15
4
2.93
Shallow Pittin . Lt. Deposits.
237
74 7
0
0.04
14
0
De osi
238
7528
0
0.04
14
5
2.90
Lt. De osits.
23
7560
0
0.05
8
6
.90
How ' e of Pits. Lt. osits.
240
7592
0
-GMQ:"
13
.92
L. osi
241
7623
0
0.03
13
5
2.95
242
7655
0
0.04
15
.91
hallow 'n of P'
243
7687
0
.03
2
osi
Penetration Body
Metal Loss Body
Page 5
Ji S-
Well: 2F-07
Field: Kuparuk
Company: ConocoPhillips Alaska, Inc.
PDS
Report Joint Tabulation
Survey Date: May 14, 2019
Analyst: Waldrop
Sheet
Pipe Description
3.5 in. 9.3 ppf J-55 EUE
8RD Tubing
Nom. ID Body Wall Top Depth Bottom Depth
2.992 in. 0.254 in. 19 ft 8,420 ft.
Joint Jt. Depth
No. (Ft.)
Pen.
Upset
Pen.
Body
Pen.
%
Metal
Loss
%
in.
I.D.
(in.)
Comments
Damage Profile
(% wall)
0 50 100
4 7718
17
6
2.93
allow "ne of Ps. Lt. Deo its.
245 7750
0 1
0.05
20
5
2.94
in orro io .
246 7782
0 1
0.04
15
3
2.93
Shallow Line of Pits.
247 7813Q
1
fl4
17
7
.92
' allow Pi . Lt. sits.
248 845
0
3
13
4
2.94
249 7876
0
0.05
20
5
2.94
Line Corrosion.
50 7908
n
0.03
13
6
2.93
Lt. Deposits.
1 7939
1 0
0.04
17
6
2c)IShallow
Pitti
252 7971
0
0.05
20
4
2.92
Line Corrosion. Lt. De osits.
2530
4
15
4
2.
Shal Pi-
ittin
25 4 8034
M4
0
0.03
11
6
2.91
Lt. Deposits.
55 8066
0
0.04
16
4
2.94
ShallQw Line of Pits.
256 1 8097
0
0.04
14.
5
2.94
257 1 8129
0
0.03
11
4
2.96
8 8160
0
004
14
6
2.94
259 1 8192
0
0.03
11
4
.95
260 8224
0
0.08
32
11
2.97
A arentMillDama e.
61 1 82
.03
11
4
2.9
262 8287
0
oo4
14
7
3
263 1 8318
0
0.04
17
4
2.95
Shallow Line Corrosion.
263.1 8351
0.
10
1
.92
Lt. -:-
263.2 8360
0
0
0
n
0
4 AT H 0
263.3 8367
1 0 1
0.04
14
3
2.92
Pu Lt. De osits.
263.4 8377
0
0
0
.98
R P
263.5
0
0
0
0
7 qf
RAk'FR F141 P CKE
263.6 8397
0.25
0.02
9
3
2.92
P --p Probable Hole in U set! Lt. De osits.
263.7 8 07
0
2.74
CAMCO Q NIPPLE
263.8 8409
0
0.03
10
1 0 1
2.86
Pui2 Lt. Deposits.
263.9 6420
0n
0
1 0 14.87
ING L
Penetration Body
Metal Loss Body
Page 6
ji:�
Field:
Company:
Country:
2F-07
Kuparuk
ConocoPhillips Alaska, Inc.
USA
PDS Report Cross Sections
Survey Date:
May 14, 2019
Tool Type:
UW MFC 24 Ext. No. 10011398
Tool Size:
1.69
No. of Fingers:
24
Cross Section for Joint 260 at depth 8,249.540 ft.
Tool speed = 59
Nominal ID = 2.992
Nominal OD = 3.5
Remaining wall area = 89%
Tool deviation = 47°
Finger = 16 Penetration = 0.082 in.
ii� PDS Report Cross Sections
Well:
2F-07
Survey Date:
May 14, 2019
Field:
Kuparuk
Tool Type:
UW MFC 24 Ext. No. 10011398
Company:
ConocoPhillips Alaska, Inc.
Tool Size:
1.69
Country:
USA
No. of Fingers:
24
Cross Section for Joint 216 at depth 6,846.440 ft.
Tool speed = 55
Nominal ID = 2.992
Nominal OD = 3.5
Remaining wall area = 98%
Tool deviation = 52°
Finger = 15 Penetration = 0.053 in.
Line Corrosion 0.05 in. = 21% Wall Penetration HIGH SIDE= UP
ji --a
Well: 2F-07
Field: Kuparuk
Company: ConocoPhillips Alaska. Inc.
Country: USA
d
E
Z
Z
M
C
.O
c
10
Minimum Diameter Profile
Survey Date:
May 14, 2019
Tool Type:
UW MFC 24 Ext, No. 10011398
Tool Size:
1.69 inches
Tubing I.D.:
6.276 inches
Minimum Measured Diameters (in.)
1.75 2 3 4 5 fi
r
IEEE
ONE
8,420
6,421
3,466
3,509
1,552
c_
O
1,594 ?
a�+s
a
a
,612
,630
673
715
8,420
6,421
3,466
3,509
1,552
c_
O
1,594 ?
a�+s
a
a
,612
,630
673
715
PipeNom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth
7 in. 26 ppf 1-55 BTC 6.276 in 8,420 ft 8,757 ft
Damage Profile (%wall)
Penetration body Metal loss body
0 50 100
1
2
3
4
5
6
7
8 —
10
Bottom of Survey = 10 Perforations
PDS Report Overview
CP'S
Body Region Analysis
Well:
2F-07
Survey Date: May 14, 2019
Field:
Kuparuk
Tool Type: UW MFC 24 Ext. No. 10011398
Company:
ConocoPhillips Alaska, Inc.
Tool Size: 1.69 inches
Country:
USA
No. of Fingers: 24
Pipe
7 in. 26 ppf 1-55 BTC
Analyst: Waldrop
PipeNom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth
7 in. 26 ppf 1-55 BTC 6.276 in 8,420 ft 8,757 ft
Damage Profile (%wall)
Penetration body Metal loss body
0 50 100
1
2
3
4
5
6
7
8 —
10
Bottom of Survey = 10 Perforations
Penetration Perforations
Metal Loss Perforations
Page 1
Penetration Body
Mehl Loss Body
PDS
Report Joint Tabulation
Sheet
Well: 217-07
Survey Date: May 14, 2019
Field: Kuparuk
Analyst: Waldrop
Company: ConocoPhillips Alaska,
Inc.
Pipe Description
Nom. ID Body Wall Top Depth Bottom Depth
7 in. 26 ppf J-55 BTC Casing
6.276 in. 0.362 in. 8,420 ft.
8,751 ft.
Joint Jt. Depth Pen.
Pen.
Pen.
Metal
Min.
Damage Profile
No. (Ft.) Upset
Body
%
Loss
I.D.
Comments
(%wall)
(in.)
(in.)
%
(in.)
0 50 100
1410 0. 2
0.0
23
.99
in C r o ion. De o'
2 4 1 0.1
0.13
36
(
5.93
i Corrosion. Lt. Deposits.
3 8466 0.08
0.13
36
6
5.74
Line Corrosion. HeavyDeposits.
4 50 0.08
0.16
3
5
4
in rro ' n. He De 't .
5 8552 .20
0
81
23
5.4
Corrosion. Heavy De sits.
6 8594 0.22
0.29
79
22
6.02
Marker ointCorrosion. Lt. De osits.
7 8612 0.1
74
24
6.01
Mar Joint Corrosion.t. D osits.
8630 0.17
0,35
96
23
6.12
Perforations Lt. Deposits.
86730.15
ff,V
0.50
100
34
5.97
Perforations Lt. De osits.
71 5 0.10
31
6
5.97
Li e C rosion. Lt. De sits.
Penetration Perforations
Metal Loss Perforations
Page 1
Penetration Body
Mehl Loss Body
iiS� PDS Report Cross Sections
Well:
2F-07
Survey Date:
May 14, 2019
Field:
Kuparuk
Tool Type:
UW MFC 24 Ba. No. 10011398
Company:
ConocoPhillips Alaska, Inc.
Tool Size:
1.69
Country:
USA
No. of Fingers:
24
Tubing:
7 in. 26 ppf J-55. BTC
Analyst:
Waldron
Cross Section for Joint 5 at depth 8,590.011 ft.
Tool speed = 59
Nominal ID = 6.276
Nominal OD = 7
Remaining wall area = 81%
Tool deviation = 33°
Finger =8 Penetration = 0.295 in.
Corrosion 0.30 in. = 81% Wall Penetration HIGH SIDE = UP
JR—S PDS Report Cross Sections
Well:
2F-07
Survey Date:
May 14, 2019
Field:
Kuparuk
Tool Type:
UW MFC 24 &t. No. 10011398
Company:
Conoco Phillips Alaska, Inc.
Tool Size:
1.69
Country:
USA _
No. of Fingers:
24
Cross Section for Joint 6 at depth 8,597.730 ft.
Tool speed = 58
Nominal ID = 6.276
Nominal OD = 7
Remaining wall area= 82%
Tool deviation = 35°
Finger = 9 Penetration = 0.286 in.
Corrosion 0.29 in. = 79% Wall Penetration HIGH SIDE = UP
Ji4�s PDS Report Cross Sections
Well:
2F-07
Survey Date:
May 14, 2019
Field:
Kuparuk
Tool Type:
UW MFC 24 Ext. No. 10011398
Company:
ConocoPhillips Alaska, Inc.
Tool Size:
1.69
Country:
USA
No. of Fingers:
24
Cross Section for Joint 7 at depth 8,614.221 ft.
Tool speed = 58
Nominal ID = 6.276
Nominal OD = 7
Remaining wall area = 76%
Tool deviation = 50°
Finger = 10 Penetration = 0.269 in.
Corrosion 24%Cross-Sectional Wall Loss HIGH SIDE = UP
L"'Ci!m
CAI
PDS Report Cross Sections
Well:
2F-07
Survey Date:
May 14, 2019
Field:
Kuparuk
Tool Type:
UW MFC 24 Ext. No. 10011398
Company:
ConocoPhillips Alaska, Inc.
Tool Size:
1.69
Country:
USA
No. of Fingers:
24
_Tubing:
7 in. 26 ppf J-55 BTC _
Analyst:
Waldron
Cross Section for Joint 5 at depth 8,589.761 ft.
Tool speed = 59
Nominal ID = 6.276
Nominal OD = 7
Remaining wall area = 77%
Tool deviation = 14°
Finger = 8 Penetration = 0.295 in.
Corrosion 23% Cross -Sectional Wall Loss HIGH SIDE =UP
Ji4s,
Well: 2F-07
Field: Kuparuk
Company: Conoco Phillips Alaska, Inc.
Country: USA
PDS Report Cross Sections
Survey Date:
May 14, 2019
Tool Type:
UW MFC 24 Ext. No. 10011398
Tool Size:
1.69
No. of Fingers:
24
Cross Section for Joint 5 at depth 8,558.621 ft.
Tool speed = 59
Nominal ID = 6.276
Nominal OD = 7
Remaining wall area = 88%
Tool deviadon = 38a
Minimum I.D. = 5.491 in.
Heavy Deposits Minimum I.D. = 5.49 in. HIGH SIDE= UP
JRS, PDS Report Cross Sections
Well:
2F-07
Survey Date:
May 14, 2019
Field:
Kuparuk
Tool Type:
UW MFC 24 Ext. No. 10011398
Company:
ConocoPhillips Alaska, Inc.
Tool Size:
1.69
Country:
USA
No. of Fingers:
24
Cross Section for Joint 4 at depth 8,519.101 ft.
Tool speed = 60
Nominal ID = 6.276
Nominal OD = 7
Remaining wall area= 97%
Tool deviation = 51 °
Minimum I.D. = 5.540 in.
Heavy Deposits Minimum I.D. = 5.54 in. HIGH SIDE= UP
Conoco`Phillips
A9Gku, Inu.
KUP PROD WELL -NAME 2F-07
UNIT
OUT
WELLBORE 2F-07
u.dd,!mzme Tu.m PN
Last Tag
vM:celsMwr.eaaNep
Mnoach.Pym Real Fnd Dab WNWpre Laadmdd By
Led Tag: She (Est. 5' of Fill) 8,T]9.05I32019 2F-07 zembael
----
Last Rev Reason
RAN�,eR.za
ennaenon Fna9rte weneen Last Moa av
Rev Reason: Updated Tag Depth 5132010 2F0] zembael
Casing Strings
many omodpnon
CONDUCTOR
oo tail Wllnl Top IM(91
Y6 15.08 31.0
se[oapm 111(9) sXoaplM1 lTwL.. wllLen iL.ond. Top Thr9ea
109.0 109.0 62.50 H40 WELDED
71i
SURFAeaatlpnan
SURFACE
OD Ion) Wlln) Tap Ree,
95/3 8.76 309
SM.,n hayed get happen t i maj..ImLen ll..9rWa TOP Tinerd
3,]26.8 2,888.8 36.00 JI BTC
Ovmp 9padptlon
PRODUCTION
OO llnl IO QnI Top nn9l
] 6.28 28.0
SROepm ItM91 Sd 9ep1-111 ... YNLen II.. Oratle Top Thrptl
9,051.0 6,2408 26.00 b55 STC
Tolun9 Strings ..Trend,
cocippe. etrN9 me...n did Tap InN91 se[ Onpi6 ln.. an Oepu 111011,.. w11eNn1 orad.TUBING 3112 299 23.8 8,4341 5.8315 9.30 J$tl5A
IY ILCornpietlon
amus,
Top Iwo) Llgn TaP-a NaminL
1`'.-inOm cam 1o("
23.6 23.6 0.07 HANGER FMC GEN II TUBING HANGER 3500
rh Ud T,i Ifi55
1,953.0 1,832.1 4290 SAFETYVLV 07S OLP$SSV(LOCKED OUT 1/19(2000) CLTMCKTUSING 2.812
PRESSURE
8,3810 5,8028 48.03 1 PBA BAKER PBR 3.000
8,4048 5,812.0 48.03 PACKER BAKER FHL 3.000
8,421.3 5,622.9 48.01 NIPPLE CgMCODNIPPLE 2.J50
8433.3 530
,8.9 48790505 CAMCO SHEAROUT-TTLELMD@ B240'ON SWBPPROF 2992
6lIRFPCE, 3083.%.1 P�
8/292004
Other In HGlQ iWirelina Tetrn!vablQplugs, "Ives-, ; pumps;Wsh, etC.j'
19Ka1 T� nw) Top Incl
I 1°I oei Com Run 0.[1
GMUFT,a 74,14-
88900 8.1402 46.9 FISH 2KOT KICK SPRING$LOST 5/6' WIDE, 3.5- LONG 3232011 0.000
Do
-urTn4
01
8,884.0 8,142.9 46.9 FISH GriginalCompletlon PKR LeN in M1ole tluring wOrkover 1N2/1884
Perforations 8 Slots
ma[
ers LlFge.3r4e
To Me)
--ofteddl
Tept"o)
Kdom
9MI1wl
Inden
Linked zone
one
(added,
1
Type
eem
8,554.0
8,564.0
5,81 T8
5,918.5
C4,UNITB,2F
07
1222/1987
4.0
IPEgF
30 deg. YPhasing, 21/8"
EnerJak
Rap. I earl
8,8380
8,85].0
5,988.1
5,980.87
2F-07
4/3/1984
401PERF
90 deg. Phasing, r SchINm.
Coding Gun
3,8>q.0
8,]28.0
5,992.3
8,028.974.2FA2
413/1984
q,01PERF
90deg. Phasing, I phIom.
`. 'M k re19
Casing GM
B778.0
8,]84.0
6,063.1
6,067.2
A-3, 2F-07
4,3/1984
401PERF
90 deg. Phasing, 4'SMlum.
Cesing Gun
NPPLE. a<113
Mandrel Inserts
w
SOS. 54111
as Top (Ties
N Top 1-01 (1191 Mab
Medn
Wlw
Oo 1111 Bery Type
Latch pertelze
Type pn)
Ito pun
(pa6 pun ort. Cem
2,0855 1,912.1 MMH
WHO
1 GASwri GLV
BK 0.188
1,258.0 W30I2019
2 4,749.4 3.520.11 MMH
FMHO
I f IGAS UhT Tow
BK 1 025.1
0.0 3/302019
3 6,91 4,803.1 MMH
FMHO
I 1 IGAS LIFT DMV
BK 0000
0.0 2/1]2019
PUEFla Fsl. oesel a-_
4 8,374.4 5,791.6 MMH
FMHO
1 GAS UFT DMV
OA 3,302019 No
Log
entry
m
suppP
it thin
DMY
DMV
PERF. a9±9 on E51
PERF, 84]OJU,TL'
®ERF,a1.a 11.1-
FISR, aeua
F N:a awo
PRODUCTION, M L,9 051 L
THE STATE
°fALASKA
GOVERNOR MIKE DUNLEAVY
James Ohlinger
Staff CTD Engineer
ConocoPhillips Alaska, Inc.
P.O Box 100360
Anchorage, AK 99510-0360
Re: Kuparuk River Field, Kuparuk River Pool, KRU 217-07
Permit to Drill Number: 184-020
Sundry Number: 319-227
Dear Mr. Ohlinger:
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alasko.gov
Enclosed is the approved application for the sundry approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such fixrther
time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC
an application for reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if
the 23rd day falls on a holiday or weekend.
Sincerely,
Daniel T. Seamount, Jr.
Commissioner
-0%
DATED this —7 day of May 2019.
1BDMS1iFA-'MAY 0 7 2019
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25 280
R E
MAY U 3 9L19
1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ t=ccwzl
Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑
Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: —Whipstock El
2. Operator Name:
4. Current Well Class:
5. Permit to Drill Number:
ConocoPhillips Alaska Inc
Exploratory ❑ Development ❑' -
Stratigraphic ❑ Service ❑
184-020
3. Address:
6. API Number:
PO Box 100360, Anchorage AK 99510
50-029-21076-00-00
7. If perforating:
8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool? N/A
KRU 2F-07 -
Will planned perforations require a spacing exception? Yes ❑ No ❑�
9. Property Designation (Lease Number):
10. Field/Pool(s):
ADL 25657
Kuparuk River Field / Kuparuk River Oil Pool
it. PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
9055' 6254' - 8931' 6167' 3693 N/A 8890'/ 8894'
Casing Length Size MD TVD Buret Collapse
Structural
Conductor 78' 16" 109' 109' 1640 psi 670 psi
Surface 3696' 9-5/8" 3727' 2889' 3520 psi 2020 psi
Intermediate
Production 9025' 7" 9051' 16251' 4980 psi 4320 psi
Liner
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Tubing Size:
Tubing Grade:
Tubing MD (ft):
8554'-8564', 8638'-8657', 8674'-
5912'-5919', 5968'-5981',
8728', 8778'-8784'
5992'-6029', 6063'-6067'
3-1/2"
J-55
8434'
Packers and SSSV Type: Otis QLP SSSV (locked out 1/19/2000)
Packers and SSSV MD (ft) and TVD (ft): 1953' MD / 1832' TVD
Baker FHL Retrievable Packer
8405' MD / 5812' TVD
12. Attachments: Proposal Summary ❑' Wellbore schematic Q
13. Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑
Exploratory ❑ Strati ra hic
g p ❑ Development Q Service ❑
14. Estimated Date for
15. Well Status after proposed work:
Commencing Operations: 5/15/2019
OIL ❑' ' WINJ ❑ WDSPL ❑ Suspended ❑
GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑
16. Verbal Approval: Date:
Commission Representative:
GINJ ❑ Op Shutdown ❑ Abandoned ❑
17. 1 hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
Authorized Name: James Ohlinger Contact Name: Keith Herring
Authorized Title: Staff CTD Engineer Contact Email: keith.e.herring(ftolp.corn
Contact Phone: 907-263-4321
Authorized Signature: Date: 3?��9
COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
Plug Integrity ❑ BOP Test LJ Mechanical Integrity Test ❑ Location Clearance ❑ I/
Other:%3OP �CSt fJfCSSU/'G fo 4ZC90 P5r
,Idnnvlctr /jT—rl/<n iC,�r.�/ f�5% to 15- 0 p5r'9
J
Post Initial Injection MIT Req'd? Yes E] No LJ' RBDMS H6 MAY 0 7 2019
Spacing Exception Required? Yes ❑ No Subsequent Form Required: 0 _ 4e+
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date 5/7/
I / 1
15N /'- Dl t / / Submit Form and
F 1 -403 Revi 4/ 017 Approv d applie i v i 2 f m the data of approval. Attachments in Duplicate
t'y/�y -b� s-6 4
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
April 30, 2019
Commissioner - State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
ConocoPhillips Alaska, Inc. hereby submits Sundry Application (10-403) to set a High Expansion Wedge in KRU
217-07 (PTD #184-020) in order to drill two CTD laterals using the coiled tubing drilling rig, Nabors CDR3-AC.
Attached to this application are the following documents:
- 10-403 Sundry Application for KRU 2F--07
- Operations Summary in support of the 10-403 Sundry Application
- Proposed CTD Schematic
- Current Well Bore Schematic
If you have any questions or require additional information, please contact me at 907-263-4321.
Sincerely,
Keith Herring
ConocoPhillips Alaska
Coiled Tubing Drilling Engineer
KRU 2F-07 (PTD #184-020) CTD Summary for Sundry
Summary of Operations:
KRU well 2F-07 is a Kuparuk A/C -Sand producer equipped with 3-1/2" tubing and 7"
production casing. The CTD sidetrack will utilize two laterals to target the A -sands to the
northeast and southeast of 217-07. The laterals will target reservoir to the east that has been
sheltered due to a large sealing fault.
Nabors CDR3-AC will set a mechanical whipstock (High Expansion Wedge) inside the 7"
casing at the planned kick off point of 8,645' MD. The 2F -07L1 lateral will exit through the 7"
at 8,645' MD and drilled to TD at 12,100' MD, targeting the A -sand to the southeast. It will be
completed with 2-3/8" slotted liner from TD up to 9,225' MD with an aluminum billet for kicking
off the 2F-071-1-01 lateral.
The 2F-071-1-01 lateral will drill to a TD of 12,050' MD targeting the A -sand to the northeast.
It will be completed with 2-3/8" slotted liner from TD up into the 3-1/2" tubing at 8,425' MD. If
the western side of the fault is swept the lateral will be completed with a swell packer and liner
top packer.
CTD Drill and Complete 2F-07 Laterals: June 2019
Pre -CTD Work
1. RU Slickline: Dummy whipstock drift, C/O GLV's
2. RU E -line: Caliper
3. RU CTU: Mill out D -Nipple to 2.80" ID
4. Prep site for Nabors CDR3-AC rig.
Rig Work
�vnc�✓y 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test.
2. 2F -07L1 Lateral (A4 sand - South)
a. Set top of high expansion wedge at 8645' MD.
Mill 2.80" window at 8645' MD.
c. Drill 3" bi-center lateral to TD of 12100' MD.
d. Run 2-3/8" slotted liner with aluminum billet from TD up to 9225' MD.
Mo w 3. 21F-071-1-01 Lateral (A4 sand - North)
PT7D a. Kick off of the aluminum billet at 9225' MD.
b. Drill 3" bi-center lateral to TD of 12050' MD.
c. Run 2-3/8" slotted liner with deployment sleeve from TD up to 8425' MD.
4. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig.
Post -Rip Work
1. Return well to production.
Page 1 of 1 4/30/2019
2F-07
16" 62# H-40 shoe
@109'MD
9-5/8" 36# J•55 shoe
@ 3727' MD
C4-santl perl
8554' - 8564' MD
F5146 -sand perfs
8638' - 8657' MD
8674' - 8728' MD
8778' - 8784' MD
7" 26# J-55
sMa @ 9051' MD
CTD Schematic
3-1/2" OTIS QLP SSSV (Locked Out 1/19/2000)
3-1/2" 9.3#J-55 EUE 8rd Tubing to surface
3-1/2" Camm MMG gas lift mandrel at 2066', 4749', 6807', 8374'
MD
Baker PBR @ 8391' MD (3" ID)
Baker FHL packer @ 8405' MD (3" ID)
D -nipple at 8421" MD (2.75" min ID, No -Go)
3-1/2" Baker SOS @ 8433' MD
2F -07L (($Doth)
TD @ 12.100' MD
Top of Dille[ @ 9225 Mo
2F-07L1-01(North)
TD @ 12,050' MD
Top of Uw@ 8425' MD
r'
KUP PROD WELLNAME 2F-07 WELLBORE 2F-07
ConoeoPhllllpS1&1�7�titt
nbutes Max Angler MD TD
gle&) T
Alasi IniKUPKRIVER
EaWellba�ePpllUlMWtlIWreSraruzMax
Blm (NNB)
UNIT 50025210]600 PROD 580 2400A0 9055.0
Comment X35 (ppm) pale gnnMMbn Entl Oare XBGM(1 Rig RII-11 nate
SSStOLOCKED OUT 75 1252016 La9W0: 9/30/1984 2900 317/1984
X-0], 411 &1n 19B3l:�gM
Last Tag
WnitJ-mnic Vai
Mrossam peplh tYlKB) i0.--::I--Les, WMlpre Mad By
Last Tag: RKB SIIJ.09298 2F-0] fergusp
Last Rev Reason
HLnGEB ria
Mwdim End Game WNlbrc IxiMM By
Rev Reason'. Update from Dost resin lob. 4/18/2019 2F-0] fergusp
Casing Strings
Cazinp U seaipnon GB(m) 10 (an) Tcp(1HB)
CONDUCTOR 16 15.06 31.0
Set nepM poild SN Dep Unda)... vtdo (I.,. Gratle Tap TMeatl
109.0 109.0 62.50 HAO WELDED
c'some Desumpiion 0,in Ip pn) Top(hKB)
SURFACE 95/8 8.]fi 30.9
Setpeplll (I1 KB) Sn mmun (NO)... WIM1en (L.. Grab iap TNreatl
3,]26.8 2,8688 36.00 J55 BTC
coNwcraR;m 6mWD
Casing pncriptron 00 (nl 12th) rp1M1KB)
PRODUCTION ] fi28 26.0
Set DepM INKS) --am r vi- tviin_GnEa Top TbeaE
9,051.0 62508 2600 J-55 STC
Tubing Strings
sang Deacriptiaa sl,iag Ma... nidal TOP (nk8) Sat Oep, (N..Sel Dewh "a Grine TaP Lann«tun
TUBING 31/2 299 23.6 8434.1 5.83L5 9.30 J-55 EUEIto
9gFETY.1. I.tasi
IConnjgjedgonuaweiia
TapINO) Tap Incl HamIIw1
T -o,.. (NN.) I-) Item Det Cam ID (n)
232 23,6 0.07 HANGER -1-1 II TUBING HANGER 1 3.500
Gqs uFT:2Ws.s
OMB 1,832.1 42.90 SAFETYVLV UUS OLP SSSV (LOCKED OUT111119 0) CL TRACK TUBING 1 2.812
PRESSURE
8.391.0 1 5,802.6 48.03 PER EAKERPBR 1 3.0001
8,4019 5,812.0 I8,03 PACKER BAKER FHL 3.000
B,d21.3 5,8229 48.01 NIPPLE CAMCO DNIPPLE 2.750
8433.3 7830.9 48.00505 CAMCOSHEAROUT-TTLELMD@840' NSWS PPROF 2.99
SURFADE:a1....-
8292004
arinHofe(Witellne ratrievs6le plugs, valves, pumps, sh, etc:)
ccsufr;e,]aeA
7T,p(ftKB)
TOP(rvm Topmd (NKq) p nee eom89046,19IS
2KOr KICK SPRINGS LOST S/6" WIOE.3. 5 -LONG 323/2011 0.0008940
GAS IIFT',6aJ].e
6,142.9 469 FISH Original Completion PKRLel in hole during worsover 102/1984
Perforations & Slots
snm
GASLIFT:a3]aa
To,fKSH
Btm(NKBI
roP IND)
HIKE)
wn TvaN
MKB)
Llnky Zone
Deme
(iMmsM
)
Tyce
Cmn
B,SSd.O
8,564.0
5.911.8
5.918.5
C.4,UNIT B.2F
-07
123112198)
0.0
(PERF
30 deg.V Phavng,2118"
EnerJet
PSR. S.arg
7630.0
8,657.0
5968.1
5,980.8
A -5,21i
413119844.0IPERF
9ptleg,Pha9ng,4"SchIDM,
Casing Gun
8.8]4.0
8.728.0
5992.3
6,028.9
Ad, 2F-0]
4/3/1984
4.0IPERF
191,Phasmg,CSMlum.
PA<KEq: a...9
Casoni
8778.2
8)84.0
63ff1
6,067.2
A -3,21i
4911984
400
PERF
90 deg.Phasing,d"$cMaan
Casing Gun
xIwLE: ee2t.a
Mandrel Inserts
SOS'. &,i
N Tpp Ka,
T^P MKB) @KB) Mab
MWs1
Wlw ta4M1 Port Soe TRO Run
Op fin) sery Typo ryp (ln) (peq Run Oame
Com
2.65 .5 1,912.1 MMH
FMHO
AS LIFT LV BK 0.188 1,2 ZW2019
2 4,]49.4 .5 0,1 MMH
FMHO
1 GAS LIFT OV B 0.250 0.0 3/30/2019
6.807. 4,003.1 MMH
FM HO
1 I GAS LIFT IDMY BK0. 80 2/1712019
IPERF, Sesesaata� .5
4 14.4 5791 .6 MMH
MH
1 ASLIFT MY W2019
No
Lag
entry
to
INS
n Mi
DMV
IPERF', r1, 6i9Da,�].0�
IPERF', aannissa ia-
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PROCUCTgx 2508,851,8
Loepp, Victoria T (DOA)
From: Ohlinger, James J<James.J.Ohlinger@conocophillips.com>
Sent: Tuesday, May 7, 2019 11:02 AM
To: Loepp, Victoria T (DOA)
Cc: Germann, Shane
Subject: RE: [EXTERNAL]KRU 2F-07(PTD 184-020, Sundry 319-227) Set Whipstock
Good morning
Shane Germann has joined the CTD group at ConocoPhillips.
He'll be the drilling engineer for 2F-07.
I've cc: him on the email so you have each other's email address.
Thanks
3. Blowout Prevention Equipment Information
(Requirements of 20 AAC 25.005 (c)(3))
Please reference blowout prevention (BOP) schematics on file with the Commission for Nabc
BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations.
- Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,:
maximum formation pressure in the area of 4290 psi in 2F-15 (i.e. 13.6 ppg EMW),
potential surface pressure in 2F-07, assuming a gas gradient of 0.1 psi/ft, would be
"Drilling Hazards Information and Reservoir Pressure" section for more details.
- The annular preventer will be tested to 250 psi and 2,500 psi.1
From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>
Sent: Tuesday, May 07, 2019 10:38 AM
To: Ohlinger, James J <James.J.Ohlinger@conocophillips.com>
Subject: [EXTERNAL]KRU 2F-07(PTD 184-020, Sundry 319-227) Set Whipstock
Please provide BOP test pressure.
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria. Loeoo(a)alaska gov
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged
information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended
recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to
you, contact Victoria Loepp at (907)793-1247 or victoria LoecpGalaskaxov
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Ima~'~roject.WellHistory File Covee-~ge
XHVZE
This page identifies those items that were not scanned during the. initial production scanning
phase. They are available in the original file, may be scanned during a special rescan activity or
are viewable by direct inspection of the file..
RESCAN DIGITAL DATA OVERSIZED (Scannable)
[] Color items: [] Diskettes, No. [] Maps:
[3 Grayscale items: [] .Other, No/Type [] Other items scannable by
· large scanner
o Poor Quality Originals:
OVERSIZED (Non-Scannable)
[] Other:
NOTES: '[] Logs of various kinds
[3 Other
BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/
Project Proofing
BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL
Scanning Preparation
BY: BEVERLY BREN VINCENT SHERYL[MARIA,~ LOWELL
Production Scanning _ ~
Stage I PAGE COUNT FROM SCANNED FILE:
BY:
Stage 2
BY~
(SCANNING I$ COMPLETE AT THIS POINT UNLES~ SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS
DUE TO QUALITY GRAYSCALE OR CO{.OR IMAGES )
DATE: /S/
+ _(~L_ = TOTALPAGES ~)~
OUNTMATCHES NUMBER IN SCANNING PREPARATION: f'~ES
NO
IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO
ReScanned (individ[~al page [special attenUo~l $cannin.q. corr~pletedJ
RESCANNEDBYZ BEVERLY BREN VINCENT SHEEYL MARIA LOWELL DATE:
/si
General Notes or Comments about this file:
Quality Checked
•
ConocoPhillips
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
November 3, 2008
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West 7~' Avenue, Suite 100
Anchorage, AK 99501
Dear Mr. Maunder:
•
~ a, b
~~ .~ o
7
~C
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLI). 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 27 and October 30, 2008. The corrosion inhibitor/sealant was
pumped November 2, 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, ~~I~~~ ti~C1' 1 ~' ?..~0
Perry In
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
Date 19/3/2008
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
2F-01 183-183 88' 13.10 21" 10/30/2008 4.68 11/2/2008
2F-04 183-190 48" NA 48" NA 25.5 11/2/2008
2F-07 184-020 10' 3.00 22" 10/27/2008 4.25 11/2/2008
2F-08 184-021 SF NA 20" NA 2.55 11/2/2008
2F-09 184-036 18" NA 18" NA 1.7 11/2/2008
2F-10 184-040 22" NA 22" NA 1.28 11/2/2008
2F-12 184-043 20" NA 20" NA 2.12 11/2/2008
2F-15 183-172 93' 10.10 10" 10/30/2008 3.82 11/2/2008
2F-16 183-177 42' 5.90 9" 10/27/2008 1.28 11/2/2008
STATE OF ALASKA
ALAS, .,-, OIL AND GAS CONSERVATION COMMISSi,Jr~
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Performed: Operation Shutdown Stimulate X Plugging
Pull tubing Alter casing Repair well
Perforate
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
4. Location of well at surface
565' FSL, 1570' FEL, Sec. 28, T11N, R9E, UM
At top of productive interval
1586' FSL, 1285' FEL, Sec. 27, T11N, R9E, UM
At effective depth
1637' FSL, 1013' FEL, Sec. 27, T11N, R9E, UM
At total depth
1653' FSL, 924' FEL, Sec. 27, T11N, R9E, UM
12.
Present well condition summary
Total Depth: measured
true vertical
6. Datum elevation (DF or KB)
RKB 127 feet
7. Unit or Property name
Kuparuk River Unit
8. Well number
2F-07
9. Permit number/approval number
84-20
10. APl number
5o-029-21076-00
11. Field/Pool
Kuparuk River Field/Oil Pool
9055 feet
6253 feet
Plugs (measured) None
Effective depth: measured 8 9 31
true vertical 61 67
feet
feet
Junk (measured) Original packer @ 8894'
Casing Length Size
Structural
Conductor 8 0'
Sudace 3 6 8 9'
Intermediate
Production 8986' 7"
Liner
Perforation depth: measured
8554'-8564',
true vertical
5911 '-591 8',
Cemented Measured depth True vertical depth
150 Sx CS II 109' 1 09'
1040 Sx AS III & 3727' 2889'
710 Sx Class G
300 Sx Class G 9 0 21 ' 6 2 2 9'
& 250 Sx AS I
I 6"
9-5/8"
8638'-8657', 8674'-8728',
5967'-5980', 5992'-6028',
Tubing (size, grade, and measured depth)
3.5", 9.3#/ft., J-55 @ 8448'
Packers and SSSV (type and measured depth)
Packer: Baker FHL @ 8417'; SSSV: Otis QLP @ 1953'
8778'-8784'
6062'-6066
EC£1VF. D
1997
13. Stimulation or cement squeeze summary & Gas Cons. C0n~isSt01t
Fracture stimulate 'A' Sands on 7/13/97. (-~ [~) ~ I'~ ~ ~ ,[\ ~.AJaska0i'
Intervals treated (measured) U ['r~ ~ t~| |~i/-~1-- Anchorage
8638'-8657', 8674'-8728', 8778'-8784'
Treatment description including volumes used and final pressure
Pumped 222.6 Mlbs of 20/40 & 12/18 ceramic proppant into formation, fl:) was 5777 psi.
14. Representative Daily Average Production or Injection Data
OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation 129 144 338 1193 139
Subsequent to operation
390 566 1032 1207 152
15. Attachments
Copies of Logs and Surveys run
Daily Report of Well Operations
16. Status of well classification as:
Oil X Gas Suspended Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
A i
Signed /~'~/~,¢~.,,./~)1/"7 ~!~,. Title Wells Superintendent
FormJlD-404 Rev ~/88
Date
SUBMIT IN DUPLICATE
ARCO Alaska, Inc. KUPARUK RIVER UNIT
~l~ WELL SERVICE REPORT
~ K1 (2F-07(W4-6))
WELL JOB SCOPE JOB NUMBER
2F-07 FRAC, FRAC SUPPORT 0703971829.3
DATE DAILY WORK UNIT NUMBER
07/13/97 PUMP 'A' SANDS REFRAC
DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR
3 (~) Yes O No (~) Yes O No DS-YOKUM JOHNS
FIELD AFC# COif DALLY COST ACCUM COST Si
ESTIMATE KD1346 230DS28FL $1 39,966 $160,365 ,
Initial Tb_q Press Final Tbq Press Initial Inner Ann Final Inner Ann I Initial Out~ic'/~n'n I Fine'ti/Outer Ann
1282 PSI 1300 PSI 700 PSI 900 PSII 250 PSII 350 PSI
DAILY SUMMARY
PUMPED 'A' SANDS REFRAC W/222,576# PROPPANT FLUSHED TO PERFS W/12# PPA 12/18, LEAVING 700# IN PIPE.
TIME LOG ENTRY
07:00 MIRU DOWELL FRAC EQUIP., LITTLE RED PUMP AND APC VACUUM TRUCK.
07:41 HELD JOB SITE SAFETY MEETING
07:54 PRESSURE TEST TREATING LINE TO 10,600 PSI.
07:56 PUMPED 100 BBLS BREAKDOWN, 50# GEL AT 25 BPM AND 6680 PSI.
08:01
PUMBED..!#P_P~ 201 ~1# 20/40 SCOUR STAGE AT 15 BPM AND 4875 PSI.
08:03 PUMPED_~;U ¢¢8LS CONDITION STAGE, 15 BPM AND 5411 PSI.
08:05 PUMPED 2# PPA 3860# 20/40 SCOUR STAGE AT 15 BPM AND 5159 PSI.
08:08 PUMPED 10 BBLS GELAND 119 BBLS STRAIGHT SEAWATER FLUSH AT 15 BPM AND 5072 PSI. SHUT DOWN FOR
ISIP 2092 PSI AND PUMPED PULSE TEST.
10:52 PUMPED 190 BBLS PAD AT5 TO 15 BPM AND 5118 PSI.
11:14 PUMPED 2# PPA, 20/40 STAGE AT 15 BPM AND 5832 PSI.
11:27
12:38
PUMPED 6# TO 12# PPA 12/18 (207,276#I PROPPANT TO FLUSH TO PERFS. 15 BPM AND 5777 PSI.
SHUT DOWN & RDMO
SERVICE COMPANY - SERVICE DAILY COST J ACCUM TOTAL
$0.00 $819.00
APC $6,700.00 $11,700.00
ARCO $0.00 $500.00
DOWELL $131,646.00 $137,666.00
HALLIBURTON $0.00 $3,881.00
LR-FLE RED $1,620.00 $5,800.00
TOTAL FIELD ESTIMATE $1 39,966.00 $1 60,366.00
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMI~.~,51ONO ~
REPORT OF SUNDRY WELL OPERATIONS
1. Type of Request:
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
Exploratory
Stratigraphic
Service
i4. Location of well at surface
565' FSL, 1570' FEL, Sec. 28, T11N, R9E, UM
At top of productive interval
1586' FSL, 1285' FEL, Sec. 27, T11N, R9E, UM
At effective depth
1637' FSL, 1013' FEL, Sec. 27, T11N, R9E, UM
At total depth
1653' FSL, 924' FEL, Sec. 27, T11N, R9E, UM
12. Present well condition summary
Total Depth: measured
true vertical
9055' feet
6253' feet
Plugs (measured)
Effective depth:
measured 8 9 31 ' feet
true vertical 6168' feet
Junk (measured)
Casing Length
Structural
Conductor 1 0 9'
Surface 3 7 2 7'
Intermediate
Production 9 0 21 '
Size Cemented
1 6" 150 Sx C.S. II
9-5/8" 1040 Sx A.S. III &
710 Sx Class "G"
7" 300 Sx Class "G" &
250 Sx A.S. I
6. Datum elevation (DF or KB)
RKB 127'
7. Unit or Property name
Kuparuk River Unit
8. Well number
2F-07 Producer
9. Permit numbe~approval number
~4-20 ~'-~ .5/ 7~~/
10. APl number
so-029-21 07600
11. Field/Pool
Kuparuk River Oil Pool
109' 109'
3727' 2889'
9021' 6230'
8778'-8784' MD
6062'-6067' TVD
feet
Liner
Perforation depth: measured
8554'-8564', 8638'-8657', 8674'-8728',
true vertical
5912'-5918', 5968'-5981', 5992'-6029',
Tubing (size, grade, and measured depth)
3 1/2", J-55 9.3 #/ft., EUE, 8434' MD
Packers and SSSV (type and measured depth)
Packer: Baker FHL, 8406' MD, SSSV: Otis OLP~ 1953'.
MD
Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
13. Stimulation or cement squeeze summary
Hydraulically fractured the A & C Sand with gelled water & 16/20 Mesh Carbolite,
Intervals treated (measured) 8554'-8564', 8638'-8657', 8674'-8728', 8778'-8784'
Treatment description including volumes used and final pressure
Pumped 1502 bbls gelled water, 110969 # 16/20 Carbolite, WHTPF=5480psi
14. - Representative Daily Average Production or In!action Data
OiI-Bbl
Prior to well operation
Subsequent to operation
15. Attachments
Copies of Logs and Surveys run
Daily Report of Well Operations X
978 1354 0 1325psi 140psi
2883 4689 0 1750psi 260psi
16. Status of well classification as:
Oil X Gas Suspended Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
FormSi~ned 1//0_~404~~ ~06/15/88~"~'~ TitleSr. Operations En~]ineer
SUBMIT IN DUPI'ICATE~
ARCO Alaska, Inc'~
Subsidiary of Atlantic Richfield Company
c'"NTRAC_.L,,,,~T/G~ (,.4)~/[.. "-
REMARKS
WELL SERVICE REPORT
IFIELD - DISTRICT- STATE
OPE'R~TION AT"R,~RT( ~U/~ p
e~ L c~t
/~.o0
/ '-/-,-/5-
i .~--~a
i 73c)
df_:& Per--
, /
I--1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK
WeetherReport I Temp.
"F
Chill Factor. FIVisibility miles
Wind Vel.
knots1 ~/~~'~Signed
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
June 5, 1989
Mr. C. V. Chatterton, Chairman
Alaska Oil and Gas Conservation Commission
3001 ~orcupine Drive
Anchorage, Alaska 99501
Dear Mr. Chatterton-
Attached in triplicate are multiple Applications for Sundry Approvals on the following
Kuparuk wells.
W~ll Action
Anticipated Start Date
3 H- 1 0 Conversion June, 1989
2Z-04 Storm Ck. March, 1989
2F-07 Refracture July, 1989
3H-04 Acidize June, 1989
2Z-07 Acidize May, 1989
3 B- 0 2 Tbg. Leak June, 1989
3K-1 5 Stimulate June, 1989
2Z-29 Acidize June, 1989
If you have any questions, please call me at 265-6840.
Sincerely,
G. B. Smallwood
Senior Operations Engineer
, ECi IVED
Gas Cons.
~nchorage
ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request:
Operation Shutdown__ Stimulate X 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
4. Location of well at surface
565' FSL, 1570' FEL, Sec. 28, T11N, R9E, UM
At top of productive interval
1586' FSL, 1285' FEL, Sec. 27, T11N, R9E, UM
At effective depth
1637' FSL, 1013' FEL, Sec. 27, T11N, R9E, UM
At total depth
1653' FSL, 924' FEL, Sec. 27, T11N, R9E, UM
12. Present well condition summary
Total Depth: measured
true vertical
9 0 5 5' feet
6253' feet
Plugs (measured)
Effective depth:
measured 8 9 31 ' feet
true vertical 61 68' feet
Junk (measured)
Casing Length
Structural
Conductor I 0 9'
Surface 3 7 2 7'
Intermediate
Production 9 0 21 '
Liner
Perforation depth: measured
true vertical
Tubing (size, grade, and measured depth)
Size Cemented
1 6" 150 Sx C.S. II
9-5/8" 1040 Sx A.S. III &
710 Sx Class "G"
7" 300 Sx Class "G"&
250 Sx A.S. I
8554'-8564', 8638'-8657',
5912'-5919', 5968'-5981',
6. Datum elevation (DF or KB)
RKB 127'
7. Unit or Property name
Kuparuk River Unit
8. Well numberv,
:2F-07 //~ ,Z. ~,
9. Permit number/approval number
84-20
10. APl number
50-029-2107600
11. Field/Pool
Kuparuk River Oil Pool
RECEIVED
feet
o 7
,~i~_la~k_a,.0il & Gas Cons, C0mmissi0_n
Measured depth Irue vemcal depth
109' 109'
3727' 2889'
9021' 6230'
8674'-8728', 8778'-8784' MD
5992'-6029', 6062'-6067' TVD
3 1/2", J-55 9.3 #/ft., EUE, 8434' MD
Packers and SSSV (type and measured depth)
Packer: Baker FHL, 8406' MD, SSSV: Otis OLP, 1953'.
13. Attachments Description summary of proposal _ Detailed operation program _ BOP sketch_
14. 15.
Estimated date for commencing operation
7/15/89
16. If proposal was verbally approved
Name of approver
Date approved
Status of well classification as:
Oil X Gas __ Suspended
Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed ,::~4/,.~ ~ Title Sr. Operations Engineer
FOR COMMISSION USE ONLY
Date
Conditions of approval: Notify Commission so representative may witness IApproval No. /'~
Plug integrity_ BOP Test_ Location clearance__ I
Mechanical Integrity Test_ Subsequent form require 10-,,~/-/-
Approved Copy
ORIGINAL SIGNED BY -
Approved by the order of the Commission
LONNIE C. SMITH
Commissioner Date ~:::~
Form 10-403 Rev 5/03/89
SUBMIT IN TRIPLICATE
Messrs Lyden and Wade
June 1, 1989
Page 2,
Kuparuk Well 2F-07
'A' Sand Re-Fracture Procedure
1. Obtain a 24 hour well test.
.
.
MIRU Slickline unit. RIH with tubing end Iocator and tag fill. Pull GLV's at 2066',
4749', 6808', and 8375' and run DVs.
RIH with Standing Valve and set in Camco 'D' nipple. Pressure test tubing to 4500
psi to ensure DVs are set. RIH and pull SV.
4. RDMO Slickline.
If less than 50 feet of rathole is discovered during the pre-frac wireline
operations, a CTU cleanout may be required. Consult with Operations Engineering to
determine if the CTU is necessary. If a cleanout is performed, at least 150 feet of
rathole is desired.
5. Pump Diesel/10% Musol per the attached schedule. Shut down overnight to soak.
.
.
.
MIRU fracture equipment with ball sealer dropping capability. Install "Tree
Saver".
Carry out all quality control procedures (Onsite Operations Engineering). The
specific procedures will depend on the vendor selected. Check Carbo-Lite for fines
due to excessive handling. Obtain a sample of the Carbo-Lite and the gelled water
with breaker and from the pad and slurry stages. Record the proppant weight
before and after the treatment.
Pump fracture treatment per the attached schedule. Record the 5, 10, and 15
minute pressures following the ISIP. Expected wellhead treating pressure:
7. Rig down frac equipment. Follow attached flowback schedule.
8. After well has completed flowback, obtain 24 hour well test.
Engineering for a new gas lift design when necessary.
WHTPE -- 3250 psig
Fracture Gradient = 0.70 psi/ft (6000' TVD)
Tubing Friction -- 300 psi/1000 ft (8434' MD) @25 BPM
If treating pressure during the job exceeds 6000 psi, shut down job ~(:~n~{ V ~ D
with Engineering.
,:',laska Oil & Gas.Cons
Contact OI3~d'~o¢~ C0mmjssion
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Type of Request:
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
4. Location of well at surface
565' FSL, 1570' FEL, Sec. 28, T11N, R9E, UM
At top of productive interval
1586' FSL, 1285' FEL, Sec. 27, T11N, R9E, UM
At effective depth
1637' FSL, 1013' FEL, Sec. 27, T11N, R9E, UM
At total depth
1653' FSL, 924' FEL, Sec. 27, T11N, R9E, UM
12.
Present well condition summary
Total Depth: measured
true vertical
9 0 5 5' feet
6253' feet
Plugs (measured)
6. Datum elevation (DF or KB)
RKB 127'
7. Unit or Property name
Kuparuk River Unit
8. Well number
2F-07 Producer
9. Permit number/approval
. 84-20 ? ~'-,27
I10. APl number
50-029-2107600
Ill. Field/Pool
Kuparuk River Oil Pool
feet
number
Effective depth:
measured 8 9 31 ' feet
true vertical 61 68' feet
Junk (measured)
Casing Length
Structural
Conductor I 0 9'
Surface 3 7 2 7'
Intermediate
Production 9 0 21 '
Liner
Perforation depth' measured
true vertical
Tubing (size, grade, and measured depth)
Size Cemented
1 6" 150 Sx C.S. II
9-5/8" 1040 Sx A.S. III &
710 Sx Class "G"
7" 300 Sx Class "G" &
250 Sx A.S. I
8554'-8564', 8638'-8657',
5912'-5918', 5968'-5981',
3 1/2", J-55 9.3 Ct/ft., EUE, 8434' MD
Packers and SSSV (type and measured depth)
Packer:
Measured depth
109'
3727'
9021 '
8674'-8728',
5992'-6029',
Baker FHL, 8406' MD, SSSV: Otis OLP, 1953'.
True vertical depth
109'
2889'
6230'
8778'-8784' MD
6062'-6067' TVD
!:; !,
13. Stimulation or cement squeeze summary
i,/I/ II ~ '% . .
': ....
Intervals treated (measured) .-.:.;,-'.~, &
Treatment description includin~l volumes used and final pressure
14. Representative Daily Average Production or In!ection Data
OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation
Subsequent to operation
831 1026 0 1050 120
889 1218 0 700 1 1 5
15. Attachments
Copies of Logs and Surveys run
Daily Report of Well Operations
16. Status of well classification as:
Oil X Gas Suspended Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Si,ned D ~ ~ ~,.~v~-''~'~ ~ Title
Form ld:404 ~e~ 06i1~/88 '
SUBMIT IN DUPLICATE
STATE OF ALASKA
ALASK OIL AND GAS CONSERVATION COMM,,.,SION
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 []
2. Name .of Operator
ARCO Alaska. In¢,
3. Address
P.O. Box 100360, Anchorage, Alaska 99510
4. Location of well at surface
565' FSL, 1570' FEL, Sec. 28, T11N, R9E, UM
At top of productive interval
1586' FSL, 1285' FEL, Sec. 27, T11N, R9E, UM
At effective depth
1637' FSL, 1013' FEL, Sec. 27, T11N, R9E, UM
At total depth
1653' FSL, 924' FEL, Sec. 27, T11N, R9E, UM
11. Present well condition summary 9055'
Total depth: measured 6253' feet
true vertical feet
Effective depth: measured 8931' feet
true vertical 6168' feet
Casing Length Size
Structural
Conductor 109' 16"
Surface 3727' 9-5/8"
Intermediate
Production 9021 ' 7"
Liner
8638' -8657'
Perforation depth: measured
Plugs (measured)
5. Datum elevation (DF or KB)
],27' RKB feet
6. Unit or Property name
Kuparuk River Unit
7. Well number
2F-07
8. Permit number
9. APl number
50-- 0292107600
10.
'P°°~Kuparuk River Oil Pool
Junk (measured)
...
Cemented Measured depth
150 Sx C.S. II 109'
rrue Vertical depth
109'
2889'
6230'
MD
1040 Sx A.S. III 3727'
710 Sx Class "G"
300 Sx Class "G" 9021'
250 Sx A.S. I
, 8674'-8728', 8778'-8784'
true vertical
5968'-5981', 5992'-6029', 6062'-6067' TVD
~bing (size, grade and measured depth)
3 1/2", J-55, 9.3 #/ft., EUE, 8434' MD
Packers and SSSV (type and measured depth)
Packer: Baker FHL, 8406' MD, SSSV: Otis QLP, 1953'. .
12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch []
Perforate C Sand from 8554' MD to 8564' MD at 8 SPF.
13. Estimated date for commencing operation
12/22/87
Date approved
14. If proposal was verbally approved
Name of approver
is true correct to th.~st of my knowledge
15. I hereby certify that t_he foregoin~,4,.~d
Signed ,~30/?. ~ ""' '~ % 5; ,-
Commission Use Only
Notify commission so representative may witness I Approval No.
[] Plug integrit)~pl~!~(~y [] Location clearance
I
Returned
Date ,/'A'y~ ~
Conditions of approval
ORIGINAL SIGNED BY
Approved by LONNIE C. SMITH
Commissioner
Form 10-403 Rev 12-1-85
by order of
the commission Date /" ~/'- (:~
Submit in triplicate
ARCO Alaska, Inc.
Subsidi&"y of Atf,~ltic Richfield ComDany
WELL SERVICE REPORT
WELL JPBDT
-mNTRACTOR
REMARK~ ::: ::.
FIELD - DISTRICT-STATE IDAY$ IDATE
IOPERATION AT REPORT _~M,~E
c.,-'~ 7' c ~>,~ r : ~/1~ ~ ,.~<'"'~
r'"] CHECK THIS BLOCK IF SOMMARY CONTINUED ON BACK
REMARKS CONTINUED:
DESCRIPTION DAILY ACCUM.
TOTAL
CAMCO
OTIS
SCHLUMBERGER / ~ ? ~ ~ ~ (::~. ~' ~,
DRESSER-ATLAS ~ /
DOWELL
...
HALLIBURTON
ARCTIC COIL TUBING
FRACMASTER
B. J. HUGHES
Roustabouts
Diesel
Methanol
-,
Supervision
Pre-Job Safety Meeting
AFE
TOTAL FIELD ESTIMATE / ~ ~ ~ ~
ARCO Alaska, Inc.
Post Of,'"-"' Box 100360
Anchorage, Alaska 99510-0363
Telephone 907 276 1215
DATE: 08-16-85
TRANSMITTAL NO: 5254
ARCO ALASKA, INC.
KUPARUK OPE~YIONS ENGINEERING
RECOPd3S CLEI<K "
ATO-1115B
P.O. BOX 1U0360
ANCHORAGE, AK 99510
TRANSMITTED
RECEIPT AND RETURN ONE
PRESSURE FINALS
CkN1CO
lB-3 PBU
1D-8 STATIC
1E- 5 PBU
1H-6 STATIC
1L- 2 PBU
1L-5 PBU
lQ-6 PRESSURE
FALL OFF
PBU
PRESSURE
FALL OFF
STATIC
PBU
PBU
PBU
PBU
STATIC
PBU
STATIC
STATIC
STAYIC
STATIC
PBU
lQ-9
2A-5
2A-5
2C-4
2F-7
2F-8
2F-9
2G-1
2G-1
2U-5
2U-6
2U-7
2U-8
2X-'10
OTIS
2A-2
2U-14 '
2V-2
2V-5
2V-i3
2V- 14
3B-3
3 -8
RECEIPT
B. CURRIER
CiiEVRON*
'D & M*
SIGNED .COPY OF
hEREWITH ARE THE FOLLOWING ITL2,IS. PLEASE ACKNO¥~LEDGE
THIS TRANSMITTAL.
04-21/22-85
04-29-85
04-26-28-85
04-29-85
04-24/25-85
04-28/29/85
05-07-85
05-12/13-85
STATIC
PBU
PBU
PBU
STATIC
STATIC
PBU
STATIC.
STATIC
04-21/22-85.,
05-05-85
04-24/25-85
04-14-85
04-19/20-85
04-13/14-85
04-17-85
04-29-85
05-02-85
~-05-03-85
05-04-85
05-04-85
04-25/26-85
07-04-85
06-30-85
07-27-85
06-25-85
06-22-85
06-22-85
07-26-85
-06-28-85
06-28-85
ACKNO%~LEDGED:
DISTRIBUTION:
DRILLING W. PASHER
L. -JOHNSTON EXXON
'MOBIL* PHILLIPS OIL*
NSK CLERK J. RATHMELL*
%--/
Anch0ra~
STATE OF ~ASKA*
SOHIO*
UNION*
K. TULIN/VAULT
ARCO Alaska, Inc.
Pos{ Office Box 100360
Anchorage, A]aska 99510-0360
Te!ephone 907 276 1215
DATE' C5-2 9-8 5
TRANSMITTAL NO: 5203
RETURN TO:
ARCO ALASKA, INC.
KUPARUK OPERATIONS ENGINEERING
RECORDS CLERK
ATO-1115B
P.O. BOX 100360
Ah~CHORACE, AK 99510
T [QXN SM ITTED
RECEIPT AND RETURN ONE SIGNED CO
ARE TJ!E [OLLO,qI~G ITEq PY OF THIS
SEQUENCE OF EVENTS PRESSU£?k DATA
-2A-3 PBU- '~' SAND
2A-5 SBfIP
-2B-i PBU
2B-2 PBU
2B-15 PBU- POST FRAC
~2B-16 PBU
2F-7 PBU- STATE
2F-8 _~ PBU- 'A' SAND
_2_F~ Z__~m~,/PB U- STATE
26-!2 PBU- 'A' SAND POST FRAC
2H-15 ISBHP
2W-!3 PBU- 'C' SAND
2X-13 PBU
03-16-85
11-21-84
04-01-85
04-02-85
04-09-85
04-10-85
0~.-14-85
04-20-85
04-13-85
04-11-85
03-23-85
04-10-85
04-21-85
03-30-85
PLEASE ..... '
A,.r,r.. OWLEDGE
BAKER/ LYNES PRESSURE REPORTS
(ONE COPY OF EACH)
1A-i PDU 04-23-85
lA-2 PBU 04-23-85
lA-2 PBU 04-23-85
lA-5 BUILD-UP 04-23-85
lA-6 PBU 04 -23-85
lA-6 BUiLD-UP 04-23-~5
iA-10 'BUILD-UP 0= ~-23-85
iA-10 BUILD-UP 04-23-85
SET DEPTH
7187'
7476'
7476'
6957'
8300'
8300'
8415'
8415'
TOOL NO.
1722
1302
1512
1734
1719
2062
1508
1299
RECEIPT ACKNOWLEDGED:
D PAE *
3. CURRIER*
D & M*
DRILLING
L. JOIINSTON
MOBIL*
o-'~ CLERK
DISTRID UT iON:
W. PASHER
EXXO £q
PHILLIPS OIL*
J. RATHMELL*
Ancrmrage
STATE OF ALASKA*
SOHIO*
UNION*
n.TULIN/VAoL!
ARCO Alaska, Inc.
Post Officr'"'"~x 100360
RETURN TO'
ARCO ALASKA, INC,.
ATTN' RECORDS CLERi<
..,.'-,T[.~ .... tf t _.,B ~
F:, O, BOX f
ANCHORAGE. , Al'-(
DATE: APRIL
TRAN,~'HITTAL NO' 5I 4'7.
PAGE t, OF' 2
TI-?AN,SHtTTEn ,.-,!:.._Rr. rhllTI.-! ARE 'f'l.iE FOLI...O!,.IIN[; I'~EH,~, F'~ '-'::"-
....................... :: r..i ..-:. [::. ~ C K ~',! f.'J IAI [.. ~; D (.~ E
F:.:ECI;IF'T AND RETLIRN ONE SIGNED COPY OF THIS TRAN~HI'rTAL,
EVEN. TS' .
'A' SAND FRAC-GELLED WATE~
STATIC BHP
F'Bl'J
F'BU
F'BU
F'T-',U
GELLED WATEF..' FRAC
I-IYDR~U[.IC FRAC
POST FRAC TEHF' LOGS
F'BU~
¢ TAT.,. ~? BHF'
F'I?.U
PBU
, r.- WATER
GEL,_~zD BATCH FRAC
F'O,~T - '" m
_. F RH,., TEHF' LOG
TEST ISIF'
TEHF' LOG
~.TATIC BI-il"-'
ZTATIn .,',HF
INJECTIV!TY
STATIC BHP
.r..-~ !-i F'
T:: H P-
pr-;U
F'O2T FRAC
BHF'
POST I---RAC TEHF' LOG
HYD, i--- RACTURE
F'BU
F'BU
413/85
4/3/85
~/~/8'"-.;
4/i -2/85
~/ZSf/85
~13il85
4/t/85
4/t/85.
4/2/8Z
4/9- t ~/85
4/7-8/85
4/8/85
4/tt-i3/85
4/t i -i 2/85
4/i 2/85
4/i ':.~ / r.~ q
4/f 3/85
4/iS/85
4/t 3/85
4/i i/85
4/t2/85
4/i o/8~..-
4 /t ?/,o.,~ ·
· ,~,,_,. ~...,....,.
4/t0--i i/85
4/t .4/'--Or~.;
4/t 5/~
4/t
4/i
4/t
,r.. .... ~ ^ r,,,ix!OWLEi)C ED
R," L.,_I PT '
· l'i -.,
DISTR]:BUTION:
B P A E
B,. CURRtER
;.,./t i.. %: ....
_.
DRILL!N6 W, F'ASFIEIR
L , !0 o- r-,'. F. YVfl~,~
H N ~, I :_. r4
NOT.', Z L. F'I.~ ZI_I_ Z F'$ D[L
NS:K CLERK d, RAI'HHELI.
ARCO Alaska. Inc. i~ a Subsidiary of AtlanlicRichlielclCompany
DATE'
~. C', F AI~
5' 0 I"! Z]: 0
LiN I
K ~'TUL l N/VAU!_'f'
ARCO Alaska, Inc '
Post OffiCe-b,.,x 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
March 7, 1985
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: 2F-7
Dear Mr. Chatterton.
Enclosed is the Well Completion Report for the subject well.
you have any questions, please call me at 263-4944.
Sincerely,
J. Gruber
Associate Engineer
JG/tw
GRU4/L216
Enclosure
If
RECE \;ED
MAR 1 1 85
Alaska 0il & Gas Cons. COrrlrnJssion
knchar~;ge
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
ADDENDUM
WELL:
9/25/84
10/08/84
10/12/84
10/12/84
2F-7
8981' PBTD
AFE 901857
RU S/L unit, tst lub to 2500 psi. RIH w/side pocket
retrv'g tls, pull dummy gas lift vlv f/mandrel @ 8365'.
SI well, wait on workover rig.
8885' PBTD
"A" Sand Perfs: 8638'-8657', 8674'-8728' & 8778'-8784'
RU Otis E-Line, tst BOP & Lub to 2700 psi. RIH w/CCL &
temp tl, tie in w/short jts f/8650'-8500', tag btm @
8885'. Log f/8880'-8350', POOH. Chg tl to HP press, tie
in w/short jts f/8650'-8500'. Take grad @ 8700', POOH to
lub. RD & secure well.
9364' PBTD
RU Camco, GIH w/CCL/Temp log, tag fill @ 8985', log out,
RD Camco.
FRACTURE STIMULATION SUMMARY
AFE 404128
Begin Frac Work At: 1741Hrs, 10/12/84
B. J. Hughes frac'd Kuparuk "A" sand performations
8778'-8784', 8714'-8718', 8704'-8714' & 8694'-8704' in 7
stages per revised procedure using hot diesel,
diesel/gel, 100 mesh & 12-20 sand. Pressured annulus to
1000 psi with diesel. Test lines to 6000 psi; OK.
Pumped 40 bbls of 120° diesel w/5% J-40. Stage #1, 100
bbls gel diesel pre-pad @ 14-20 BPM w/5000-3500 psi.
ISIP = 2150 psi. Stage #2, 20 bbls of gel @ 15 BPM
w/3500 psi. Stage #3, 25 bbls of gel w/1 ppg 100 mesh
(1000#) @ 15 BPM w/3200 psi. Stage #4, 25 bbls gel @
3070 psi @ 15 BPM. Stage #5, 26 bbls of gel w/2 ppg of
12-20 sand @ 15 BPM w/3100 psi (2000# of sand). Stage
#6, 50 bbls gel w/7 ppg of 12-20 sand (11,200#) @ 15 BPM
w/3100 psi. Stage #7, flush w/72 bbls of gel @ 15 BPM
when screened out (16 bbls short of total).
Pumped 1000# of 100 mesh and 8500# of 12-20 in formation,
leaving 4700# of 12-20 sand in casing. No CCL/Temp run
because of screen out.
Load to recover 348 bbls of diesel.
Job complete at 1810 hrs, 10/12/84.
RECEIVED
I 3 1985
Alaska 0ii & G~s Cons. Commission
Anchorage
ADDENDUM
WELL:
2F-7
10/14/84
10/16/84
10/18/84
10/19/84
8900' PBTD (8693' WL PBTD - Btm Perf @ 8784')
GIH, tag fill @ 8693', POH. 91' fill above perf; need to
CO. Well SI.
8900' PBTD (CTU @ 8891', Tbg tail @ 8434', Btm Perf @
8784')
GIH w/CTU while pmp'g .2 BPM. Start 350 scf N & 2.2 BPM
of gel @ 8740'. Wrk in & out of csg, tag fsh ~op @ 8891'
(CTU tally). Switch to diesel, displ hole & displ hole
while POH. SI f/sd to settle.
8900' PBTD (CTU @ 8891', Tbg tail @ 8434', Btm Perf @
8784')
"A" Sand Perfs: 8694'-8718' & 8778'-8784'
RU S/L, RIH w/sinker bars, tag fill @ 3332', POH. RIH
w/2" bailer, bailed dn to 3407', POOH. Flow well f/cln
up.
8900' PBTD (CTU @ 8891', Tbg tail @ 8434', Btm Perf @
8784')
"A" sand perfs 8694'-8718' & 8778'-84'.
Cont flowing well for cln up. Rec'd total 218 bbl (50
bbl this rept) @ 950 psi FTP. SI. RU S/L, tst BOP & lub
to 2500 psi; OK. RIH w/bailer, tag fill @ 8796' (12'
rathole). POOH LD, secure.
Drillin~ Superintendent
ED
Alaska 0ii & Gas Cons. Commission
Anchorage
z ~te
ARCO Alaska, Inc.
Post Offic/"'~x 360
Anchorage, ~laska 99510
Telephone 907 277 5637
Date: 2/05/85
Transmittal No: 4824
RE~ TO:
ARCO ALASKA, INC.
ATTN: Records Clerk
ATO-1115B
P~O. Box 100360
~,~Anchorage, AK 99510
Transmitted herewith are the following items. Please acknowledge receipt
and return one signed copy of this transmittal.
PBU SURVEYS &
SEQUENCE OF EVENTS
--2X-7/ 8/16/84 .
---2Z-6/ 9/03/84
2X-6/ 8/16/84
'-- 2X-4/ 8/16/84
--2X-lz 8/16,19/84
--2V-5/ 8/16,19/84
~-~2V-2/ 9/07/84
-~2F-9J' 8/28/84
/
--2F- %-10/08/84
--2F-~~ 10/07/84
~-2B-l~~ 9/03/84
~2C-5 / 8/17/84
· -~lY-!3/ 8/16/84
~lY-9/ 9/07/84
---1Y-5/ 9/14/84
1Y-5~ 9/06/84
~lG-6~ '8/25/84
~lH-4~ 9/04/84
--1F-12¥ 9/09/84
~-lF-9 ~ 8/17,18/84
~-iF-8z 8/16,17/84
--1E-8~~ 10/12/84
~lD-5~ 10/07/84
~lA-4~ 9/02/84
~--1A-3~ 9/02/84
Gearhart
Otis
Gearhart
Camco
Camco
Dresser
Otis
Otis
Camco
Otis
Otis
Otis
Dresser
Camco
Camco
Otis
Otis
Otis
Otis
Camco
Camco
Otis
Camco
Otis
Otis
Receipt Acknowledged:
B. Currier
Drilling
"HP 232"
"HP 233"
9/0.5/84
8/17/84
8/16/84
10/1.5/84
10/07/84
"Static BHP"
"PBU""
"PBU"
"SBHP" "E Line"
"Pressure ?alloff"
DISTRIBUTION
W. Pasher
State of AK
BPAE
Geology
G. Phillips
Sohio
Chevron
Mobil
Phillips Oil
Union
D&M
NSK Ops.
J. Rathme!l
Well Files
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510
Telephone 907 276 1215
January 10, 1985
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT' 2F-7
Dear Mr. Chatterton'
Enclosed is a Well Completion Report for the subject well.
you have any questions, please call me at 263-4944.
Sincerely,
Gruber
Associate Engineer
JG/tw
GRU3/L44
Enclosures
If
RECEIVED
J A ~ 1 ~ 1985
Alaska Oil & Gas Cons. Commission
Anchorage
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
ARCO Oil and Gas Company
Daily Well History-Final Report
Instructions: Prepare and submit the "Fil~a~rt" on the first Wednesday atter allowable has been assigned or well is Plugged, Abandoned, or Sold.
"Final Report" should be submitted als~-wl~;bPerations are suspended for an indefinite or appreciable length ol time. On workovers when an official test is not
required upon completion, report col~ple~tf~i¥ alld representative test data in blocks provided. The "Final Report" form may be used for reporting the entire
operation if space is available. ~:.?:~ -
~ ::.- ~
Accounting cost center code
District
Alaska
North Slope Borough
State
Alaska
I County or Parish
Fie~d [LeaseorUnit IWellno.
Kuparuk River ADL 25657 2F-7 W/O
Auth. or W.O. no. ~ Title
AFE 901857 I Recompletion
Pool 102 API $0-029-21076
Operator A.R.Co. W.I.
ARCO Alaska, Inc. 56.24%
Spudded or W.O. begun Date
~orkover 9/26/84
Iotal number of wells (active or inactive) on this
cst center prior to plugging and J
bandonment of this well
I
our I Prior stalus if a W.O.
I
1730 hrs
Date and depth
as of 8:00 a.m.
10/02/84
Old TO
Released rig
1000 hrs
Classilications (oil, gas, etc.)
Oil
Complete record for each day reported
7" @ 9021'
8900' PBTD (Parker), RR
Diesel & crude
RR @ 1000 hrs, 10/01/84. Wait on weather to lower
derrick & move to DS 2F-8.
RECEIVED
] 1 4 19 5
Alaska 011 & Gas Cons. Commission
Anchorage
INew TD
Date
10/01/84
PB Depth
8900' pBTD
Kind of rig
Type completion (single, dual, etc.)
Single
Rotary
Producing method Official reservoir name(s)
Flowing Kuparuk Sands
Potential test data
Well no. Date Reservoir Producing Interval iOil or gas Test time Production
Oil on test Gas per day
Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Etlective date
corrected
The above is correct
For form preparation and distribution,
see Procedures Manual, Section 10,
Drilling, Pages 86 and 87,
10/23/84 [it,e
Drilling Superintendent
AR3B-459-3-C
Number all daily well history forms consecutively
Jas they are Drepared for each we .
jPage no.
2
Dlvll~on of AllantlcRk::hfleldComp~ty
AtlanticRichfieldCompany ~'
Daily Well History-Initial Report
Instructionl: Prepare and submit the "lltlt~J Report" on the first Wednesday after a well is spudded or workover operalions are starled.
Daily work prior to sPUddlng-~floUld be summarfzed on the form giving inclusive dates only.
:
_
District County or Parish
Alaska North Slope Borough
Field Lease or Unit
Kuparuk River ADL 25657
Auth. or W.O. no. T t a
AFE 901857 Recompletion
JState
Alaska
Well no.
2F-7 W/O
Pool 102 AP1 50-029-21076
Operator ~ A.R.Co's W.I.
ARCO Alaska, Inc.
Workover 9/26/84 I 1730 hrs
Date and depth
as of 8:00 a.m.
9/27/84
9~28~84
9/29/84
thru
10/01/84
Complete record for each day reported
56.24%
7" @ 9021'
8931' PBTD, Set BPV
10.1NaCl/NaBr
Accept rig @ 1730 hrs, 9/26/84. Pull BPV, Pmp 465 bbls 10.1 ppg
N~C1/NaBr, gas bubbling out of tbg. RU FMC to set BPV.
7" @ 9021'
8931' PBTD, RIH w/fsh'g string
10.1NaC1/NaBr
ND tree, NU & tst BOPE; OK. Pull 264 its, 3½" tbg, PBR backed out of XO
bet PBR & pkr. PU fsh'g tls, RIH.
7" @ 9021'
8900' PBTV (Parker), Set BPV
Diesel & crude
RIH w/fsh'g string, latch into fsh, CBU, POOH, no rec'y. RIH
w/OS, tag fsh @ 8403', fsh fell away. RIH w/singles to 8894',
tag fsh, no indication of latch up on fsh, CBU, POOH w/OS & LD
fsh'g string. PU 6-1/8" bit, RIH, tag fsh @ 8894', CBU, POOH.
Old pkr left in hole, TOF @ 8894' RIH w/263 jts, 3½", 9.3#
J-55 tbg & lnd w/ FHL retv pkr @ 8406', "D" Nipple @ 8422',
shear out sub @ 8434'. ND BOPE, NU & tst tree to 3000 psi.
Dlspl w/30 bbl diesel & 280 bbls crude. Drop ball. Set
packer. Test tubing to 2200 psi. Test annulus to 2500 psi.
Shear out ball. Set'BPV.
RECEIVED
.. AN 1 a 1985
Alaska 0ii & Gas Cons. Commission
Anchorage
The above is correct
Signature
For form preparation and distribution,
see Procedures Manual, Secffon 10,
Orilling, Pages 86 and 87.
JDate
10/23/84
Drilling Superintendent
AR3B-459-1-B
INumber all daily well hislory forms consecutively
as they are preparecl for each well.
i Pag~ no.
ARCO Alaska, I?----
Post Off, z:lox 100360
Anchorage, Alaska 99510
Telephone 907 276 1215
December 31, 1984
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: Subsequent Sundry Reports - Various Wells
Dear Mr. Chatterton'
Enclosed are Subsequent Sundry Reports for the following wells'
1E-5
1E-24
2F-7
2F-8
If you have any questions, please call me at 263-4944.
.
Sincerely,
Gruber
Associate Engineer
JG/tw
GRU3/L24
Enclosures
RECEIVED
JAN 0 2 1985
Alaska 0il & Gas Cons. Commission
Anchorage
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
"-" STATE OF ALASKA ~-'
ALASKA L~L AND GAS CONSERVATION COwlMISSION
SUNDRY NOTICES AND REPORTS ON WELLS
DRILLING WELL []
COMPLETED WELL
OTHER []
2. Name of Operator
ARCO Alaska, Inc,
3. Address
P. 0. Box 100360, Anchorage, AK 99510
4. Location of Well
Surface: 565' FSL, 1570' FEL, Sec.28, T11N, R9E, UN
5. Elevationinfeet(indicate KB, DF, etc.)
127' RKB
I 6. Lease Designation and SerialNo.
ADL 25657 ALK 2583
7. Permit No.
84-20
8. APl Number
50- 029-21076
9. Unit or Lease Name
Kuparuk River Unit
10. Well Number
2F-7
12.
11. Field and Pool
Kuparuk River Field
Kuparuk River Oil Pool
Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data
NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF'
(Submit in Triplicate) (Submit in Duplicate)
Perforate [] Alter Casing [] Perforations [] Altering Casing
Stimulate [] Abandon [] Stimulation [] Abandonment
Repair Well [] Change Plans [] Repairs Made [] Other
Pull Tubing [] Other [] Pulling Tubing ~
(Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.)
13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any
proposed work, for Abandonment see 20 AAC 25.105-170).
Accepted rig ~ 1730 hfs, 09/26/84. Killed well. Set BPV. ND tree. NU BOPE & tstd to 3000 psi - ok. Pullec
tubing hanger and 3-1/2" tubing. (Old packer left in hole.) Ran 3-1/2" completion assy w/tail ~ 8434', FHL
pkr ~ 8406', & SSSV ~ 1953'. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well w/30 bbls diesel & 280
bbls crude. Dropped ball Set BPV. Secured well & released rig @ 10/01/84.
RECEIVED
JAN 0 2 ]985
Alaska Oil & Gas Cons. Commission
Anchorage
14. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed Title Associate Enqi neet
The space below f~ Commission use
Conditions of Approval, if any:
Approved by
Form 10403
GNU3/SNO5
By Order of
COMMISSIONER the Commission
Date
Submit "Intentions" in Triplicate
Rev. 7-1-80 and "Subsequent Reports" in Duplicate
ARCO Alaska, '
Post Ofh~,= Box 100360
Anchorage, Alaska 99510
Telephone 907 276 1215
September 21, 1984
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK. 99501
SUBJECT' 2F-7
Dear Mr. Chatterton'
Enclosed is a Sundry Notice for the subject well. We propose to
pull the existing tubing, replace the PBR/packer crossover, and
re-run the 3-1/2" completion assembly.
Since we expect to start this work on September 28, 1984, your
earliest approval will be appreciated. If you have any
questions, please call me at 263-4970.
Si nc/~e~ely,
JBK/JG/tw
GRU1/L47
Enclosures
RECEIVED
SEP 2 41 1t
At~S~a Oil & Gas Cons. Commission
Anchorage
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION t;OMMISSION
SUNDRY NOTICES AND REPORTS ON WELLS
DRILLING WELL []
COMPLETED WELLx~
OTHER []
2. Name of Operator
ARCO Alaska, Inc.
3. Address
P. 0. Box 100360, Anchorage, AK 99510
4. Location of Well
Surface: 565' FSL, 1570' FEL, Sec.28, T11N, RgE, UM
5. Elevation in feet (indicate KB, DF, etc.)
RKB 127'
12.
6. Lease Designation and Serial No.
ADL 25657 ALK
7. Permit No.
84-20
8. APl Number
50- 029-21076
9. Unit or Lease Name
Kuparuk Riv~.r Iln'i~
10. Well Number
2F-7
1 1. Field and Pool
Kuparuk River Field
Kuparuk River Oil Pool
Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data
NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF'
Perforate
Stimulate
Repair Well
(Submit in Triplicate) (Submit in Duplicate)
[] Alter Casing [] Perforations [] Altering Casing
[] Abandon [] Stimulation [] Abandonment
[] Change Plans [] Repairs Made [] Other
[]
[]
[]
Pull Tubing ~. Other ~ Pulling Tubing
(Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.)
13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any
proposed work, for Abandonment see 20 AAC 25.105-170).
ARCO Alaska, Inc., proposes to perform a workover on 2F-7. The procedure will be as follows:
1. Kill well with brine.
2. Pull tubing.
3. Change out crossover between packer and PBR.
4. Re-run 3-1/2" completion assembly.
A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work.
operationally tested each tirp. A non-freezing fluid will be left in all uncemented annuli within the
permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work.
subsurface saf~y valve will be installed and tested upon conclusion of the job.
BOP equipment will be tested weekly and
The
Estimated Start: sePtember 28, 1984
Subsequent Work Beported __ .,
~,+. i nereoy c~"~ mat the foregoing is true and correct to the best of my knowledge.
// -/ //~" - _.. Area Dri]ling Enginee
Signed / / _~,~_ ~/~,J' ~/ ~,~</~,~_,,~ /,tie r
RECEIVED
SEP 2 4 1984
Alaska Oil & Gas Cons. Commission
Anchorage
Conditic~f~s of Approval, if any:
Approved by
6RIGiNAI. SIGN[t~
BI LIIINI[ 8. SBliti
COMMISSIONER
^pproveo Cop;.
Returned
By Order of 7.,, 2 ,.~' -~¢
the Commission Date __
Submit "Intentions" in Triplicate
Form 10-403 GRU1/5N53 and "Subsequent Reports" in Duplicate
R,a~t 7-1J~(~
, :.
KUPARUK ENGINEERING
Well Name: T~~ .~
Transmittal
Date Run #
q/2:Z
/2o
(oqq, o, q COOLPo-_K~,}.,
DISTRIBUTION
NSK Operat ions
Dr il 1 ing
Geolbgy /Ken
State of AK
Bluel~ine
B lu el ine
Film
Blueline & Sepia
as receipt of'" dat~.~,-~_.~.~&~
"-1.'.,.? ,Jori
AT0-1115~
~.0. ~o~ 100360
A~c~o~age, AK 99510
ARCO, Alaska; Inc
Post office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
May 7, 1984
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK. 99501
SUBJECT: 2F-7
Dear Mr. Chatterton'
Enclosed are the well completion report and gyroscopic survey for
the subject well. If you have any questions, please call me at
263-4944.
Sincerely,
. Gruber ~
Associate Engineer
JG' tw
GRU7/L31
Enclosure
Alaska Oil & G~,3 Cons. Commission
AnChorage
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
- .-~\ STATE OF ALASKA .~-~_..
~'~ ALASI'. ')~ AND GAS CONSERVATION ~llSSION
WELL COMPLETION OR RECOMPLETION REPORT AND LO
1. Status of Well Classification of Service Well
OIL C~X GAS [] SUSPENDED [] ABANDONED [] SERVICE []
2. Name of Operator 7. Permit Number
ARCO Alaska, Inc. 84-20
3. Address 8. APl Numbe'r
P. 0. Box 100360, Anchorage, AK 99510 50- 029-21076
4. Location of well at surface 9. Unit or Lease Name
565' FSL, 1570' FEL, Sec.28, TllN, RgE, UM "~LOCATIONS Kuparuk River Unit
At Top Producing Interval ~ VE,~IFIED 10. Well Number
1586' FSL, 1285' FEL, Sec.27, TllN, RgE, UM ~ 2F-7
Total Depth I Surf.
At
1653' FSL, 924' FEL, Sec.27, TllN, RgE, UMI B.H. ~-~ ll. Field and Pool
' Kuparuk River Field
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool
127' RKB ADL 25657, ALK 2583
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions
02/27/84 03/06/84 04/04/84 N/A feet MS LI 1
17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost
9055'MD,6253'TVD 8931 'MD,6167'TVD YES [] NO [] 1953 feet MDI 1400' (approx)
22. Type Electric or Other Logs Run
D IL/SFL/SP/GR/Cal/FDC/CNL, GR/CBL/CCL, Gyro
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 109' 24" 150 sx Cold Set II
9-5/8" 36.0# J-55 Surf 3727' ' 12-1/4" 1040 sx AS Ill & 710 s. Class G
7" 26.0# J-55 Surf 9021' 8-1/2" 300 sx Class G & 250 s. 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)
8778' - 8784' 3-1/2" 8448' 8417'
8674, - 8728, w/4 spf, 90° Phasing "
8638' - 8657' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED
N/A
_.
27. N/A PRODUCTION TEST
Date First Production ] 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 I~
I
Flow Tubing Casing Pressure CALCULATED ~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. 24-HOUR RATE
28. CQRE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
None
'
iVi~--~Y '''~ n -.
A,~,a 0il & Cons. Comn~ission
Anchorana
Form 10-407 GRUT/WC09 Submit in duplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
'" GEoLoGIC MARKERS . ' ' -' ',iF'oRMATIONTESTS ·
i-
NAME Include interval tested, pressure data, all fluids recovered and graviiy,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Top Upper Sand 8553' 5910'
Base Upper Sand 8562' 5916'
Top Lower Sand -8624' 5958' N/A
Base Lower Sand 8810' 6084'
31. LIST OF ATTACHMENTS
Drillino History. Completion Summarv. Gvroscooic Survey f2 cooies)
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
, ,
,-_/' /./.¢ //v ..............
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-
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".
2F-7
Drilling History
NU 20" hydril and diverter. Spudded well @' 1830 hrs on 2/27/84. Drld 12¼"
hole to 3738'. Ran 94 jts 9-5/8" 36# J-55 HFERW BTC csg w/shoe @ 3727'.
Cmtd 9-5/8" csg w/1040 sxs AS III and 710 sxs class "G". Bumped plug w/2500
psi - ok. ~ 20" hydril and diverter. Performed top job w/100 sxs AS I.
Instld 9-5/8" packoff and tstd to 3000 psi - ok. NU BOPE and tstd to 3000
psi - ok witnessed by Doug amos w/AOGCC. Tstd csg to 1500 psi - ok. Drld FC
and cmt. Drld FS and 10 new form. Tstd form to 13.0 ppg - EMW - ok. Drld
8½" hole to 9000'. Ran logs DIL/SFL/SP/GR/CAL/FDC/CN~ f/8992' to 3727'.
·
Cont drlg 8½" hole to 9055'TD as of 3/6/84. Ran 208 its 7" 26# J-55 HFERW
·
BTC csg w/shoe @9021. Cmtd 7" csg w/300 sxs class "G". Bumped plug w/3000
psi - floats held - ok. ND BOPE. Installed 7" packoff and tstd to 3000 psi
- ok. Displ brine from well for freeze protection. Performed arctic pack
w/250 sxs Arctic Set I and 56 bbls csg pack. Secured well and released rig
@2330 hrs on 3/7/84.
DH130
4/16/84
ih
2F-7
COMPLETION SUMMARY
Ran GR/CBL/CCL & Gyro. RD
art/Ea stman-Whi pstock-
RU Gearh ...... ~ Secured well.
~earhart/Eastman-vJnl pseudo, ok
Accepted rig @ 0100 hrs, 04/03/84. ND tree. NU BOPE & tstd - ·
Perforated the following intervals w/4 spf, 90° phasing'
8778' - 8784'
8718' - 8728'
8714' - 8718'
8704' - 8714'
8694' - 8704'
8684' - 8694'
8674' - 8684'
8648' - 8657'
8638' - 8648'
s w/tail @ 8448', pkr @ 8417' & sSSV @ 1953'. ND
~n 3-1/2" complet!o.njas Y~k Disp well w/l_O_..bbls diesel followed by crude
~° e & ts~o - v · ed SSSV. Set BPV. Secured well &
BOPE. NU tre t kr. Open
oil. Dropped~ ~b~al~1 ~&~:se04 %4/84
released rig Lo uoou ,,,2, / '
i'-,m--, ( ¥'
Al~,ska Oil & F;~: Cons. Commission
Anchorage
GRU7/CS09 · tw
KUPARUK ENGINEERING
Date: ~/'7- ~'"/
Well Name:
Transmittal
Log Date Run
DISTRIBUTION
NSK Operat ion Blueline
Drilling Blueline
Geology/L. J. B1/Se
R&D Blueltne
D&M Blueline
F.G. Baker Bluel
D.B. Schafer Blueline
G mology/Ken Film
Return to:
ARCO ALASKA,, ....
ATTN: D. Fay"ALLISON
ATO-1115B
P.0. Box 100360
AnchoraEe, AK 99510
OHFinal
KUPARUK ENGINEERING
Date: ~/~.~'~.~ ~, / ?~.~
Well Name: ,.,~ ~~.c/
Transmittal
Log Date Run eL
DISTRIBUTION
NSK Operat ions
Dr ill ing
Geolbgy /Ken
~te ~f AK
Bluel-ine
Blu el ine
Film
Blueline & Sepia-~
/~/Sign & return the attached
...~I ....
copy as receip~ o.~, dat~ ~ ~ '-" ~
~.. ,., : '.:-
Return to:
ARCO ALASKA, .INC._~
ATTN: D. Fay ALLISON
ATO-1115B
P.O. Box 100360
Anchorage, AK 99510
ARCO Alaska, In(~-~'~
Post Office c~ox 100360
Anchorage, Alaska 99510
Telephone 907 276 1215
April 15, 1984
Mr. C. ¥. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Dear Mr. Chatterton:
Enclosed are the Monthly State Reports for the following wells:
2B-9 2F-7 WSP #3
2B-10 2F-8 WSP #9
2B-11 2F-9 WSP #12
2B-12 2F-10 Hemi Springs State #1
2A-1 WSP #1S
Thank you.
Sincerely,
z Actir~g/District Drilling Engineer
JBK/SHi:ih
ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany
.. , ~ STATE OF ALASKA ._.. /'~),~ //'
AI'ASKi ~IL AND GAS CONSERVATION (' MMISSION
MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIO
1. Drilling well ~ Workover operation []
2. Nam. ~o..f..op~ri~tor _ 7. Perr~
A~UU A±asma, Inc. -
~'Ad~r~SSO. Box 100360, Anchorage, ~ 99510 8'A~N~21076
4. 565' FSL, 1570' FEL, Sec.28, TllN, R9E, ~ 9. Uni~r~easeName
Location of Well
at surface
5. Elevation in feet (indicate ~F, etc.) I 6. Lease Desianation and Serial No.
PAD 98', 127' ADL 25657 ALK 2583
11. Field and Pool
KPK River Field
KPK River Oil Pool
March 84
FortheMonthof. ,19__
:12. Depth at end of month, footage drilled, fishing jpbs, directional drilling problems, spud date, remarks
Spudded well @ 1830 hrs, 02/27/84. Drld 12¼" hole to 3738'. Ran, cmtd &
csg. Performed top job. Drld 8½" hole to 9000'. Ran logs. Cont drlg
9055'TD. Ran, cmtd & tstd 7" csg. Displ brine from well for freeze
Performed arctic pack. Secured well and released rig @ 2330 hrs on 3/7/84.
tstd 9-578"
8½" hole to
protection.
13. Casing or liner run and quantities of cement, results of pressure tests
9-5/8" 36# J-55 HFERW BTC csg w/shoe @ 3727.
"G"o 7" 26# J-55 HFERW BTC csg w/shoe @9021'.
Cmtd w/1040 sxs AS III and 710
Cmtd w/300 sxs class "G".
sxs class
14. Coring resume and brief description
N/A
15. Logs run and depth where run
DIL/SFL/SP/GR/CAL/FDC/CNL f/8992' to 3727'.
6. DST data, perforating data, shows of H2S, miscellaneous data
N/A
APR ! 9 ]f 84
Alaska 011 & Ga~ ¢o~s. ~mmi~don
Anchorage
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
NOTE~uired for each ca!eh_dar month, regardless of the status of operations, and must berfiled in duplicate with the Alaska
Oil and G n Commission by the 15th of the succeeding month, unless otherwise directed.
Form 10~,04 HILL/MR135 Submit in duplicate
2F-7
Drilling History
NU 20" hydril and diverter. Spudded well @ 1830 hrs on 2/27/84. Drld 12¼"
hole to 3738'. Ran 94 jts 9-5/8" 36# J-55 HFERW BTC csg w/shoe @ 3727'.
Cmtd 9-5/8" csg w/1040 sxs AS III and 710 sxs class "G". Bumped plug w/2500
psi - ok. ND 20" hydril and diverter. Performed top job w/100 sxs AS I.
Instld 9-5/8" packoff and tstd to 3000 psi - ok. NU BOPE and tstd to 3000
psi - ok witnessed by Doug amos w/AOGCC. Tstd csg to 1500 psi - ok. Drld FC
and cmt. Drld FS and 10 new form. Tstd form to 13.0 ppg - EMW - ok. Drld
8½" hole to 9000'. Ran logs DIL/SFL/SP/GR/CAL/FDC/CNL f/8992' to 3727'.
Cont drlg 8½" hole to 9055'TD as of 3/6/84. Ran 208 jts 7" 26# J-55 HFERW
BTC csg w/shoe @9021. Cmtd 7" csg w/300 sxs class "G". Bumped plug w/3000
psi - floats held - ok. ND BOPE. Installed 7" packoff and tstd to 3000 psi
- ok. Displ brine from well for freeze protection. Performed arctic pack
w/250 sxs Arctic Set I and 56 bbls csg pack. Secured well and released rig
@2330 hrs on 3/7/84.
DH130
4/16/84
ih
ARCO Alaska, Inc
Post Office ,.,ox 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
April 16, 1984
Mr. C. V. Chatterton
Commi s s i oner
State of Alaska
Alaska Oil & Gas Conservation
Commi ssi on
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: 2F-7
Dear Mr. Chatterton'
Enclosed is a Subsequent Sundry Report for the subject well.
you have any questions, please call me at 263-4944.
Sincerely,
· Gruber
Associate Drilling Engineer
GRU6L95'rb
Enclosure
If
ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany
'STATE OF ALASKA
ALASK, ~ILAND GAS CONSERVATION £ '~IMISSION
SUNDRY NOTICES AND REPORTS ON WELLS
1. DRILLING WELL[]
COMPLETED WELL F~X
2. Name of Operator
ARCO Alaska, Inc.
3. Address
P.-0. Box 100360, Anchorage, AK 99510
4. Location of Well
Surface;
565' FSL, 1570' FEL, Sec.28, T11N, RgE, UM
5. Elevation in feet (indicate KB, DF, etc.)
127' RKB
6. Lease Designation and Serial No.
ADL 25657 ALK 2583
7. Permit No.
84-20
8. APl Number
50-- 029-21076
9. Unit or Lease Name
Kuparuk River Unit
10. Well Number
2F-7
oTHER []
12.
11. Field and Pool
Kuparuk River Field
Kuparuk River Oil Pool
Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data
SUBSEQUENT REPORT OF: (Submit in Duplicate)
Altering Casing
Abandonment
[] Other
NOTICE OF INTENTION TO:
(Submit in Triplicate)
Perforate [] Alter Casing [] Perforations
Stimulate [] Abandon [] Stimulation
Repair Well [] Change Plans [] Repairs Made
Pull Tubing [] Other [] Pulling Tubing
(Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.)
13. Describe Proposed or Completed Operations (Clearly state all 'pertinent details and give pertinent dates, including estimated date of starting any
proposed work, for Abandonment see 20 AAC 25.105-770).
RU Gearhart/Eastman-Whipstock. Ran GR/CBL/CCL and Gyro. RD Gearhart/Eastman-Whipstock. Secured well.
Accepted rig ~ 0100 hfs, 04/03/84. ND tree. NU BOPE & tstd - ok. Perforated the following intervals w/4
spf, 90° phasing:
8778' - 8784'
8714' - 8718'
8704' - 8714' APR ,~ .? i()8~,
8694' - 8704' -' -~
', /
8694 '
8674' - 8684'
8648' - 8657'
8638' - 8648'
/
Ran 3-1/2" completion assy w/tail ~ 8448', pkr ~ 8417', & SSSV ~ 1953'. ND BOPE. NU tree & tstd - ok. Disp!
well w/lO bbls diesel followed by crude oil. Dropped ball & set pkr. Opened SSSV. Set BPV. Secured well
released rig @ 0530 hfs, 04/04/84.
8684' -
AIzska Oil & G.:-_.'s C,.?~;.:;. C'ommis:;ion
[4!." ;' ""-g2,
14. I hereby c~r't-lfy that the foregoing j,s .true and correct to the best of my knowledge.
Signed Title ^rea Dri l 1 ing Engi neet
The space ission use
Conditio~ of Appr~l, if any:
By Order of
Approved byl COMMISSIONER the Commission
Date
Form 10403
Rev. 7-1-80 GRU6/SN41
Submit "Intentions" in Triplicate
and "Subsequent Reports" in Duplicate
KUPARUK ENGINEERING
TRANSMITTAL # ,,.~,_~
TO' FROt,1: . . . b. F~y Allison
DATE' ~.;?~ 2- ~ ~,/ WELL NAME' see 'belo~
!
Transmitted herewith are the following'
PLEASE NOTE- BL - BLUELINE, S - SEPIA, F - FILM~ PC - PHOTOCOPY
·
Well De s c r ipt i on Date
6j6 ?
RECEI PT ACKNOWLEDGED'
-z:-./.../ /b ,,-
DATE' . ,' -: i:.::-::,
PLEASE RETURN RECEIPT ~.O~RCO ALASKA, INC.
ATTN' D. FAY ALLISON- ATO/l115-B
P.o. :oo o
.
· ANCHORAGE, AK. 99510
ARCO Alaska, Inc'
Post Office Box 100360
Anchorage, Alaska 99510
Telephone 907 276 1215
March 26, 1984
Mr. C. V. Chatterton
Commi s s ioner
State of Alaska
Alaska Oil & Gas Conservation
Commi ssi on
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: 2F-7
Dear Mr. Chatterton:
Enclosed is the Subsequent Sundry Report for 2F-7.
any questions, please call me at 263-4944.
Sincerely,
· Gruber
Associate Engineer
JG:tw
GRU6/L59
Enclosure
If you have
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
SUNDRY NOTICES AND REPORTS ON WELLS
1. DRILLING WELL [] COMPLETED WELL []
2. Name of Operator 7. Permit No.
ARCO Alaska, Inc, 84-20
3. Address 8. APl Number
P, 0, Box 100360, Anchorage, AK 99510 50- 029-21076
OTHER []X
4. Location of Well
Surface: 565' FSL, 1570' FEL, 5ec.28, T11N, RgE, UH
5. Elevationinfeet(indicate KB, DF, etc.)
127' RKB
12.
I 6
. Lease Designation and Serial No.
ADL 25657 ALK 2583
9. Unit or Lease Name
Kuparuk River Unit
10. Well Number
2F-7
11. Field and Pool
Kuparuk River Field
Kuparuk River Oil Pool
Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data
NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF:
(Submit in Triplicate) (Submit in Duplicate)
Perforate [] Alter Casing [] Perforations [] Altering Casing
Stimulate [] Abandon [] Stimulation [] Abandonment
Repair Well [] Change Plans [] Repairs Made [] Other
Pull Tubing [] Other [] Pulling Tubing []
(Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.)
13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any
proposed work, for Abandonmentsee20 AAC 25.105-170).
Spudded well ~ 1830 hrs, 02/27/84. Drilled 12-1/4" hole to 3738'. Ran, cemented & tested 9-5/8" casing
w/shoe ~ 3727'. Continued with well as originally planned.
14. I hereby certify~t~hat the foregoing is true and correct to the best of my knowledge.
//
/./~/~..~~..._~ Title Area Dri 11 ing Engineer
Signed
/
/
The space b b n use
Conditions/cf Approval ~f/any:
By Order of
Approved by COMMISSIONER the Commission
Form 10A03
Rev. 7-1-80 GRU6/SN20
Date
Submit "Intentions" in Triplicate
and "Subsequent Reports" in Duplicate
ARCO Alaska, In~
Post Office Box 360
Anchorage, Alaska 99510
Teiephone 907 277 5637
March 15, 1984
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Dear Mr. Chatterton:
Enclosed are the Monthly State Reports for the following wells:
2F-5 2B-5 WSP #3
2F-6 2B-6 Hemi Spring St #1
2F-7 2B-7
2B-8
2B-9
Thank you.
Sincerely,
A~'~~~lling Engineer
JBK/SHi:ih
MAR ]. ,5 t984
Alaska ['iii & Gas Cons. CommissJor~
Anchorage
ARCO Alaska. Inc. is a subsidiary of AtlanticRichfieldCon:pan,.'
MO___NT_H_LY REPORT OF DRILLING AND___WORKOVER OPERATION
· Drilling well ~ Workover operation []
2. Name of operator 7. PermitNo.
ARCO Alaska, Inc. 84-20
3. Address 8. APl Number _____
' P.O. Box 100360, Anchorage, AK 99510 50-
OZg-ZiU/b
9. Unit or Lease Name
565' FSL,1570' FEL, Sec.28, TllN, R9E, UM KPK
4. Location of Well
at surface
5. Elevation in feet (indicate KB, DF, etc.)
PAD 98' 127' RKB
,
6. Lease Designation and Serial No.
ADL 25657 ALK 2583
10. Well No.
2F-7
11. Field and Pool
KPK River Field
KPK River Oil Pool
For the Month of, February ,1~4
12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks
Spudded well @ 1830 hrs, 02/27/84. Drld 12¼" hole to 3738'. Ran, cmtd & tstd 9-5'/8"
csg. Performed top job. Instld 9-5/8" packoff and preparing to tst same as of 3/1/84.
13. Casing or liner run and quantities of cement, results of pressure tests
9-5/8" 36¢~ J-55 HFERW BTC csg w/shoe @ 3727.
"O".
Cmtd w/1040 sxs AS III and 710 sxs Class
14. Coring resume and brief description
N/A
15. Logs run and depth where run
N/A
DST data, perforating data, shows of H2S, miscellaneous data
N/A
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
NOTE--Rep' t~h~ /orm-~'s required for each calendar month, regardless of the status o~f oper:tions, and must b~filed in duplicate with the Alaska
Oil and Gas Conser~ion Commission by the 15th of the succeeding month, unless otherwise directed·
Form 10404 RIT,T./M~] ] 5 Submit in duplicate
2F-7
Drilling History
NU 20" hydril and diverter. Spudded well @ 1830 hrs on 2/27/84. Drld 12¼"
hole to 3738'. Ran 94 jts 9-5/8" 36# J-55 HFERW BTC csg w/shoe @ 3727'.
Cmtd 9-5/8" csg w/1040 sxs AS III and 710 sxs class "G". Bumped plug w/2500
psi - ok. ND 20" hydril and diverter. Performed top job w/100 sxs AS I.
Instld 9-5/8" packoff and preparing to test as of 3/1/84.
DHiO1
3/14/84
ih
STATE OF ALASKA ~-'
~-'~ AND GAS cONSERVATION CC vlIsSION
ALASKA, -
· Status of Well
OIL ~X GAS [} susPENDED [~
Operator
Alaska, Inc.
Address AnchOrage AK 99510
p. 0. Box 100560, '
Location of well at surface
565' FSL, 1570' FEL, Sec.28, TllN, RgE, UM
At Top Producing Interval
1586' FSL, 1285' FEL, Sec.27,
At Total Depth
1653' FSL, 924' FEL, 5ec,27
Elevation in feet (indicate KB, DF, etc.)
127' RKB
Date T.D. Reached
Date Spudded ,3/06/84
02/27/84
Total DeP 8931 ' MD ,6167 ' TVD
9055 ' MD ,6253' TVD
Electric or ~er Logs Run
DIL/SFL/SP/GR/Cal/FDC/CNL, GR/CBL/CCL, Gy
TllN, R9E, UM
ABANDONED [~]
7"
sERVICE El
T11N, RgE, UM
Lease Designation and Serial No.
ADL 25657, ALK 2583
Date comP., Susp. or Aband.
04/04/84
19. Directional Survey
YES [~ NO iii
J-55 Surf
J-55 Surf
CCL/Temp-
!PTH MD
24"
3727'
9021'
1953
Number
84-20
Number
029-21076
9. Unit or Lease Name
Kuparuk River Unit
Number
2F-7
.1. Field and Pool
Kuparuk River Fi el d
Kuparuk River 0il Pool
of Completions
Water DeE if offshore 1
N/A feet MSL
ThickneSs of Permafrost
)th where ssSV set
feet M O 1400 ~
150 s
1040
24. Perforations open to Production {MD+TVD of ToP and Bottom and
interval, size and number)
8778' - 8784'
8674' - 8728' w/4 spf, 90° phasing
8638' - 8657'
ACID, FRACTURf
sQUEEZE, ET(
N/A
Date First Production
of Test ours Tested
PRODU~
of Operation (Flowing, gas lift, etc.)
)IL-BBL
-ER-BBL
'ER-BBL
OIL-BBL
Tubing Pressure _HOUR RATE I~ ATA .
d~ate r. Submit core chips.
Press.
Brief description of lithoiOg¥, porosity, fractures, apparent dips an None
KE sIZE
½AS-OIL RATIO
(corr)
RECEIVED
MAR i 1985
Alaska 0il & Gas Cons. Commission
Anchorag9
Submit in duplicate
GRU4/WC59
cONTINUED ON REVERSE sIDE
Form 10-407
Rev. 7-1-80
,., . '....tGEOLOGic-M-ARKERS .: ' .'~ · ~.: ': ' ': 7~...-... ' ' , ¢ORMATi.ON TES.i~S: ' .
·
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Top Upper Sand 8553' 5910' N/A
Base Upper Sand 8562' 5916'
Top Lower Sand 8624' 5958'
Base LoWer Sand 8810' 6084'
:
31. LIST OF ATTACHMENTS
Artrl~nrl, ,m
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
/]- ,,.~.~,v, u.,.,. ,-,,~j, GCC;'
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 10~107
EMORAN DU M State of Alaska
ALAS_K~.OIL ~D GAS CONSERVATION COMMISSION
/ A~ on ,
TO: cC~a~t . bATE: March 5 1984
./.
THRU:
FROM:
Lonnie C.. Smith / ~*
Commissioner
Doug Amos~
Petroleum Inspector
TELEPHONE NO:
SUBJECT: Witness the BOP Test
on ARCO' s Kuparuk 2F-7
Sec. 28, TllN,R9E,UM,
Permit No. 84-19 on
Parker Rig No. 141.
Wednesday, February 29, 1984: I traveled this date from Anchorage
T0 P~d~e Bay." After witnessing the meter proving at the COT
Plant, I traveled to Parker P~ig No. 141 to Witness the BOP test on
ARCO's Kuparuk 2F-7 Well. The BOP test was delayed because of a
top cement job.
Thursday, March 1, 1984: %"ne BOP test commenced at 7:00 am and was
co~'c'l~ed 'at' 8~-~0' am. One choke manifold valve failed during this
test The valve was replaced and retested. I filled out an
A,O.G.C.C. BOP test report which is attached.
In summary, I witnessed the BOP test at ARCO's Kuparuk 2F-7 Well.
Attachment
02-001AfRev. 10/79)
O&G
4/~
STATE OF AI,ASKA
ALASFJt OIL & GAS CONSERVATION COMMISSION
B.O.P,E. Inspection Report
Inspector
Operator
Well
Location: Sec..
Drilling-Contracto.r
Rig #
Well ~F' 7_~-q
Representative.
Permit ~
~ ~/~asing Set
Representative
Location, General
Well Sign
General Housekeeping
Reserve pit
Rig
-BOPE Stack
Annular 'Preventer_
Pipe Rams h~
Blind aa:ns
Choke Line Valves°.~v%~_~'~.
H.C.R. Valve
Kill Line Valves~~
Check Valve
Test Results: Failures
Test Pres sure
ACCUMULATOR SYSTEM
Full Charge Pressure
Pressure After Closure [Z~) psig
200 psig Above Precharge Attained:
Full Charge Pressure Attained:
Controls: Master
Remote-
~\ OO ps ig I
mil z~ sec
mil ~ sec
Blinds switch cover
Kelly and Floor Safety Valves
Upper Kelly, ,/ /Test Pressure
Lower Kelly. 1 ~'~Test Pressure
Ball Type I u~ Test Pressure
Inside BOP \ ~Test Pressure
Choke Manifold i
No. Valves
No. flanges
Adjustable Chokes
Hydrauically operated choke
Test Time .... ~ ...... ~:~s ~)
Test Pressure
Repair or Replacement of failed equipment to be made within . days and
Inspector/Commission office notified.
I1
Distribution
orig' - A0&GCC .
cc - Operator
cc - Supervisor Inspector
ARCO Alaska, Inc.?='-~
Post Office ~,,.,x 100360
Anchorage, Alaska 99510
Telephone 907 276 1215
February 8, 1984
Mr. C. V. Chatterton
Commi ssi oner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: 2F-7
Dear Mr. Chatterton:
Enclosed is a Sundry Notice for the subject well. We propose to
complete this well with our workover rig.
We expect to start this work on April 5, 1984. If you have any
questions, please call me at 263-4970.
Sincerely,
JBK/JG:tw
GRU5/L163
Enclosures
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
~--.-,.. STATE OF ALASKA .---
ALASKA IL AND GAS CONSERVATION C,..AMISSION
SUNDRY NOTICES AND REPORTS ON WELLS
1. DRILLING WELL [] COMPLETED WELL []
2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 84-20
3. Address 8. APl Number
P. 0. Box 100360, Anchorage, AK 99510 50- 029-21076
OTHER F~X
4. Location of Well
Surface: 565' FSL, 1570' FEL, Sec.28, T11'N, RgE, UN
5. Elevation in feet (indicate KB, DF, etc.)
127' RKB
6. Lease Designation and Serial No.
ADL 25657 ALK 2588
9. Unit or Lease Name
Kuparuk River Unit
10. Well Number
2F-7
11. Field and Pool
Kuparuk River Field
Kuparuk River Oil Pool
12.
Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data
NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF:
(Submit in Triplicate) (Submit in Duplicate)
Perforate ¢ Alter Casing [] Perforations [] Altering Casing []
Stimulate [] Abandon [] Stimulation [] Abandonment []
Repair Well [] Change Plans [] Repairs Made [] Other []
[] Other )~ Pulling Tubing []
Pull Tubing
(Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.)
13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any
proposed work, for Abandonment see 20 AAC 25.105-170).
ARCO Alaska, Inc., proposes to complete this well with the Westward Well Service Rig #1. The procedure will
be as follows:
1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro.
2) The rig will be moved on location; the BOPE will be nippled up and tested.
3) Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports.
4) The well will be completed with 3-1/2", 9.2#/ft, J-55, BTC tubing.
A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested
weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within
the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. Th~
subsurface safety valve will be installed and tested upon conclusion of the job.
Estimated Start: April 5, 1984
Subsequent 'Work Beportecl
14. I hereby cert~,fy that the foregoing is trLJe and correct to the best of my knowledge.
Signed . Title
Th e space ~ ~r C~o~ss;o n"~use
Conditions'of APprov~l, if any:
Date
SIGN[II
LONfllE C. Sliii]lf
Approved by COMMISSIONER
Approved Copy
Returned
By Order of
the Commission
Form 10-403 GRU5/SN87
Rev. 7-1-80
Submit "Intentions" in Triplicate
and "Subsequent Reports" in Duplicate
ARCO Alaska, Inc.~%
Post Office ~,,.,x 100360
Anchorage, Alaska 99510
Telephone 907 276 1215
February 8, 1984
Mr. C. V. Chatterton
Commi ssi oner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: 2F-7
Dear Mr. Chatterton:
Enclosed is a Sundry Notice for the subject well. We propose to
change the 9-5/8" casing depth in order to cover the West Sak
Sands.
Since we expect to start this work on February 25, 1984, your
earliest approval will be appreciated. If you have any
questions, please call me at 263-4970.
Sincerely,
~ea R~qlling Engineer
JBK/GRU5L167: tw
Enclosures
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
STATE OF ALASKA ....
ALASKA _.IL AND GAS CONSERVATION C~..¢IMISSION
SUNDRY NOTICES AND REPORTS ON WELLS
DRILLING WELL []
COMPLETED WELL []
OTHER ~X
2. Name of Operator
ARCO Alaska, Inc.
3. Address
P. 0. Box 100360, Anchorage, AK 99510
4. Location of Well
Surface: 565' FSL, 1570' FEL, Sec.28, T11N, RgE, UN
5. Elevation in feet (indicate KB, DF, etc.)
127' RKB
6. Lease Designation and Serial No.
ADL 25657 ALK 2583
7. Permit No.
84-20
8. APl Number
50-- 029-21076
9. Unit or Lease Name
Kuparuk River Unit
10. Well Number
2F-7
11. Field and Pool
Kuparuk River Field
Kuparuk River Oil Pool
12.
(Submit in Triplicate)
Perforate [] Alter Casing [] Perforations
Stimulate [] Abandon [] Stimulation
Repair Well [] Change Plans ~ Repairs Made
Pull Tubing [] Other [] Pulling Tubing
(Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.)
Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data
NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF:
(Submit in Duplicate)
[] Altering Casing
[] Abandonment
[] Other
13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any
proposed work, for Abandonmentsee20 AAC 25.105-170).
Due to an error in the geologic picks for the K-12 marker on 2F-Pad, ARCO Alaska, Inc., proposes to set the
9-5/8" casing at 3588'MD (2869'TVD)in order to cover the West Sak.
Estimated Start: February 25, 1984
14. I hereby certi.~ that the foregoing is true and correct to the best of my knowledge.
//
,.,&, Drilling Engineer
Signed ( /~ t Title
Area
Condition~ of APprove, if any: Approve¢ Copy
ORIGINAL SIGNED 2Returned/
8Y LOHHIE C. SMITB ~--- / ~
By Order of
Approved by COMMISSIONER the Commission
Date
Form 10403
Rev. 7-1-80 6RUS/SN92
Submit "Intentions" in Triplicate
and "Subsequent Reports" in Duplicate
February 3, 1984
Mr. Jeffrey B. KeWin
Area Drilling Engineer ~
ARCO Alaska, Inc.
P. O. Box 100360
Anchorage, Alamka 99510
Re:
Mupar~k River Unit 2F-7
ARCO Alaska, Inc.
Permit t~o. 84-20
Sur. Loc. 565'FSL, 1570'FB~, Sec. 28, TllN, RgE, tN.
Btmho!e Loc. 1354'FSL, !070'FE~L, Sec. 27, TllN, R9E, L~.f.
Dear Mr. Kewtn:
Enclosed is the approved application for permit to drill the
above referenced well.
If coring is conducted, a one cubic inch chip from each foot of
recovered core t~ required. Sa~p!es of well cuttings and a mud
log are not required. A continuous directional survey !~
required as per 20 AAC 25.050(b)(5). If available, a tape
containing the digitized log information shall be submitted on
al! logs for copying except experimental logs, velocity surveys
and d~_pmeter ~urveys.
Mmny rivers in Alaska and their drainage systems have been
classified as important for the spawning or migration of
anadromous fish. Operations in these areas are subject to
AS 16.05.870 and the regulations promulgated thereunder (Title 5,
Alaska Administrative Code). Prior to com~nctng operations ynu
may be contacted by the Eabltat Coordinator's Office, Department
of Fish and Game.
Pollution of any waters of the State is prohibited by AS 46,
'Chapter 3, Article 7 and the regulation~ promulgated there~mder
(Title 18, Alaska Administrative Code, Chapter 70) and by the
Federal Water Pollution Control Act, as amended. Prior to
co~eneing operation~ yon ma? be contacted by a r~presentative of
theDepartment of Environmental Conservatlon~
To aid u~ in scheduling field work, please notify this office 24
hour~ prior to commencing in_~ta!lation of the b!~wont prevention
Mr. Je~rey B. Ke~_~n
February 3, 1994
eouiDment so that ~ representative of the Co~m3ssion may be
present to witne~ ~st~ng of the ~ ~ ' ~
~ equ~.p~..nt before the stlr~ac~
casing ~hoe ~8 drilled. ~ere a diverter system J s required,
please also notf. fy this off,ce 24 hours prior to co~enclng
equipment instalI~!on so that the Comission may witness t,stt~g
,_h.~ shoe of the conductor DJ. pc
before drii!~ng below ~ ~ ~ .
In the event of suspension or abandonment, please give this
office adequate advanc~ notification so that we
witness present.
~. _ .._-.: ?/. ,, ,.: . .
Chaises of
Alaska Oil and Gas Conservation
Ese losure
cc: Department of Fish & Game, Habitat Section w/o encl.
Department of Environmental Con,ernest!on w/o encl.
STATE OF ALASKA
ALASKA O,~_ AND GAS CONSERVATION COl~,,vllSSlON
PERMIT TO DRILL
20 AAC 25.OO5
la. Type of work.
DRILL
REDRILL
DEEPEN
1 b. Type of well
EXPLORATORY []
DEVELOPMENT OIL
DEVELOPMENT GAS []
SERVICE [] STRATIGRAPHIC L~
SINGLE ZONE []
MULTIPLE ZONE
2. Name of operator
ARCO Alaska, Inc.
3. Address
P. 0. Box 100360, Anchorage, Alaska 99510
4. Location of well at surface
565' FSL, 1570' FEL, Sec.28, T11N, RgE, UN
At top of proposed producing interval
1307' FSL, 1414' FEL, Sec. 27, T11N, RgE, UN
At total depth
1354' FSL, 1070' FEL, Sec. 27, T11N, RgE, UN
5. Elevation in feet (indicate KB, DF etc.)
RKB 127' PAD 98'
6. Lease designation and serial no.
ADL 25657 ALK 2583
9. Unit or lease name
Kuparuk River Unit
10, Well number
2F-7
11. Field and pool
Kuparuk River Field
Kuparuk River 0~l Pool
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 completed
:30 mi. NW of Deadhorse miles 1070' (~ TD feet 2F-6 well 60' ¢ surface feet
16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date
8848' HD~ 6219' TVD feet 2560 02/25/84
19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2778 psig@ RO°F Surface
KICK OFF POINT 500 feet. MAXIMUM HOLE ANGLE 50 Ol(see20AAC25.035 (c) (2) 2~117 _psig@_6092 ft. TD (TVD)
21
SIZE
Hole Casing Weight
~4" 16" 65.5#
[12-1/¥' 9-5/8" 36.0#
~-1/2" 7" 26.0#
22. Describe proposed program:
Proposed Casinq,
CASING AND LINER
Grade I Couplingl Length
H-40 / Wel~l
J-55 HF'IRW BTC/
J-55 / BTC/ 8820'
HF-ERW/ I
Liner and Cementing Program
SETTING DEPTH QUANTITY OF CEMENT
MD TOP TVD
80' 29' I 29'
3418' 29' I 29'
I
I
28' I 28'
MD BOTTOM TVD
109' 109'
3447'12779'
I
8848'1 6219'
I
I
(include stage data)
+ 200 cf
1040 sx AS III &
710 sx Class G
450 sx Class G neat
ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 8848' MD (6219'
TVD). A 20", 2000 psi annular diverter will be installed on the 16" conducto~ while drilling the surface hole.
The 9-5/8" casing will be set'through the West Sak Sands at approximately 3447' MD(2779' TVD). A 13-5/8", 5000
psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and
weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is
2778 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an
unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well
will be completed with 3-1/2", 9.2#, J-55, 8rd tbg. Non-freezing fluids will be left in uncemented annuli
through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported
on subsequent reports. A downhole safety valve will be (see attached sheet)
23. I hereby certify that the foregoing is true and correct to the best of my knowledge
SIGNED TITLE Area Drilling Engineer
Th e spa ce b elyf-o r~ro~'myo n ~se '
CONDITIONS OF APPROVAL
DATE
Samples required Mud log required Directional Survey required APl number
[]YES [~O I--lYES J~NO ~"YES I-INO 50- O~1,~- ~/~l 07 ~,
Permit number
~~-q~~ SEE COVER LETTER FOR OTHER REQUIREMENTS
APPROVED
BY
Form 10-401 GR~33
Approval date
,COMMISSIONER DATE February 3, 1 gR4
by order of the Commission
Submit in triplicate
PERNIT TO DRILL
2F-7
installed and tested upon completion of the job. 2F-7 will be 60' away from 2F-6 at the surface. There are no
other close wellbores anywhere downhole. Top of cement for the production string will be placed at 7597'MD,
approximately 800'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8"
x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the
disposal process.
..... ~ ~ :~ . .: : :: ; :.~ ~. , : :: __~' ~ ; ' : ' ~ ~ ~I l, ~:' :'i ; -~ ~ :' ~ ,; ~' ' : : ;: ~ , ' ' ' ' ~ ~ ~ , , ~ ,---' I {~ ~" ~ ~
: : , ~ : { ~ , ~ , , ,
- : : ~ { ~ ~ ~ : ~ ,~ ~ ~ .: ; , : :" ~ :~ : ~ ,~ ', ~, ,~ ~ : * . -~: , ,~ ~ : . . .__~ i . ,,
; .
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~ : . . : . ; ~ : ~ , . i ; , , . ~ , } ~ ~ I : . '
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~ i :.
,~ : : . : ' : , ~ , . ....
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: : ~ ; { }TARI',FT cNT~ '.q'vn=~t~"Trln=Rs~-'nFF=~Rm : "~-- ' * : ~7 , .=- : ~ : ;
~: ,l: ~ ': ,. .... : -'
,~ ................... , _~-~
} . . : : ~ : . , : ..................... ~ ....... ~ .......
: ~ ~ ' , ~ { ' : ............ ; -~ ~- ; : ,
-_~ - _ .... . ~ . :
{ , , . . .....
Surface Diverter S,vs~.em
1. 16" - 2000 psi Tankco starting head.
2. Tankco quick connect assy.
3. I6" x 20" 2000 psi double studded adapter.
¢. 20" 2000 psi drilling, spool w/lO" side
outl ets.
5. 10" ball valves, hydraulically actuated,
w/lO" lines to reserve pit. Valves to open
automat'ically upon closure of annular
preventer.
6. 20" 2000 psi annular'preventer.
· 7. 20" bell nipple.
·
h
Maintenance & Operation
1. Upon initial installation close annular
preventer and verify that ball valves have
opened properly.
2. Close annular preventer and blow air
through diverter lines 'every 12 hours.
3. Close annular preventer in the event.that
gas or fluid flow to surq'ace is detected.
If necessary, manually override and close
ball valve to upwind diverter line. 0o not
shut in well under any circumstances.
16" Conductor
ANNULAR
PREVENTER
II i
~... BLIND RAMS
D IAGR/U'~ .~1
13-5/8" 5000 PSI RSRRA BOP STACK
I. 16" - 2000 psi Tankco stat'ting head
2. 11" - 3000 psi casing head
3. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool
4. 13-5/8" - 5000 pst x 13-5/8' - 5000 pst drJlllng
spool
~. 13-5/8' - 5000 psi pipe rams
6. 13-5/8" - 5000 psi drilling spoo! w/choke and kill
lines
7. 13-5/8" - 5000 psi pipe rams
8. 13-5/8" - 5000 psi blind rams
· 9. 13-5/8" - 5000 ps1 annular
SP OL . %
· . ·
L*
-PIPE
CSG
HD
I I ·
ACCUMULATOR CAPACITY TEST
1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER
LEVEL WITH HYDRAULIC FLUID.
ASSURE TI,IAT ACCUMULATOR PRESSURE IS 3000 PSI glTH
1500 PSI DO~TREAM OF THE REGULATOR.
3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY
AND RECORD THE TIME AND PRESSURE REMAINING AFTER.
ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF.
4. RECORD ON KN)C REPORT. THE ACCEPTABLE LOITER LIMIT
IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING
PRESSURE.
10.
11.
12.
13.
14.
13-5/8' 80P STACK TEST
15.
16.
1. FILL BOP STACK AND I~IFOLD WITH ARCTIC DIESEL.
2. .CHECK TMAT AL/. HOLD O01dN SCRE~IS ARE FULLY RETRACT-
ED. PREDETERMINE DEPTH THAT TEST PLIJ6 IdlLL SEAT
AND' SEAT IN WEUJ'IEAD. RUN IN LOCK I)~ SCREIJS IN
HEAD.
3. CLOSE ANNULAR PREVEETER ANO CHOKES AND BYPASS
VALVES ON MANIFOLD.
4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10
#IMUTES.
5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR I0
MINUTES. BLEED TO ZERO PSI.
6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE
RA~.
7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10
MINUTES.
8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED
DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES.
TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY,
¥ITH 3000 PSI UPSTREN~ OF VALVE AND ZERO PSI
I~STREAM. BLEED SYSTEM TO ZERO PSI.
OPEN TOP SET OF PIPE RAMS AND CLOSE BOTrOM SET OF
PIPE RAMS.
INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10
lqINIJTES BLEED TO ZERO PSI.
OPEN BOll'OM SET OF PIPE RAHS. BACK OFF RUNNING
JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND
TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO
PSI.
OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE
MANIFOLD AriD LINES ARE FULL OF ARCTIC DIESEL AND
ALL VALVES ARE SET IN DRILLING POSITION.
TEST STANDPIPE VALVES TO 3000 PSI.
TEST KELLY COCKS AND INSIDE BOP'TO 3000 PSI WITH
KOOMEY PUMP. *
RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST
FORM SIGN AND SENO TO DRILLING SUPERVISOR.
PERFORH COHPLETE BOPE TEST ONCE A ~IEEK AND FUNC-
TIOI~LY OPERATE BOPE DAILY.
ANNULAR
PREVENTER
·
jm
C
-.
BLIND RAMS'.
) zo
PIPE RAMS
9 f
DRILLING
SPO8OL
PIPE RAMS
~ 7
4
HD
D IAGPJUq #2
13-5/8" 5000 PSI RSRRA BOP STACK
9.
10.
11.
13-5/8" BOP STACK TEST
1. FILL BOP STACK AND MANIFOLD WITH ARCTI.C OIESEL.
CHECK THAT* ALL HOLD BOWN SCREWS ARE FULLY RETRACT-
ED. PREDET~INE DEPTH THAT TEST PLUG WILL SEAT
ANO SEAT IN WELLHEAO. RUN IN LOCK OOWN SCREWS IN
3. CLOSE ANNULAR PREVENTER AND .. CNOKES AND BYPASS
VALVES ON MANIFOLD.
4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10
MINUTES.
$. INCREASE PRESSURE TO 1800 PSI mD HOLE FOR 10
MINUTES. BLEED TO ZERO PSI.
6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE
RA~S.
7. INCREASE PRESSURE TO 3000 PSI &~ID HOLD' FOR
MINUTES.
8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED
BONNSTREAN PRESSURE TO ZERO PSI TO TEST VALVES.
TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY?,
WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI
OUdNSTREA~. BLEED SYSTEN TO ZERO PSI.
OPEN TOP SET OF PIPE RAMS ANO CLOSE BOTTOH SET OF
PIPE RAMS.
INCREASE PRESSURE TO 3000 PSI ANO HOLO FOR
MINUTES BLEED TO ZERO PSI.
OPEN BOTTO~ SET OF PIPE RAMS. BACK OFF RUNNING
JOINT ANO PULL OUT OF HOLE. CLOSE BLINO RAMS ANO
TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO
PSI.
12. OPEN 8LIND RAMS ANO RECOVER TEST PLUG. MAKE SURE
MANIFOLO ANO LINES ARE FULL OF ARCTIC OIESEL AND
ALL VALVES ARE SET IN ORILLING POSITION.
13. TEST STANOPIPE VALVES TO 3000 PSI.
14. TEST KELLY? COCKS ANO [NSIOE BOP TO 3000 PSI WITH
KOO~EY PUMP.
1S. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST
FORM SIGN AND SENO TO DRILLING SUPERVISOR.
16. PERFORM COMPLETE BOPE TEST ONCE A WEEK ANO FUNC-
TIONALLY OPERATE 80P£ OAILY.
9. 13-S/8' -
10. 13-$/8" -
11. 13-S/8' -
7. 13-5/8' -
8. 13-5/8' -
1. 16' - 2000 psi Tankco starting head
2. 11' - 3000 psi casing head
3. 11" - 3000 psi x 7-1/16' - 3000 psi tubing head
4. 7-1/16' - 3000 psi x 1I" - 3000 psi double studded
adapter
S. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool
6. 13-5/8" - 50130 psi x 13-$/8" - SO00 psi dri111ng
spool -
5000 psi pipe rams
5000 pst drt111ng spool w/choke and ktll
lines
5000 psi pipe ram
5000 psi bltnd ram
5000 psi annular
ACOJ~LATOR CAPACITY TEST
1. CHECK AND FILL ACCU/4ULATOR RESERVOIR TO PROPER
LEVEL WITH HYORAULIC FLUID.
2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH
1500 PSI OOgNSTREAN OF THE REGULATOR.
3. OBSERgE TIME THEN CLOSE ALL UNITS SIMULTANEOUSLY
AND RECORD THE TIME ANO PRESSURE RE]~IAINING AFTER
ALL UNITS ARE CLOSED WITH CILRRGING PU~P OFF.
4. RECORD ON NADC REPORT. THE ACCEPTABLE LO~ER LIMIT
- IS 45 SECONDS CLOSING TIME AND i200 PSI REMAINING
PRESSURE.
ARCO Alaska, Inc. '~'~
Post Office Bo,, 100360
Anchorage, Alaska 99510
Telephone 907 276 1215
January 24, 1984
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: Kuparuk 2F-7
Dear Mr. Chatterton:
Enclosed are:
An application for Permit to Drill Kuparuk 2F-7, along with a
$100 application fee
Diagrams showing the proposed horizontal and vertical
projections of the wellbore
o A proximity plat
° A diagram and description of the surface hole diverter system
° Diagrams and description of the BOP equipment
Since we estimate spudding this well on February 25, 1984, your
earliest approval would be appreciated.
If you have any questions, please call me at 263-4970.
Sincerely,
A~~ea~~n~~.En~in.. g'
JBK/JG5L138:tw
Enclosures
ARCO Alaska, Inc, is a Subsidiary of AllanticRichfieldCornpany
PHASE I AS BUILT:
CONDUCTORS I - 8
94.4
160
130
09
010
011
28
27
BASIS OF PAD ELEV. I$ T.B.M.
O.G. ELEV.'s INTERPOLATED FROM DWG.
SR. 8 F- 12- :50 30
REV. I RENUMBER ALL WELLS PER NSK ~
DRILLING 12,/2/83. (180°ROTATION OF ~_
NUMBERING)
REV. 2 CHANGE ALL ELEVATIONS
LOCATED IN PROTRACTED SECTION
TOWNSHIP il N.~ RANGE
2 8 ~ ~ ~1~
9 E'' U M I AT ::'MER? "i'~
,~ltSl$ OF LOCATION IS MONUMENTS C~F.-2 N.E. &
2'C MIDDLE PER LHD ASSOCIATES.
DR IF'-' SITE
AS BUILT
2-F CONDUCTORS
LOCATIONS
WELL I
WELL 2
Y= 5,949, .341.8:5
~ 517,392.5§
9' FSL
Y= 5,949,4(~.95
.X= 517~ 382.34
518' FS L
Y= 5,949,460.06
X' 517~372.18
577' FS L
Lat. 70e !'6'21. 9780"
Loag.. 1,49e 5 I' 33.357~'
1857' FEL
Lat. 70e 16'22.5595"
I.oa~. 149e51'33.896''
1847' FEL
I.at. 70e 16'23.1413"
Lenq. !49e51'34. 161'
1856' FEL
WELL 4 Y, 5,949,51 9.07
X= 517,362.08
636' FSL
WELL 5 Y.5,949,566.39
X= 5,17~658.11
68:5 FS L
WELL 6 'Y-5~949,507.09
x, 517~648.17
624' FS L
WELL. 7
WELL 8'
Y"~949,448.14
~51~17,658'31
FSL
Y · 5~ 949,389.02
X · 517~668.$:5
506' FS L
Lat. 70el6'23.7~19''
Lol~. ~49o51 '34.451"
1866 FEI~
Lat.?O° 16' 24. 18 I I"
LO~. 1,49°51'26.410"
159.0' FEL'
LOt 70° 16'25. 5977"
Lea~. I~ge~i '26. 121"
1580' FEL
~t. ~19'2~.0176"
~ 1~°51'25.851''
1570' FEL'
L~.~e ~'22.435 7'"
LO~. 14~eSl~ 25.54~
1561' FEL
DAVID FILUCCI 52.;
50
I HEREBY CERTIFY THAT I AM PROPERLY .
REGISTERED AND LICENSED TO PRACTICE LAND
SURVEYING IN THE STATE OF ALASKA AND
THAT THIS PLAT R.EPRESENTS A SURVEY MADE
· UNDER MY DIRECT SUPERVISION AND THAT ALL.
DETA/LS ARE CORRECT AS OF NOV.' 5 ~ ! 98~.
~"?[~ ARCO Alaska, Inc.
34 ~ll~x~ DRILL SITE 2,F
CONDUCTOR AS'BUILT
, LOCATIONS
-i~SSSOg! date' 11.9,83 scale' ,". 400'
STATE OF ALASKA .~--.
r- ALASKA ~AND GAS CONSERVATION CC ~ISSION
.WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] -
2. Name of Operator 7. Permit Number
ARCO Alaska, Inc. 84-20
3. Address 8. APl Number
P. 0. Box 100360, Anchorage, AK 99510 50- 029-21076
4. Location of well at surface 9. Unit or Lease Name
565' FSL, 1570' FEL, Sec.28, T11N, RgE, UN Kuparuk River Unit
At Top Producing Interval 10. Well Number
1586' FSL, 1285' FEL, Sec.27, TllN, R9E, UM 2F-7
At Total Depth 11. Field and Pool
1653' FSL, 924' FEL, Sec.27, TllN, R9E, UM Kuparuk River Field
5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet Oi 1 Pool
127' RKBJ ADL 25657, ALK 2583
12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. Nc. of Completions
02/27/84 03/06/84 04/04/84I N/A feet MS LI 1
17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I-VD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost
9055'MD,6253'TVD 8931 'MD,6167'TVD YES [] NO [] 1953 feet MDI 1400' (approx)
22. Type Electric or Other Logs Run
D IL/SFL/SP/GR/Cal/FDC/CNL, GR/CBL/CCL, Gyro
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZEi WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
16" 62.5# H-40 Surf 109' 24" 150 sx Cold Set II
9-5/8" 36.0# J-55 Surf 3727' 12-1/4" 1040 sx AS Ill & 710 s: Class G
7" 26.0# J-55 Surf 9021' 8-1/2" 300 sx Class G & 250 s; 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)
8778' - 8784' 3-1/2" 8434' 8406'
8674' - 8728' w/4 spf, 90° phasing
8638' - 8657' 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED
N/A
27. N/A PRODUCTION TEST
Date First Production Method of Operation (Flowing, gas lift, etc.)
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAs-OIL RATIO
TEST PERIOD II~
Flow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. 24-HOUR RATE q~
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
o.e RECEIVED
~ t '
,AN i z, 1985
Alaska 0ii & Gas Cons. Commission
Anchorage
Form 10-407 GRU3/WC22 Submit in duplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
29. . . 30. ....
-. ....
- -GEOLOGIC MARKERS' ~" . .- 'FORMATION TESTS :
·
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Top Upper Sand 8553' 5910'
Base Uppe~ Sand 8562' 5916'
Top Lower Sand 8624' 5958' N/A
Base Lower Sand 8810' 6084'
.-.
31. LIST OF ATTACHMENTS
Workover Well History
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
>i ,,,,
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-
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 10-407
,, ...-., (.)
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I< I...ll:::' A l:'~l_lK F l: E L D, N O R T H '.S L. O1::' E~ A L A SI< A /
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· ICA L.-..S;E C-I.:.-I.O bE,CA L i'j': LI I_ A T
A PETROLANE COMPANY
REE:ORI'~ ,~. ~ SiUBLV_F~
RADII. J~ OF CURVATLIRE METHOD
CD
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c,L..C F' E. ALASKA
I<UF:'AI::~UK F' I EL.D., NCIR]"H ~''' I" ".~
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TIME ' DATE
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DEF"TH ANF'iLE DIRECTIAN LENGTH DEPTH SECTION 'l"VO C: I] 0 R D I N A T E S D I .-,] AN -.E DIREF:TION F:;EVE]=<ITY
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200. O0 0, 7:=:.. . ._ .., , . . ....... 1 1 I:..Z 0 . 1 ::ii:
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Well History " Yes
-,.
_s~i~ ~/~ ~ ~/., - ...... ~2' .
Core Chips -' ~//z~ ~ --- O/~,. ..
Core Description ~4/df ,'~- __ ~ ..
Registered Survey Plat y~ /_ ~ ~,~. ~? ~:~.
Inclination Survey /~/~.~ ..... ~ ~/~,
Directional Survey ~/~ ~?i ~ ~ ~J ,?~ ~.:z/L/~/~//../ /~~~___
-" t ~ /' /
Drill Stem Test Reports ,/-//j'~,/;z',~_
,
·
PrcddctiOn Test Reports ~ .
Digitized Data ..~x-~.~
· ·
ITEM APPROVE DATE
(1) Fee
(2) Loc
/
(q'thru ~ 5 "5t
(8)
(3) Admin(~hru 11)
(10 a~d 11)
/
(12 thru 20)
e
10.
11.
Lease & Well No. /~__.~
YES Nd REMARKS
1. Is the permit fee attached .........................................
2. Is well to be located in a defined pool .............................
3. Is well located proper distance from property line .....
4. Is well located proper distance from other wells .......
5. Is sufficient undedicated acreage available in this pool
6. Is well to be deviated and is well bore plat included ..
7. Is operator the only affected party ....................
8. Can permit be approved before ten-day wait .............
Does operator have a bond in force ..................................
Is a conservation order needed ......................................
Is administrative approval needed ...................................
..
(21 thru 24)
12.
13.
14.
15. '
16.
17.
18.
19.
20.
Is conductor string provided ........................................
Is enough cement used to circulate on conductor and surface .........
Will cement tie in surface and intermediate or production strings ... ff~.
Will cement cover all known productive horizons .....................
Will surface casing protect fresh water zones .......................
Will all casing give adequate safety in collapse, tension and burst .
Is this well to be kicked off from an existing wellbore .............
Is old wellbore abandonment procedure included on 10-403 ............
Is adequate well bore separation proposed ................ ' .......... ~ ..
21.
22.
23.
24.
Is a diverter system required .........................
Are necessary diagramS 0f diverter and BOP equipment attached
Does BOPE have sufficient pressure rating - Test to 3,~'~'~ ps g .
Does the choke manifold comply w/API RP-53 (Feb.78) ..................
(6) Add:
25.
Additional requirements .............................................
Additional Remarks: ~Z~$~7' ~~D~ /J ~ ~g) ~L~-~ /=~D~
Geology: Engtgeerin~:
.cs
WVA~ JKT~HJH ~T~
JAL/~__~._.M2M ~
rev: 12/08/83
INITIAL GEO. UNIT ON/Orr
POOL CLASS STATUS AREA NO. SHORE
m /-'.,;/ frs'5,,
i
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 APPENDIXi
No special'effort has been made to chronologically
organize this category of information.
I,,,TS
VERIFICAg. ION
!.,vp 01.0.~t02 VERIFICATION ],,I$?'I.~,~G PAGE
DATE :g4/03/ 8
** T~PM NEADER **
SE~VIC~ NA~E :EDIT
ORIGIN :0000
T~PE N~NF :9035
CONTINUATION
PREVIOI~S TAPS :
COMMENTS :TAPE COM~ENTS
,********** E:OF
** F%L[: READER **
FIbE NANF :SPIT ,00!
SE~VIC~ NA~E :
VERSION ~
~ATE :
WILE TYPE
PREVIOUS F'ILF :
** IMFOR~A~In~t R~CORD$ **
~N~N COMT~,MT$
UNIT TYPE CATE SIZE CODE
000 00' 016
o o0~ 004
~o 000 0o:~
000 000 0'02
ooo ooo 004
000 000 0:0:2
000 000 008
000 000 006
000 000 O04
°6.ss:
06
O65
mmmm~ ~ i m I mil ,I~1 ~ [:-1 ~
LYP Ol.t'~.H02 VE~IFICATI, r~N !,IST:!~G PAGE
WELL = 2~-7
STATE = hl,hSKa
JOB t~U~,BER AT ACC: 69035
RUM ~1, DATE b~GC, ED." 5-MAP,-84
bDP: HGH
CASING
TYPE Ft,!I?D
DENSITY
VISCOS?TY
Zt, U'I D LOSS
9.625" ~ 3725' - ~IT SIZE = 8.5" TO g000'
X'C P~LYMER
1,0.2 LB/G R~ ~ 3 810 9 70,0 DF
36,0 S R~F - 4~760 m 70,0 DF
9,0 RMC = 3,300 ~ 70 0 DF
6,6 C3 R~ AT FHT = 1.868 ~ 15~,0 DF
I,VP Ol~.H02 VERtFIC~\TION I,ISTING PAGE
** DAT~..wOR~4AT RFCORD *~
4
9
0
DATU~ ~PECIFTCATION BLt~CKS
~NEM SERVICE: SMRVICE UNI~
.'iD f3. PDER ~
SIZE
4
LOG TYPE
0 0
7 0
7 12
7 0
7
42 68
42 44
42 35
42,. 34
4,2 34
4~ 28
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4.~ 31.
WEPR CODE
86
73
65
66.
AP1 ~P? FILE
CLASS ~OD NO,
0 0 0
0 0 0
48 0 0
0 0 0
O 0 0
32 0 0
2 0 0
0 0 0
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92 0 0
93 0 0
3 0 0
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1
60
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SIZE PROCESS SAMPLE
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0
0
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CODE
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68
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3,7656 g~
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38,7207 DRHO
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wILE; N~ME :EDIT .001
U,AXINU~ I,~NGTH : 1024,
FILE TYPE :
LVP OI.O,HO~. VF~IFIC~T.If~o [.)7. STING PfiGE 9
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