Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout185-225STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
ECEIV50
APR 2 5 2019
1. Operations AbandC1 Plug Perforations E] Fracture Stimulate E] Pull Tubing E]0 o
Performed: Susper❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑
Plug for Redi❑ !rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Whipstoce
2. Operator
Name: ConocoPhillips Alaska, Inc.
4. Well Class Before Work:
5. Permit to Drill Number:
Development Q Exploratory ❑
Stratigraphic❑ Service ❑
185-225
3. Address: P. 0. BOX 100360, Anchorage, Alaska
6. API Number:
99510
50-029-21446-00-00
7. Property Designation (Lease Number):
8. Well Name and Number: K
RU 3F-01
ADL 25643
9. Logs (List logs and submit electronic and printed data per 20AAC25.071):
10. Field/Pool(s):
NIA
Kuparuk River Field / Kuparuk River Oil Pool
11. Present Well Condition Summary:
Total Depth measured 8,730 feet Plugs measured 8295 feet
true vertical 6,245 feet Junk measured None feet
Effective Depth measured 8,646 feet Packer measured 7974, 8280 feet
true vertical 6187 feet true vertical 5723, 5936 feet
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 78 feet 16 115' MD 115' TVD
SURFACE 3,934 feet 9 5/8 " 3,971' MD 3062' TVD
PRODUCTION 8,611 feet 7 8,646' MD 6187' TVD
Perforation depth: Measured depth: 8066-8219. 8417-8423, 8428-8468 8498-8526 feet
True vertical depth: 5787-5893. 6030-6034, 6037-6065. 6085-6105 feet
Tubing (size, grade, measured and true vertical depth) 3.5" x 2.875" @ 8279 L -80/J-55 8,303' MD 5,952' TVD
Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER FHL PACKER 7,974' MD 5,723' TVD
PACKER - BAKER FB -1 PACKER 8,280' MD 5,936' TVD
SSSV -NONE
12. Stimulation or cement squeeze summary:
Intervals treated (measured): Cement Squeeze 8000'-8265'
Treatment descriptions including volumes used and final pressure:
37 bbls 15.8ppg Class "G" Cement
13. Representative Daily Average Production or Injection Data
0Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation: Shut -In
Subsequent to operation: Shut -In
14. Attachments (required per 20 A C 25.070, 25.071, 8 25.283)
15. Well Class after work:
Daily Report of Well Operations O
Exploratory ❑ Development Q Service ❑ Stratigraphic ❑
Copies of Logs and Surveys Run ❑
16. Well Status after work: Oil O 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 N/A if C.O. Exempt:
319-093
Contact Name: Ryan McLaughlin
Authorized Name: Ran McLaughlin
Contact Email: ryan.mclaughlin@cop.com
Authorized Title: CTD Engineer
Authorized Signature: Date: z_/ � Contact Phone: (907) 265-6218
Form 10-404 Revised 4/2017 V -7-L 5-1-7// '1 Submit �/q `J Submit Original Only
`O/ / / REIDI iIS4�- APR 2 6 2019
KUP PROD WELLNAME 3F-01 WELLBORE 3F-01
Conocomillips \ Well AtWtiutes Max Angle 8 MD TO
_ _ 1 Held Na11N W¢Ilbose APV11W1 WellMeslalus [Ifl151 MB^fl-, p[I Btm (RXB)
ABJIt(1.IFIC. IKUPARUH RIVER UNIT IS(NITl9lddfiM IPann Ir, al nnn aoann
ISSSV'. NIPPLE
a501.amola 2'.14:sa vM
Last Tag
vdadd wma&addi
Annotation oepin(WE) 1 an. pass
wellEole fast Mal Br
........_..................... _
................
1wuGER; x4o--
Last Tag: SLM 8,460)/9201)
3F-01 zembaej
Last Rev Reason
Annomtlon End pate 1 Naddid reLast MM BY
REV REASON: POST RIG GLV INSTALL 41112019 3F-01 aappleh
Cuing Strings
Cae Ina paMhption Op pn) I)Tm Top IRKBI set peOn(nleel Set Oeplh(TVD1... WIILen JI -Glade TOP rnryaU
CONDUCTOR 16 15.06 37.0 1150 115.0 82.50 HAO WELDED
n 0,115°
C sft Bes[nption 00 (In) Ip Anl TOPINKBI Bet Oepin INKS) SetppMITVB)._YNLen 11... Gentle Top Th.CONDUCTOR;
SURFACE 9518 8.92 37.0 3,970.6 3,061.6 38.00 J-55 BTC
NIPPLE', 5181
Caslna pa"N'd*" OD gnl .(m) Top IM(BI setorom M.)SNM 11VBI... W41en 11...G,ada Tap Thread
PRODUCTION 7 828 35.0 8.646.1 6,18)1 2680 755 BTC
Tubing Strings
TuErut Oes[nplion St11n0 Ma... ID lint Top INKS) set Oepin (N.. 3N OepM jNp)(... W<(IhM) Glade lap Connection
TUBING -WO 3112 2.99 33.0 ),968.5 5,719.1 9.30 L-80 EUE9rntl
GABLIFT:aBQa
Completion Details
TOP(1VD) TupinaNnminm
Top NINE) NX.)('1 dom pes Com m(nl
33.0 33.0 003 HANGER JFMC TUBING HANGER 2992
518.1 51801 399 INIPPLE ICAMCO2875""DS"NIPPLE 2.875
suRFACE. a]os.ame_
7,9558 5,)10.2 45.83 LOCATOR BAKER LOCATOR 3.830
),9566 5]108 4582 SEAL ASBV BAKER SEAL ASSY me PER, 3N"$ikk-uD" 2990
G46 LIFT, 4050.5
TuOlnp pKM,mn anima Ma...lI(in)
TUBING -Original 3112 2.99
3.5"x2.8)5"@82)9'
TaP ISim,
),960.2
9N Depth llL.
8,303.4
set OepM jTVO1I
5,951.6
Wt11K911
9.20
Grad.
0
Tap Conndcdan
EUE BRD
Completion Details
G4SUFT, F.L
Top IND) I TaPIMI xo(iin
TO79602 INKS) PI IM1m pes cam 10 (in)
7,9603 5,713.3 45.81 PER BAKER PER 3.000
GASLFT;Eamon
7,9)39 5.)22.9 4575 PACKER BAKER FHL PACKER 3.000
9,2659 5.925) 48.32 NIPPLE AVA BPL PORTED 0% NIPPLE 2.300
82682 5,9273 46. 70-ReCunng CROSSOVER 3.5"TO 2.875" 2.441
Ons .1. T.4]4a
8 784 5,934.3 4634 LOCATOR BAKER LOCATOR 3.060
8,2802 5,935.6 4. PACKER BAKER FB -1 PACKER 4000
,283.4 5,937.8 4.35 SBE BAKER SEAL BORE EXTENSION 4.000
GAB LIFT', i,fl99.3
8295.2 5,945.9 4.36 NIPPLE CAMCO D NIPPLE NO GO .50
8,3027 5,951.1 4638 SOS ICAMCC SHEAROUT BUB 2441
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
L(CATOR; ],BSSB
Top MKB)
Top ( D)
(NKB)
IDD .
1.1 Des Com Run pots ID(in)
SEnL near 76%6
vaR. ],eapx
8?43.05909.9
4629 WHIP TOCK- et a'monobone lop 43'bottom @8 3/1912019 1.000
MONOBORE
..R: To".
8,265.0
5,925.1
46.32 Sand HILT Dump added sandon pliug mol' o saacarb 31412019 0.000
On top.
PlWctlm caslry<:anynL
spend B
8.295.0
5,9458
46.36 PIUA Se12.25"CA2PIpg NZ2019 0000
PRODNCTI A 80117
perforation S Slots
Top INKBI
BM(NKB)
TOp (NO)
INKS
Blm Np
( 1
IM(9
LMY2, bne
Ilan
am.
Dena
InI
)
Type
Cam
C WERPrs:alzamuB
IPERF: e.oeeoe,zlso-
8.066.0
8,2180
5,)8).1
5,893.3
- -1,
UNIT B, 3F-01
112A1985
12.0 IPERF
1
Csg
deg. aslnp.
Gun
8,41]0
6,423.0
6.0298
6,033.9
A-4, 3F-01
11rzL1985
4.0 IPERF
deg Pbasmg, 'HJ II
Csg
Gun
8,428.0
8,4600
6.03).4
6,064.87
3F-01
1112)11965
4.0 IPERF
deg. phasing, H
Csg
Gun
8.4988
8526B
6.085.4
6,1043
A-2, 3F-01
112711985
40 IPERF
WITeA. p5asing, ZFRJ 17
NMIPBTGCK-MONOBORE;
CSg
Gun
&aw0
Cement
Squeezes
Top IND) I Bim Bob)
wPPLE; e,3b5,5
T,pdNB) Blm(fiKB) PIKE) plan) I Des s.no. eom
80008 82658 5741.0 5,925.1 PF -put" 3182019 BBL 15.8PPGCuS CEMENT PU IPD
sale vLO:am.
PAcI(EA.IUNa.z
Casing Cement INTO FORMATION
8.123.0 8,285.0 5,826.8 5,925.1 Plug 3182018 L 15. PPGCLASS IFNAENILAIDIN
SBE:&zea.4
lCiannumn
TUBING
Mandrel Inserts
sl
NIPPL,N.2
an
Php:9.A50
H Tap (TVD) Valve Latch PMUds TRORon
TaPINt81 WB) Mahe Mosel Op(In) a. Trye raw Rn) (.0 Run WW Com
1 3,162.8 2,5)11 dA MNG 112 GAS LIFT GLV RK 0 186 1 1,204.0 14ItY2019
2 4,8505 3,6248 5WCO MM= 112 GAS LIFT OV RK 0.250 0.0 411 18
sps; e.mzT
3 5,996.9 4,3704 CAMCO MMG 1112 GAS LIFT OMY RK 0000 0.0 4/1Q019
4 6,840.4 4,940.4 CAMCO MM 1112 GAS LIFT MY- RK 0.000 0.0 4/12019
5 7,4743 5,376.5 Z5 MCO MM11
G 12 GAS LIFT DMV RK .000 OB 4/11 19
6 7,896.3 5,858.8 CAMCO MMG 112 GAS LIFT DMY RK RBBB 0.0 4111209
7 8,0117 5,749.3 CAMCO KBUG 1 PROD OMY BK 0.000 0.0 IUIBII988
IPERF:841708Lw 0-
Notes: General & Safety
End Dad Annual -
51412003 NOTE. WAIVERED WELL: IA x OA COMMUNICATION
IPERF, dA...,4aa.0-
IPERF, 89�0$5m.0-
PRGDUCPPV;st"Nia.1
Operations Summary (with Timelog Depths)
3F-01
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Time
End Time
our (M
Phase
Op Code
Activity Cade
Time P -T -X
Operation
Start Depth
(aKB)
End Depth (NKB)
3/15/2019
3/15/2019
2.00
MIRU
MOVE
RURD
P
Continue RD checklist, move shop &
0.0
0.0
15:00
17:00
1/2 -Way house from 2G-Pag to 3F -
1BOP's
Pad, secure stairs & landings, secure
3/15/2019
3/15!2019
3.00
MIRU
MOVE
RURD
P
Complete RD checklist, RU to NES
0.0
0.0
17:00
20:00
trucks, pull modules off well, jeep -up
modules, ready to move
3115/2019
3/16/2019
4.00
MIRU
MOVE
MOB
P
Begin move from 2G -Pad to 3F -Pad
0.0
0.0
20:00
00:00
3/16/2019
3!16/2019
3.50
MIRU
MOVE
MOB
P
Arrive at 3F -Pad
0.0
0.0
00:00
03:30
3/16/2019
3/16/2019
4.50
MIRU
MOVE
MOB
P
Spot sub & pits over well, lay mats,
0.0
0.0
03:30
08:00
drop stairs
3/16/2019
3/16/2019
1.50
MIRU
MOVE
TURD
P
Begin RU checklist, get COMMS up,
0.0
0.0
08:00
09:30
set -down shop & lay mats, install
scaffolding & platform around well
3/16/2019
3/16/2019
2.50
MIRU
MOVE
NUND
P
Continue RU checklist, spot tiger -tank
0.0
0.0
0930
12:00
& MU hard-line, begin NU ROPE, MU
PUTZ, grease tree valves & Tangos,
complete NU BOP
.' Rig Accept: 3/16/19 @ 1200 him
3/1612019
3/16/2019
2.10
MIRU
WHDBOP
OTHR
P
Complete RU checklist, grease Bravo
0.0
0.0
12:00
14:06
& Romeo valves, fluid pack lines
3/16/2019
3/16/2019
0.40
MIRU
WHDBOP
PRTS
P
Perform shell test 5000 psi
0.0
0.0
14:06
14:30
3116/2019
3/16/2019
7.00
MIRU
WHDBOP
BOPE
P
Begin BOP test (250 low / 3500 high)
0.0
0.0
14:30
21:30
F/P Lower 2", cycled once and
passed.
"' Witnessed by Matt Herrera of the
AOGCC
3/16/2019
3/16/2019
1.00
MIRU
WHDBOP
RURD
P
PT tiger tank lin and PDL to 2501
0.0
0.0
21:30
22:30
3500 psi - good, checked pack offs
3116/2019
3/16!2019
1.00
MIRU
WHDBOP
RURD
P
Blow down post BOP test, open well
0.0
0.0
22:30
23:30
and confirm zero pressure. Pick up
elevators, prep floor for picking up
tools.
3!16/2019
3/17!2019
0.50
SLOT
WELLPR
PULD
P
PJSM, PU BHA#1 and load into a
0.0
63.0
23:30
00:00
1
dead well.
3/17/2019
3/17/2019
0.60
SLOT
WELLPR
PULD
P
Compete BHA#1 and load into a dead
0.0
63.0
00:00
00:48
well, Bump up, set counters.
3/17/2019
3/17!2019
1.20
SLOT
WELLPR
TRIP
P
RIH W BHA#1.
63.0
7,960.0
00:48
02:00
3/17/2019
3/17/2019
0.30
SLOT
WELLPR
DLOG
P
Tie into K1 for -4.5' correction Note
7,960.0
8,011.0
02:00
02:18
Ki is 7963'
3/17/2019
3/17!2019
1.00
SLOT
WELLPR
-91-SP-
P
Pump seawater flush, CT 6100 psi, @
8,011.0
8,027.0
02:18
03:18
2.4 bpm, - 220 bbls total
3/17/2019
3/17/2019
0.50
SLOT
WELLPR
DISP
P
Start pumping cement milling fluid, 1
8,027.0
8,032.0
03:18
03:48
ppb Power Pro with 0.5% lubes 7761
low torque.
3/17/2019
3117/2019
0.20
SLOT
WELLPR
TRIP
P
After 15 bbls drilling fluid out the bit,
8,032.0
8,119.0
03:48
04:00
park,close EDC, RIH, tag bottom @
8119'
Page 1116 Report Printed: 4/23/2019
Operations Summary (with Timelog Depths)
3F-01
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Time
End Time
Dur (hr)
Phase"
COGe
Adiviry Corte
Time P -T -X
pparetion
Stan Depth
(f!(S)
End DOM(RKa)
3/17/2019
3/17/2019
1.00
SLOT
WELLPR
DRLG
P
PU W129 k lbs, Set rate, CT 3512 psi
6,119.0
8,129.0
04:00
05:00
@ 1.89 bpm, diff 454, BHP 3121 psi -
10.37 EMW @ sensor. WH 73 psi,
RIH Wt 13 k lbs
OBD, CT Wt 10.7 k lbs, WOB 0.8 klbs,
40 Whir w 100 lbs of motor work.
Stall 8124' PU 30 k lbs
Stall 8124' PU 34 k lbs
Set ROP to 20 fill hr, drill ahead
Stall 8130' PU 32 k lbs
3/17/2019
3/17/2019
1.70
SLOT
WELLPR
DRLG
P
Continue milling, pumping 1.87 bpm,
8,129.0
8,151.9
05:00
06:42
CWT = 11.2K, WOB =.5K, pump =
3562 ps,
Stalls at: 8129', 8132', 8137', PUW =
26K from 8151', wiper to 8076'
3/17/2019
3/17/2019
1.50
SLOT
WELLPR
DRLG
P
Drilling, FS = 440 psi @ 1.87 bpm,
8,151.9
8,172.0
06:42
08:12
stall getting started, PUW = 26K,
annular = 3173 psi, bleed down IA
from 1077 (1 hr, drops to 350 psi,
shut-in & climbs back to 1050 psi).
Stalls at: 8161', 8166' (PUW = 29K)
3/17/2019
3/17/2019
0.40
SLOT
WELLPR
WPRT
P
Wiper (300' while circulating bottoms
8,172.0
8,172.0
08:12
08:36
up), PUW = 28K
3/17/2019
3/17/2019
0.90
SLOT
WELLPR
DRLG
P
Drilling cement, FS = 448 psi @ 1.9
8,172.0
8,190.0
08:36
09:30
bpm, CWT = 8.9K, WOB = 0.5K,
annular = attempt more WOB to
increase ROP, 0.8K WOB @ 36 fph,
pump sweeps
3/17/2019
3/17/2019
0.60
SLOT
WELLPR
WPRT
P
Wiper, PUW = 28K, losing milling fluid
8,190.0
8,190.0
09:30
10:06
over shakers, circulate bottoms up,
losing prime on MP, resolve, swap
shaker screens, reslove issue
3/17/2019
3/17/2019
1.60
SLOT
WELLPR
DRLG
P
Drilling, FS = 458 psi @ 1.93 bpm,
8,190.0
8,230.0
10:06
11:42
CWT = 8.3K, WOB = 0.9K, stall @
8196', PUW = 31K, bleed down OA
Stall at 8196', 8197.5', 8199', 8204',
8217',
3/17/2019
3/17/2019
0.30
SLOT
WELLPR
WPRT
P
Wiper, PUW = 28K, circulate bottoms
8,230.0
8,230.0
11:42
12:00
up, set-downl OK WOB at 8000' (No
Jewelry at that depth. Update: GLM at
corected depth of 8000')
3117/2019
3/17/2019
1.20
SLOT
WELLPR
DRLG
T
Difficulty getting started @ 8230' (7
8,230.0
8,230.0
12:00
13:12
stalls —8230', various speeds), attempt
getting started at 1 fph 8229.8', stall,
confer w/ town
3/17/2019
3/17/2019
0.10
SLOT
WELLPR
WPRT
T
PUH to log K1, PUW = 29K
8,230.0
7,969.0
13:12
13:18
1
3/17/2019
3/17/2619
0.10
SLOT
WELLPR
DLOG
T
Log K1 for +1' correction
7,969.0
7,997.0
13:18
13:24
3/17/2019
3/17/2019
0.30
SLOT
WELLPR
DRLG
T
Attempt to get started at 8230', stall,
7,997.0
8,230.0
13:24
13:42
confer w/ town, decision made to
POOH & inspect tools
3/17/2019
3/17/2019
2.10
SLOT
WELLPR
TRIP
T
Pumps sweeps, POOH, PJSM, flow-
8,230.0
62.0
13:42
15:48
check
3/17/2019
3/17/2019
0.50
SLOT
WELLPR
TULD
T
LD BHA #1
62.0
0.0
15:48
16:18
3/17/2019
3/17/2019
0.50
SLOT
WELLPR
TULD
T
PU BHA #2 (new motor & D331 w/
0.0
62.0
16:18
16:48
ridge -set mill), bit come out a 2-2
(broken & chipped cutters), slide in
cart, MU to coil, tag up, set counters
Page 2116 Report Printed: 412 312 01 9
. Operations Summary (with Timelog Depths)
3F-01
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Time
End Time
Dur (hr)
Phase
Op Code
Activity Code
Time P -T -X
Operation
Start Depth
(aKB)
End Depth (16(13)
3/17/2019
3/17/2019
1.40
SLOT
WELLPR
TRIP
T
RIH w/ BHA #2
62.0
7,970.0
16:48
18:12
3/17/2019
3/17/2019
0.20
SLOT
WELLPR
DLOG
T
Log Kl for-6'comection
7,970.0
7,998.0
18:12
18:24
3/17/2019
3/17/2019
1.90
SLOT
WELLPR
TRIP
T
Continue in hole w D331 ridge set,
7,998.0
8,231.5
18:24
20:18
SD 8032', 3.5 k WOB, and again at
8040'7.5 k WOB - PU wl 34 k lbs.
On bottom, 5 stalls 8231.4 to 8231.9.
No hole made, variability in lag depth
simply CT stack.
PU and restart @ 8231.4' auto drill at
1 ft/ hr - stall 8231.6', PU and attempt
tp auto drill @ 0.5' per hr, stall @
8231.6', clean pick ups - 29 k lbs.
3/17/2019
3/17/2019
0.30
SLOT
WELLPR
DLOG
T
PU hole, 29 k Ibs, Log Kt for zero
8,231.5
7,996.0
20:18
20:36
correction
3/17/2019
3/17/2019
1.20
SLOT
WELLPR
DLOG
T
Swap MWD over to CCL mode, log
7,996.0
8,230.0
20:36
21:48
CCL from 7848'- 8179'@ 16 ft/min
CCL on with the July 2019 caliper and
the tubing detail.
Consult with town engineering.
3/17/2019
3/17/2019
1.40
SLOT
WELLPR
TRIP
T
POOH for venturi basket.
8,230.0
75.0
21:48
23:12
3/17/2019
3/18/2019
0.80
SLOT
WELLPR
PULD
T
LD BHA#2 over a dead well. D331
0.0
0.
23:12
00:00
starting to ring out just past the tip.
Agressive damage to that area
only,diamond cutters missing in a Ong
and matrix removed. 2.79 NO, 2.80
go.
3/18/2019
3/18/2019
0.60
SLOT
WELLPR
PULD
T
Stand by for BOT hand bringing
0.0
0.0
00:00
00:36
ventu0 out -Hold Sunday Safety
-1
meetng in dog house.
3/18/2019
3/18/2619
o0
SLOT
WELLPR
PULD
T
Pick BHA #3, Venturi with 1 ° bent sub
0.0
64.9
00:36
01:36
and 3/4 mule shoe under a HOT.
Bent sub high sided. Note mule shoe
scoop -180 ° out from bent sub.
Skid cart, inspect pack offs - good,
bump up,set counters.
3/18/2019
3/18/2019
1.60
SLOT
WELLPR
TRIP
T
RIH.
64.9
7,970.0
01:36
03:12
3/1812019
3/18/2019
0.20
SLOT
WELLPR
DLOG
T
Tie into the K1 for a -7' correction.
7,970.0
7,997.3
03:12
03:24
3/18/2019
3/18/2019
0.20
SLOT
WELLPR
TRIP
T
continue to RIH, park, close EDC.
7,997.3
8,095.9
03:24
03:36
3/18/2019
3/18/2019
0.90
SLOT
WELLPR
WASH
T
Run in to 8200'- 8230' HS, 90, 180,
8,095.9
8,231.6
03:36
04:30
270, then worked from 8220' to bottom
at HS, 90,180, 270 while pumping 2
bpm.
3/18/2019
3/18/2019
1.70
SLOT
WELLPR
TRIP
T
Down on the pump, PU above TOC,
8,231.6
65.0
04:30
06:12
1
open EDC, POOH
3/18/2019
3/18/2019
0.50
SLOT
WELLPR
PULD
T
LD BHA#2, 3 fish in basket, upload
65.0
0.0
06:12
06:42
pictures 8 confer with town
3/18/2019
3/18/2019
0.70
SLOT
WELLPR
WAIT
T
Determine path forward, decision
0.0
0.0
06:42
07:24
made to make additional Venturi run
3/18/2019
3/18/2019
0.40
SLOT
WELLPR
PULD
T
PU BHA #4 Venturi with 1 ° bent sub
0.0
65.0
07:24
07:48
and 3/4 mule shoe under a HOT
3/18/2019
3/18/2019
1.50
SLOT
WELLPR
TRIP
T
RIH w/BHA #4
65.0
7,970.0
07:48
09:18
3/18/2019
3/18/2019
0.20
SLOT
WELLPR
DLOG
T
Log K1 for -6.5' correction, close EDC,
7,970.0
8,200.0
09:18
09:30
PUW = 30K, RIH to 8200'
Page 3116 Report Printed: 412312019
Operations Summary (with Timelog Depths)
3F-01
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Steri Time
Eno Tme
Dur(hr)
Phase
Op Cafe
Activity Dade
Tme P-T-X
Operation
Stan Depth
(MB)
End Depth (flKB)
3/18/2019
3/18/2019
1.00
SLOT
WELLPR
WASH
T
Perform Venturi passes from 8200' to
8,200.0
8,230.0
09:30
10:30
8230' @ HS, 90°, 180°. & 270°, 5 fpm,
PUH to 8000', wash past GLM, wash
down to TO twice work just off bottom,
PUH & wash past 8000' one additional
time
3/18/2019
3118/2019
1.20
SLOT
WELLPR
TRIP
T
POOH, open EDC, PJSM
8,230.0
65.0
10:30
11:42
3/18/2019
3/18/2019
0.50
SLOT
WELLPR
PULD
T
Flow check, LD BHA #4, cement
65.0
0.0
11:42
12:12
pieces in basket, no metal, decison
made to PU bi-center bit
3/18/2019
3/18/2019
0.90
SLOT
WELLPR
PULD
T
PJSM, PU BHA#5 Cement Drilling (0°
0.0
62.0
12:12
13:06
AKO motor, RR HYC 2.98" bi-center),
slide in cart, MU to coil, tag up, set
counters
3/18/2019
3/18/2019
1.50
SLOT
WELLPR
TRIP
T
RIH w/BHA#5
62.0
7,960.0
13:06
14:36
3/18/2019
3/18/2019
0.20
SLOT
WELLPR
DLOG
T
Log K1 for -7' correction, close EDC,
7,960.0
7,998.0
14:36
14:48
PUW = 29K
3/18/2019
3/18/2619
0.10
SLOT
WELLPR
TRIP
T
Continue RIH
7,998.0
8,231.0
14:48
14:54
3/18/2619
3/18/2019
1.10
SLOT
WELLPR
DRLG
P
Drilling, FS = 331 psi, @ 1.9 bpm,
8,231.0
8,258.0
14:54
16:00
CWT = 11.8K, WOB = 0.7K, pump =
3462 psi, PUW = 27K from, pump 5x5
sweeps, recip from 8100'to TD, PUW
= 27K
3/18/2019
3/18/2019
1.70
SLOT
WELLPR
TRIP
P
POOH, flow-check, PJSM
8,258.0
65.0
16:00
17:42
3/18/2019
3/18/2019
0.70
SLOT
WELLPR
PULD
P
LD BHA #5
65.0
0.0
17:42
18:24
3/182019
3/18/2019
1.30
SLOT
WELLPR
WAIT
P
Discuss caliper plan forward, agree on
0.0
0.0
18:24
19:42
190 min activation time for caliper,
hand returns to truck to program tool
SIMOPS: inspect & torque storage
reel bolts
3/18/2019
3/18/2019
0.60
SLOT
WELLPR
PULD
P
PJSM, PU BHA #6 PDS 24 Arm
0.0
56.0
19:42
20:18
Memory Caliper, slide in cart, MU to
coil, tag up, set counters
3/18/2019
3/18/2019
1.50
SLOT
WELLPR
TRIP7_T_
RIH w/ BHA #6
56.0
7,970.0
20:18
21:48
3/182019
3/182019
0.10
SLOT
WELLPR
DLOG
P
Log K1 for-7' cortection
7,970.0
7,993.0
21:48
21:54
3/18/2019
3/18/2019
0.60
SLOT
WELLPR
TRIP
P
Continue RIH, PUW = 28K, RIH to
7,993.0
8,256.8
21:64
22:30
3/18/2019
3/18/2019
0.70
SLOT
WELLPR
WAIT
P
Wait on caliper activation
8,256.8
8,256.8
22:30
23:12
3/18/2019
3/18/2019
0.20
SLOT
WELLPR
DLOG
P
Log 8256.8'to 7800'
8,256.8
7,705.0
23:12
23:24
3/18/2019
3/18/2019
0.30
SLOT
WELLPR
DLOG
P
Stop, allow arms to Gose, RIH & log
7,705.0
7,705.0
23:24
23:42
K1 for+1.5' correction (up-hole per
PDS rep)
3118/2019
3/192019
0.30
SLOT
WELLPR
TRIP
P
Begin POOH w/ BHA #6
7,705.0
6,476.0
23:42
00:00
3/19/2019
3/19/2019
1.10
SLOT
WELLPR
TRIP
P
Complete POOH, flow-check, PJSM
6,476.0
75.0
00:00
01:06
3/19/2019
3/192019
0.50
SLOT
WELLPR
PULD
P
LDBHA#6 memory caliper, good
75.0
0.0
01:06
01:42
data.
Page 4116 Report Printed: 4/23/2019
Operations Summary (with Timelog Depths)
3F-01
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
Start Time
End Time
Our (hr)
Phase
Op Code
Ac#vfty Code
Time P -T -X
Operation
(BKB)
End Depth (MS)
3/19/2019
3/19/2019
0.60
SLOT
WELLPR
PULD
P
PJSM, PU BHA 97, dummy WS drift,
0.0
49.0
01:42
02:18
17.85' long 2.64" OD barbell shaped
to mimic setting tool and WS.
•• Inspected coil 20' back from CTC,
tested wall thickness@ 12' back from
CTC, ODS 1.76", Reel 1.78", DW
1.79", DS 1.88" slight gouges, from
down hole - 9' back.
3/19/2019
3/19/2019
1.50
PRODi
WHPST
TRIP
P
RIH w/ BHA#7
49.0
7,966.0
02:18
03:48
3/19/2019
3/19/2019
0.20
PROD?
WHPST
DLOG
P
Log Kt for -6' correction
7,966.0
8,003.0
03:48
04:00
3/19/2019
3/19/2019
0.20
PRODt
WHPST
TRIP
P
Continue in hole with dummy
8,003.0
8,258.6
04:00
04:12
whipstock. tag depth of 8258.55'&
1.16 k lbs WOB, PU Wt 27 k - clean.
3/19/2019
3/19/2019
1.40
PROM
WHPST
TRIP
P
POOH w dummy WS drift
8,258.6
50.0
04:12
05:36
3/19/2019
3/19/2019
0.90
PROD1
WHPST
PULD
P
Bump up, crew change, LD BHA#7
50.0
0.0
05:36
06:30
3/19/2019
3/19/2019
1.20
PRODt
WHPST
PULD
P
PU BHA #8, BOT 3.5 "whipstock.
0.0
70-0-
G6:30
07:42
3/19/2019
3/19/2019
1.80
PROM
WHPST
TRIP
P
RIH w 3.5" BOT whipstock
70.0
7,180.0
07:42
09:30
3/19/2019
3/19/2019
0.10
PROM
WHPST
DLOG
P
Tie into the Kt for a -7' correction.
7,180.0
8,000.0
09:30
09:36
3/19/2019
3/19/2019
0.20
PROD1
WHPST
WPST
P
RIH to 8200', PU Wt 29 k lbs. Close
8,000.0
8,254.0
09:36
09:48
EDC, orient HS, RIH to bit depth
8253.4' Online w the pump @ 0.50
bpm, WOB built from 64 lbs to 4.6 k
lbs, sheared at 3,700 psi, WOB fell to
1.9 k lbs, SO to 3.5 k lbs.
"Top of WS 8243' 0°ROHS
3/19/2019
3/19/2019
1.20
PROD1
WHPST
TRIP
P
PU 37 k lbs, POOH
8.254.0
70.0
09:48
11:00
3/19/2019
3/19/2019
0.80
PROD1
WHPST
PULD
P
LD BHA #8, WS selling assembly
70.0
0.0
11:00
11:48
3/19/2019
3/19/2019
0.70
PROM
WHPST
PULD
P
PU BHA#9, l at window milling
0.0
70.0
11:48
12:30
assembly, bump up, set depths,
3/19/2019
3/19/2019
1.20
PRODt
WHPST
TRIP
P
RIH, swapping coil over to milling fluid
70.0
7,985.0
12:30
13:42
3/19/2019
3/19/2019
0.20
PROD1
WHPST
TRIP
P
Tie into the K1 for a -7' connection.
7,985.0
8,005.0
13:42
13:54
3/19/2019
3/19/2019
0.80
PRODt
WHPST
DISP
P
Open EDC, circulate milling fluid to
7,985.0
8,092.0
13:54
14:42
surface, close EDC.
3/19/2019
3/19/2019
0.10
PROM
WHPST
TRIP
P
RIH, dry tag TOWS 8245.2, PO Wt 29
8,092.0
8,245.2
14:42
14:48
k lbs
3/19/2019
3/19/2019
0.20
PROM
WHPST
WPST
P
PU, set rate, RBIH
8,245.2
8,245.2
14:48
15:00
CT 4249 psi, @ 1.90 bpm, diff 481 psi,
BHP 3434 psi, 11.25 ppg EMW at the
window, Open choke, WH 18 psi, IA
941, OA 567.
is 3 times, Get started on 8245.19'
3/19/2019
3/19/2019
2.20
PROD1
WHPST
WPST
P
OBD, CT Wt 11 k lbs, WOB 0.48 k lbs,
8,245.2
8,247.0
15:00
17:12
50 lbs of motor work.
Increase ROP to 0.8 ft/ hr, CT 11 k lbs,
WOB 2.53 k lbs
Page 5116 Report Printed: 412 312 01 9
Operations Summary (with Timelog Depths)
3F-01
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Smrt Time
End Mme
Dur (hr)
Pheae
Op COCe
Activity Coce
Time P -T -x
Opefemn
Smit Depth
(US)
End Depth (M(8)
3/19/2019
3/19/2019
4.80
PROD1
WHPST
WPST
P
Continue milling window exit as per
8,247.0
8,251.2
17:12
22:00
RP and BOT rep. 1.9 bpm at 4,100
psi, Diff -489 psi,WHP=-16,
BHP=3418, IA=956, OA=617
"' Note: Increased motor work @
8,248.7',8,249.2', and 8,249.4', motor
work milled off nomally.
3/19/2019
3/19/2019
0.15
PROD1
WHPST
TRIP
P
TD first window run, PUH to ream
8,251.2
8,243.0
22:00
22:09
window area, PUW=30 k
1***
Note: No indication of 7" contact
3/19/2019
3/19/2019
0.60
PROD1
WHPST
REAM
P
Make reaming passes @ 60 fph x 3
8,243.0
8,251.2
22:09
22:45
3/19/2019
3/20/2019
1.25
PROD1
WHPST
TRIP
P
POOH, with closed EDC, pumping 1.9
8,251.2
1,255.0
22:45
00:00
bpm at 4,010 psi
3/20/2019
3/20/2019
0.25
PROD1
WHPST
TRIP
P
Continue POOH w/window milling
1,255.0
74.7
00:00
00:15
BHA#9
3/20/2019
3/20/2019
0.75
PRODt
WHPST
PULD
P
PU/MU BHI X-Treme 1.25° bend
74.7
0.0
00:15
01:00
motor and FAT Radius mill
3/20/2019
3/2012019
0.50
PROD1
WHPST
PULD
P
PU/MU Window Milling section #2
0.0
78.7
01:00
01:30
BHA#10
3/20/2019
3/202019
0.25
PROD1
WHPST
PULD
P
Stab onto well, perform surface test
78.7
78.7
01:30
01:45
(good -test)
3120/2019
3/20/2019
1.40
PROD1
WHPST
TRIP
P
RIH, w/BHA#10
78.7
7,980.0
01:45
03:09
32012019
320/2019
0.20
PROD1
WHPST
DLOG
P
Log formation (K1 marker) correction
7,980.0
8,252.0
03:09
03:21
of minus 7.0'
3/20/2019
3/20/2019
0.20
7R0D1
WHPST
TRIP
P
Continue IH, dry tag @ 8,252.05'
6,252.0
8,252.0
03:21
03:33
3/20/2019
3/20/2019
0.20
PROD1
WHPST
TRIP
P
PUH, obtain pump parameters
8,252.0
8,251.9
03:33
03:45
3/20/2019
3/20/2019
2.20
PROD1
WHPST
MILL
P
OBM, 1.86 bpm at 3,955 psi, Diff=464.
8,251.9
8,253.3
03:45
05:57
WHP=14. BHP=3,413, IA=950,
OA=600
3/20/2019
320/2019
1.30
PROD1
WHPST
MILL
P
Engage auto drill
8,253.3
8,254.9
05:57
07:15
OBM, CT 4253 psi @ 1.85 bpm in and
1.85 bpm out, BHP 3490 psi. WH 117
psi, IA 961, OA 636 psi. CT 10.4 k lbs,
WOB 2.1-2.99k1bs
3/20/2019
3/20/2019
0.80
PROD1
WHPST
MILL
P
Drill off, out of 7" @ 8254.9'
8,254.9
8,255.9
07:15
08:03
Reamer out @ 8255.5'
3/20/2019
3/20/2019
1.90
PROD1
DRILL
DRLG
P
Drilling ahead
8,255.9
8,270.0
06:03
09:57
CT 4261 psi @ 1.85 bpm in and 1.85
bpm out, 666 psi diff, BHP 3498 psi,
CT 9.2 k lbs, WOB 2.5 k lbs, ROP 8
fthr. Geologist confirms formation in
sample.
" TD Build @ 8270'
3/2012019
3/20/2019
1.60
PROD1
DRILL
REAM
P
Perform Reamming up passes at 330,
8,270.0
8,243.0
09:57
11:33
30, and 180", down passes @ 0°
ROHS.
Launch TO sweeps.
3/20/2019
320/2019
0.40
PROD1
DRILL
CIRC
P
Dry drift clean, PUH, open EDC,
8,243.0
8,123.0
11:33
11:57
chase sweeps out of coil.
3/202019
3/20/2019
1.40
PROD1
DRILL
TRIP
P
POOH.
8,123.0
68.0
11:57
13:21
3/20/2019
320/2019
1.10
3ROD1
DRILL
PULD
P
PUD BHA#10, WH 640 psi.
66.0
0.0
13:21
14:27
3/20/2019
3/202019
0.60
PROD1
DRILL
CIRC
P
PUII checks, stab injector, jet stack
0.0
0.0
14:27
15:03
1
I
Page 6/16 Report Printed: 4123/2019
Operations Summary (with Timelog Depths)
3F-01
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Time
End Time
our (mr)
Phase
op Code
Ac"i Code
Time P -T -x
Operation
Start Depth
(AK8)
End Depth (RKB)
3/20/2019
3/20/2019
0.40
PROM
DRILL
CTOP
P
Reverse circulate, unstab, replace
0.0
0.0
15:03
15:27
upper quick connect.
3/20/2019
3/20/2019
1.00
PROM
DRILL
PULD
P
PU & PD BHA#11, L1 build drilling
0.0
72.0
15:27
16:27
assembly.
3/20/2019
3120/2019
1.80
PROM
DRILL
TRIP
P
RIH,
72.0
7,975.0
16:27
18:15
3/20/2019
3/20/2019
0.20
PRODi
DRILL
DLOG
P
Tie into the K1 for -6' correction.
7,975.0
7,996.0
18:15
18:27
3/20/2019
3/20/2019
0.40
PROD1
DRILL
TRIP
P
Continue RIH, tag bottom 8,270'
7,996.0
8,270.0
18:27
18:51
3120/2019
3/20/2019
0.60
PROD1
DRILL
DRLG
P
OBD, 1.86 bpm at 4,244 psi, Diff--
8,270.0
8,295.0
18:51
19:27
464, WHP=120, BHP=3538, IA=962,
OA=638
3/20/2019
3/20/2019
0.15
PROD1
DRILL
WPRT
P
Tools hung up in window area, PUH,
8,295.0
8,295.0
19:27
19:36
PUW 33 k, Restart
3/20/2019
3/20/2019
0.25
PROD1
DRILL
DRLG
P
OBD, 1.86 bpm at 4,244 psi, Diff--
8,295.0
8,303.0
19:36
19:51
464, WHP=120, BHP=3538, IA=962,
OA=638
3/20/2019
3120/2019
0.15
PROM
DRILL
WPRT
P
PUH, PUW 33 it, restart
8,303.0
8,303.0
19:51
20:00
3/20/2019
3/20/2019
1.60
PROM
DRILL
DRLG
P
OBD, 1.86 bpm at 4,244 psi, Diff-
8,303.0
8,340.0
20:00
21:36
464, WHP=120, BHP=3538, IA=962,
OA=638
3/202019
3/20/2019
0.15
PROM
DRILL
WPRT
P
PUH, PUW 33 k, restart
8,340.0
8,340.0
21:36
21:45
3/2012019
31202019
0.35
PROM
DRILL
DRLG
P
OBD, 1.86 bpm at 4,244 psi, Diff=
8,340.0
8,357.5
21:45
22:06
464, WHP=120, BHP=3538, IA=962,
OA=638
3/20/2019
3/202019
0.25
PROD1
DRILL
WPRT
P
TD build section (Avg. DLGS 49.26"
8,357.5
8,245.0
22:06
22:21
DLGS), PUW 33 k, pull wiper to the
window, chasing 5x5 sweep
3/20/2019
3/20/2019
1.50
PRODt
DRILL
WPRT
P
POOH
8,245.0
78.0
22:21
23:51
3/20/2019
3/21/2019
0.16
PROD1
DRILL
PULD
P
Tag up, spaceoul, PJSM for PUD build
78.0
78.8
23:51
00:00
assembly
3/21/2019
3/212019
0.60
PROD1
DRILL
PULD
P
PUD, build assembly
78.8
0.0
00:00
00:36
3/21/2019
3/21/2019
1.20
PRODt
DRILL
PULD
P
PD, L1 Lateral section assembly
0.0
78.3
00:36
01:48
3/21/2019
321/2019
1.55
PROD1
DRILL
TRIP
P
RIH, w/Lateral Drilling BHA#12, 0.5°
78.3
7,975.0
01:48
03:21
ako motor, agitator, bi-center bit.
3212019
3212019
0.20
PROM
DRILL
DLOG
P
Log the Ki for depth control (minus
7,975.0
8,000.0
03:21
03:33
6.0'), PUW 30 k
321/2019
3/21/2019
0.20
PROM
DRILL
TRIP
P
Continue IH
8,000.0
8,265.0
03:33
03:45
3/21/2019
3/21/2019
0.20
PROD1
DRILL
DLOG
P
Log the RA marker
8,265.0
8,265.0
03:45
03:57
Note:
Of6cal Window Depths
TOWS=8245.5'
RA Marker -8251.5'
BOW=8252.5'
EOB=8357.5'
3/21/2019
3/212019
0.20
PROD1
DRILL
TRIP
P
Continue IH
8,265.0
8,357.5
03:57
04:09
3/21/2019
3212019
2.50
PROD1
DRILL
DRLG
P
OBD, 1.87 bpm at 5,150 psi,
8,357.5
8,616.0
04:09
06:39
Diff -1,375, WHP=53, BHP=3533,
IA=958, OA=618
PU 30 k lbs - 8588'
Page 7116 ReportPrinted: 4/23/2019
Operations Summary (with Timelog Depths)
3F-01
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Ste n"
End Time
our (hr)
Phew
Op Code
Activity Code
Time P-T-X
Operation
rt De pth
Start EI)
End Depth (fIKB)
3/21/2019
3/21/2019
1.30
PROD1
DRILL
DRLG
P
OBD,CT 5386 psi, 1.89 by min 1.83
8,616.0
8,760.0
06:39
07:57
bpm out, WHP=44, BHP=3538,
IA=970, OA=641 pump 5x5 sweep
3/21/2019
3/21/2019
0.20
PROD1
DRILL
WPRT
P
PU 30 k Ib, wiper trip#1 -460'
8,760.0
8,300.0
07:57
08:09
3/21/2019
3/21/2019
0.10
FROM
DRILL
WPRT
P
RBIH, RIH Wt 8.7 k lbs
8,300.0
8,760.0
08:09
08:15
`• bleed IA for 1 hr
3/21/2019
3/21/2019
1.20
FROM
DRILL
DRLG
P
CT 5265 psi @ 1.90 bpm in and 1.89
8,760.0
8,903.0
08:15
09:27
bpm out, BHP 3569 psi, 11.45 EMW
the window. WH 49 psi, IA 806 psi,
OA 643 psi.
OBD, CT Wt 6 k lbs, WOB 1.6 k lbs
Average ROP while on bottom - 119
fUhr
3/21/2019
3/21/2019
0.90
PROD1
DRILL
DRLG
P
1.87 bpm in, returns fell to 1.35 bpm.
8,903.0
8,954.0
09:27
10:21
P, 34 k lbs, RBIH, loses increased,
returns fell to 1 bpm. Drill ahead, high
WOB with low diff, PU, 35 k lbs, restart
drill ahead, ratty drilling, High ROP low
WOB, then stack out. PU, 35 k lbs.
Losses healing as we drill ahead, 1.88
bpm in, 1.75 bpm out.
Average ROP while on bottom - 56
ft/hr
3/21/2019
3/21/2019
0.70
FROM
DRILL
DRLG
P
CT 525 psi, 1.88 bpm in and 1.82 bpm
8,954.0
9,070.0
10:21
11:03
out, free spin diff 1399 psi, BHP 3562
psi, CT Wt 6 k lbs, WOB 0.8 k lbs,
Launch 5x5 in anticipation of wiper
trip.
Average ROP while on bottom - 166
ft/hr
3/21/2019
3/21/2019
0.20
PROD1
DRILL
WPRT
P
PU Wt 33 k lbs,
9,070.0
8,850.0
11:03
11:15
Pull wiper chasing 5x5 sweep. Wipe
above original loss zone -8905'
3/21/2019
3/21/2019
0.10
FROM
DRILL
WPRT
P
RBIH
8,850.0
9,070.0
11:15
11:21
3/21/2019
3/21/2019
3.00
PROM
DRILL
DRLG
P
Initiate Continuous rotation of the
9,070.0
9,543.0
11:21
14:21
HOT, new stearable script, Limit ROP
to 160 fUhr or less. CT 5230 psi
1.87 bpm in and 1.82 bpm out. Free
spin diff 1360 psi, BHP 3625, Ct Wt
5.5 k lbs,
Had to slide and increase WOB to
arrest from 9463'- 9476'
Pump 5x5 sweep and chase with new
mud.
Average ROP while on bottom - 157
f1hr
3/21/2019
3/21/2019
0.30
FROM
DRILL
WPRT
P
PU Wt 32 k lbs - Wiper # 2, - 1145'
9,543.0
8,400.0
14:21
14:39
PUH chasing sweeps
""new mud at the bit - 9543'
3/21/2019
3/21/2019
0.60
FROM
DRILL
WPRT
P
RBIH, RIH Wt 7.9 k lbs
8,400.0
9,543.0
14:39
15:15
3/21/2019
3/21/2019
2.75
PROM
DRILL
DRLG
P
CT 4995 psi @ 1.89 bpm in and 1.96
9,070.0
9,543.0
15:15
18:00
bpm out. Free spin diff 1327 psi, BHP
3552, Ct Wt 4.7 k lbs,
Average ROP while on bottom - ft/hr
321/2019
3/21/2019
PROD
DRILL
WPRT
P
Wiper up hole, PUW 32 k
9,543.0
8,270.0
18:00
18:39
3/21/2019
3/21/2019
DRILL
DLOG
P
Log the RA marker correction of plus
8,270.0
8,287.2
18:39
18:51
JO
EPROD
3.0'ff3/21/2019
3/21/2019
DRILL
WPRT
P
Wiper back in hole, RIW 9 it
8,287.2
9,973.0
18:51
19:27
Page 8116 Report Printed: 4/23/2019
. Operations Summary (with Timelog Depths)
3F-01
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan lime
End Tim
Dur(m)
PhaseStan
Op Code
Activity Code
Time P -T -X
Operation
Depth
(MUS)
End Depth(ftKB)
3/21/2019
3/21/2019
0.25
PROD1
DRILL
DRLG
P
BOBD, 1.89 bpm at 5,000 psi,
9,973.0
10,023.0
1927
19:42
Diff=1,190, WHP=138, BHP=3,606,
IA=911, OA=599
3/21/2019
3/21/2019
2.20
PROD1
DRILL
DRLG
P
Geo steer from 86° NBI to 97",
10,023.0
10,270.0
19:42
21:54
discontinue conlinous rotation drilling
(test interval 9,070'-10,023'), continue
drilling ahead @ 345° TF, 1.89 bpm at
5,277 psi, ROP=165 fph, off bottom
Diff --1,190, WHP=97, BHP=3,631,
IA=610, OA=588
3/21/2019
3/21/2019
0.25
PROD1
DRILL
WPRT
P
Wiper up hole PUW 33 k
10,270.0
9,570.0
21:54
22:09
3/21/2019
3/21/2019
0.30
PRODi
DRILL
WPRT
P
Wiper back in hole, RIW 8 k
9,570.0
10,270.0
22:09
22:27
3/21/2019
3/21/2019
1.30
PROD1
DRILL
DRLG
P
BOBD, 1.89 bpm at 4.987 psi,
10,270.0
10,398.0
22:27
23:45
Diff --1,102, WHP=69, BHP=3,631,
IA=611, OA=605
3/21/2019
3/21/2019
0.15
PROM
DRILL
WPRT
P
PUH, and restart, BHA wiper
10,398.0
10,398.0
23:45
23:54
3/21/2019
3/22/2019
0.10
PROD1
DRILL
DRLG
P
BOBD, 1.89 bpm at 4.987 psi,
10,398.0
10,410.0
23:54
00:00
Diff --1,102, WHP=69, BHP=3,631,
IA=611, OA=605
3/22/2019
3/22/2019
2.00
PROM
DRILL
DRLG
P
OBD, 1.89 bpm at 5,125 psi,
10,410.0
10,551.0
00:00
02:00
Diff -1,264, WHP=90. BHP=3,633,
-0
IA=616, OA=624
3/22/2019
3/22/2019
15
PROD1
DRILL
WPRT
P
PUH, restart, BHA wiper PUW 30 k
10,551.0
10,551.0
02:00
02:09
3/22/2019
3/22/2019
1.60
PROM
DRILL
DRLG
P
BOBD, 1.89 bpm at 5,008 psi,
10,551.0
10,673.0
02:09
03:45
Diff -1,089, WHP=106, BHP=3,693,
IA=616, OA=624
019
3/22/2019
0.30
PRODi
DRILL
WPRT
P
Wiper up hole, PUW 32 k
10,673.0
9,473.0
03:45
03:45
04:03
3/22/2019
3/22/2019
0.40
PRODt
DRILL
WPRT
P
wiper back in hole, RIW 8 k
9,473.0
10,673.0
04:03
04:27
3/22/2019
3/22/2019
0.90
PRODi
DRILL
DRLG
P
CT 4973 psi, @ 1.89 bpm in, 1.89
10,673.0
10,754.0
04:27
05:21
bpm, free spin 1025 psi, BHP 3623
psi.
OBD, CT Wt 2.9 k lbs, WOB 1.3 k lbs,
ROP -130
@10754 sudden loss in returns, 1.89
bpm in, returns fell to -0.45 bpm
PU Wt 31 k lbs, PU slowly, returns not
healing,
3/22/2019
3/22/2019
1.70
PROM
DRILL
WPRT
P
PUH to the window. adjust choke to
10,754.0
8,077.0
05:21
07:03
11.1 ppg EMW at the window to
manage losses while pulling to the
window.
3/22/2019
3/22/2019
0.20
PROD1
DRILL
DLOG
P
Tie int othe RA tag for a+4.5
8,077.0
8,291.0
07:03
07:15
correction
3/22/2019
3/22/2019
0.90
PRODt
DRILL
TRIP
P
RBIH,
8,291.0
10,754.0
07:15
08:09
S/D @ 8769' Higher gamma area, 1.8
k WOB, bounced through.
1.85 bpm in and 1.73 bpm out fell to
1.14 bpm out at bottom
3/22/2019
3/22/2019
1.40
PROD1
DRILL
DRLG
P
CT 4790 psi, at 1.86 bpm in and 1.14
10,754.0
10,888.0
08:09
09:33
bpm out, free spin diff 978 psi, WH
109 psi holding 11.1 ppg. Drill ahead,
returns heal to 1.4 bpm whie holding
11.1 EMW
Page 9/16 Report Printed: 412 312 01 9
Operations Summary (with Timelog Depths)
3F-01
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
start Tim
End Time
Our (hr)
Phaee
Op Code
AcYWity Code
Time P-T-x
Operation
(fIKB)
End Depth(flKB)
3/22/2019
3/22/2019
2.40
PROM
DRILL
DRLG
P
Ecountered additional losses, retums
10,888.0
11,109.0
09:33
11:57
fell to 0.25 bpm. PU, 33 k lbs, RBIH,
drill ahead with multiple pick ups, CT
PU WT 35-33 k lbs. targeting 11.0
ppg EMW @ the window, returns
healing
CT 4962 psi, 1.86 bpm in and 1.51
bpm out. BHP 3593 psi
3/22/2019
3/22/2019
0.40
PROD1
DRILL
WPRT
P
PU Wt 34 k lbs -#1 - 1000'
11,109.0
10,009.0
1157
1221
1.88 bpm in, 1.48 bpm out while
pulling 50 ft/min losses -0.25 bpm
3/22/2019
3/22/2019
0.30
PRODt
DRILL
WPRT
P
RBIH
10,009.0
11,109.0
12:21
12:39
WellWorc shows .5 bbl solids
returned.
3/22/2019
3/22/2019
4.40
PROD1
DRILL
DRLG
P
CT 4625 psi, @ 1.88 bpm in and 1.60
11,109.0
11,401.0
12:39
17:03
bpm out, free spin diff 980 psi, BHP
3506 psi, holding 11.0 ppg @ the
window.
11190' PU 35 k Ibs
11414'PU 40 k lbs
3/22/2019
3/22/2019
0.50
PROD1
DRILL
DRLG
P
OBD, 1.88 bpm at 4,800 psi,
11,401.0
11,462.0
17:03
17:33
Diff--1,190, WHP=132, BHP=3,565,
IA=595, OA=588
3/22/2019
3/22/2019
2.50
PRODt
DRILL
WPRT
P
Encountered 100% losses, PUH,
11,462.0
8.240.0
17:33
20:03
PUW 36 k, pull slow wiper up hole,
circulate 10x10 sweep, confer with
town team, called TD early 11,462',
continue wiper up hole, returns slow to
return. pull slow wiper to the window
chasing sweep.
3122/2019
3/22/2019
2.00
PRODt
DRILL
WPRT
P
Pull through the window, bring pump
8,240.0
2,400.0
20:03
22:03
back up to full rate, continue pulling
swab wiper @ 25 fpm, maintaining
0.75 bpm returns. @ 6,500', WHP
steadly climbing, increase pulling
speed to 80 fpm, maintaining 0.85
bpm retums,
3/22/2019
3/22/2019
0.70
PROM
DRILL
WPRT
P
Increase pulling speed to 90 fpm
2,400.0
78.2
22:03
2245
maintaining 0.9 bpm returns.
3/22/2019
3/22/2019
0.20
PROM
DRILL
TRIP
P
Tag up, reset counter depths, RIH
78.2
1,529.0
22:45
2257
3122/2019
3/2212019
0.45
PROD1
DRILL
TRIP
P
Set down, PUH dean, inspect INJH,
1,529.2
1,529.2
22:57
23:24
seems to be pac-off lube, continue
RIH
3/22/2019
3/23/2019
0.60
PROD1
DRILL
TRIP
P
RBIH, pumping 0.62 bpm/0.20 bpm
1,529.2
3,195.0
23:24
00:00
returns, w/ Lateral drilling BHA#12
3/23/2019
3/23/2019
0.80
PROM
DRILL
TRIP
P
Continue RIH w/ BHA#12 to confirm
3,195.0
7,980.0
00:00
00:48
TD
3/2312019
3/23/2019
0.20
PROM
DRILL
DLOG
P
Log the K1 (minus 6.0) PUW 30 k
7,980.0
8,000.7
00:48
01:00
3/23/2019
3/23/2019
0.20
PROD1
DRILL
TRIP
P
Continue IH
8,000.7
8,215.0
01:00
0112
3/23/2019
3/23/2019
0.15
PROD1
DRILL
TRIP
P
Perform Pressure Survey-3 min-
8,215.0
8,215.0
01:12
01:21
Falling quickly, come back online with
pump.
Press Sesor @ 5,856.9 TVD
AP=3,012
9.899 ppg
3/23/2019
312312019
1.35
PROW
DRILL
TRIP
P
Continue IH, holding 11.0 ppg at the
8,215.0
11,463.0
01:21
02:42
1
window, pumping 1.7 bpm at 4,014
psi, 0.50 bpm returns, WHP=328,
Page 10/16 Report Printed: 4/23/2019
Operations Summary (with Timelog Depths)
3F-01
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Siert Time
End Tune
our (hr)
Phase
Op Code
Adviy Code
Time P -T-%
Operation
Start Depth
(MB)
End Depth (NKB)
3/23/2019
3/23/2019
1.80
PROD1
DRILL
TRIP
P
Tag bottom @ 11,463', PUW 35 k,
11,463.0
5,778.0
02:42
04:30
painting EOP flags TO flag (Yellow
9073.25'), Window flag (White
5778.25)
3/23/2019
3/23/2019
1.00
PR0D1
DRILL
TRIP
P
Continue to POOH. while tuning coil
5,778.0
93.0
04:30
05:30
over to 10.5 pgg KWF.
3/23/2019
3/23/2019
2.00
PROD1
DRILL
DISP
P
Park and pump 50 bola, of viscosifled
93.0
93.0
05:30
0730
(100k Cp LSRV) 10.5 ppb liner
running pill down the kill line /back
side, followed by 50 additional bbls of
10.5 ppb normal vise liner running pill.
3/23/2019
3/23/2019
0.90
PROM
DRILL
PULD
P
PJSM, Flow check, initial losses -12
93.0
0.0
07:30
08:24
bbl/hr. LD BHA#12 over a dead well.
3/23/2019
3/23/2019
0.40
COMPZI
CASING
PUTB
P
Pre floor for running liner
0.0
0.0
08:24
08:48
3/23/2019
3/23/2019
0.40
COMPZ1
CASING
BOPE
P
BOP function test
0.0
0.0
08:48
09:12
323/2019
3/23/2019
3.40
COMPZI
CASING
P U T B
P
PU 2-3/8 "4.6 # STL slotted liner, 81
0.0
2,410.8
09:12
12:36
joints over a non ported bull nose
( LOA 2410.84'), clean floor of liner
running equipment.
3/23/2019
3/23/2019
1.10
COMPZI
CASING
PULD--F7-
PU L1 liner running BHA( GS stabbed
2,410.8
2,464.1
12:36
13:42
into an aluminum liner top billet), skid
cart, stab injector, inspect pack offs,
bump up, set counters.
"'118 bbls KWlost while picking up
liner and BHA
3/23/2019
3/23/2019
2.50
COMPZI
CASING
RUNL
P
RIH W Lt completion, lined up across
2,464.1
11,456.0
13:42
16:12
the top, pumping KW away with just
the charge pump pressure, lined up
down the coil @ 0.5 bpm, caught
returns @ 4065', 0.6 bpm losses.
Tie into white window flag for -10.78'
correction. Pu wt 32 k bs, RIH WOB -
5.39 k lbs
S/D shallow @ 11,456', PU and RBIH,
S/D 11,452', PU 44 k and SID 11448'
Consult town, Pump of linerl.5 bpm,
800 psi diff, PU 30k bs.
TOL @ 9028' bottom of liner 11448'
3/232019
3/23/2019
1.50
COMPZ1
CASING
TRIP
P
PUH after dropping off Lt completion,
11,456.0
8,218.0
16:12
17:42
UNG
park, reset counters.
3/23/2019
3/23/2019
0.90
COMPZI
5AS I
DISP
P
Turn well over to mud
8,218.0
8,218.0
17:42
18:36
323/2019
3232019
1.30
COMPZI
CASING
TRIP
P
POOH
8,218.0
44.2
18:36
19:54
323/2019
3/23/2019
0.80
COMPZI
CASING
PULD
P
At surface, spaceout, PUD/LD setting
44.2
0.0
19:54
20:42
tools
3/23/2019
3/232019
1.00
PROD2
STK
PULD
P
PU/PD, L1-01 Lateral Drilling
0.0
78.3
20:42
21:42
Assembly, BHA#14
j
3/23/2019
3/23/2019
0.30
PROD2
STK
TRIP
P
Tag up, reset counters, close EDC,
78.3
486.0
21:42
22:00
RIH @ 486'surface test mud
motor/agitator (good -test)
3/23/2019
323/2019
1.40
PROD2
STK
TRIP
P
Continue RIH
486.0
7,980.0
22:00
23:24
3/23/2019
3/23/2019
0.20
PROD2
STK
DLOG
P
Log the Kt marker (minus 6.6)
7,980.0
8,000.8
23:24
23:36
3/23/2019
3/242019
0.40
PROD2
STK
TRIP
P
Continue IH
8,000.8
8,618.0
23:36
00:00
3/24/2019
3/24/2019
0.60
PROD2
STK
TRIP
P
Continue IH, dry tag TOB
8,618.0
9,026.0
00:00
0036
Page 11116 Report Printed: 4/23/2019
Operations Summary (with Timelog Depths)
6 3F-01
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Star) Depth
Start Time
End Time
our (hr)
Phase
Op Code
Activity Code
Time P -T -X
Operation
(W)
End Depth(WB)
3/24/2019
3/24/2019
0.20
PROD2
STK
TRIP
P
PUH PUW 30 k, obtain pump
9,026.0
9,026.0
00:36
00:48
parameters
3/2412019
3/24/2019
0.60
PROD2
STK
KOST
P
Kickoff Billet, 1.88 bpm at 4,272 psi,
9,026.0
9,027.0
00:48
01:24
Diff --903, WHP=155, BHP=3,405,
IA=603, OA=584, Time mill 2 tenths @
6 min
3/24/2019
3/24/2019
0.70
PROD2
STK
KOST
P
Increase ROP to 2 fph, 1.88 bpm at
9,027.0
9,028.0
01:24
02:06
4,287 psi, Diff --935, WHP=149,
BHP=3,408, IA=605, OA=593, 0.7
k=DHWOB, CTSW= 12 k
3/24/2019
0.60
PROD2
STK
KOST
P
Increase ROP to 3 fph, 1.88 bpm at
9,028.0
9,029.0
02:06
13/24/2019
02:42
4,376 psi, Diff --1,008, WHP=147,
BHP=3,399, IA=607, OA=599, 0.74
k=DHWOB, CTSW=11.1 k
3/24/2019
3/24/2019
0.30
PROD2
STK
KOST
P
Increase ROP to 10 fph, 1.88 bpm at
9,029.0
9,036.0
02:42
03:00
4,376 psi, Diff --1,008, WHP=147,
BHP=3,399, IA=607, OA=599, 0.74
k=DHWOB, CTSW=11.1 k
3/24/2019
3/24/2019
0.90
PROD2
DRILL
DRLG
P
Drill ahead 1.88 bpm @ 4,325 psi,
9,036.0
9,142.0
03:00
03:54
Di"- 90, WHP=118, BHP=3,402,
IA=609, OA=604,
312412019
3/24/2019
0.30
PROM
DRILL
WPRT
P
PU Wt 39 k lbs, PUH to dry drift billet.
9,142.0
9,142.0
03:54
04:12
9070' Pull -1k WOB
RBIH See WOB spike @ 9075' to 1.3
k lbs, same area we started the
continuous rotation test during the L1
lateral drilling
Billet drifted clean
3/24/2019
3/24/2019
2.40
PROD2
DRILL
DRLG
P
CT 4310 psi @ 1.9 bpm in and 1.9
9,142.0
9,426.0
04:12
06:36
bpm out. BH 3374 psi, holding 11.0
EMW @ the window. OBD, CT 6.3 k
Is, WOB 2.1
0500 - increase choke to target 11.2
ppg EMW @ the window, BHP 3477
psi
Average ROP over section = 118 ft/hr
3/24/2019
3/24/2019
0.40
PROD2
DRILL
WPRT
P
PUWt 33 k Ibs, - Wiper #1 - short
9,426.0
9,426.0
06:36
07:00
wiper to just below the billet - 379'
Turn around @ 6:48 and 9047'
RBIH, No evidence of issues at 9070'
clean
3/2412019
3/24/2019
0.90
PROD2
DRILL
DRLG
P
CT 4629 psi @ 1.9 bpm in and 1.9
9,426.0
9,552.0
07:00
07:54
bpm out. free spin diff 948 psi, BH
3475 psi, holding 11.2 EMW @ the
window. OBD, CT 9 k lbs, WOB 2.8
Average ROP over section = 140 ft/hr
3/24/2019
312412019
2.50
PROD2
DRILL
DRLG
P
Initiate continuous rotation of the HOT
9,552.0
9,826.0
07:54
10:24
-AKA and from here forward -
RotoTrak
CT 5016 psi @ 1.89 bpm in and 1.89
bpm out, 3461 psi BHP, 11.2 ppg
EMW @ the windowCT Wt 0.2 k lbs,
2.4 k lbs WOB.
Average ROP over section = 110 ft/hr
3/24/2019
3/24/2019
0.30
PROD2
DRILL
WPRT
P
PU Wt 32 k lbs, Wiper trip #2 - 778'
9,826.0
9,048.0
10:24
10:42
1
I
j
3/24/2019
3/24/2019
0.20
PROD2
DRILL
WPRT
P
RBIH
9,048.0
9,826.0
10:42
10:54
1
I
WellWorc indicates 0.27 bbls cutting
returned on the trip.
Page 12116 Report Printed: 412 312 01 9
" Operations Summary (with Timelog Depths)
3F-01
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start TIM
End 7me
Dur (hr)
Phase
Op Code
Activity Coot,Time
P -T-%
Operation
SfeR Depth
(NCB)
Eno Depth (N<a)
3/24/2019
3/24/2019
0.40
PROD2
DRILL
DRLG
P
RotoTrak
9,826.0
9,875.0
10:54
11:18
CT psi 5128 psi @ 1.89 bpm in and
1.89 bpm out, free spin 886 psi, 3492
psi BHP, 11.2 ppg EMW @ the window
CT Wt -0.2 k lbs, 3.1 k lbs WOB.
Average ROP over interval 122 ft/hr
3/24/2019
3/24/2019
3.50
PROD2
DRILL
DRLG
P
RotoTrak
9,875.0
10,226.0
11:18
14:48
.. Losses, returns fell to 0.2 bpm, PU
Wt 33 k lbs, Reduced choke to hole
11.0 ppg EMW at the window.
Losses slowly healed retruns climbed
tol.6 bpm RBIH and drill ahead. CT
psi 5064 psi @ 1.69 bpm in and 1.60
bpm out, free spin 885 psi, 3439 psi
BHP, 11.0 ppg EMW @ the window
CT Wt -3 k lbs, 2.2 k lbs WOB.
3/24/2019
3/24/2019
0.60
PROM
DRILL
WPRT
P
PU Wt 32 k lbs, Wiper trip #3, long
10,226.0
8,270.0
14:48
15:24
wier to the window for tie in.
Saw negative WOB tug @ 9066'- 1k
lbs
3/24/2019
3/24/2019
0.20
PROD2
DRILL
DLOG
P
Tie into the RA tag for a +3.5
8,270.0
8,302.0
15:24
15:36
correction.
3/24/2019
3/24/2019
0.60
PROD2
DRILL
WPRT
P
RBIH, Window clean
8,302.0
10,226.0
15:36
16:12
Saw WOB bobble @ 9072' 0.4 k lbs
Billet clean
3/24/2019
3/24/2019
0.80
PROD2
DRILL
DREG
P
RotoTrak
10,226.0
10,335.0
16:12
17:00
CT 4693 psi, @ 1.89 bpm in and 1.73
bpm out, free spin 931 psi, BHP 3438
psi, 11.0 ppg EMW @ the window. CT
Wt -1.9 k lbs, 2.5 k WOB.
3/24/2019
3/24/2019
0.20
PROD2
DRILL
WPRT
P
PUH, PUW 33 k, restart
10,335.0
10,335.0
17:00
17:12
3/24/2019
3/24/2019
1.50
PROD2
DRILL
DRLG
P
BOBD, 1.87 bpm at 4,800 psi,
10,335.0
10,501.0
17:12
18:42
Diff=941 psi, WHP=108, BHP=3,471,
IA=623, OA=654,
RotoTrak Drilling
10,335'-10341' (6')
10,357'-10,398' (41')
10,407'-10,428' (21')
10,448'-10,501' (53)
3/24/2019
3/24/2019
0.20
PROD2
DRILL
WPRT
P
PUH, PUW 32k, restart
10,501.0
10,501.0
18:42
18:54
3/24/2019
3/24/2019
2.00
PROM
DRILL
DRLG
P
BOBD, 1.88 bpm at 4,900 psi,
10,501.0
10,653.0
18:54
20:54
Diff=940 psi, WHP=94, BHP=3,481,
IA=623, OA=655
RotoTrak
10,501'-10,567' (66')
10,633'-10.653'(20')
3/24/2019
3/24/2019
0.30
PROD2
DRILL
WPRT
P
Wiper up hole to 9,653', PUW 33 k
10,653.0
9,653.0
20:54
21:12
3/242019
3/24/2019
0.30
PROD2
DRILL
WPRT
P
Wiper back in hole, RIW 7 k
9,653.0
10,653.0
21:12
21:30
3/24/2019
3/24/20190.50
PROD2
DRILL
DRLG
P
BOBD, 1.88 bpm at 4,238 psi,
10,653.0
10,705.0
21:30
22:00
Diff --940 psi, WHP=94, BHP=3,481,
IA=623, OA=655
3/24/2019
324/2019
PROD2
DRILL
WPRT
P
Losses increased from 0.15 bpm -
10,705.0
10,705.0
22:00
22:12
::0.20
0.65 bpm @ 10,694', PUW 35 k,
restart
Page 13/16 Report Printed: 4123120191
. Operations Summary (with Timelog Depths)
3F-01
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Time
End Time
our (m)
Phase
Op Cafe
ActivityCode
Time RT -X
Dpereadn
Sart Depm
(MB)
End Depth (f1KB)
3/24/2019
3/25/2019
1.80
PROD2
DRILL
DRLG
P
BOBD, 1.88 bpm at 4„922 psi,
10,705.0
10,901.0
22:12
00:00
Diff --940 psi, WHP=153, BHP=3,474,
IA=622, OA=656, encounter another
loss zone @ 10,726', MM IN=1.87
bpm, MM OUT=1.53 (losses 0.35
bpm)
RotoTrak
10,705'-10,750' (45)
10,765'-10,830' (65')
10,850'-10,901' (51)
3/25/2019
3/25/2019
0.30
PROD2
DRILL
DRLG
P
OBD, 1.88 bpm at 4„922 psi, Dif(=940
10,901.0
10,922.0
00:00
00:18
psi, WHP=153, BHP=3,474, IA=622,
OA=656, encounterd drop in return
rate @ 10,913' and 10,922'
3/25/2019
3/25/2019
0.30
PROD2
DRILL
DRLG
P
BOBD, 1.88 bpm at 4„922 psi,
10,922.0
10,971.5
00:18
00:36
Diff=940 psi, WHP=153, BHP=3,474,
IA=622, OA=656
3/25/2019
3/25/2019
0.20
PROD2
DRILL
WPRT
P
100% losses, PUH, PUW 35 k
10,971.5
10,505.0
00:36
00:48
3/25/2019
3/25/2019
0.30
PROD2
DRILL
WPRT
P
RBIH, circ 5x5 sweep, down the tail
10,505.0
10,900.0
00:48
01:06
3/25/2019
3/25/2019
0.50
PROD2
DRILL
WPRT
P
Pull wiper up hole to 9,900',
10,900.0
9,900.0
01:06
01:36
3/25/2019
3/25/2019
0.50
PROD2
DRILL
WPRT
P
Wiper back in hole, RM 10 k
9,900.0
10,971.0
01:36
02:06
3/25/2019
3/25/2019
0.50
PROD2
DRILL
DRLG
P
BOBD, 1.77 bpm at 4,460 psi,
10,971.0
11,019.0
02:06
02:36
Diff -829, WHP=273, BHP=3,456,
IA=608, OA=638
3/25/2019
3/25/2019
0.20
PROD2
DRILL
WPRT
P
Wiper up hole 250', PUW 40 k
11,019.0
11,019.0
02:36
02:48
3/25/2019
3/25/2019
0.55
PROD2
DRILL
DRLG
P
BOBD, 1.77 bpm at 4,460 psi,
11,019.0
11,058.0
02:48
03:21
Diff -829, WHP=273, BHP=3,456,
IA=608, OA=638
3/25/2019
3/25/2019
0.35
PROD2
DRILL
WPRT
P
ROP increased >180 fph, PUW 32 k,
11,058.0
10,837.0
03:21
03:42
pull short wiper up hole
Note: Choke Fully closed 10,610'-
10,810', WHP=850 psi, open choke,
maintaining 11.0 ppg at the window
3/25/2019
3/25/2019
0.25
PROD2
DRILL
WPRT
P
Wiper back in hole, set down @
10,837.0
11,058.0
03:42
03:57
10,929' and 10,960', PUH clean
3/25/2019
3/25/2019
0.60
PROD2
DRILL
DRLG
P
BOBD, 1.76 bpm at 4,500 psi,
11,058.0
11,123.6
03:57
04:33
Diff -880, WHP=230, BHP=3475,
IA=607, OA=632,
3/25/2019
3/25/2019
1.30
PROD2
DRILL
WPRT
P
Wiper trip to the window, PUW 33 k
11,123.6
8,266.0
04:33
05:51
WellWorc shows 0.68 bbls of cuttings
removed.
3/25/2019
3/25/2019
0.20
PROD2
DRILL
DLOG
P
Tie into the RA tag for a + 5.5'
8,266.0
8,299.0
05:51
06:03
1
1
1
correction.
3/25/2019
3/25/2019
1.00
PROD2
DRILL
TRIP
P
RBIH to drill marginal relums 1.4 to
8,299.0
11,123.6
06:03
07:03
0.6 bpm returns whie holding 1.9 bpm
in.
3/25/2019
3/25/2019
2.70
PROD2
DRILL
DRLG
P
RotoTrak
11,123.6
11,400.0
07:03
09:45
CT 4806 psi @ 1.9 bpm in and 1 bpm
out. Reduce choke setting to hold
10.9+ EMW @ the window. Retuns
fluctuated from 1.4 to 1.5 bpm.
CT Wt 8 klbs, WOB 1.2 Mbs
11193' PU 38 k lbs, 11253' PU 36 k
lbs, 11381 PU 37 k lbs. launch 5x5
sweep in anticipation of TD.
ROP over interval = 103 ft/hr
Page 14116 Report Printed: 4123/2019
Operations Summary (with Timelog Depths)
3F-01
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Time
End Time
Dur (hr)
Phase
Op cods
Ac11Wry
Time ma P -T-%
Operation
start Depth
(fIKB)
End Depth (MB)
3/25/2019
3/25/2019
1.20
PROD2
DRILL
WPRT
P
Wiper trip to the window, PUW 33 k
11,400.0
8,015.0
09:45
10:57
PUH chasing sweeps to surface
3/25/2019
3/25/2019
1.90
PROD2
DRILL
WPRT
P
Continue out of hole on wiper trip.
8,015.0
78.0
10:57
12:51
3/25/2019
3/25/2019
1.40
PR652
DRILL
TRIP
P
Bump u, set counters, RBIH to
78.0
7,985.0
12:51
14:15
measure BHP and confirm TD
3/25/2019
3/25/2019
0.20
PR0D2
DRILL
DLOG
P
Tie into the K1 for a -6' correction
7,985.0
8,006.0
14:15
14:27
3/25/2019
3/25/2019
0.30
PROD2
DRILL
DLOG
P
Park at 8236.05 CTMD and 5871.85
8,006.0
8,236.0
14:27
14:45
ND, trap 3312 psi, observe pressure.
initial 3312 psi 10.84 ppg
1 min 3293 psi 10.78 ppg
2 min 3287 psi 10.76 ppg
5 min 3239 psi 10.61 ppg
10 min 3185 psi 10.43 ppg
Bled off fluid to 70 psi well head
13 min 3155 psi 10.33 ppg - BHP
did not appear to break trend
Bled WH to 371 psi, BHP did break
trend
15 min 3126 psi 10.24 ppg
20 min 3083 psi 10.1 ppg
3/25/2019
3/25/2019
1.20
PROD2
DRILL
TRIP
P
PU Wt 30 k lbs, continue to RIH
8,236.0
11,401.0
14:45
15:57
'•• Confirm TD Q 11,401'
3/25/2019
3/25/2019
2.00
5R0D2
DRILL
DISP
P
PU Wt 34 k lbs, Complete building
11,401.0
11,395.0
15:57
17:57
weighted tier running pil I(LRP) and
pump to bit.
3/25/2019
3/25/2019
1.10
PR0D2
DRILL
DISP
P
PUH laying in 10.5 ppg LRP while
11,395.0
8,178.3
17:57
19:03
painting flags
Yellow flag 8178.29'
3/25/2019
3/25/2019
1.80
PROD2
DRILL
TRIP
P
Continue to POOH displacing the well
8,178.3
73.0
19:03
20:51
to 10.5 KW
Paint whit flag
3/25/2019
3/25/2019
0.80
PROD2
DRILL
PULD
P
LD BHA #14 over a dead well.
73.0
0.0
20:51
21:39
3/25/2019
3/25/2019
0.40
C0MPZ2
DRILL
PUTB
P
Prep floor for running liner
0.0
0.0
21:39
22:03
3/25/2019
3/26/2019
1.95
C0MPZ2
DRILL
PUTB
P
PUALl-01 liner-107jointsof2-
0.0
1,028.8
22:03
00:00
3/8"4.6 # STL slotted liner under a
shorty deployment sieve with a non
ported bull nose
3/26/2019
3/26/2019
3.75
COMPZ2
CASING
PUTS
P
PUAL1-01 liner-107jointsof2-
1,028.8
3,164.0
00:00
03:45
3/8"4.6 # STL slotted liner under a
shorty deployment sieve with a non
ported bull nose
"' Note: Lost 28 bbl while PU liner
3/26/2019
3/26/2019
0.75
COMPZ2
CASING
PULD
P
PU CoilTrak tools, change out upper
3,164.0
3,209.4
03:45
04:30
checks, change out pac-offs, surface
lest tools (good -test)
3/26/2019
3/26/2019
1.00
COMPZ2
CASING
RUNL
P
RIH, with L1-01 liner, 107jts of slotted
3,209.4
8,100.0
04:30
05:30
liner, shorty deployment sleeve, and
non -ported bullnose.
3/26/20193/26/2019
0.15
C0MPZ2
CASING
RUNE---
Pi
Correct to the EOP flag, minus10.0'
8,100.0
8,100.0
05:30
05:39
3/26/2019
3/26/2019
1.50
50MPZ2
CASING
RUNL
P
Continue IH with liner assembly
8,100.0
10,876.0
05:39
07:09
3/26/2019
3/26/2019
1.15
COMPZ2
CASING
RUNL
P
Work liner to bottom, PUW 41-44k, tag
10,876.0
11,401.0
07:09
08:18
bottom, PUH, tag bottom again
Page 15116 Report Printed: 412 312 01 9
Operations Summary (with Timelog Depths)
3F-01
Rig: NABORS CDR3-AC
Job: DRILLING
SIDETRACK
Time Log
StaM1Time
EEM Time
Dur (hr)
Phase
Op Code
Activity Code
Time P-T-X
Operation
Sted Depth
(faCB)
Ertl Depth (f%B)
3126/2019
3/26/2019
0.30
COMPZ2
CASING
RUNL
P
Bring pump online 1.6 bpm, 990 psi
11,401.0
8,214.7
08:18
08:36
diff, PUW 30 k, remove liner length
from counters, PUH for static.
3/26/2019
3/26/2019
0.50
COMPZ2
WHDBOP
DISP
P
"` Note: SBHP @ 8,214.7', Sensor
8,214.7
8,185.2
08:36
09:06
depth 8,200.3' CTMD, 5880.43' TVD,
10.41 ppg, 3179 psi,
" LRS on location, PJSM, rig up air
and confirm line is free, rig up to
customer line and PT to 4,500 psi
3/26/2019
3/26/2019
1.10
DEMOB
WHDBOP
DISP
P
Line up to circulate SW down the coil
8,185.2
8,185.0
09:06
10:12
1
3/26/2019
3/26/2019
1.00
DEMOB
WHDBOP
TRIP
P
POOH, ,while displacing well
8,185.0
44.2
10:12
11:12
3/26/2019
3/26/2019
1.45
DEMOB
WHDBOP
FRZP
P
At surface, spaceout, PUD & LD
44.2
0.0
11:12
12:39
setting tools.
Note: Final Tubing Pressure 372 psi,
SW 8,185'-2,500', Deisel 2,500'-0'
3/26/2019
3/26/2019
1.50
DEMOB
WHDBOP
RURD
P
Install Nozzle, stab back on with INJH,
0.0
-F0-
12:39
14:09
jet stack
3/26/2019
3/26/2019
0.75
DEMOB
WHDBOP
RURD
P"`
Note: Wellhead bolts loose torque
0.0
0.0
14:09
14:54
up tree bolts
3/26/2019
3/26/2019
3.10
DEMOB
WHDBOP
RURD
P
RDMO, work the rig move checklist
0.0
0.0
14:54
18:00
3/26/2019
3/26/2019
2.00
DEMOB
WHDBOP
RURD
P
Crew change, Comtinue working Rid
0.0
18:00
20:00
down chaeck list, Nipple down stack
and secure for transport, Pits
offloaded, Putz rig down. Blow down
steam. RIG RELESE 20:00
Page 16116
Report Printed:
412312019
ji
S—W
PROACTIVE DIAgNOSTIC SERVICES, INC.
WELL LO
TRANSMITTAL
To: AOGCC
Natural Resources Technician
333 West 7th Avenue
Suite 100
Anchorage, Alaska 99501
(907) 793-1225
8 52 25
30487
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
DdsanchorageCa)memorvlog.com
19 -Mar -19 3F-01
CD
50-029-21446-00
Date : Mlwy_
PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518
PHONE: (907)245-8951 FAX: (907)245-8952
E-MAIL: PDSANCHORAGEaMEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM
I):lAclu,estMsskfl'empla4Pil�isTempLtcsDistributirni.TmrtmittdSheetx ronowPlvllips Tvmsmitdocx
785.225
30487
Memory Multi -Finger Caliper
Company: ConocoPhillips Alaska, Inc.
Log Date: March 19, 2019
Log No.: 14371
Run No.: 1
Pipe Description: 3.5 inch 9.3 Ib. L-80 ELIE 8RD ABMOD
Log Results Summary
Well:
Field:
State:
API No.
Top Log Interval:
Bottom Log Interval:
3F-01
Kuparuk
Alaska
50-029-21446-00
7,726 Ft. (MD)
8,254 Ft. (MD)
Inspection Type : Corrosive and Mechanical Damage Inspection Prior to Setting
COMMENTS:
This caliper data is tied into GLM 6 at 8,000 feet (SLB Caliper and Jewelry Log dated July 5, 2018).
This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical
damage prior to setting a whipstock near the bottom of the interval logged.
The caliper recordings indicate the interval of 3.5 inch tubing logged appears to be in good to fair condition, a
maximum recorded wall penetration of 25% is recorded as an isolated pit. An area of deposits restrict the ID
to 2.78 in. at 8,033 ft. No other significant wall penetrations or areas of cross-sectional wall loss or
restrictions are recorded in the interval logged.
A 3-D log plot of the caliper recordings across the interval of tubing logged is included in this report.
Joint numbering in this report starts with the top joint logged labeled as joint 1.
3.5 INCH TUBING - MAXIMUM RECORDED WALL PENETRATIONS:
Isolated Pit 25 9 8,010 Ft. (MD)
No other significant wall penetrations (> 18%) are recorded in the interval logged.
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:
Deposits
No other significant I.D. restrictions are recorded.
2.78 9 8,033 Ft. (MD)
C. Goerdt J. Thompson E. Zemba
Pro4cive DiaSn.-AicServicFs,'nc. J P.O. Box, 1369, Stafford, I`; T'97
Phone: (281) -131-7100 or (89d) 555-4085 Faz: (281) u.31-7125 =-mail: PDSAnalvsisCcbmemorvloo com
Prudhoe Pay Field Ofic, Phoae: (�07) 559-2307 t=a (007) X54-2 14
a
Ml
,__�,_� -- .- - a_
d
Correlation of Recorded Damage to Borehole Profile
Pipe 1 3.5 in (7,707.9'- 8,254.3') Well: 3F-01
Field: Kuparuk
Company: ConocoPhillips Alaska, Inc.
Country: USA
Survey Date: March 19, 2019
■ Approx.
1
Tool Deviation
■ Approx.
Borehole
Profile
7,708
5
7,817
GL
GLM-
E
Z
c
o.
O
P
10
8,038
15
8,196
16
8,226
0
50
100
Damage
Profile
(%
wall) /
Tool Deviation
(degrees)
Bottom of Survey = 16
M
Z
c
O
10
15
ji
PDS Report Overview
�
Body Region Analysis
Well:
3F-01
Survey Date: March 19, 2019
Field:
Kuparuk
Tool Type: UW MFC 24 No. 218527
Company:
ConocoPhillips Alaska, Inc.
Tool Size: 1.69 inches
Country:
USA
No. of Fingers: 24
Pipe
3.5 in. 9.2 ppf L-80
Analyst: Thompson
Pipe NOm.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth
L 3.5 i n. 9.2 ppf L-80 2.992 in 7,708 ft 8 254 ft
Damage Configuration (body)
10
8
6
4
2
0
Isolated General Line Other Hol,!
Pitting Corrosion Corrosion Damage Pos. Hole
2 0 1 0 0
Damage Profile (% wall)
Penetration body Metal loss body
0 50 100
1
6
GLM
7.1
PM
14
Bottom of Survey = 16
Ji3ls I
Minimum Diameter Profile
Well: 3F-01 Survey Date: March 19, 2019
Field: Kupamk Tool Type: UW MFC 24 No. 21852;
Company: ConocuPhillips Alaska, Inc. Tool Size: 1.69 inches
Country: USA Tubing I.D.: 2.992 inches
Minimum Measured Diameters (in.)
1.75 2 2.25 2.5 2.75
7,708
7,726
7,756
7,786
7,817
7,847
7,877
7,887
7,896
',906
7,937
',947
',959
',968
,000
,009
,038
,069
,101
,133
,164
,196
,226
L
c
a
ji-�s
Well: 3F-01
Field: Kuparuk
Company: ConocoPhillips Alaska, Inc.
PDS
Report Joint Tabulation Sheet
Survey Date: March 19, 2019
Analyst: Thompson
Pipe Description
3.5 in. 9.2 ppf
L-80 Tubing
Nom. ID Body Wall Top Depth Bottom Depth
2.992 in. 0.254 in. 7,708 ft. 8,254 ft.
Joint Jt. Depth
No. (Ft.)
Pen.
Upset
(in.)
Pen.
Body
(in.)
Pcn.
Metal
Loss
%
Min.
I.D.
(in.)
Damage Profile
Comments (% wall)
0 50 100
1 7708
0
0.02
6
2
2.93
e osi2
Lt. Deposits -
27726
0
002
8
1
2.93
Lt. Deposits.
3 7756
0
0.02
6
2
2.92
Lt. Deposits.
4 7786
0
0.01
5
2
293
Lt. Deposits.
5 781 7
. 2
6
1
2.93
Lt. De sits.
6 7847
1 0
1 0.02
6
1
2193
6.1 7877
1 0
1 0.03
11
2
2.88
P, in Lt.
6.2 7887
1 0
1 0
0
0
2.87
GI M
6.3 7896
0
0.02
8
2
2.90
P-De ,-sits.
6Lt.
7 0
0
0. 1
5
1
2.93
7.1 7937
0
0.02
7
2
2.90
Pu Lt. De ,-sits.
7.2 47
0
0. 1
5
1
95
Pu
7 9
0
0
0
4
P--',--
c r8
8 7968
0
0.04
15
3
2.93
Shallow Pitfin . LtjnDe-,-,stA,0
0
2.87
Producfion Mandrel800
0
0 6
25
11
. 8
Isol ted Pi in e10
8038
0
003
10
3
2.96
1 8
0.03
13
2
Ton
12 8101
0
0.03
11
5
2..
Ton t13
8133
0
0.02
3
2.95
Ton .
14 8164
0
. 2
9
3
2.
Ton15
8196
0
.02
7
2
2.96
Ton .
16 8226
0
005
18
9
293
Shallow Line of Pit
Penetration Body
Metal Loss Body
Page 1
Well:
3 F-01
Field:
Kuparuk
Company:
ConocoPhillips Alaska, Inc.
Country:
USA
PDS Report Cross Sections
Survey Date:
March 19, 2019
Tool Type:
UW MFC 24 No. 218527
Tool Size:
1.69
No. of Fingers:
24
Cross Section for Joint 9 at depth 8,009.759 ft.
Tool speed = 50
Nominal ID = 2.992
Nominal OD = 3.5
Remaining wall area = 89%
Tool deviation = 43°
Finger =3 Penetration =0.063 in.
Isolated Pitting 0.06 in. = 25% Wall Penetration HIGH SIDE = UP
PDS Report Cross Sections
Well:
3F -0I
Survey Date:
March '19, 2019
Field:
Kuparuk
Tool Type:
UW MFC 24 No. 218527
Company:
ConocoPhillips Alaska, Inc.
Tool Size:
1.69
Country:
USA
No. of Fingers:
24
Cross Section for Joint 9 at depth 8,033.499 ft.
Tool speed = 49
Nominal ID = 2.992
Nominal OD = 3.5
Remaining wall area = 98%
Tool deviation = 44°
Minimum I.D. = 2.783 in.
Deposits Minimum I.D. =2.78 in. HIGH SIDE= UP
THE STATE
°fALASKA
GOVERNOR MIKE DUNLEAVY
Kai Starck
CTD Director
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 317-01
Permit to Drill Number: 185-225
Sundry Number: 319-093
Dear Ms. Starck:
Alaska Oil and Gas
Conservation Commission
333 west Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
wvnv.aogcc.alaska.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 further
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 . eamount, Jr.
Co issioner
DATED this dayy of February, 2019.
B��S�' MpR 0 5 �p19
a
RECEIVE
STATE OF ALASKA FEB 2 6 2019
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS �OG(;G
20 AAC 25.280
1. Type of Request: Abandon ❑ Plug Perforations ❑� Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑
Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑
Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: WhipsOk
2. Operator Name:
4. Current Well Class:
5. Permit to Drill Number:
ConocoPhillips Alaska Inc
Exploratory ❑ Development ❑�
Stratigraphic ❑ Service ❑
185-225 '
3. Address:
6. API Number:
PO Box 100360, Anchorage AK 99510
50-029-21446-00-00
7. If perforating:
8. Well Name and Number:
,
What Regulation or Conservation Order governs well spacing in this pool? N/A
KRU 3F-01
Will planned perforations require a spacing exception? Yes ❑ No ❑�
9. Property Designation (Lease Number): 1p z e
10. Field/Pool(s):
I
ADL 25643 'Atif'289>t r y kk
Kuparuk River Field / Kuparuk River Oil Pool
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
8730' 6245' 8646' 6187' 2722 N/A N/A
Casing Length Size MD TVD Burst Collapse
Structural
Conductor 80' 16" 115' 115'
Surface 3873' 9-5/8" 3908' 3068'
Intermediate
Production 8750' 7" 8784' 6259'
Liner
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Tubing Size:
Tubing Grade:
Tubing MD MY
8066'-8219', 8417'-8423', 8428'-
5787'-5893', 6030'-6034', 6037'-
3-1/2"
L -80/J-55
8303'
8468', 8498'-8526'
6065', 6085'-6105'
Packers and SSSV Type: Baker FHL Packer / Baker FB -1 Packer
Packers and SSSV MD (ft) and TVD (ft): 7974' MD / 5722' TVD, 8280' MD / 5936' TVD
12. Attachments: Proposal Summary ' Wellbore schematic
13. Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑
Exploratory ❑ Stratigraphic ❑ Development ❑� Service ❑
14. Estimated Date for
15. Well Status after proposed work:
Commencing Operations: 3/4/2019
OIL .r❑ 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: 7ames-OhG°ger /S5, Contact Name: Ryan McLaughlin
Authorized Title: Skiff-GID-Engineergi Contact Email: Ryan. McLauhlln eD .Dom
Contact Phone: 265-2618
Authorized Signature: Date: L
COMMI SION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
319 . 09 3
,�, /
Plug Integrity ❑ BOP Test T Mechanical Integrity Test ❑ Location Clearance ❑
Other: 8D p rr-f t tin 3 SUO 12 s -r 3
4tifr v/cir Pr-tvl//n i -t✓ rtSt fo 2500 T2s r5
Post Initial Injection MIT Req'd? Yes ❑ No LJ
Spacing Exception Required? Yes ❑ No O' Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
rhA ` V Y ` L Z/Z 0 / l l � � \' (� SubmA Form and
V' ti") Form 10.403 Revised 4/2017 Approved application is va f tttyyy ii 'ifielll of approval. Attachments in Duplicate
I/ � lu: o_ 9k1Z114
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
February 25, 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 whipstock and cement the C -
sand perforations for tubing stability while kicking off the whipstock in the KRU 3F-01 (PTD# 185-225).
Attached to this application are the following documents:
- 10-403 Sundry Application for KRU 3F-01
- Operations Summary in support of the 10403 Sundry Application
- Proposed Pre -CTD Schematic
- Current Well Bore Schematic
If you have any questions or require additional information, please contact me at 907-265-6218.
Sincerely,
Ryan McLaughlin
ConocoPhillips Alaska
Coiled Tubing Drilling Engineer
3F-01 Proposed CTD Schematic
16" 62# H-40 5hce
9-5/8" 40# J-55 shoe
@ 3971' MD
CGsand Paris 8066'
- 8219 MD
KOP @ 8243' MD
A:' Peds
8417' - 8423' MD
8428'- 8468' MD
8498'- 8526' MD
T' 26# J-55 shoe @
8646' MD
3-1/2" Camco DS nipple @ 518' MO (2.875" min ID)
3-12" 9.3# L-80 EUE 8rd Tubing to surface
3-12" Camco gas lift mandrels @ 3163', 4851', 5997', 6841', 7474',
7896' MD
Baker 3-1/2" PBR @ 7960' MD (3" ID)
Baker FHL packer @ 7974' MD (4.0" ID)
3-1/2" Camoo MMG production mandrels @ 8012' MD
AVA BP Ported Nipple @ 8266' MD (2.3" min ID)
XO 3.5" to 2.875"
Baker FB -1 packer @ 8280' MD (4.0" ID)
Baker SBE @ 8283' MD
3-1/2" Camco D landing nipple @ 8295' MD (2.25" min ID, No -Go)
Camco SOS @ 8303' MD
3F -01L1-01 wp05
TD @ 11,500' MD
Top of Liner @ 8,243' MD
31F-011-1 wpD5
TD @ 11,500' MD
Billet @ 9,100' MD
KUP PROD 3F-01
Conoc P lllllps
Alaska. Inc.
Well Attributes Max Angle & MD TO
Mo lnKe Pcl Bhn (nKB1
Fleed Name WenM,a APu1nN w9lBoresawa VIE,
KUPARUK RIVER UNIT 500292144600 PROD .85 3..'0.00
Cdnmeni H35 (PPmI Date AIIRatanon End Dont
SSSV. NIPPLE 120 W/2015Lest WO: 412412014
Ke�Grtl (RI BE Repose 0a[e
41.00 912511985
3Fa1.SggXWJNJd Sl AM
Last Tag
VeniuleaM1ematk(xi
MnoMlronEnd Dale DeplM1 MKBI Laa1MW By
Last Tag, RKSJust 19' of Fill leaving 441' of Open parts) L&=O18 $50].0 aambaej
_ NNS.i 330
CGNDUCTOR:371Fn}o
NIPPLEBdI
GAS IIFi: 3.1 R.a
SURFAOE,37. ,,] 6-
GAs.""Ldasos
GAa DFT; S.�S.9
GASUFT;88W.4
GAs uFT;;nos
GASLIFT:zeea3
...A,7.9Ei
SEAL Nagy
pop; Ing"i
PACKER;)9)}9
PRODUCINON;S.ptt)
IPERF', 8.'594x1.00-
275' NEW STYLE TPc
SLEEVE ex6v.J
NIPPLE 81
PACKER: ii..x
SBE'. emte
MPPLE: SJohi
505; 89R]
IPERT :8417..e9.p-
IPERF; 84%S.0S.4a9.0-
IPERF; 849p0$SG0-
PROIMICTINK3508.61a.1
Last Rev Reason
A-darmn End DMe vel MM By
Rev Reason'. Open C Sands, Swapped Out TPI for TPC 101912018 fergUsp
Casing Strings
easing Deaehpgon oDgnl m(iN TIgodil sa Depidn'Wel xl oepm lTVDI-. wuTen lL.. Graae Taprnread
CONDUCTOR 16 15A6 37.0 1150 115.0 6250 FNO WELDED
Casing Description GDllnl oe, Tepponel eedgend. KBI Set Oepin IND).. WIILen 11... Grant Top TIN.
SURFACE 9510 8.92 37.0 3,970.8 3061.6 36.00 655 BTC
Casing Description losing lists) TMgIKBI eel Despholo B) aet DeplM1 (/VDI... W1rten IL.. Grade Top TM1read
PRODUCTION 7 628 35.0 8,816.1 818).1 26.00 J-55 BTC
Tubing Strings
Tuhing DescnPlion
TUBING - WO
a4ing Ma... lD (1n) Top IflKB ee[DepIM1 11t.. 5a Depm (N01 (.. wl(IWX) Grade Top eonneclbn
31/2 2.99 33.0 ),960.5 5719.1 9.30 L-80 EUEBrnd
Completion Details
Top IND' Top Inst Nominal
TopRKO) (Me) YI Item D. Cam to (in)
330 33.0 0.03 HANGER FMC TUBIN HANGER .992
518.1 518.0 3.99 NIPPLE CAMCO Z11 ""DS"NIPPLE 2.875
7,955.8 5,710.2 4583 LOCATOR BAKER LOCATOR 3.830
7.956.6 5,110.8 4582 SEAL ASSY BAKE ASSY the PER, 3ft'Stickup' 2.990
Tuhing Us. pi Wring Ma_. ID lin)
TUBING -OId 1 31/2 299
3.5'x2 815" @82)9'
TaP(nKtg
>960.2
Set DeplM1 M -Ba
83034
Dawn NVD14_WIItNIII
5951.6
9.7,0
Gntle
155
Top ConnxiIN
EUE BRD
Completion Details
Top IND) TWInd Nominal
Top DIKE) (a-) 1') Item Des Lam ID(inl
7,960.2 5.713.3 45.81 PER SWEEPER 3.000
7,9]3.9 5,122.9 45.75 PACKER BAI�RFHLPACKER 3.000
8,2If R 5,925.7 46L32 NIPPLE AVA BPL PORTE D 05B NIPPLE 2.300
6,268.2 5,927.3 46.33 70.Radetin9 CROSSOVER 3.5- TO 1.875" 2.441
6,278.4 6,934.3 46.34 LOCATOR BANERLOCATOR 3.000
82802 5,935.6 46.34 PACKER BAKER FB -1 PACKER 4.000
83.4 5,937.8 4635 TBE BAKER SEAL BORE EXTENSION 4.00
8,9,2 5,945.9 46.3 NIPP CAMEO D NIPPLE NO GO 2.250
8,302.71 5,951.1 4fi.38 SOS CAMCOSHEAROUTSUB 2.441
Other In Knife (Wireline retiiavable plugs,
valves, pumps, fish, else "''
Inag g
TIP IND'
hi
Tap Incl
PI
Des
Com
Run ONe
10 (1.)
8,265.3
5,925.3
46.32215
"NEW
STYLE TPC
LEEVE
275' NEW STYLE TPC (INS "GAL 1230"ID)C Sands 10/9/2018
Open
2.300
Perforations &Slots
T,
mpinKel
Bim mlee)
i
IM(BI
BIMIND)
(WSJ
unkeizone
Date
01
D-
lama"
I
Tvce
Cam
8,066.0
8,219.0
578].1
5.893.3
C -3,C -2,C-1,
UNIT 8, 3F-01
110]11985
12.0 IPERF
120 deg. phasing. 5' HJ II
Ceti Gun
8,417.0
8,423.0
6,029.8
6,0 .9
A.4. 3F-01
110]11985
4.0 IPERF
90 deg. Phasin8�4"HJ II
Csg Gun
8.428.0
8.066.0
6,03).4
6,064.0
A -3, 3F-01
1101/1985
4.0 IPERF
90 deg. phasing, 4"HJ II
C59 Gun
8,498.0
8.52fi.0
6.085.4
6,104.)
A -2,3F-01
11/9/1985
4.0 IPERF
90 deg. phasing. 4- HI II
Csg Gun
Mandrel Inserts
A
on Top fri Vd. Latch Pon Sha TRO Run
N TOP(-) ItIKB) Make MadN Solid s- Type Twe (in) 1%g Run Date Com
3,162.8 2,571.1 CAMCO MMG IFT GLV RK 0.188 1,248.0 5/212018
2 4,850.5 3.624A CAMEO MMG IFT GLV RK 0.1 8 1,240.0 5/20018
3 5,996.9 4,370.4 CAMEO MMG IFT GLV RK 0.188 1,234.0 &20018
4 6,840.4 4,940.4 CAMEO MMG IFT GLV RK 0.180 1,227.0 5122018
1112AS
5 7,474.3 5,376E CAMCO MMG IFT GLV RK 0.188 1,220.0 Sn0018
6 1,396.3 5,668.8 CAMCO MMG IFT OV RK 0.188 0.0 5/112018
J 8,011.7 5.)49.3 CAMCO KRUG DMY BK 0000 0.0 511811988
Notes: General & Sat
Entl Dale
AnWasion
51112003
NOTE: WAIVERED WELL: IA OA COMMUNICATION
KRU 3F-01 (PTD# 185-225) Summary for Sundry
Background
KRU Well 3F-01 is a Kuparuk producer equipped with 3-1/2" tubing and two packers straddling the C -sand
interval. The project targets at risk C -Sand resource to the south of 3F-01 in a heterogenous 100' thick sand
package. This project will involve drilling two CTD laterals from the 3F-01 parent wellbore. Prior to setting the
whipstock, a tubing punch will be performed at 8250' and cement will be squeezed behind the 3-1/2" tubing to
mechanically stabilize the tubing while milling a window during CTD operations.
Pre -CTD Work
1. RU Slickline: Pull TPC sleeve from AVA Nipple, set plug at 8205', bail sand on top of plug
2. RU E -line: Perforate tubing, injectivity test
3. RU Coil: Pump Cement, mill/underream cement in 3-1/2" tubing
4. RU Slickline: Dummy whipstock Drift
5. RU E -Line: Caliper, set whipstock @ 8243' MD
6. Prep site for Nabors CDR3-AC rig.
Rig Work
1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test.
2. 3F -01L1 Lateral (C sand - south)
a. Mill 2.80" window at 8243' MD
b. Drill 3" bi-center lateral to TD of 11,500' MD.
c. Run 2-3/8" slotted liner with aluminum billet from TD up to 9,100' MD.
3. 31F-011-1-01 Lateral (C sand - south)
a. Kickoff of the aluminum billet at 9,100' MD.
b. Drill 3" bi-center lateral to TD of 11,500' MD.
c. Run 2-3/8" slotted liner with deployment sleeve from TD up to 8,243' MD.
4. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig.
Post -Rig Work
S. Return well to production.
Loepp, Victoria T (DOA)
From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com>
Sent: Thursday, February 28, 2019 9:32 AM
To: Loepp, Victoria T (DOA)
Subject: RE: [EXTERNAL]KRU 3F-01 (PTD 185-225, Sundry 319-093) Set whip stock - BOP test
pressure
Hello Victoria,
We plan on testing to 3500 psi.
Regards,
Ryan McLaughlin
Coiled Tubing Drilling Engineer
ConocoPhillips Alaska
Office: 907-265-6218 Cell: 907-444-7886
700 G St, ATO 670, Anchorage, AK 99501
From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>
Sent: Thursday, February 28, 2019 9:30 AM
To: McLaughlin, Ryan <Ryan.McLaughlin @conocophillips.com>
Subject: [EXTERNAL]KRU 3F-01(PTD 185-225, Sundry 319-093) Set whip stock - BOP test pressure
Ryan,
What is the BOP test pressure for KRU 3F-01?
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil 8 Gas Conservation Commission
333 W. 7th Ave
Anchorage, AK 99501
Work: (907)793-1247
Victoria LoePP(&alaska.aov
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 a=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)7931247 or Victoria Loeoo@alaska.aov
LCl
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WELL LOG TRANSMITTAL DATA LOGGED
‘Qt'. 2013
M K BENDER
To: Alaska Oil and Gas Conservation Comm. September 24, 2013
Attn.: Makana Bender
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501 C _ E
()CT 1 0 tit:
RE: Plug Setting Record: 3F-01
Run Date: 9/21/2013
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Matthew Cook, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
matthew.cook@halliburton.com
3F-01
Digital Data in LAS format, Digital Log Image file 1 CD Rom
50-029-21446-00
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline&Perforating
Attn: Matthew Cook
6900 Arctic Blvd.
Anchorage, Alaska 99518 SCAN s ��
Office: 907-273-3572
Fax: 907-273-3535
matthew.cook@halliburton.com
Date: 01 3 Signed: /315.a.ae-fetoc-__
WELL LOG TRANSMITTAL
To: Alaska Oil and Gas Conservation Comm.
Attn.: Christine Shartzer
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: Production Profile: 3F-O1
Run Date: 7/27/2010
August 11, 2010
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of
Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
3F-O1
Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom
50-029-21446-00
Production Profile Log 1 Color Log
50-029-21446-00
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline & Perforating
Attn: Klinton Wood
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907-273-3527
Fax: 907-273-3535
klinton.wood@halliburt .
Date: ~~~~ ~ ~.ZG1~
~'3 $
. .~
/ 5 ;aas
'1~~
Signed:
~
KRU Producer~l-~' O1 (PTD185-22~TxIA • Page 1 of 2
Regg, James B (DOA)
From: NSK Problem Well Supv [n1617@conocophillips.com]
Sent: Monday, August 31, 2009 12:19 PM ~~~r ~~j~~ )((~~
To: Regg, James B (DOA)
Cc: Schwartz, Guy L (DOA)
Subject: RE: KRU Producer~1,F-01 (PTD185-225) TxIA
3~
Jim,
-? 3F-01 would be correct. Sorry about that. Since the report, the OV was replaced and passed a TIFL on
08/11/09. Please let me know if you need anything else.
Brent Rogers/Martin Walters
Problem Wells Supervisor
ConocoPhillipsAlaska, Inc. = k =~'~ ~;~'~ '' ~ ~~~~
~ ~; t~.v,.
Desk Phone (907) 659-7224
Pager (907) 659-7000 pgr. 909
From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov]
Sent: Monday, August 31, 2009 11:27 AM
To: NSK Problem Well Supv
Cc: Schwar~, Guy L (DOA) ;~F'
Subject: RE: KRU Producer~01 (PTD185-225) TxIA
should this be 3F-01 (PTD 185-225)?
Jim Regg
AOGCC
333 W.7th Avenue, Suite 100
Anchorage, AK 99501
907-793-1236
From: NSK Problem Well Supv [mailto:n1617@conocophillips.com]
Sent: Tuesday, August 04, 2009 10:51 AM
To: Regg, James 6(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA)
Cc: NSK Problem Well Supv; NSK Well Integrity Proj
Subject: KRU Producer 1F-01 (PTD185-225) TxIA
Jim,
Kuparuk Producer 1 F-01 (PTD185-225) TxIA is suspected of having tubing by IA communication due to a high IA
pressure while SI.
This well is on the Master SCP report for IAxOA communication and will be added to our internal weekly report. If
the current annuli pressures stabilize it will be repaired or secured with in 14 days. If OA pressure rises above
45% burst it will be secured immediately and the Commission will be re notified. Current T/I/O pressures are
8/31 /2009
KRU Producer 1F-O1 (PTD185-22,5~ TxIA • Page 2 of 2
~
SI/1500/680.
The schematic and TIO are attached.
Please let me know if you have any questions.
MJ Loveland
Well Integrity Project Supervisor
ConocoPhillips Alaska, Inc.
Office (907) 659-7043
Cell (907) 943-1687
«3F-01 TIO.pdf» «3F-01.pdf»
8/31 /2009
~~
~~~ SC
300U
It
III
111 27~D
111
~ 240U
2100
18~0
1500
1200
900
600
300
WELL NAME
0
' 1
'------------------------------------------------------------------------------------------------------------------------------------------------------------------------- -
-----~
PLOT START TIME MIN(1F~ "T~TME F'I.ii ~N PLO"T END TIME
06-MAY-09 10: 40 t~ir"~,(t)!' ~1' iMi•: WEEK 1
PICK TI2iE :
SC T'AG H~liE DESCRIPTION P-V~LIIE LATEST
~ WL3F-OI-CHOKE FLOW T[1BING CHOKE 84.
~
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~ AI-P3F5002-O1 GL CASING PRESSURE 11?~~
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~ SCRATCH_31 OiITER ANNIJLUS PRES 840.
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~
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~ '
` 500292144600 KUPARUK RIVER UNIT PRODUCING 52.85 3,100.00 8,730.0
Comme,rt H2S (ppm) Date Annotation End Date K81irtl (tt) Rig Release Date
~gu,~ .-~~~ 7{. .~,~ _
~~ SSSV: TRDP 85 12/18/2008 Last WO: 41.00 9/25/1985
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~~:-:-
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Last Tag: RKB 8,509A 5/22/2009 Rev Reason: GLV GO, TAG Imosbor 525/2009
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~
~ CONDUCTOR 16 15.062 41.0 ll5.0 115.0 62.50 H-40
CONDUCTOR
115 SURFACE 9 5/8 8J65 0.0 3,971.0 3,061.9 36.00 J-55
:;;r- PRODUCTION 7 6.151 0.0 8,646.0 6,187.0 26.00 J-55
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- TUBING 3 1/2 2.992 0.0 8,259.0 5,920.9 9.30 J-55 SRD EUE
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Descrlpdon CommeM Run Data ID (in)
1,801 1,692.0 40.01 SAFETY VLV Camco TRDP-IA-SSA' 12/5/1985 2.813
GASLIFL
4,509 'I,C)4] 2,258.1 52.43 GAS LIFT CAMCOMBUG/1/GLVBK/.156/7250/Comment: STA 1 524Y2009 2.875
4,509 3,400.1 50.06 GAS UFT CAMCO/KBUG/1/GLVBK/.156/1255/Comment: STA2 5/242009 2.875
GAS UFT, 5,z6~ 3,889.4 50.32 GAS LIFT CAMCO/KBUG/t/DMYBW// Comment: STA 3 12/5/1985 2.875
5.zs~ - 5,731 4,194,9 48.63 GASLIFT CAMCO/KBUG/VGLV/BKl.188/1290/Comment:STA4 5/24/2009 2.875
~" 6,173 4,487.5 48.08 GASLIFT CAMCO/KBUG/1/OVBK/.25//Comment:STAS 5/23/2009 2.875
° 6,648 4,809.0 46.86 GAS LIFT CAMCO/KBUG/1/DMY/BTM/// CommenC STA 6 5/23l2009 2.875
GASLIFT, J
OSJ 5
089
1 46
48 GASLIFT CAMCO/KBUG/1/DMY/BK/UComment:STA7 12/5/1985 2.675
5,731 , ,
. .
^ 7,527 5,413.0 46.45 GAS LIFT CAMCOlKBUG/1/DMY/BK/// CommenC STA 8 5/23/2009 2.875
- 7,902 5,672.8 46.04 GAS ~IFT MERLA/I'PDX/1.5/DMY/RM/// CommenC STA 9 8Y29/2002 2.875
GASLIFT,
6,173 ~,JSO 5,706.2 45.85 PBR Baker 1215/1985 3.000
7,964 5,715.9 45.79 PACKER Baker'FHL' 12/5/1985 3.000
8,002 5,742.2 45.58 PRODUCTION CAMCO/KBUG/1/DMY/BK/// Comment: CLOSED STA 10 5/18/1988 2.875
GAS LIFf,
6,648 S,2$6 5,918.9 46.28 NIPPLE AVA BPL PORTED NIPPLE 12/5/1985 2.750
6,277 5,9292 46.31 PACKER Baker'FB-1' 12/5/1985 3.000
8,286 5,939.6 46.34 NIPPLE Camco'D' Nipple NO GO 12/5/1985 2250
GASLIFT,
~.os~ _ $~QQQ 5,945.1 46.36 SOS Camco ~ 12/5/1985 2.441
8,294 5,945.1 46.36 TfL 12/5/1985 2.441
~~I'~4Ed ~COIS$ ~t -.~~li'~ ~ , - s ,~r _ ~'~r' __ E` ~ ' 1~ ' ~ ~ ' n~ ~ ,p;~
~
OA6LIFf, Shot
~'SZ~ Top (ND) Btm (ND) Dens
~ Top RKB Btm (RKB ) (ftK8) (RKB) Zone Date (°M1~° Type Comment
= 8,066 8,219 5,787.1 5,893.2 C -3, G2, C-1, 1127/1985 12.0 IPERF 120 deg. phasing, 5" HJ II Csg Gun
- U NIT B, 3F-01
cns uFr,
~'~ 8,417 8,423 6,029.9 6,034.0 A -4, 3F-01 11/27/1985 4.0 IPERF 90 deg. phasing, 4" HJ II Csg Gun
--- 8,428 8,468 6,037.4 6,064.9 A -3, 3F-01 11/27/1985 4.0 IPERF 90 deg. phasing, 4" HJ II Csg Gun
PBR, 7,950 - B,49H 8,526 6,085.4 6,104J A -2, 3F-Ot 11/27/1985 4.0 IPERF 90 deg. phasing, 4" HJ II Csg Gun
F~~#e~;' ~i~t'a t ~, `f8 ' ` ~" ~~ ~ ~ ~ ~~ 7air .~; ~ ,'~r ~LL~9 ` ! ~ Y
End D Me AnnMa tion
~` ~'~ 5/4/2003 NOTE: WAIVERED WELL: IA x OA COMMUNICATION
PACKER, 7,964 7Y27/2006 NOTE: VERIFY COM BETN/EEN TBG 8 TRDP (STUCK OPEN) CONTROL LINE
PRODUCTION,
8,002
IPERF, ~ n-^~~"'"
8.0668.219 ~ " ~._.~:
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4:
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8.417A.423 +~~'
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8,428A.46B -
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8,49&B.52fi -.-~y,..-
PRODUCTION.
8,646
TD, 8,730
3F-O1 (PTD 185-225) Report of~ed TIFL • Page 1 of 1
Regg, James B (DOA)
From: NSK Problem Well Supv [n1617@conocophillips.com]
Sent: Thursday, May 14, 2009 1:31 PM .
To: Maunder, Thomas E(DOA); Regg, James B(DOA)
Cc: NSK Problem Well Supv
Subject: 3F-01 (PTD 185-225) Report of failed TIFL
Attachments: 3F-01 schematic.pdf; 3F-01 90 day TIO plot.jpg
Tom, Jim
Kuparuk gas lifted producer 3F-01 (PTD 185-225) failed a dia~nostic TIFL on 05/13/09 and was added to the
weekly SCP report. The TIO prior to the test was 250%1375/116~-AleaTcing GLV is suspected. Slickline will
troubleshoot the GLV's and repair if possibie. ~
Attached is a schematic and a 90 day TIO plot.
/
Please let me know if you have any questions.
Brent Rogers/Martin Walters
Problem Wells Supervisor
ConocoPhillips Alaska, Inc.
Desk Phone (907) 659-7224
Pager (907) 659-7000 pgr. 909
~ ~ W• ~a " t~ ~, r^ ~ ~"~
:..`'a. 1"! '~r',!,,.~. ~ t_,,{., i ~' ~ ~#.J~J.,~~r
«3F-01 schematic.pdf» «3F-01 90 day TIO plot.jpg»
8/7/2009
,~,~, KUP ~ 3F-01
V.rV~ I II~E'~~~ ~ . .?~~ ~~ *` = 4 i~.n ?~ ==._ „ g -t. . "~ _.., ~M; .,~~~ ~~.,t~..,::
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Incl (°) MD ~kKB) Act Bbn (kKB~
Field Name
500282144600 KUPARUK RIVER UNIT PRODUCING 52.85 3,100.00 8,730.0
Comment H2S (ppm) Date Annoution End Oate KB-Grd (ft) Rig Ralease DaN
~~~ SSSV: TRDP 85 1/1I2009 Last WO: 41.00 925/1985
M ,
- f
V Annotatlon Depth (/tKB) End Date Annofatlon Lasl Mod By End Date
Last Tag: SLM 8,503.0 Bl23/2008 Rev Reason: RE PLACE W EB SCHEMATIC Mplwj 3/16/2009
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~
' CONDUCTOR 18 15.082 41.0 115.0 715.0 62.50 H-40
CONDUCTOR,
115 SURFACE 9 5/8 8.765 0.0 3,971.0 3,061.9 36.00 J-55
PRODUCTION 7 6.151 0.0 8,64fi.0 ~ 6,187.0 26.00 J-55
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- TUBING 3 1!2 2.992 0.0 8,259.0 5,920.9 9.30 J-55 BRD EUE
cnsuFr, " TUBING 27/8 2.441 8,259.0 8,294.0 5,945.1 6.50JS5 SRDEUE
z,sa~
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2 2
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1 52
43 GAS LlFT CAMCOMBUG/1/GLVlBK/
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- 4,509 3,400.1 50.06 GAS LIFT CAMCO/KBUGl1/GLV/BK1.188112961 Comment: STA 2 1W31/2004 2.875
GAS LIFT, S,ZB'I 3,889.4 50.32 GAS LIFT CAMCO/KBUG/1IDMY/BW// Comment: STA 3 12/5/1985 2.875
s,2si 5,731 4,194.9 48.63 GASLIFT CAMCO/KBUCa/1lGLVIBK/.188/1292/Comment:STA4 10l31I2004 2.875
6,173 4,487.5 48.08 GAS LIFT CAMCOIKBUGI7IDMY/BKII/ Comment: STA 5 1?J511985 2.875
6,648 4,809.0 46.86 GAS LIFT CAMCO/KBUG/1/GLVBTM/25l1393/ Comment: STA 6 11It/2004 2.875
cns uFr,
5,731 s 7,057 5,089.1 46.48 GAS LIFT CAMCO/KBUGIt/DMYIBIC~/I Comment: STA 7 12I5/1985 2.875
7,527 5,413.0 46.45 GAS LIFT CAMCO/KBUG/1/OVIBKl.25// Commenf: STA 6 10/30/2004 2.875
- 7,902 5,672.8 46.04 GAS LIFT MERLA/TPDX/1.5/DMY/RM/d Comment: STA 9 8/29/2002 2.875
GASLIFT,
6,173 _ ~,JSO 5,706.2 45.85 PBR Baker 12/5I1985 3.000
- 7,964 5,715.9 45.79 PACKER Baker'FHL' 12I5/1985 3.000
~,
~ 8,002 5,7422 45.58 PRODUCTION CAMCOIKBUG/1lDMY/BKII/ Commenk CLOSED STA 10 5I18I1988 2.875
I cns uFT, 8
256 5
918
9 4628 NIPPLE AVA BPL PORTED NIPPLE 12/5/1985 2.750
B,B48 , ,
.
8.271 5,9292 46.31 PACKER Baker'FB-1' 17J5/1985 3.000
GAS~ " 8,286 5,939.6 46.34 NIPPLE Camco'D' Nipple NO GO t?!5/1985 2.250
57 - 8,294 5,945.1 46.36 SOS Camco 12/5/1965 2.441
8,294 5,945.1 46.36 TTL ~ ~ 12I5/1985 2.441
~ F~1`~6f`~ trKl~3'8~$r~S`Y#tf8 ,';~ ; ~ a ~~;-;~rt',i'~ '' .^:37mI~~ ~ - ~I~t~'I~ ~~`-} s 1i~''"!`~ Gpuw"I6~iii~v;wr
GA6 LIFT, Shot
7.527
Top (TVD) Btm (ND) Dena
- Top (ftKB) Btm (ttKB) (ftKB) (kKB) Zone Dale (sh•~~ Type Comment
8,066 8,219 5,787.1 5,893.2 C -3, C-2, C-1, 1 t127/1985 12.0 IPERF 120 deg. phasing, 5" HJ II Csg Gun
cas uFr,
'
~
eo2
" U NIT B, 3F-01
,
,
I g,417 8,423 6,029.9 6,034.0 A -4, 3F-01 11/27/1985 4.0 IPERF 90 deg. phasing, 4" HJ II Csg Gun
; 8,428 8,468 6,037.4 6,064.9 A -3, 3F-01 11/27/1985 4.0 IPERF 90 deg. phasing, 4" HJ II Csg Gun
I aeR, ~,eso =
2 8,498 8,526 6,085.4 6,104.7 A 4, 3F-01 11/27/1985 4.0 IPERF 90 deg. phasing, 4" HJ II Csg Gun
~ „ @~~ ~ ~ ~'~ -~ `~m ~ ~ xpi"
~~ ~ , ' " ~_ '
~
~ ~ ~ *r~
r
s ~ _ ~ q~ w ~ ~~-
End D aW ~ Annota tion
....._~~~... 5/4/2003 NOTE: WANERED WELL: IA x OA COMMUNICATION
PACKER, 7,964 7/27I2006 NOTE: VERIFY COM BETWEEN TBG & TRDP (STUCK OPEN) CONTROL LINE
I PRODUCTION,
8,002
l
~
IPERF, ~
6
~
8,068-8,279 ^~~"' ,~
NIPPLE,8,256
I
r
PACKER, 8,271
NIPPLE,8.286
505, 8,284
TTL,8,284
IPERF
~ ~
,
8,477-8,4Y3 ~'~,
~
IPERF. .~.^~~.....~,,.^^ .,,~
Bp28A,468 ~ ~
~
IPERF,
"',„„,-~""
8.498-8,52fi ~"`',",~"," ~
PROOl1CTION,
8,648
TD.8,13U
KRU 3 F-O 1
PTD 185-225
5/14/2009
TIO Pressures
T/I/O Plot - 3F-01
1200
,ooo
800
~
a 600
400
Zoo
....... _ .. .. .... ............ r.T .,.'. ... , . '....!.'.L..,......'.~!.'. . 1.'.. ' ,....'.,....I.,....'.'... ':~
. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .v. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ~,, . . . . . . . . . . . . . . . . . . . . . . . . .
o ~
14-Feb-09
27-Feb-09 12-Mar-09 25-Mar-~9 07-Apr-09
Date
20-Apr-09 03-May-09
200
150
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100 ~
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L
V
50
0
i
~
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~/
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NO. 5005
Schiumberger -DCS
2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm
Anchorage, AK 99503-2838 Attn: Christine Mahnken
ATTN: Beth ~ ~ • ~ ~ C ~ 333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk
Well Job # Log Description Date BL Color CD
12/17/08
2X-10 11978476 PRODUCTION PROFILE f - ~ • 08/17/08 1 1
2V-09 12100460 PRODUCTION PROFILE (p 11/16!08 1 1
1Y-06A 12100461 PRODUCTION PROFILE 11/17/08 1 1
2X-12A 12100464 PRODUCTION PROFILE 9 '^ 11/21/08 1 1
2U-08 12096574 PRODUCTION PROFILE - 11/28/08 1 1
3K-108 12100466 USIT 11/23/08 1 1
3K-30 12097433 LDL _ / 11/28/08 1 1
30-01 12097434 LDL -Q ~ 11/29/08 1 1
1 E-04 12097436 LDL 'T 11/30/08 1 1
3A-04 12097432 INJECTION PROFILE L 11/27/08 1 1
iH-16 12096581 PRODUCTION PROFILE ~ 12/05/08 1 1
3A-06 12114994 BAKER LOWER STRADDLE PACKER 11/26/08 1 1
2U-14 12096578 INJECTION PROFILE C -~ j 12/02/08 1 1
1G-06 12096580 INJECTION PROFILE 12/04/08 1 1
2V-10 12096582 PRODUCTION PROFILE - 12106/08 1 1
~ 3F-01 12086694 PRODUCTION PROFILE ^' 12/07/08 1 1
2W-14 12086695 INJECTION PROFILE u 12/08/08 1 1
iJ-102 12086701 INJECTION PROFILE - 12/14/08 1 1
1 D-07 12114999 USIT _ ~ 12/15/08 1 1
3C-02 12114997 INJECTION PROFILE - ~ 12/13/08 1 1
2T-18 12086703 INJECTION PROFILE ~ 12/17/08 1 1
C~
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
.
.
~illips
Alaska
RECEIVED
SEP 0 6 2006
Alaska Oil & Gas Cons. Commission
Anchorage
P.o. BOX 100360
ANCHORAGE, ALASKA 99510-0360
September 2, 2006
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West ih Avenue, Suite 100
Anchorage, AK 99501 SCANNeD SEP 0 82005
~ %'ó~ :}.'}.5"
Dear Mr. Maunder:
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU) 3F Pad.
Each of these wells was found to have a void in the conductor by surface casing annulus. The
voids that were greater than 6 feet were first filled with cement to a level of2.5 feet. The
remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion
inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler,
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 top-fill operation was completed on August 14,2006 and is reported as follows.
Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was
pumped into the conductor bottom and cemented up via a hose run to the existing top of cement.
The corrosion inhibitor and sealant were pumped in a similar manner August 21-29, 2006. The
attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes
used on each conductor.
Please call Jerry Dethlefs or myself at 907-659-7043 . you have any questions.
A~
-M'J'~
ConocoPhillips Well Integrity Supervisor
Attachment
.
.
ConocoPhillips Alaska Inc.
Surface Casing by Conductor Annulus
Cement and Sealant Top-off
Kuparuk Field
8/31/2006
Well Name
PTD#
Initial Top
of Cement
Feet
Cement
Volume
Barrels
Final Top
of Cement
Feet
Cement
Date
Sealant
Volume
Gallons
Sealant
Date
Schlumbergel'
Schlumberger -DCS
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
Well
Job #
2C-05
2Z-09
2D-09
3F-03
3F-01
3F-15
1 F-03A
1G-17
1J-164
3G-25X
1 Q-20A
11072930
11057062
11141218
11141219
11057064
11057065
11141222
11141221
N/A
11141229
11144038
SIGNED:tl¿_~c~r..\ 1---
~ - rT
J
INJECTION PROFILE
INJECTION PROFILE
LEAK DETECTION LOG
INJECTION PROFILE
PRODUCTION PROFILE
INJECTION PROFILE
LEAK DETECTION LOG
PRODUCTION PROFILE
USIT
SBHP SURVEY
SBHP SURVEY
,~EC~Et\JED /
C\
¿12:J05 i\j;¡\D(?
. .'
c¡\ S~ Ga~} Cens. Corf.mm-s;cr'
:t\n\:hori~_:~8
0\' 'ì (:', t'J005
_ . . <1.\.\. cr-,¡ N,...l .fJ ~ L
fr---'rh.Ì'b~~'b ,"?
~yb"\
Log Description Date
t ~ -'):2'!Çf-
11/02/05
11/03/05
11/04/05
11/05/05
11/05/05
11/07/05
11/08/05
11/07/05
11/12/05
11/16/05
11/17/05
NO. 3604
Company: Alaska Oil & Gas Cons Comm
Attn: Helen Warman
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field:
Kuparuk
BL
Color
CD
1
1
1
1
1
1
1
1
1
1
1
DATE: n) ~1)0-S-
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
11/18/05
--
ìó3-0'19 Ul'
- ,,,. .
1[Y::-~ 1:2L: UtC
; ~-+ - \6::-
j '63 -,;ì;ìl U 'I (
ÎS5-d;)S
1F-.5 -,~'1~. U¡ L-
yg ~~ D9to
ic¡q -û(cd..
:105- 141-
J0fJ7 - j 30
¡q5-15/¿
Schlumberger
Schlumberger Technology Corporation, by and through is Geoquest Division
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Beth
NO. 2879
Company:
Alaska Oil & Gas Cons Comm
Attn: Lisa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
O6/24/O3
Field: Kuparuk
Well Job # Log Description Date BL Color CD
3S-17A ~-~(~)"~ -t-'~j.4~!SBHP SURVEY 05107/03 1
3S-06 .~(~.~ '~.~2 ~' PERF RECORD W/SBHP & JEWELRY LOG 05/25/03 1
3S-08B .i~--'~'~-O/--~.~ PROD PROFILE W/TEMP SURVEY 05/24103
3S-23 ~'-~C'~ '~,J~-L_'~'PRODUCTION PROFILE 05/10/03 1
1H-17 -{qCt~' i~"'~ PRODUCTION PROFILE 05/14/03 1
2U-08 '~'~.~- .(~ 1 SBHP SURVEY 05/09/03 1
~ , -
1R-14 !~l- I,.'~ '~ LDL 05108103
3F-01 )9~'-~_ry~-_'~ PRODUCTION PROFILE 05/19/03
1D-103 ~,~..~-~-('~'~(_~ MEM PSP INJECTION PROFILE 04/04/03
3S-17A/~,~7~.~ " 23351 ' SCMT 05107/03 .1
3S-06 ,.~"')."~ y"¥~-) ,-? 23353 SCMT 05~23~03
,
DATE:
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
!
.
·
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Performed: Operation Shutdown__ Stimulate Plugging_
Pull tubing __ Alter casing __ Repair well __
Perforate
Other X
2. Name of Operator
ARCO Alaska, Inc.
3. Address
P. O. Box 100360, Anchorage, AK
99510
5. Type of Well:
Development
Exploratory
Stratigraphic
Service
4. Location of well at surface
89' FNL, 162' FWL, Sec 29, T12N, R9E, UM
At top of productive interval
1425' FSL, 1485' FEL, Sec 29, T12N, R9E, UM
At effective depth
1169' FSL, 1279' FEL, Sec 29, T12N, R9E, UM
At total depth
1078' FSL, 1190' FEL, Sec 29, T12N, R9E, UM
12. Present well condition summary
Total Depth: measured
true vertical
8730
6243
feet
feet
6. Datum elevation (DF or KB)
RKB 93
7. unit or property name
Kuparuk River Unit
8. Well number
3F-01
9. Permit number/approval number
85-225
10. APl number
50-029-21446
11. Field/Pool
feet
Kuparuk River Oil Field/Pool
Plugs (measured) None
Effective depth: measured 8 5 5 5
true vertical 6123
feet
feet
Junk (measured) None
Casing
Structural
Conductor
Surface
Intermediate
Production
Liner
Perforation depth:
Length Size
80' 16"
3934' 9.625"
8611' 7"
250 Sx PF 'C'
measured
8066'-8219', 8417'-8423',
true vertical
5786'-5892', 6028'-6032',
Cemented Measured depth
348 SX AS II 1 1 5'
1020 Sx PF 'E' & 3971'
400 Sx PF 'C' w/50 Sx PF 'C' Top Job
325 Sx Class G & 86 46'
8428'-8468'
6036'-6063'
8478'-8526'
6070'-6103'
True vertical depth
115'
3061'
6185'
Tubing (size, grade, and measured depth)
3 1/2", 9.3#, J-55 @ 8259', 2 7/8", 6.5#, J-55 @ 8259' - 8294'
Packers and SSSV (type and measured depth)
PKR: Baker 'FHL' @ 7964' & Baker 'FB-I' @ 8271'; SSSV: Camco TRDP-1A-SSA @ 1801'
13. Stimulation or cement squeeze summary
Polymer profile modification/scale treatment on 4/21/96.
Intervals treated (measured)
8066'-8219'
Treatment description including volumes used and final pressure
Pumped 1000 lbs EDTA & 1100 gals SI-4004. Final WHTP = 400 PSI
14. Representative Daily Average Production or Iniection Data
OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure
Tubing Pressure
Prior to well operation
1553 1572 2256 1380 750
Subsequent to operation
1861 821 2575 1380 400
15. Attachments
Copies of Logs and Surveys run __
Daily Report of Well Operations X
16. Status of well classification as:
Oil X Gas
Suspended
Service
17.
F o r m//~z~OI4 U'R,~ 66~!~,~~'~ --
I hereby certify that the foregoing is true and correct to the best of my knowledge.
Title Wells Superintendent
SUBMIT IN DUPLICATE
ARCO Alaska, Inc.
KUPARUK RIVER UNIT
WELL SERVICE REPORT
Kl(3F-01(W4-6))
WFI 1. JOB SCOPE JOB NUMBER
3F-01 POLYMER PROFILE MOD 1030951750.4
DATE DAILY WORK UNIT NUMBER
04/21/96 POLYMER PROFILE MOD/SCALE INHIBITION TREATMENT
DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR
9 YES[ YES APC-KENNEDY APC
FIELD AFC# CC# DAILY COST ACCUM COST Signed
ESTIMATE 998487 230DS36FL $18,194.00 $68,202.16
Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann
750 PSI 400 PSI 1380 PSI 1380 PSII 200 PSII 200 PSi
DAILY SUMMARY
MARCIT GEL CLEANUP/SCALE INHIBITION TREATMENT: PUMPED 38 BBLS SW W/120 GAL SS-5206 & 110 BBLS FW 1% KCL W/10t2)0
LBS EDTA AND 1100 GAL SI4004.
TIME LOG ENTRY
18: 00 PT LINE TO 2500g.
18:05 BEGIN PUMPING 40.9 BBLS SW/SS-5206 PREFLUSH AT 750 PSIG, 2.0 BPM.
18:15 20 BBLS AWAY; PUMPING AT 1100 PSIG, 2.0 BPM.
18:25 SHUTDOWN; END OF PREFLUSH.
18:30 BEGIN PUMPING 136.2 BBLS FW 1% KCL W! 1000 LBS. DISODIUM EDTA AT 500 PSIG, 2.0 BPM.
18:40 20 BBLS AWAY; PUMPING AT 800 PSIG, 2.5 BPM.
18:49 40 BBLS AWAY; PUMPING AT 800 PSIG, 2.5 BPM.
18:59 60 BBLS AWAY; PUMPING AT 700 PSIG, 2.5 BPM.
19:10 80 BBLS AWAY; PUMPING AT 750 PSIG, 2.5 BPM.
19:19 100 BBLS AWAY; PUMPING AT 750 PSIG, 2.5 BPM.
19:30 SHUTDOWN; END OF TREATMENT.
19: 3 3 FREI~YF. PROTECTING TBG; BEGIN PUMPING DIESEL AT 2.0 BPM DOWN TBG.
19:3 8 10 BBLS AWAY; PUMPING AT 750 PSIG, 2.0 BPM.
19:45 20 BBLS AWAY; SHUT DOWN.
20:10 FRF. F.77E PROTECT FL; BEGIN PUMPING MEOH AT 1.0 BPM, 400 PSIG.
20:15 5 BBLS AWAY; PUMPING AT 1.0 BPM, 400 PSIG.
20:20 10 BBLS AWAY; SHUT DOWN.
I
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Performed: Operation Shutdown __
Pull tubing Alter casing
Stimulate X Plugging
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
89' FNL, 162' FWL, Sec 29, T12N, R9E, UM
At top of productive interval
ORIgiNAL
6. Datum elevation (DF or KB)
RKB 93
7. Unit or Property name
Kuparuk River Unit
feet
8. Well number
3F-01
9. Permit number/approval number
85-225
10. APl number
50-029-21446
1425' FSL, 1485' FEL, Sec 29, T12N, R9E, UM
At effective depth
1169' FSL, 1279' FEL, Sec 29, T12N, R9E, UM
At total depth
1078' FSL, 1190' FEL, Sec 29, T12N, R9E, UM
12. Present well condition summary
Total Depth: measured
true vertical
8730
6243
feet
feet
11. Field/Pool
Kuparuk River Oil Field/Pool
Plugs (measured) None
Effective depth' measured 8555
true vertical 6123
feet
feet
Junk (measured) None
Casing Length
Structural
Conductor 80'
Surface 3 9 3 4'
Intermediate
Production 8 61 1'
Liner
Perforation depth: measured
8066'-8219',
true vertical
5786'-5892',
Tubing (size, grade, and measured depth)
Size
16"
9.625"
7"
Cemented Measured depth
348 Sx AS II 1 15'
1020 Sx PF 'E' & 3971'
400 Sx PF 'C' wi 50 Sx PF 'C' Top Job
325 Sx Class G & 8 6 4 6'
250 Sx PF 'C'
8417'-8423', 8428'-8468', 8478'-8526'
6028'-6032', 6036'-6063', 6070'-6103'
3 1/2", 9.3#, J-55 @ 8259', 2 7/8", 6.5#, J-55 @ 8259' - 8294'
Packers and SSSV (type and measured depth)
PKR: Baker 'FHL' @ 7964' & Baker 'FB-I' @ 8271'; SSSV:
True vertical depth
115'
3061'
6185'
RECEIVED
MAY 0 7 199
Camco TRDP-1A-SSA @ 1801'~
13. Stimulation or cement squeeze summary
Perforate "A" Sand interval on 11/25/95.
Intervals treated (measured)
841 7'-8423', 8428'-8468', 8478'-8526'
Treatment description including volumes used and final pressure ..
Pumped 136 Mlbs of 20/40 & 12/18 ceramic proppant into formation, fI:) was 5600 psi.
14. Representative Daily Average Production or In!ection Data
OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation
735 375 0 850 144
Subsequent to operation
1 2 8 0 556 0 658 208
15. Attachments
Copies of Logs and Surveys run __
Daily Report of Well Operations X
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.
Signed ~ ~,.~
Form 10-404 Rev 06/15/88
Title Wells Superintendant
Date ~,~J~ ,..~/
SUBMI-I~N DUPLICATE
ARCO Alaska, Inc. KUPARUK RIVER UNIT
WELL SERVICE REPORT
~' K1 (3F-01 (W4-6))
WELL JOB SCOPE JOB NUMBER
3F-01 FRAC, FRAC SUPPORT 1 124951608.1
DATE DAILY WORK UNIT NUMBER
11/25/95 "A" SAND FRAC
DAY OPERATION COMPLETE J SUCCESSFUL KEY PERSON SUPERVISOR
1 ~ Yes (~ No! (~) Yes (~ No DS-YOAKUM CHA.,i~E~ ,~
Sig 'd
FIELD AFC,# ~ DALLY COST ACCUM COST,~(~igr~d / ~;,/,/'~
ESTIMATE 998457 230DS36FL $1 37,671 $137,671
Initial Tb_(:l Press Final Tba Press Initial Inner Ann Final Inner Ann I Initial Outei' A~n I Final Outer An~
250 PSI 1000 PSI 1200 PSI 1500 PSI! 400 PSII ~'0 PSI
DAILY SUMMARY
SAND FRAC COMPLETED. SCREENED OUT TOP TO BTM WITH 12/18 PROPPANT, HIGHEST PSI REACHED BEFORE S/D 5600
PSI. TOTAL SLURRY VOLUME 1689 BBLS. 136000 LBS BEHIND PIPE, 17000 LBS OF 12/18 IN TBG. 9.2# @ PERFS.
TIME
-06:30
08:00
08:45
09:00
10:50
11:05
12:30
14:00
15:00
LOG ENTRY
MIRU DOWELL EQUIP.,HOT OIL UNIT AND VAC TRKS. HELD SAFETY MTG(14 PEOPLE ON LOCATION).
RIGGED UP TO BACKSIDE AND PT'D HARDLINE TO 4000 PSI.
SET TREESAVER AND PT HI-PRESS PIPING TO 7800 PSI.
PUMP CONDITION 40~ DELAY-XL GW AND STRAIGHT WATER @20 BPM, LOST SUCTION ON 1 TURBINE ON LAST
STAGE AND S/D FOR APP.' 1 MIN THEN RESUMED PUMPING. FINAL PUMPING PSI 3550 PSI, VOLUME PUMPED 324
BBLS, USED 2011 LBS OF 20/40. ISIP 1830 PSI AND S/D FOR CLOSURE.
PUMP DATAFRAC 40~ DELAY-XL GW AND STRAIGHT WATER @ 20 BPM. FINAL PUMPING PSI 3870 PSI, TOTAL
VOLUME PUMPED 176 BBLS. ISIP 1813 PSI AND S/D FOR CLOSURE.
PUMP FRAC 40# DELAY-XL GW @ 20 BPM, SCREENED OUTTOP TO BTM WITH 12/18 PROPPANT @ 9.9 PPA,
HIGHEST PSI REACHED BEFORE S/D 5600 PSI. VOLUME PUMPED 1188 BBLS.
STARTED CLEARING UNES AND RIGGING DOWN DOWELL EQUIP. BLED 7" DOWN TO 1500 PSI AND SECURED
BACKSIDE. REMOVED TREESAVER( ALL CUPS RETURNED). TOTAL SLURRY VOLUME 1689 BBLS. TOTAL
PROPPANT USED 157410 LBS, 10200 LBS OF 20/40 PROPPANT AND 147210 LBS OF 12/18 PROPPANT. 136000 LBS
OF 9.2# BEHIND PIPE, 17000 LBS IN 'I'BG, 4410 LBS IN SURFACE PIPE.
RU HOT OIL UNIT TO FLOWLINE AND FREEZE PROTECTED WITH 20BBLS OF DIESEL
RD COMPLETE AND WELL SECURED NOTIFIED DSO OF STATUS.
MA, Y 0 7 l_qqcl
Cons. Commission
Ancl~rage
SERVICE COMPANY - SERVICE
APC-LABOR
APC-TRUCKING
DIESEL
DOWELL-STIMULATION
LITTLE RED HOT OIL
TOTAL FIELD ESTIMATE
DAILY CC)RT I AC~IIM TOTAl
ARCO Alaska, Inc.
Date: February 23, 1989
Transmittal #: 7432
RETURN TO:
ARCO Alaska, Inc.
Attn: Brenda K. Miernyk
Kuparuk Records Clerk
ATO-1119
P.O. Box 100360
Anchorage, AK 99510-0360
Transmitted herewith are the following items. Please acknowledge receipt and return
one signed copy of this transmittal.
3F-15
3N-18
3F-01
3F-02
3F-09
3F-06
3F-10
3F-11
3F-15
3F-14
3N-10
3N-06
3N-09
31-01
3N-11
3N-14
3F-08
3N-01
3N-14
3F-15
3F.-15
3F-13
3F-15
1B-05
1E-25
3B-11
3A-03
3H-01
2Z-19
31-12
1E-08
3M-18
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Re,
Kupaurk Fluid Level Re~
Kupaurk Fluid Level Re~
Kupaurk Fluid Level Re
Kupaurk Fluid Level Re
Kupaurk Fluid Level Re
Kupaurk Fluid Level Re
Kupaurk FlUid Level Re
Kupaurk Fluid Level Re
Kupaurk Fluid Level Re
Kupaurk Fluid Level Re
Kupaurk Fluid Level Re
Kupaurk Fluid Level Re
Kupaurk Fluid Level Re
Kupaurk Fluid Level Re
Kupaurk Fluid Level Re
Kuparuk Well Pressure Report
3ort
3ort
3ort
3ort
3ort
3ort
3ort
3ort
3ort
3ort
3ort
3ort
3orr
3ort
3ort
3ort
Kuparuk Well Pressure Report
Bottom-Hole Pressure Survey
Kuapruk Well Pressure Report
Kuparuk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
Kupaurk Fluid Level Report
12-03-87
12-18-87
8-29-87
8-29-87
8-29-87
8-29-87
8-29-87
8-29-87
8-29-87
8-29-87
5-18-87
5-22-87
5-21-87
4-24-87
4-15-87
4-13-87
4-14-87
4-20-87
12-04-87
2-02-89
8-27-87
8-27-87
8-25-87
2-20-89
2-19-89
2-20-89
2-21-89
2-21-89
2-20-89
2-2O-89
2-1 9-89
2-15-89
Casing
Casing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Tubing
Casing
Casing
Casing
Casing
Casing
Casing
Casing
Casing
Casing
Tubing
Sand 'C'
BHP
Amerada
Casing
Casing
Casing
Tubing
Casinl
Casin~
3 H-01 Kupaurk Fluid Level Report 2-15-89 Casing
3 B- 1 3 Kupaurk Fluid Level Report 2-1 7-89 Casing
I E-29 Kupaurk Fluid Level Report 2-15-89 Casing
1 C-05 Kupaurk Fluid Level Report 2-18-89 Casing/Tubing
3 M- 1 7 Kupaurk Fluid Level Report 2-16-89 Casing
2Z-20 Kupaurk Fluid Level Report 2-18-89 Tubing
30-10 Kupaurk Fluid Level Report 2-16-89 Casing
31-1 2 Kupaurk Fluid Level Report 2-20-89 Tubing
3 H- 1 0 BHP Report 2-13-89 BHP
Receipt Acknowledged- - .......................... Date' - ...........
DI~,T,R, IBUTION:
D&M State of_ Alaska SAPC Unocal Mobil Chevron
-
-_
ARCO Alaska, Inc.
Post Office B( ')0360
Anchorage, Aia>r.a 99510-0360
Telephone 907 276 1215
October 31, 1986
RETURN TO'
ARCO ALASKA, INC.
ATTN- Kuparuk Records Clerk
AT0-1119
P.O. Box 100360
Anchorage, AK 99510-0360
Transmittal =5806
Transmitted herewith are the following items. Please acknowledge
receipt and return one signed copy of this transmittal.
Final Prints'
~ --~IR- 14
~ ,-~IR- 14
-J 2A-14
~J ~3A-1
-~ ~'3A-2
-u J-3A-3
~ ",,3 .... 3A-15
--~--~ 3A- 16
~ ~--~3C- 15
~ '-,a ~- 3C-16
',,:, ~ ~3F- 1
~ ~ -3F-10
~'~ ~3F:11
~ ~ --3J-4
~ _~ ~3J-6
~3J-9
CET/CEL 10-12-85 Run #2 8600
CET/CEL 10-13-85 Run #3 85.50
CET/CEL 10-02-85 Run #1 6795
CET/CEL 10-01-85 Run #1 7550
CET/CEL 10-01-85 Run #1 6680
CET/CEL 10-01-85 Run #1 6080
CET/CEL 12-30-85 Run #2 6400
CET/CEL 12-30-85 Run #2 7300
CET/CEL 10-!5-85 Run ~1 5887
CET/CEL 10-15-85 Run ~1 3995
CET/CEL 10-17-85 Run =1 7000
·
.
.CET/CEL 12-19-85 Run #1 5166
CET/CEL 12-19-85 Run ~1 6950
CET/CEL 10-05-85 Run #1 6860
CET/CEL 10-19-85 Run ~1 7000
CET/CEL 12-18-85
Receipt Acknowledged'
- 9120
- 8894
- 7763
- 9467
- 8570
- 8256
- 8038
- 9030
- 7730
- 6753
- 8488
- 6483
- 8322
- 8410
- 8487
Run ~1 36 - 6678'
. //"~ Alaska Oil & Gas Cram. CommJssJo,~.
Anchora[ie
~K Drilling Vault(1 film)
AR~,O Alask-'. Inc. is ,! Subsidiary O~ AtlanhcRichlieldCorn~eny
'~-"~ STATE OF ALASKA r---..~ ~
ALASKA OIL AND GAS CONSERVATION CO,v,I~ISSlON "/~
PL,=TION OR RECOMPLETION REPORT AND LOG
.
Classification of Service Well
1. Status of Well
oILX~i~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ,~.
2. Name of Operator' 7. Permit Number
ARCO Alaska, Inc. 85-22_5
3. Address 8. APl Number
P. 0. Box 100360, Anchorage, AK 99510 50- 029-21446
4. Location of well at surface 9. Unit or Lease Name
89' FNL, 162' FWL, Sec.29, T12N, R9E, UM Kuparuk River Unit
At Top Producing Interval 10. Well Number
1425' FSL, 1528' FEL, Sec.29, T12N, R9E, UM 3F-1
At Total Depth 11. Field and Pool
1078' FSL, 1190' FEL, Sec.29, T12N, R9E, UM Kuparuk River Field
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool
93' RKB ADL 25643 ALK 2574
12. Date Spudded 13. DateT.D. Reached 14. Date ComP., Susp-°rAband. 115. Water Depth, if°ffsh°re 116'N°'°fC°mpleti°ns
09/19/85 09/23/85 09/25/85*I IN/A feet MSL 1
17. Total Depth (MD+TVD) 18.Plug Back Depth'(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost
8730'MD,6243'TVD 8555'MD,6123'TVD yE~Yi[~ NO []I 1801 feet MD 1500' (approx)
22. Type Electric or Other Logs Run
DIL/GR/SP/SFL, FDC/CNL, Cal, CET, GCT
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
16" 62.5# H-40 Surf 115' 24" 348 sx AS II
9-5/8" 36.0# J-55 Surf 3971' 12-1/4" 1020 sx PF "E" & 400 sx FF "C"
Top job performed w/50 s~ PF "C"
7" 26.0# J-55 Surf 8646' 8-1/2" 325 sx Class G & 250 sx FF "C"
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)
8526' - 8478' 3-1/2" 8294' 7964' & 8271'
8468' - 8428' w/4 spf, 90° phasing
8423 ' - 8417 ' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED
8219' - 8066' w/12 spf, 120° phasing See addendum attaeI,ed to Well Completion Report dated
04/01/86.
27. N/A PRODUCTION TEST
Date First Production I Method of Operation (Flowing, gas lift~ etc.)
I
Date of Test' Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO
TEST PERIOD I~
Flow Tubing Casing Pressure CALCULATED" OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. 24-HOUR RATE ~
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
None
Form 10-407 * NOTE: Tubing was run & well perforated 11/29/85. WC1/042
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
Submit in duplicate
TS
' N'AME' ' ': .' -'-: ' ' ' ~ :' ........... ~ ' ' '" i~bde interVal tested,'pressu'~e data, all fluids r~overed and gravity,
MEAs. DEPTH TRUE VERT. DEPTH GOR, and time of each ~hase.
.
...... · -...
.
Top Kuparuk C 8062~ 5783~ N/A
Base Kuparuk C 8220[-~~ 5892~ .... '.': .
Top Kuparuk A 8~01 ~ 6017 ~
Base Kuparuk A _ 859~~ 6150~ ' '
.
.
:
.
. ~ ~:.:-: ~.:
~ . ..: .:
. , ..
2.
.
.
.
.
.
.
.
..
31. LIST OF ATTACHMENTS
None.
32. I hereby certify that the foregoiBg is true and corr~t to ~h~ 'best of my knowledge
....... Associate Engineer .24'BG
Sign~ Title 'Date
INSTRUCTIONS
General: This fOrm is designed for submitting a complete and correct well completion report and' log on
all types of lands and leases in Alaska.
; .
Item 1' ClassifiCation of serViCe Wells' Gas injection, water injection, steam injectiOn, air injection, salt
water disposal, water supply for injection, observation, injection for in-situ combustion.
Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements
given in other spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interVal (multiple
completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported
in item 27. Submit a separate form for each additional interval to be separately produced, showing the
data pertinent to such interval.
Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23' Attached supplemental records for this well should show the details of any multiple stage cement-
lng and the location of the cementing tool.
Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Ga~ Injection, Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none".
Form 10~107
~'-
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COiwMISSlON 14Z-~.~.
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. 85-225
3. Address 8. APl Number
P. 0. Box 100360, Anchorage, AK 99510 50- 029-21446
4. Location of well at surface 9. Unit or Lease Name
89' FNL, 162' FWL, Sec.29, T12N, R9E, UM Kuparuk River Unit
10. Well Number
At Top Producing Interval
1425' FSL, 1528' FEL, Sec.29, T12N, R9E, UM 3F-1
At Total Depth 11. Field and Pool
1078' FSL, 1190' FEL, Sec.29, T12N, RgE, UH Kuparuk River Field
5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool
93' RKBI ADL 25643 ALK 2574
12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116' No. of Completions
09/19/85 09/23/85 09/25/85*I N/A feet MS LI 1
17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ FVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost
8730'MD,6243 'TVD 8555'MD,6123'TVD YES [~X NO []I 1801 feet MD 1500' (approx)
22. Type Electric or Other Logs Run
DIL/GR/SP/SFL, FDC/CNL, Cal, CET, GCT
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
16" 62.5# H-40 Surf 115' 24" Conductor installation report not yet receive
9-5/8" 36.0# J-55 Surf 3971' 12-1/4" 1020 sx PF "E" & 400 sx PF "C"
Top job performed w/50 sx PF "C"
7" 26.0# J-55 Surf 8646' 8-1/2" 325 sx Class G & 250 sx PF "C"
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)
8526' - 8478' 3-1/2" 8294' 7964' & 8271'
8468' - 8428' w/4 spf, 90° phasing
8423' - 8417' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED
8219' - 8066' w/12 spf, 120° phasing See attached Addendum, dated 2/27/86.
27. N/A PRODUCTION TEST
Date First Production I Method of Operation (Flowing, gas lift, etc.)
I
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OILRATIO
I
TEST PERIOD I~
Flow Tubing !Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. 24-HOUR RATE ~
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
None
RECEIVED
APRO 1986
Alaska Oil & Gas Cons. commission
Anchorage
d,
Form 10-407 * NOTE: Tubing was run and the well perforated 11/29/85. GRU1/WC16 Submit induplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
· - GEOLQGicMA.R, KE~S ..~,_/ .<~{ : : : !-~& ...';~'!-',..;,.,~ :~.i ~i.~. FORMATION.TESTS
~- ' ·NAME ' ' ' ' Include interval tested, pressure data, all fluids recover~ and gravity,'
' MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Top Kuparuk ~ 8062~ 5783 ~ N/A
Base Kuparuk C 8~20' 5892~
Top Kuparuk A ~,-~-:,._,~8~01~. 6017~ ..... ~ --: ,
Base KUparuk A 859~ 6150~
.. . ;
. _ . _ . .- , ~
, . .
.
31. LIST OF ATTACHMENTS
.Addendum (da~ed 2/27/86) ......
32. '~ ' i'hereb~'certi~Y ~hat'the foregoing is true and correct to the be~t of my kn'~w~edge
. . .
~/ .
-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 (G L) or other elevation (DF, KB, etc.).
Item 23' Attached supplemental records for this well should show the details of any multiple stage cement-
lng ar~ ~t'h~dc~ib.n';o.f. !the cementing tool.
Item ~,7,...;.: M~etho, d of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
. . ~'.¢;"' : , ..; ~ '~.; t: . . .
jectlofi,~Ga$ Inje{;~t~on, Shut-in, Other-explain.
Form 10-407
ADDENDUM
WELL:
3F-1
FRACTURE STIMULATION SUMMARY
Begin Frac Work At: 2200 hrs, 12/28/85.
Frac'd Kuparuk "A" sand perfs f/8417'-8423', 8428'-8468'
& 8498'-8526' in 6 stages per 12/17/85 procedure using
gelled diesel, Musol, 100 mesh & 20/40 sand. Press'd ann
to 2450 psi w/diesel. Tst ins to 7300 psi; OK. Pmp'd 45
bbls 5% U66 Musol, followed by 75 bbls cln diesel on
12/20/85.
Stage 1: 48 bbls gelled diesel pad @ 5 BPM & 2600 psi.
Stage 2: 18 bbls gelled diesel w/1 ppg, 100 mesh @ 20
BPM & 4150/3470 psi.
Stage 3: 73 bbls gelled diesel spacer @ 19 BPM,
3850/3550 psi. Loosing suction when switching to
spacer @ start of Stage 3 (thick gel). Regained
full suction & finish job; OK.
Stage 4: 25 bbls gelled diesel w/3 ppg, 20/40 mesh sand
@ 17.5/20 BPM & 4200 psi.
Stage 5: 44 bbls gelled diesel w/8 ppg, 20/40 mesh sand
@ 17.5 BPM & 4300 psi.
Stage 6: 68 bbls gelled diesel flush @ 14/9.0 BPM &
4650/3850 psi. Screened out w/7 bbls short of Stage
6 on gelled diesel flush w/5500 psi, final press of
3500 psi.
Pmp'd 800# 100 mesh w/1 ppg, 2000# 20/40 sand w/3 ppg, &
10,756# 20/40 sand w/8 ppg in formation leaving approx
2200# 20/40, 8 ppg sand in well. (PBTD @ 8554')
Load to recover 348 bbls of diesel.
Job complete @ 2255 hrs, 12/28/85.
RECp v ..r)
APR 0
Alaska 0ii & Ga,s
Anchorage
Drilling dSuperintendent
STATE OF ALASKA "-- (~
ALASKA L~iL AND GAS CONSERVATION CO,v, MISSION
"WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
REV I SED
OIL E~x GAS [] SUSPENDED [] ABANDONED [] SERVICE []
2. Name of Operator 7. Permit Number
ARCO Alaska, Inc. 85-225
3. Address 8. APl Number
P. 0. Box 100360, Anchorage, AK 99510 50- 029-21446
4. Location of well at surface 9. Unit or Lease Name
89' FNL, 162' FWL, Sec.29, T12N, R9E, UM Kuparuk River Unit
At Top Producing Interval 10. Well Number
1425' FSL, 1528' FEL, Sec.29, T12N, R9E, UM 3F-1
At Total Depth 11. Field and Pool
1078' FSL, 1190' FEL, Sec.29, T12N, R9E, UM Kuparuk River Field
5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool
93' RKBI ADL 25643 ALK 2574
12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. I 15. Water Depth, if offshore 116. No. of Completions
09/19/85 09/23/85 09/25/85*I N/A feet MS LI 1
17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost
87:~0'MD,6243'TVD 8555 'MD ,6123 'TVD YES [~X NO []I 1801 feet MD 1500~ (approx)
22. Type Electric or Other Logs Run
D IL/GR/SP/SFL, FDC/CNL, Cal, CET, GCT
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
16" 62.5# H-40 Surf 115' 24" Conductor installation 'eport not yet receive
9-5/8" 36.0# J-55 Surf 3971' 12-1/4" 1020 sx PF "E" & 400 sx PF "C"
Top job performed w/50 ;x PF "C"
7" 26.0# J-55 Surf 8646' 8-1/2" 325 Sx Class G & 250 sx PF "C"
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)
8526' - 8478' 3-1/2" 8294' 7964' & 8271 '
8468' - 8428' w/4 spf, 90° phasing
842:~' - 8417' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED
8219' - 8066' w/12 spf, 120° phasing N/A
27. N/A PRODUCTION TEST
Date First Production i Method of Operation (Flowing, gas lift, etc.)
I
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO
ITEST PERIOD I~
I
Flow Tubing !Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r)
Press. 24-HOUR RATE "~
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
None
Form 101407 ~ff NOTE: Tubing was run and the well perforated 11/29/85. DAM/WC56 Submit in duplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE ~ p//
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 Kuparuk C 8062' 578:3' N/A
Base Kuparuk C 8220'' 5892'
Top Kuparuk A 8401 ' 6017'
Base Kuparuk A ' 8594, 6150' -.
.
.
...
31. LIST OF ATTACHMENTS
None
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed ~1~ ~~ ~/'~('z~ i" Associate Engi neet ~.~_~
Title Date __
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and log on
all types of lands and leases in Alaska.
Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt
water disposal, water supply for injection, observation, injection for in-situ combustion.
Item 5' Indicate which elevation is used as reference (where not otherwise shown)' for depth measurements
given in other spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple
completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported
in item 27. Submit a separate form for each additional interval to be separately produced, showing the
data pertinent to such interval.
Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cement-
ing and the location of the cementing tool.
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28' If no cores taken, indicate "none".
Form 10-407
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
February 11, 1986
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT' 3F-1
Dear Mr. Chatterton-
Enclosed is a copy of the 3F-1 Well History (completion details) to
include with the Well Completion Report, dated 12/11/85. If you
have any questions, please call me at 263-4944.
Sincerely,
· Gruber
Associate Engineer
JG/tw
GRU13/L92
Enclosure
cc' 3F-1 Well File
RECEIVED
Alaska Oil & Gas Cons. Oommissior~
Anchorage
ARCO Alaska, Inc. is a, Subsidiary of AtlanticRichfieldCompany
ARCO Oil and Gas Company
Daily Well History-Final Report
Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold.
"Final Report, should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not
required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire
operation if space is available.
District JCounty or Parish
I
Alaska
Field ~Lease or Unit
I
Kuparuk River
Auth. or W.O. no. ~Title
I
AFE AK0391
Nordic 1
Operator A.R.Co. W.I.
ARCO
Alaska, Inc.
Date
Spudded or W.O. begun
Complete
Date and depth
as of 8:00 a.m.
Old TD
11/27/85
11/28/85
thru
11/30/85
Complete record for each day reported
Released rig
North Slope Borough
ADL 25643
Completion
Accounting cost center code
State
Alaska
IWell no.
3F-1
API 50-029-21446
rrotal number of wells (active or inactive) on this
i
Icost center prior to plugging and I
56,24% labandonment of this well
I
IHour J Prior efetus if a W.O,
11/26/85 | 0700 hrs.
7" @ 8644'
9.9 NaCl/NaBr
~ccept yig @ 0700 hfs, 11/26/85. ND tree, NU & tst BOPE to
3000 psi. PU 3½" DP, RIH, drl FC & cmt to 8595', CBU, POH, LD
DP.
7" @ 8644'
8560' PBTD, RR
7.2 ppg Diesel
PeR, LD DP. RU WL, take fluid sample @ 8200'. Perf w/4", 4
SPF, 90° phasing f/8498'-8526', 8428'-8468' & 8417'-8423'.
Perf w/5" gun, 12 SPF, 120° phasing f/8066'-8219'. RD WL. RIH
w/6.125" GR/JB, rec'd wiper plug rubber. RIH w/5.90" GR/JB.
RIH w/WL, set pkr @ 8271'. RIH w/3½" tbg w/SSSV @ 1801', retry
pkr @ 7964', Perm pkr @ 8271', "D" Nipple @ 8286'. Rn total of
256 its, 3½", 9.3~ RUE 8RD J-55 IPC tbg & ind. Displ well, set
pkr, shear PBR, tst SSSV, shear out. Set BPV. ND BOPE, NU &
tst tree. Displ well to cln diesel. RR @ 0900 hfs, 11/29/85.
I N ew TD
Date
0900 hrs. 11/29/85
Classifications (oil, gas, etc.)
Oil
A!aska Oil & Gas Cur~s. Commissirm
I PB Depth Anohoraoo
8560 ' PBTD
I Kind of rig
Rotary
Type completion (single, dual, etc.)
Single
Producing method Official reservoir name(s)
Flowing Kuparuk Sands
Potential test data
Well no. Date Reservoir Producing Interval Oil or gas Test time Production
,
Oil on test Gas per day
Pump size, SPM X length Choke size T.P. C.P. Water % G'OR Gravity Aliowsble Effective dale
corrected
The above is correct
Sign atu r e~?~f ~,~¢1~,) IDate ITM
For form preparation and d~stribution,
see Procedures Manual, Section 10,
Drilling, Pages 86 and 87.
Drilling Superintendent
ARCO Alaska, Inc. "--'
Post Office Bo^ ~00360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
December 13, 1985
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT' 3F-1
Dear Mr. Chatterton:
Enclosed are the Well Completion Report and gyroscopic survey for
3F-1. I have not received the Well History (completion details).
When I do, I will forward a copy to you.
If you have any questions, please call me at 263-4944.
Sincerely,
d. Gruber
Associate Engineer
JG/tw
GRU12/L121
Enclosures
RECEIVED
2 0 1985
Alasr, ....., .... ~ i,',;i,:~, uu,iifllJssJofl
ARCO Alaska, Inc. is a Subsidiary of AtlanticRich{ieldCompany
STATE OF ALASKA ....
ALASKA C-- AND GAS CONSERVATION CO; IlSSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
OIL I-~x GAS [] SUSPENDED [] ABANDONED [] SERVICE []
2. Name of OperatOr 7. Permit Number
ARCO Alaska, Inc. 85-225
3. Address 8. APl Number
P. 0. Box 100360, Anchorage, AK 99510 50- 029-21446
4. Location of well at surface 9. Unit or Lease Name
89' FNL, 162' FWL, Sec.29, T12N, RgE, UM .LOCATIONSI Kuparuk River Unit
VEI~IFIED
At Top Producing Interval~ 10. Well Number
1425' FSL, 1528' FEL, Sec.29, T12N, RgE, UM Surf. J~ ' 3F-1
At Total Depth 11. Field and Pool
1078' FSL, 1190' FEL, Sec.29, T12N, RgE, UM Kuparuk River Field
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i ] Pool
93' RKB ADL 25643 ALK 2574
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions
09/19/85 09/23/85 09/25/85* N/A feet MSL N/A
17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21.Thickness of Permafrost
8730'MD,6243'TVD 8555'MD,6123'TVD YES [~)( NO [] 1801 feet MD 1500' (approx)
22. Type Electric or Other Logs Run
DIL/GR/SP/SFL, FDC/CNL, Cal, CET, (:;CT
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
16" 62.5# H-40 Surf 115' ' 24" Conductor installation report not yet receive~
9-5/8" 36.0# J-55 Surf 3971' 12-1/4" 1020 sx PF "E" & 400 sx PF "C"
Top .iob performed w/50 .,x PF "C"
7" 26.0# J-55 Surf 8646' 8-1/2" 325 sx Class G & 250 sx PF "C"
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)
8526' - 8478' 3-1/2" 8294' 7964' & 8271'
8468' - 8428' w/4 spf, 90' phasing
8423' - 8417' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL '(MD) AMOUNT& KIND OF MATERIAL USED
8219' - 8066' w/12 spf, 120° phasing N/A
27. N/A PRODUCTION TEST
Date First Production I Method of Operation (Flowing, gas lift, etc.)
I
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIo
TEST PERIOD II~
Flow Tubing Casing Pressure CALCULATED=~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. 24-HOUR RATE
Brief description of lithology, porosity, fractures, apparent dips and presence OfNone oil, gas or water. Submit core chips. ._,r'/ V~'"D
e, (-:;;-,'d~ C,t?,,,~6. C'OA'/ilTJSSJo~
Form 10-407 * NOTE: Tubing was run and the well perforated 11/29/85. TEMP3/WC06 Submit induplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
29. li-- ''~' ~..:~. ~!? ~-?(~EoLo'(~"IO'M:ARI~ER'S; i!::[-i.:::~'':: ~; ,l' [.'] ~' :~.i:. ::.~' ;'.,'i-: '.'..[ '"':.: t:.'Fb~'~AT'iON'TES~s .... " "'
I
·
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Top Kuparuk C 8062' 5783' N/A
Base Kuparuk C 8220, 5892'
Top Kuparuk A 8401' 6017'
Base Kuparuk A 8594' 6150'
.
.
31. I'IST OF ATTACHMENTS
Gyroscopic Survey (2 copies)
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed (~~ ~C~'L~'/ Tide Associate Engineer Date
//
INSTRUCTIONS
General' This form is designed for submitting a complete and correct well completion report and log on
ail 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".
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
November 19, 1985
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT' 3F-1
Dear Mr. Chatterton'
Enclosed is a copy of the 3F-1 Well History to include with the
Well Completion Report, dated 10/16/85. If you have any questions,
please call me at 263-4944.
Sincerely,
J. Gruber
Associate Engineer
OG/tw
GRU12/LgO
Enclosure
cc' 3F-1 Well File
RECEIVED
NO ? 2
Aleska Oil & Gas Cons. CommJssior~
Anchoraoe
ARCO Alaska, Inc. is a Subsidiary o( AtlanticRichfieldCompany
ARCO Oil and Gas Company
Well History - Initial Report - Daily
Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started.
Daily work prior to spudding should be summarized on the form giving inclusive dates only.
District
ICounty. parish or borough
North Slope Borough
Lease or Unit ADL 25643
I?mo Drill
IState
Field
Alaska
Kuparuk River
Alaska
IWell no.
3F-1
Auth. or W.O. no.
AFE AK0391
Doyon 9
API 50-029-21446
I ARCO W.I.
Operator -,.
ARCO Alaska, Inc.
Spudded or W.O. begUnspudded IDate 9/19/85 I"°ur 1515 hrs. IPri°rstatusifaw'O'
56.24%
Date and depth
as of 8:00 a.m.
9/20/85
9/21/85
thru
9/23/85
9/24/85
Complete record for each day reported
16" @ 115'
1386', (1271'), Navi-Drlg
Wt. 9.4, PV 14, YP 22, PH 9.0, WL 15.6, Sol 8
Accept ri~ @ 1030 hrs, 9/19/85. NU diverter sys. Spud well @
1515 hrs, 9/19/85. Navi-Drl & surv 12¼" hole to 1386'.
362', Assumed vertical
483', 2.7°, S37E, 483 TVD, 3 VS 2S, 2E
819' 13.1°, S46E, 815 TVD, 50 VS, 39S, 32E
1182:, 23.6°, S44E, 1160 TVD, 163 VS, 120S, llOE
9-5/8" @ 3971'
6375', (4989'), Navi-Drlg
Wt. 9.4, PV 15, YP 9, PH 9.5, WL 6.4, Sol 8
Navi-Drl, drl & surv 12¼" hole to 3995', short trip, CBU, POH.
RU & rn 94 jts, 9-5/8", 36#, J-55 BTC csg w/FS @ 3971', FC @
3881'. Cmt w/1020 sx PF "E" & 400 sx PF "C". No cmt to surf.
CIP @ 2015 hfs, 9/21/85. Perform top job w/50 sx PF "C". ND
diverter sys. NU & tst BOPE. RIH, tst csg to 1500 psi. DO
FC, cmt, FS + 10' new hole. Conduct formation tst to 12.5 ppg
EMW. Navi-Drl & surv 8½" hole to 6375'.
1308', 26°, S42E, 1274 TVD, 216 VS, 159S, 146E
1808', 39°, S47E, 1700
2220', 49°, S46E, 1994
2814', 52°, S46E, 2364
3256', 52°, S45E, 2633
3944', 53°, S44E, 3052
4133', 52°, S46E, 3168
'5D73', 50°, S45E, 3782
6174', 48°, S46E, 4502
TVD, 476 VS, 336S, 337E
TVD, 763 VS, 537S, 542E
TVD, 1228 VS, 859S, 878E
TVD, 1578 VS, 1107S, 1126E
TVD, 2124 VS, 1499S, 1505E
TVD, 2273 VS, 1606S, 1610E
TVD, 2985 VS, 2108S, 2113E
TVD, 3817 VS, 2695S, 2704E
9-5/8" @ 3971'
8730', (2355'), Short trip
Wt. 9.9+, PV 14, YP 9, PH 9.4, WL 5.6, Sol 11
Navi-Drl & surv 8½" hole f/6375'-8730', short trip to 3971'.
6491', 47°, S45E, 4716 TVD, 4051VS, 2860S, 2870E
7121', 46°, S45E, 5147 TVD, 4511VS, 3189S, 3190E
7877', 46°, S46E, 5670 TVD, 5057 VS, 3579S, 3573E
8255', 46°, S47E, 5932 TVD, 5329 VS, 3767S, 3770E
8670', 46°, S46E, 6218 TVD, 5630 VS, 39755, 3987E
k/C[IVED
~.laska Oil & Gas Cor~s. Commissior~
Anchoraqe
The above is correct
Date
ITitle
Drilling Superintendent
ARCO Oil and Gas Company
Daily Well History-Final Report
Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold.
"Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not
required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire
operation if space is available.
I Accounting
District ICounty or Parish I State
Alaska North Slope Borough
Field lLease or Unit
Kuparuk River I ADL 25643
Auth. or W.O. no. ~Title
, AFE AK0391 I Drill
Doyen 9 API 50-029-21446
Operator W.I.
ARCO Alaska, Inc. 56.24%
cost center code
Alaska
JWell no,
3F-1
Spudded or W.O, begun
IA.R.Co.
Date
Spudded
Date and depth
as of 8:00 a.m.
9/25/85
9/26/85
10/03/85
Complete record for each day reported
Old TD
Released rig
2400 hrs.
Classifications (oil. gas, etc.)
Oil
Producing method
Flowing
Potential test data
9/19/85
Iotal number of wells (active or inactive) on this,
ost center prior to plugging and
I
bandonment of this well
our J Prior status if a W.O.
I
1515 hrs.
9-5/8" @ 3971'
8730', (0'), POH, LD DP
Wt. 9.9+, PV 12, YP 6, PH 9.5, WL 5.2, Sol 10
Fin short trip to 3971', POH, LD BHA. RU & rn DIL/GR/SP/SFL
f/8702'-3966', FDC/CNL f/8702'-7850' & 5800'-5300', CAL
f/8702'-5150', RD loggers. PU BHA, RIH, C&C, POH, LD DP & prep
to rn 7" csg.
7" @ 8646'
8555' PBTD, RR
9.9 ppg NaC1
Fin POOH, LD DP. RU & rn 205 jts, 7", 26#, J-55 BTC csg w/FS @
8646', FC @ 8555'. Cmt w/325 sx C1 "G". CIP @ 1905 hrs,
9/25/85. ND BOPE, set slips & pack-offs. NU & tst tree. RR @
2400 hrs, 9/25/85.
Arctic packed well w/250 sx PF "C".
INew TO J
8730' TD PBDepth 8555t PBTD
Date Kind of r g
9/25/85 Rotary
Type completion (single, dual, etc.)
Single
Official rese~oir name(s)
Kuparuk Sands
Well no. Date R ..... ,, Producing Interval Oil or gas Test ,,n~ j~~P~'or~ct~ol~ / E r~
L
~Oil.~a t~stV L ~Gas per day
Pump size, SPM X length Choke size T.P. C.P. Water % GOR ;Gravity ~AIIowabl~ ~'~'~'v Effective date
corrected ~
~~chor~ge
r'he above is correct
Signature I Date I Title
~-J_~ ~-z~.t.*~_} 1/~/~.~' Drilling Superintendent
For form preparation and dFstribution,
see Procedures Manual, Section 10,
Drilling, Pages 86 and 87.
RETURN TO:
ARCO Alaska, Inc
Post Office'Dox 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
..
· .
~i'I'~::- ~'7 ~-"~?~-~-~ "~' 'i-: DATE: 10-31-85
.... ,~:~:~: .... TRANSMITTA~ NO: 5422
KUPARUK.-OPE~TIONS ENGINEERING
~CO~S CLE~
ATO-1115B
P.O. BOX 100360
A~hO~GE, ~ 99510
TRANSMITTED HER~54ITH AR~ THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE
RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSMITTAL.
FINAL PRINTS/SCHL
OPEN HOLE
3F-1 ~"'5"
3A-3 ""~5"
7-,2
~ x2
/ ~2
(ONE * OF EACH)
DIL/SFL-GR 09-24-85 RUN %1 3966-8634
DIL/SFL-GR 09--24-85 RUN %1 3966-8634
DEN/NEU PORO 09-24-85 RUN #1 7850-8609
DEN/NEU PORO 09-24-85 RUN ~1 7850-8609
DEN/NEU ~U%W 09-2 ~-85 RUN %1 7~50-8609
DEN/NEU kAW 09-24-85 aUN ~1 7850-8609
CYBEkLOOK 09-24-85 RUN %1 7850-8500
DIL~ SFL-GR 09-14-85 RUN %1 3890-8268
DIL/SFL-GR 09-14-85 RUN #1 3890-~268
DEN/NEU PORO 09-14-85 RUN ~1 3890-8242
DEN/NEU PORO 09-14-85 1{UN ~1 3890-~242
DEN/Nk'U R~2~{ 09-14-85 RUN #1 3890-8242
DEN/NEU RAW 09-14-85 RUN %1 3890-~242
CYBERLOOK 09-14-85 RUN ~1 7550-8219
BHC SONIC-GR 09-15-85 RUN #1 3890-8270
BHC SONIC-GR 09-15-85 RUN %1 3890-8270
1R-4 ~%5"
% 2"
-\ ~5"
~2"
~5"
'2"
DIL/SFL-GR 09-17-85 RUN %1 4297-~336
DIL/SFL-GR 09-17-85 RUN #1 4297-8336
DEN/NEU PORO 09-17-85 ~UN %1 4297-8310
DEN/NEU PORO 09-17-85 RUN %1 4297-8310
DEN/NEU R3~W 09-17-85 RUN %1 4297-8310
DEN/NEU RAW 09-17-85 RUN %1 4297-8310
CYBERLOOK 09-17-85 RUN %1 7600-8287
KECEIPT ACKNOWLEDGED:
~PAE
B. CURRIER
CHEVRON
D & M*BL
DISTRIBUTION:
DRILLING*EL ~. PASHER
L. JOHNSTON EXXON
MOBIL PHILLIPS OIL
NSK CLEF, K'EL J. RAT~4ELL*BL
~TATE OF ALA~K~*~
~OHIO /bE
UNION
VAULT/ ~ O* F I LMS
ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompan¥
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
October 23, 1985
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT' 3F-1
Dear Mr. Chatterton'
Enclosed is the Well Completion Report for 3F-1. I have not yet
received the Well History. When I do, I will forward a copy to
you. Also, the bottomhole location, TVDs, geologic markers, and
tubing details will be submitted when the gyroscopic survey is run
and the well completed.
If you have any questions, please call me at 263-4944.
Sincerely,
d. Gruber
Associate Engineer
JG/tw
GRU12/L32
Enclosure
RECEIVED
Alaska Oil & Gas Cons. Commission,
f-~nchora.ge,
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
,., r-.~ STATE OF ALASKA
ALASKA L .,AND GAS CONSERVATION CO AlSSlON
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status Of Well Classification of Service Well
OIL [] GAS [] SUSPENDED ~ ABANDONED [] SERVICE []
2. Name of Operator 7. Permit Number
ARCO Alaska, Inc. 85-225
3. Address 8. APl Number
P. 0. Box 100360, Anchorage, AK 99510 50- 029-21446
4. Location of well at surface 9. Unit or Lease Name
89' FNL, 162' FWL, 5ec.29, T12N, RgE, UM (Approx.) Kuparuk River Unit
At Top Producing Interval 10. Well Number
To be submitted when gyro is run. 3F-1
At Total Depth 11. Field and P°ol
To be submitted when gyro is run. Kuparuk River Field
5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk Ri ver 0i 1 Pool
93' RKBI ADL 25643 ALK 2574
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions
09/19/85 09/23/85 09/25/85I N/A feet MSLI N/A
17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost
8730'MD 8555'MD YES [] NO I~X N/A feet MDI 1500' (Approx)
22. Type Electric or Other Logs Run
DI L/GR/SP/SFL, FDC/CNL, Cal
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
16" 62.5# H-40 Surf 115' 24" Conductor Installation Rpt not received yet,
9-5/8" 36.0# J-55 Surf 3971' 12-1/4" 1020 sx PF "E" & 400 s~ PF "C"
Top job performed w/50 sx PF "C"
7" 26.0# J-55 Surf 8646' 8-1/2" 325 sx Class G
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)
None N/A
26. ACID, FRACTURE, CEMENT SOUEEZE, 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 OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO
TEST PERIOD J~
Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. 24-HOUR RATE ~
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
NONE
,a. iaska ¢Jil & Gas Oar, s. Corumissior~
·
Form 10-407 TEMP2/WC47 Submit in duplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
- _ ,,: _ . ~ .~ .~.~: .... , · ,. ,
":" ": :'~:' :G~oi:':o~:ic I~AF~I~ER'~' ":" "- ' :~ "' "" '~"' ' ' '-'FORMATION TE'SSS '. - ' "·
.
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
.
:
N/A N/A
31. LIST OF ATTACHMENTS
NONE
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed ~~ ~~. Title Associa,e E.g~.ee. Date /O'/~-~
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 I
SUB. SURFACE
DIRECTIONAL
~URVEY
[~UIDANCE
~ONTINUOUS
[~OOL-
Company
Well Name
Field/Location
Jot~ Reference No_.
70963
I.o,qaed
LESNIE
RECEIVED
~" .... t98b
Anchor~,9~
Computed I~.
BOLAM
GCT DIRECTIONAL SURVEY
CUSTOMER LISTING
FOR
ARCO ALASKA, INC.
3F-1
KUPARUK
NORTH SLOPE,ALASKA
SURVEY DATE: 18 OCT ~5
ENGINEER: LESNIE
METHODS OF COMPUTATION
TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH
INTERPOLATION: LINEAR
VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 44 DEG 27 MIN EAST
COMPUTATION DATE: 15-NOV-B5 PAGE
ARCO ALASKA, INC.
3F-1
KUPARUK
NORTH SLOPE,ALASKA
DATE OF SURVEY: 18 OCT 85
KELLY BUSHING ELEVATION:
ENGINEER: LESNIE
93. OD
INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH
TRUE SUB-SEA COURSE
MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH
DEPTH DEPTH DEPTH DEG MIN DEG MIN
0.00 0o00 -93.00 0 0 N 0 0 E
100.00 100.00 7.00 0 6 N 63 46 W
200.00 200.00 107.00 0 17 N 45 29 W
300.00 300.00 207.00 '0 16 N 29 26 W
400.00 400.00 307.00 0 10 S 52 15 W
500.00 499.95 406.95 3 21 S 35 1 E
600.00 599.50 506.50 6 52 S 38 18 E
700.00 698.43 605.43 10 8 S 39 42 E
800.00 796.38 703.38 12 34 S 43 0 E
900.00 893.50 800.50 15 19 S 44 3,3 E
1000.00 989.14 896.14 18 23
1100.00 1083.21 990.21 21 17
1200.00 1175.42 1082.42 24 8
1300.00 1265.95 1172.95 25 57
1400.00 1355.25 1262.25 27 27
1500.00 1443.22 1350.22 29 25
1600,00 1529.10 1436.10 32 10
1700.00 1612.24 1519.24 35 31
1800.00 1691.78 1598.78 39 3
1900.00 1767.54 1674.54 42 7
S 44 20 E
S 43 6 E
S 41 26 E
S 41 13 E
S 43 40 E
S 46 21 E
S 47 2 E
S 47 22 E
S 45 45 E
S 43 40 E
2000.00 1840.40 1747.40 44 15
2100.00 1910.63 1817.63 46 29
2200.00 1977.68 1884.68 49 18
2300.00 2041.59 1948.59 50 51
2400.00 2104.38 2011.38 51 16
S 44 16 E
S 44 45 E
S 43 48 E
S 45 24 E
S 45 31 E
VERTICAL DOGLEG RECTANGULAR COORDINATES HDRIZ. DEPARTURE
SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH
FEET DEG/IO0 FEET FEET FEET DEG MIN
0.00 0.00 0.00 N 0.00 E
-0.03 0.38 0.08 N 0.04 E
-0.39 0.15 0.30 N 0.26 W
-0.94 0.02 0.74 N 0.58 W
-1.18 1.35 0.90 N 0.76 W
1.19 4.97 1.28 S 0.39 E
10.44 2,23 8.64 S 6.10 E
24.90 4.15 19.92 S 15.25 E
44.93 1.35 34.90 S 28.58 E
68.74 3.38 52.05 S 45,09 E
0.00 N 0 0 E ,
0.09 N 28 50 E
0.39 N 40 42 W
0.94 N 38 24 W
1.18 N 40 16 \
1.34 S 16 59
10.57 S 35 13 :
25.08 S 37 25 E
45.11 S 39 18 E
68.87 S 40 54 E
97.87 2.88
131.76 3.02
170.40 2.33
212.79 1.57
257.75 2.73
305.27 2.57
356.45 2.85
411.90 3.68
472.44 3.66
537.67 2.58
72.78 S 65.56 E 97.95 S 42 0 E
97.32 S 88.95 E 131.84, S 42 25 E
125.92 S 114.97 E 170.51 S 42 23 E
157.92 S 142.88 E 212.97 S 42 8 E
191.31 S 173.04 E 257.96 S 42 7 E
224.65 S 206.92 E 305.42 S 42 38 E
259.78 S 244.19 E 356.53 S 43 13 E
297.38 S 285.05 E 411.93 S 43 47 E
338.92 S 329.14 E 472.44 S 44 9 E
385.37 S 374.95 E 537.68 S 44 12 E
606.15 2.78
677.33 2.86
751.50 2.69
828.40 1.06
906.21 0.45
434.88 S 422.26 E 606.16 S 44 9 E
485.28 S 472.53 E 677.33 S 44 14 E
538.67 S 524.01 E 751.50 S 44 12 E
593.50 S 577.93 E 828.40 S 44 14 E
647,97 S 633,52 E 906.21 S 44 21 -
2500.00 ' 2166.72 2073.72 51 36
2600.00 2228.60 2135.60 52 0
2700.00 2289.79 2196.79 52 29
2800.00 2350.50 2257.50 52 34
2900.00 2411.30 2318.30 52 37
3000.00 2471.88 2378.88 52 47
3100.00 2532.25 2439.25 52 51
3200.00 2592.67 2499.67 52 42
3300.00 2653.54 2560.54 52 25
3400.00 2714.51 2621.51 52 32
3500.00 2775.26 2682.26 52 39
3600.00 2835.90 2742.90 52 39
3700.00 2896.51 2803.51 52 44
3800.00 2957.22 2864.22 52 33
3900.00 3017.95 2924.95 52 38
S 45 13 E 984.39
S 44 33 E 1062.95
S 44 19 E 1142.03
S 44 18 E 1221.50
S 44 35 E 1300.89
S 44 31 E 1380.46
S 44 23 E 1460.17
S 44 13 E 1539.86
S 44 3 E 1619.20
S 44 8 E 1698.46
S 44 5 E 1777.89
S 43 59 E 1857.41
S 43 45 E 1936.94
S 43 31 E 2016.40
S 43 13 E 2095.82
0.45
0.77
0.41
0.39
0.36
0.15
0.23
0.78
0.36
0.32
0.18
0.34
0.10
0.29
0.35
702.93 S 689.14 E 984.39 S 44 25 ,)
758.58 S 744.59 E 1062.95 S 44 28 :
815.09 S 799.92 E 1142.03 S 44 27 E
871.97 S 855.41 E 1221.50 S 44 27 E
928.60 S 911.06 E 1300.89 S 44 27 E
985.29 S 966.88 E 1380.46 S 44 27 E
1042.18 S 1022.72 E 1460.17 S 44 27 E
1099.18 S 1078.41 E 1539.86 S 44 27 5
1156.20 S 1133.58 E 1619.20 S 44 26 E
1213.08 S 1188.78 E 1698.46 S 44 25 E
1270.08 S 1244.10 E 1777.89 S 44 24 E
1327.24 S 1299.38 E 1857.41 S 44 23 E
1384.59 S 1354.50 E 1936.95 S 44 22 E
1442.08 S .1409.36 E 2016.40 S 44 20 E
1499.82 S 1463.92 E 2095.83 S 44 18 E
COMPUTATION DATE: 15-NOV-85 PAGE
aRCO ALASKAt INC.
DATE OF SURVEY: 18 OCT 85
3F-1
KUPARUK
NORTH SLOPEtALASKA
KELLY BUSHING ELEVATION:
ENGINEER: LESNIE
93. O0 F'T
INTERPOLATED VALUES FOR EVEN 100 FEET DF MEASURED DEPTH
TRUE SUB-SEA COURSE
MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH
DEPTH DEPTH DEPTH DEG MIN DEG MIN
VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE
SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH
FEET DEG/IO0 FEET FEET FEET DEG MIN
4000.00 3078.72 2985.72 52 33
4100.00 3139.35 3046.35 52 27
4200.00 3201.01 3108.01 51 12
4300.00 3265.11 3172.11 49 38
4400,00 3329.50 3236.50 50 10
4500.00 3393.31 3300.31 50 14
4600.00 3458.71 3365.71 48 22
4700.00 3525.16 3432.16 48 30
4800.00 3591.07 3498.07 49 3
4900,00 3656,22 3563,22 49 38
S 43 27 E 2175.23
S 43 51 E 2254.75
S 44 10 E 2333.46
S 44 7 E 2410.21
S 44 5 E 2486.71
S 44 12 E 2563.71
S 43 42 E 2639.34
S 43 50 E 2714.06
S 43 34 E 2789,27
S 43 31 E 2865,12
0.76
1.16
2.14
0.47
0.40
1.46
0.54
0.42
0.63
0.70
1557,70 S 1518.30 E 2175,24 S 44 15 E
1615.24 S 1573,19 E 2254,76 S 44 14 E
1671,80 S 1627,95 E 2333,48 S 44 14 E
1726,84 S 1681.43 E 2410,22 S 44 14 E
1781.80 S 1734.66 E 2486.73 S 44 13 ~'
1836.99 S 1788,35 E 2563.73 S 44 13 )
1891.53 S 1840.75 E 2639.36 S 44 13 ~
1945.44 S 1892.49 E 2714.09 S 44 12 E
1999.83 S 1944.44 E 2789,30 S 44 11 E
2054.81 S 1996.71 E 2865.15 S 44 10 E
5000.00 3720.72 3627.72 49 51
5100.00 3785.13 3692.13 50 0
5200.00 3849.37 3756.37 50 2
5300.00 3913.38 3820.38 50 17
5400.00 3977.32 3884.32 50 11
5500,00 4041,62 3948,62 49 29
5600.00 4107.11 4014.11 48 39
5700.00 4173.30 4080.30 48 35
5800.00 4239.34 4146.34 48 44
5900.00 4305.13 4212.13 48 47
S 43 40 E 2941.53
S 43 48 E 3018.02
S 43 45 E 3094.65
S 43 30 E 3171.46
S 43 30 E 3248.35
S 43 5 E 3324,92
$ 42 21 E 3400,45
S 42 50 E 3475.37
S 42 57 E 3550.43
S 43 0 E 3525,72
0.30
0.29
0.39
0.06
0.19
1.87
0.52
0.56
0.45
0.31
2110,19 S 2049.37 E 2941.57 S 44 9 E
2165,45 S 2102.26 E 3018,06 S 44 9 E
2220.71 S 2155.36 E 3094.69 S 44 8 E
2276.35 S 2208.33 E 3171.51 S 44 7 E
2332.12 S 2261.27 E 3248.41 S 44 6 E
2387.70 S 2313.96 E 3324.98 S 44 6 E
2443,34 S 2365,10 E 3400,52 S 44 4 E
2498.57 S 2415.78 E 3475,46 S 44 2 E
2553.54 S 2466,92 E 3550,54 S 44 0 E
2608,64 S 2518,27 E 3625,84 S 43 59 E
6000.00 4371.16 4278.16 48 33
6100.00 4437.56 4344.56 48 14
6200.00 4504.33 4411.33 48 1
6300.00 4571.44 4478.44 47 37
6400.00 4638.97 4545.97 47 28
6500.00 4706.70 4613.70 47 10
6600.00 4774.91 4681.91 46 53
6700.00 4843.25 4750.25 46 54
6800.00 4911.57 4818.57 46 59
6900.00 4979.78 4886.78 46 49
S 42 57 E 3700.80
S 43 7 E 3775.54
S 43 4 E 3849.96
S 42 56 E 3924.08
S 42 57 E 3997,81
S 42 38 E 4071.35
S 42 29 E 4144.43
S 42 25 E 4217.39
S 42 31 E 4290.38
S 42 26 E 4363.46
0.42
0.22
0.06
0.39
0.19
0.52
0.20
0.31
0.22
0.36
2663.58 S 2569.48 E 3700.93 S 43 58 E
2718.24 S 2620.49 E 3775.69 S 43 57 E
2772,59 S 2671.36 E 3850,12 S 43 56 E
2826.78 S 2721,95 E 3924.25 S 43 55 E
2880.78 S 2772.19 E 3997.99 S 43 53 '
S 2822,21 E 4071.55 S 43 52 .)
2934.73
2988.60 S 2871.67 E 4144.66 S 43 51 =
3042,48 S 2920,92 E 4217.64 S 43 49 E
3096.34 S 2970.24 E 4290.64 S 43 48 E
3150.25 S 3019.65 E 4363.76 S 43 47 E
7000.00 5048.44 4955.44 46 24
7100,00 5117.38 5024.38 46 27
7200.00 5186.34 5093.34 46 22
7300.00 5255.25 5162.25 46 30
7400.00 5323.97 5230.97 46 34
7500.00 5392.82 5299.82 46 22
7600.00 5461.88 5368.88 46 20
7700.00 5530.96 5437.96 46 10
7800.00 5600.43 5507.43 45 53
7900.00 5669.87 5576.87 46 3
S 42 23 E 4436.10
S 42 15 E 4508.50
S 42 4 E 4580.87
S 42 11 E 4653.2.7
S 42 15 E 4725.87
S 42 24 E 4798.34
S 42 45 E 4870,62
S 43 11 E 4942.89
S 43 36 E 5014.82
S 43 53 E 5086.78
0.41
0.16
0.34
0.53
0.21
0.30
0.28
0.49
0.46
0.09
3203.95 S 3068.64 E 4436.42 S 43 45 E
3257.51 S 3117.43 E 4508.85 S 43 44 E
3311.19 S 3166.04 E 4581.24 S 43 42 E
3364.93 S 3214.64 E 4653.67 S 43 41 E
3418,74 S 3263.47 E 4726,31 S 43 40 E
3472.35 S 3312,30 E 4798,81 S 43 38 E
3525.61 S 3361.22 E 4871.11 S 43 37 E
3578.53 S 3410.49 E 4943.41 S 43 37 E
3630.79 S 3459.92 E 5015.35 S 43 37 E
3682.75 S 3509.71 E 5087.31 S 43 37 E
COMPUTATION DATE: 15-NOV-85 PAGE 3
ARCO ALASKA, INC.
3F-1
KUPARUK
NORTH SLOPE~ALASKA
DATE OF SURVEY: 18 OCT 85
KELLY BUSHING ELEVATION:
ENGINEER: LESNIE
93.oo AT
INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH
TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE
MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH
DEPTH DEPTH DEPTH DEG MIN, DEG MIN
FEET DEG/IO0 FEET FEET FEET DEG MIN
8000.00 5739.45 5646.45 45 39
8100.00 5809.32 5716.32 45 54
8200.00 5878.61 5785.61 46 14
8300.00 5947.65 5854.65 46 22
8400,00 6016.52 5923.52 46 35
8500°00 6085.15 5992.15 46 40
8600.00 6153.76 6060.76 46 40
8700.00 6222.38 6129.38 46 40
8730.00 6242,97 6149.97 46 40
S 44 2 E 5158.59
S 44 4 E 5230.13
S 43 57 E 5302.23
S 44 10 E 5374.57
S 44 25 E 5447.08
S 44 26 E 5519.81
S 44 26 E 5592.56
S 44 2~ E 5665.30
S 44 26 E 5687.13
0.39
0.64
0.25
0.26
6.05
0.00
0.00
0.00
0.00
3734.44 S 3559.57 E 5159.13 S 43 37 E
3785.82 S 3609.35 E 5230.67 S 43 37 E
3837.70 S 3659.42 E 5302,76 S 43 38 E
3889.69 S 3709.72 E 5375.10 S 43 38 E
3941.61 S 3760,34 E 5447.61 S 43 39 '\
3993.54 S 3811.26 E 5520.33 S 43 39 .
;
4045.48 S 3862.19 E 5593.07 S 43 40 E
4097.42 S 3913.12 E 5665.81 S 43 40 E
4113.01 S 3928.~0 E 5687.$3 S 43 41 E
COMPUTATION DATE.= 15-NOV-85 PAGE 4
ARCO ALASKAt INC.
DATE OF SURVEY: 18 OCT 85
3F-1
KUPARUK
NORTH SLOPE,/tLASKA
KELLY BUSHING ELEVATION:
ENGINEER: LESNIE
93.00 FT
INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPT
TRUE SUB-SEA COURSE
MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH
DEPTH DEPTH DEPTH DEG MIN OEG MIN
VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE
SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH
FEET DEG/IO0 FEET FEET FEET DEG MIN
0.00 0.00 -93.00 0 0
1000.00 989.14 896.14 18 23
2000.00 1840.40 1747.40 44 15
3000.00 2471.88 2378.88 52 47
4000.00 3078.72 2985.72 52 33
5000.00 3720.72 3627.72 49 51
6000.00 4371.16 4278.16 48 33
7000.00 5048.44 4955.44 46 24
8000.00 5739.45 5646.45 45 39
8730.00 6242.97 6149.97 46 40
N 0 0 E 0.00
S 44 20 E 97.8'7
S 44 16 E 606.15
S 44 31 E 1380.46
S 43 27 E 2175.23
S 43 40 E 2941.53
S 42 57 E 3700.80
S 42 23 'E 4436.10
S 44 2 E 5158,59
S 44 26 E 5687.13
0.00
2.88
2.78
0.15
0,76
0.30
0,42
0,41
0,39
0.00
0.00 N 0.00 E 0.00 N 0 0 E
72.78 S 65.56 E 97.95 S 42 0 E
434.88 S 422.26 E 606.16 S 44 9 E
985.29 S 966.88 E 1380.46 S 44 27 E
1557.70 S 1518.30 E 2175.24 S 44 1,5 ~
2110.19 S 2049.37 E 2941.57 S 44 9 ~
2663.58 S 2569.48 E 3700.93 S 43 58
3203.95 S 3068.64 E 4436.42 S 43 45 ~
3734.44 S 3559.57 E 5159.13 S 43 37 E
4113.01 S 3928.40 E 5687.63 S 43 41 E
COMPUTATION DATE: 15-NOV-85 5
ARCO ALASKA, INC.
3F-1
KUPARUK
NORTH SLOPE,ALASKA
PAGE
DATE OF SURVEY: 18 OCT 85
KELLY BUSHING ELEVATION:
ENGINEER: LESNIE
93.00 F'T
INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH
TRUE SUB-SEA COURSE
MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH
DEPTH DEPTH DEPTH DEG MIN DEG MIN
0.00 0.00 -93.00 O' 0 N 0 0 E
93.00 93.00 0.00 0 5 N 72 19 W
193.00 193.00 100.00 0 17 N 47 20 W
293.00 293.00 200.00 0 1T N 29 12 W
393.00 393.00 300.00 0 7 S 69 54 W
493.04 493.00 400.00 3 0 S 33 58 E
593.46 593,00 500.00 6 43 S 38 10 E
694.49 693.00 600,00 9 55 S 39 35 E
796.54 793.00 700.00 12 31 S 42 56 E
899.48 893.00 800.00 15 18 S 44 33 E
1004.07 993.00 900.00 18 30
1110.51 1093.00 1000.00 21 35
1219.31 1193.00 1100.00 24 32
1330.15 1293.00 1200.00 26 27
1442.68 1393.00 1300.00 28 15
1557.60 1493.00 1400.00 31 0
1676.45 1593.00 1500.00 34 39
1801.59 1693.00 1600.00 39 6
1934.56 1793.00 1700.00 42 56
2074.56 1893.00 1800.00 45 54
VERTICAL DOGLEG RECTANGULAR COORDiNaTES HORIZ. DEPARTURE
SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH
FEET DEG/IO0 FEET FEET FEET DEG MIN
2223.65 1993.00 1900.00 49 51
2381.81 2093.00 2000.00 51 13
2542.38 2193.00 2100.00 51 44
2705.27 2293.00 2200.00 52 30
2869.85 2393.00 2300.00 52 34
3034.94 2493.00 2400.00 52 50
3200.55 2593.00 2500.00 52 42
3364.67 2693.00 2600.00 52 26
3529.26 2793.00 2700.00 52 41
3694.21 2893.00 2800.00 52 44
0.00 0.00 O.DO N 0.00 E
-0.01 0.43 0.07 N 0.05 E
-0.35 0.19 0.27 N 0.23 W
-0.90 ,O.OB 0.71 N 0.57 W
-1.I7 0.59 0.90 N 0.75 W
0,78 5.20 0.95 S 0.16 E
9°67 2.24 8.03 S 5.62 E
23.96 4.02 19.19 S 14.65 E
44.18 1.43 34.36 S 28.0? E
68.60 3.38 51.95 S 45.00 E
3858.91 2993.00 2900.00 52 36
4023.52 3093.00 3000.00 52 40
4187.17 3193.00 3100.00 51 28
4343.14 3293°00 3200,00 49 52
4499.52 3393.00 3300.00 50 15
4651.53 3493.00 3400.00 48 20
4802.94 3593,00 3500.00 49 4
4956.98 3693.00 3600.00 49 52
5112.24 3793.00 3700.00 50 0
5268.09 3893.00 3800.00 50 15
S 44 17 E 99.15
S 42 59 E 135.59
S 41 13 E 178.37
S 41 36 E 226.08
S 45 23 E 277.66
S 46 44 E 334.23
S 47 29 E 398,34
S 45 43 E 473.44
S 43 34 E 561.04
S 45 3 E 658.98
S 44 3 E 769.51
S 45 33 E 892.02
S 44 57 E 1017.64
S 44 19 E 1146.22
S 44 34 E 1276.93
S 44 29 E 1408.29
S 44 13 E 1540.30
S 44 9 E 1670.43
S 44 3 E 1801.16
S 43 45 E 1932.33
S 43 21 E 2063.19
S 43 34 E 2193.91
S 44 9 E 2323.44
S 44 6 E 2443.12
S 44 12 E 2563.35
S 43 50 E 2677.81
S 43 34 E 2791.49
S 43 32 E 2908.64
S 43 50 E 3027.40
S 43 32 E 3146.92
0.00 N 0 0 E
0.09 N 37 7 E
O. 36 N 40 8 W
0.91 N 38 45 W
1.17 N 39 37
0.96 S 9 20
!
9.80 S 34 59 E
24.14 S 37 20 E
44.37 S 39 14 E
68.73 S 40 53 E
2.88
3.06
2.00
1.94
2.57
2.56
3.76
3.67
2.22
2.16
73.70 S 66.46 E 99.24 S 42 2 E
100.11 S 91.57 E 135.67 S 42 26 E
131.92 S 120.23 E 178.49' S 42 ZO E
167.91 S 151.68 E 226.27 S 42 5 E
205.48 S 187.04 E 277.86 S 42 18 E
244.58 S 227.95 E 334.34 S 42 59 E
288.19 S 275.04 E 398.38 S 43 39 E
339.62 S 329.86 E 473.45 S 44 9 E
402.32 S 391.05 E 561.05 S 44 11 E
472.31 S 459.55 E 658.99 S 44 12 E
2.26
0.35
0.76
0.42
0.52
0.26
0.79
0.29
0.16
0.16
551.65 S 536.51 E 769.52 S 44 12 E
638.04 S 623.39 E 892.02 S 44 20 E
726.40 S 712.70 E 1017.64 S 44 27 E
818.09 S 802.84 E 1146.22 S 44 27 E
911.54 S 894.23 E 1276.93 S 44 27
1005.14 S' 986.39 E 1408.29 S 44 27
1099.49 S 1078.72 E 1540.30 S 44 27
1192.97 S 1169.26 E 1670.43 S 44 25 E
1286.80 S 1260.29 E 1801.16 S 44 24 E
1381.26 S 1351.31 E 1932.34 S 44 22 E
0.22
0.52
1.51
0.66
1.43
0.45
0.64
0.22
0.26
0.30
1476.06 S 1441.53 E 2063.19 S 44 19 E
1571.24 S 1531.17 E 2193.92 S 44 15 E
1664.61 S 1620.96 E 2323.45 S 44 14 E
1750.47 S 1704.34 E 2443.13 S 44 14 E
1836.73 S 1788.09 E 2563.36 S 44 13 E
1919.30 S 1867.36 E 2677.83 S 44 12 E
2001.44 S 1945.97 E 2791.52 S 44 11 E
2086.37 S 2026.68 E 2908.67 S 44 10 E
2172.22 S 2108.76 E 3027.44 S 44 9 E
2258.54 S 2191.43 E 3146.97 S 44 8 E
COMPUTATION DATE: 15-NOV-85 PAGE 6
~RCD ALASKA, INC.
DATE OF SURVEY: lB OCT 85
3F-1
KUPARUK
NORTH SLOPE,ALASKA
KELLY BUSHING ELEVATION:
ENGINEER: LESNIE
93.00 F'T
INTERPOLATED VALUES FOR EVEN lO0 FEET OF SUB-SEA DEPTH
TRUE SUB-SEA COURSE
MEASURED VERTICAL VERTICAL DEVIATIDN AZIMUTH
DEPTH DEPTH DEPTH DEG MIN DEG MIN
VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE
SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH
FEET DEG/IO0 FEET FEET FEET OEG MIN
5424-49 3993.00 3900,00 50 B
5578.60 4093.00 4000.00 48 52
5729.82 4193.00 4100.00 48 40
5881.59 4293.00 4200.00 48 51
6032.96 4393.00 4300.00 48 27
6183.05 4493.00 4400.00 48 2
6331.95 4593.00 4500.00 47 32
6479.83 4693.00 4600.00 47 15
6626.47 4793.00 4700.00 46 52
6772,80 4893.00 4800.00 46 55
S 43 31 E 3267.16
S 42 25 E 3384.38
S 42 55 E 3497.74
S 43 0 E 3611.87
S 42 58 E 3725.47
S 43 5 E 3837.37
S 42 55 E 3947.65
S 42 42 E 4056.54
S 42 27 E 4163.74
S 42 30 E 4270.50
0.34
1.27
0.30
0.45
0.19
0.12
0.25
0.52
o.og
0.22
2345.76 S 2274.22 E 3267.22 S 44 6 E
2431.45 S 2354.26 E 3384.45 S 44 4 E
2514.96 S 2431.02 E 3497.84 S 44 1 E
2598.50 S 2508.82 E 3611.98 S 43 59 E
2681.64 S 2586.30 E 3725.61 S 43 57 ~
2763.38 S 2662.76 E 3837.52 S 43 56
2844.05 S 2'738.00 E 3947.82 S 43 54 E
2923.85 S 2812.16 E 4056.74 S 43 53 E
3002.85 S 2884.70 E 4163.97 S 43 51 E
3081.68 S 2956.80 E 4270.77 S 43 48 E
6919.31 4993.00 4900.00 46 45
7064.60 5093.00 5000.00 46 27
7209.65 5193.00 5100.00 46 23
7354.93 5293.00 5200.00 46 35
7500.27 5393.00 5300.00 46 22
7645.09 5493.00 5400.00 46 19
7789.34 5593.00 5500.00 45 54
7933.35 5693.00 5600.00 45 59
8076.58 5793.00 5700.00 45 46
8220.79 5893.00 5800.00 46 17
S 42 23 E 4377.53
S 42 18 E 4482.86
S 42 5 E 4587.84
S 42 12 E 4693.15
S 42 24 E 4798.53
S 42 55 E 4903.24
S 43 33 E 5007.18
S 43 55 E 5110.79
S 44 6 E 5213.33
S 43 59 E 5317.23
0.40
0.45
0,44
0.10
0.30
0.39
0.54
0.46
0.57
0.51
3160.64 S 3029.14 E 4377.82 S 43 46 E
3238.52 S 3100.17 E 4483.19 S 43 44 E
3316.37 S 3170.72 E 4588.22 S 43 42 E
3394.49 S 3241.46 E 4693.57 S 43 40 E
3472.49 S 3312.43 E 4799.00 S 43 38 E
3549.54 S 3383.41 E 4903.74 S 43 37 E
3625.25 S 3454.66 E 5007.71 S 43 37 E
3700.05 S 3526.37 E 5111.33 S 43 37 E
3773.75 S 3597.67 E 5213.87 S 43 37 E
3848.50 S 3669.84 E 5317.77 S 43 38 E
8365.83 5993.00 5900.00 46 32
8511.45 6093.00 6000.00 46. 40
8657.18 6193.00 6100.00 46 40
8730.00 6242.97 6149.97 46 40
S 44 17 E 5422.30
S 44 26 E 5528.14
S 44 26 E 5634.15
S 44 26 E 5687.13
0.18
0.00
0o00
0.00
3923.8B S 3743.0Z E 54ZZ.B3 S 43 38 E
3999.49 S 3817.09 E 5528.66 S 43 39 E
4075.18 S 3891.31 E 5634.67 S 43 40 E
4113,01 S 3928.40 E 5587,63 S 43 41 E
COMPUTATION DATE: IS-NOV-85
ARCO ALASKA~ INC.
KUPARUK
NORTH SLOPE~ALASKA
MARKER
TOP KUPARUK C
BASE KUPARUK C
TOP KUPARUK A
B~SE KUPARUK A
PBTD
TD
PAGE
DATE OF SURVEY: 18 OCT 85
KELLY BUSHING ELEVATION:
ENGINEER: LESNIE
93.00 ~T
INTERPOLATED VA'LUES FOR CHOSEN HORIZONS
MEASURED DEPTH
BELOW KB
8062.00
8220.00
8401.00
8594°00
8555.00
8730.00
SURFACE LOCATION
AT
ORIGIN: 89' FNL, 162' FWL, SEC 29, T1ZN, RgE, UM
TVD
FROM KB
5782.82
5892.45
6017.21
6149.65
6122.89
6242.97
SUB-SEA
5589.82
5799.45
5924.21
6056.65
6029.89
6149.97
RECTANGULAR COORDINATES
NORTH/SOUTH EAST/WEST
3766.26 S
3848.09 S
3942.13 S
4042.37 S
4022.11 S
4113.01 S
3590.39
3669.44
3760.84
3859.14
3839.27
3928.40
ARCO ALASKA, INC.
3F-1
KUPARUK
NORTH SLOPE,ALASKA
MARKER
TOP KupARuK
BASE KUPARUK
TOP KUPARUK
BASE KUPARUK
PBTD
TO
COMPUTATION DATE: 15-NOV-85
PAGE
DATE OF SURVEY: 18 OCT 85
KELLY BUSHING ELEVATION:
ENGINEER: LESNIE
8
93.00 F'T
~~,~~ STRATIGRAPHIC
MEASURED DEPTH
BELOW KB
8062.00
8220.00
8401.00
8594.00
8555.00
8730.00
SUMMARY
SURFACE LOCATION
AT
ORIGIN: 89' FNL~ 162° FWL, SEC 29, T12N, RgE, UM
TVD
FROM KB
5782.82
5892
6017.21
6149.65
6122.89
6242.97
RECTANGULAR COORDINATES
SUB-SEA NORTH/SOUTH EAST/WEST
5689.82 3766.26 S 3590.39 E
5799.45 3848.09 S 3669.44 E
5924.21 39~2.13 S 3760.84 E
6056.65 4042.37 S 3859.14 E
6029.89 4022.11 S 3839,27 E
6149.97 4113,01 S 3928.40 E
FINAL WELL LOCATION AT TO:
TRUE SUB-SEA
MEASURED VERTICAL VERTICAL
DEPTH DEPTH DEPTH
8730.00 6242.97 6149.97
HORIZONTAL DEPARTURE
DISTANCE AZIMUTH
FEET DEG MIN
5687.63 S 43 41 E
SCHLUMBERGER
O I RECT I ONRL SURVEY
COMPANY
ARCO ALASKA INC
WELL
3F- 1
FIELD
KUPARUK
COUNTRY
USA
RUN
ONE
BATE LOBBED
REFERENCE 0000?0969
,WE, LL NAME: 3F-1
SDRFACE LOCATION:
- I{X~I 0 0
89' F~-'' 162' FWL, S29, T12N, R9E, UM
VERTICAL PROJECTION
PRO~CTI~ ON VERT]CRL PLRNE SE - ~ SCI:R.ED IN VERT]CI~L. DEPTHS HORIZ SCI:I_I:' = 1/1000 IN/FT
WEL, L NAME: 3F-1
SURFACE LOCATION: 89' FNI 62' FWL, S29, T12N, R9E, UM
~RTH Z'0C~ REF ~ ~CPLE - 1/lOOO I'N/FT
.:
"?: ~?f;"*.:*'~'?:"*;"t"-.:" . ........
HORIZONTAL PROJECTION
~UTH - 6~l:~)
-2000
i,I~ST
==============================
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; : : : ; : : : : ....... : ; : : ~ · : . :
- 101~ 0 ] OC~ 2000 ~0OD 400CI 5000 6000
E~IST
Suggested form t~ be inserted in each "Active" well folder to check
for timely compliance with our regulations.
Reports and Materials to be received by: /~--~-F~
Date
Required Date Received Remarks
·
Completion Report
Samples '
., ~-~/ -~ ...... _
Core Ch~p~
-
Co~ ~es~pt~o~,
Registered' Survey Plat y~ / ~--~~~ .
.
Drill Stem Test Reports .... ..~
., ~.~~-. ~-:
.
, , ',
Digitized Data
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
October 21, 1985
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT' Conductor As-Built Location Plat - 3F Pad
Wells 1-16
Dear Mr. Chatterton'
Enclosed is an as-built location plat for the subject wells.
you have any questions, please call me at 263-4944.
Sincerely,
Gruber
Associate Engineer
JG/tw
GRU11/L22
Enclosure
If
RECEIVED
OCT e 5
Alaska 0il a Gas Cor~s. Commission
,~nchora,_qe
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
AS BUI CONDUCTORS I-0 IN SECTION ~9
1- Y=5,985,734.98 LAT=70°22,20.0858,,
X= 508,662.35 LONG=149°55 ' 46. 549''
89 FNL, 162 FWL, 52 O.G., 56.1 PAD.
2- ¥=5,985,745.10 LAT=70°22' 20. 1856"
X= 508,638.99 LONG=149°55' 47. 233''
78 FNL, 139 FWL, 52 O.G., 56.3 PAD
3- Y=5,985,754.79 LAT=7OO22 ' 20. 2812"
X= 508,616.29 LONG=149°55' 47.896''
69 FNL, 116 FWL, 52 O.G. 56.3 PAD
4- Y=5,985,764.77 LAT=70°22 ' 20. 3796''
X= 508,593.66 LONG=149°55' 48. 558''
59 FNL, 93 FWL, 52 O.G. 56.2 PAD
5- Y=5,985,774.87 LAT=70°22 ' 20.4792''
' X= 508,570.43 LONG=149°55' 49.237
~ 49 FNL, 70 FWL, 52 O.G. 56.2 PAD
6- Y=5,985,784.84 LAT=70°22'20.5776''
X= 508,547.58 LONG=149°55' 49. 906"
NOTES ' 39 FNL, 48 FWL, 52 O.G. 56.1 PAD
I.COORDINATES ARE A.S.R, ZONE4. 7- Y=5,985,794.93 LAT=70°22'20.6771''
2. sEcTION LINE DISTANCE~ ARE TRUE. 'X= 508,524.44 LONG.149°55 ' 50. 582''
28 FNL, 24 FWL, 52 O.G.,55.9 PAD
3. HORIZONTAL AND VERTICAL POSITIONS ARE BASED
8- Y=5,985,804.81 LAT=70°22 ' 20. 7744''
ON MONUMENTS ~F-MIDDLE & ~F-EAST PER L.H.Q~A~. X= 508,501.41 LONG=149°55'51.256''
4. O.G. ELEVATIONS INTERPOLATED FROM S/C DWG. NO. 18 FNL, 1 FWL, 52 O.G.,55.9 PAD
CED-RIXX-3030 R~~m. AS BUILT CONDUCTOR~ 9-16 IN SE;TI~N 19
,~ OF~, 9- Y=5,985,834.85 LAT=70o22'21.0708''
----- -. -~,~ , X= 508 432 81 LONG=149°55'53 26~"
~ ~ .' A . U~ .~ ' ' ·
~-~' ~ '.~ 12 ESL, 67 EEL, 51.20.G., 56.1 PAD
~..,~,...,.,.~.~, ...... ~ 10- Y=5,985,844.70 LAT=70°22'21.1678"
x;
'~.ow,,o~.,~-*- 2.~ 11- Y=5,985,855.14 LAT=70°22'21.2708''
~ % 4~8o-s .-"~ X= 508 387 41 LONG=149°55'54.590''
~~:;* ~ [2- Y=5,985,865.[9 LAT:70°22'21.3699''
~~~ X= 508,364.05 LONG=149°55' 55. 273"
I HEREBY~CERTIFY THAT I AM ~~Y M~t~ED 42 FSL, 136 FEL, 51.10.G. 56.2 PAD
A~ LICB~ED TO PRACTICE LAND B~EYIM'IN 13- Y=5,985,874.97 LAT=70°22'21.4663,,
THE STATE OF ALASKA, ~AT ~11 ~T ~~~NT8 X= 508,341.36 LONG=149°55 ' 55.937"
A 8~VEY ~DE U~R MYDI~CTMRV~AND 52 ESL, 158 FEL,51.]. O.G., 56.3 PAD
THAT CQND~TOR8 I TIIA~.O~OT Al ~ 14- Y=5 985 885 08 LAT=70°22'21 5660"
SEP~ER 19,198~ A~.C~T~'I ~U le ' ' ' '
ARE COR~CT A8 ~ ~P~ER lt, lHl. X: 508,318.27 LONG=149°55' 56.612"
" 62 FSL, 181 FEL, 51.1 0.G.,56.3 PAD
DS. 3B 15- Y=5,985,894.96 LAT=70°22 ' 21.6635''
°u~V~o 2 X= 508,295.72 LONG=149°55' 57. 271''
~~~ 72 FSL, 204 FEL, 51 O.G. 56.~ PAD
D.S3FTM ~ / .~ - ~Qi ~( ~ ~ ~.~ 16- Y=5,985,904.95 LAT=70°22'21.7619''
~~ ,. ~J...~...~ ~ p.~_~.,~.~2 FSL, 227 FELI 5~ O.O.
~- ~ , ~ ~ L ~ ~ ~ DRILLSI~ F
' II~ii CONDUCTOR AS BmLT
~~/: :.:~ LOCATI~
SEC. 29, T. 12N.,R. gE.,U. MER. Dlte:~to~r 11,1985 8Oe~: N.T.S.
CONDUCTORS 9 THRU 16 LOCA~D IN P~TR~TED ·
SEC. 19, T.I~N.,R.9E.,U. MER. ~M,~~ Drifted by:Sydney2 ~l. ~. N~85-26
ARCO Alaska,
Post olfic~':-~x 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
[)ATE: 10-10-85
TRANSMITTAL NO: 5393
I{.ETUIiN TO:
ARCO ALASKA, INC.
KUPARUK OPt;RATIONS ENGINEERING
I{13COldPS
ATO-1115B
P.O. BOX 100360
ANCtiORAGE, AK 99510
J-5/ 09-2
J-4~'' 0'9-1
1-o-O
09-24-
09-15-
'- i;/'
3A- 4/ 09-21-
2A-13~' 07 16-
IIEI{I:ii,,"I'TII ARE TIiE FOLLOWING ITEMS.
I<ETU!{N ONE ::;IGNUD COPY Ob' Tills TI{AN
It; TAPL;3/ bClil,/ ONL 'i'~PE PLUS LISTIN
2-85 1~U14 !il 4284.5-~649.5 REF
5-85 RUN ~1 4317.5-8679.0 liEF
7-85 I{UN il 1688.5-8522.0 REF
2-85 RUI'4 ~1 3493.5-7865-.5 REF
85 t<UH ~1 3944.0-8654.0 kEF
85 RUN ~1 3~58.0-7622.0 REF ~
85 RUN ~1 2450.0-8308.0 t{gl,' ~
U5 i~UN ~1 3798.5-8484.0- i<I:;F
85 RUN ~1 7643.5-Ui60.0 REF
PLLAIJE ACKNOWLEDGI:;
SI'*ITTAL.
G
70853
70840
70824
70854
7ou25
70832
70830
70645---RgVISED
AFICO ,'%!;,.~.'!. !nc is a gub~.i(l,ar¥ OI Allnl,l!cRirhliehiComlmny
ARCO Alaska, Inc. ~'~
Post Office E, _ 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
October 14, 1985
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commi ssion
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT: State Reports
Dear Mr. Chatterton:
Enclosed are the September monthly reports for the following wells:
3A-2 3C-3 3J-4 WSP-6I (workover) L3-5 9-29
3A-3 3C-16 3J-5 L1-2 4-21 11-8
3A-4 3F-1 3J-6 L1-14 (workover) 4-30 11-9
3C-1 3F-2 1R-3 L2-13 4-32 11-11
3C-2 3J-3 1R-4 L2-26 9-24 15-7
16-17
If you have any questions, please call me at 263-4944.
Sincerely,
· Gruber
Associate Engineer
JG/tw
GRU11/L62
Enclosures
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
STATE OF ALASKA
ALASKA <..._ AND GAS CONSERVATION CO,..,¢IISSION
MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS
· Drilling well ~ Workover operation []
2. Name of operator 7. Permit No.
ARCO Alaska, lnc. 85-225
3. Address 8. APl Number
P. O. Box 100360, Anchorage, AK 99510 50- 029-21446
4. Location of Well
at surface
89' FNL, 162' FWL, Sec.29, T12N, RgE, UM (approx)
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No.
93' RKB ADL 25643 ALK 2574
9. Unit or Lease Name
Kuparuk River Unit
10. Well No.
3F-1
11. Field and Pool
Kuparuk River Field
Kuparuk River 0il Pool
For the Month of September ,19 85
12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks
Spudded well ~ 1515 hfs, 9/19/85. Drilled 12-1/4" hole to 3995'. Ran, cmtd, & tstd 9-5/8" csg. Drilled
8-1/2" hole to 8730' TD. (9-23-85). Ran logs. Ran, cmtd, & tstd 7" csg. P§TD = 8555'. Secured well & RR ~
2400 hfs, 9/25/85.
13. Casing or liner ru.n and quantities of cement, results of pressure tests
16", 62.5#/ft, H-40 weld conductor set ~ 115'. Cement detail not available ~ this time
9-5/8", 36.0#/ft, :J-55, BTC csg w/shoe ~ 3971'. Cmtd w/1020 sx PF "E" & 400 sx PF "C".
w/50 sx PF "C".
7", 26.0#/ft, J-55, BTC csg w/shoe @ 8646'. Cmtd w/325 sx Class "G".
Top job was performed
14. Coring resume and brief description
None
15. Logs run and depth where run
DIL/GR/SP/$FL f/8702'-3966'
FDC/CNL f/8702' - 7850' & 5800'-5300'
CAL f/8702'-5150'
6. DST data, perforating data, shows of H2S, miscellaneous data
None
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
SIGNED ~n ~ _~,/¢_.~¢ TITLE Associate Engineer DATE /~)"//'(~'
NOTE--Report this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska
Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed.
I:=nrn,~ I N_~.N/I
Submit in duplicate
MEMORANL)UM State of Alaska
~fLASKA OIL AI-~ GAS CONSERVATION C0~'R,~ISSION
Chair~Ri~--~
~RU: Lonnie C. Smith '~'~'~ ~/
Commissioner
DATE: September 24, 1985
FILE NO: D. HPd{. 73
TELEPHONE NO:
FROM: Harold R. Hawkins ,,,~ .~ SUBJECT:
Petroleum inspector
BOPE Test
ARCO K.R.U. DS 3F-1
Permit No. 85
Kuparuk River Field
Sunda~, S~ptember 22~ 1985: I left ARCO's DS 3J, subject of
~n~h~ r~p~t~,~ to ARco'S DS 3F to witness a BOPE Test.
I witnessed the BOPE Test on ARCO's Well No. 3F-t, there were no
failures.
I filled out an A.O.G.C.C. Report which is attached.
In s~ary, i witnessed the BOPE Test that Doyan 9 crew performed
for ARCO on Well No. 3F-1. The tests were satisfactory.
Attachment
02-00IA(Rev. 10/79)
5184
Inspector
STATE OF ALASKA
ALASKA 0IL & GAS CONSERVATION COMMISSION
B.O.P.E. Inspection Report
Date
Well
Operator
Well 3/=--/
Location: Sec
Drilling Contractor
Location, General
Well Signa~
General Housekeeping ~/f Rig &ft~
Reserve Pit ~/~
Mud Systems Visual
Audio-
Trip Tank
Pit .Gauge
Flow Monitor
ACCUMULATOR SYSTEM
Full Charge Pressure ~~ psig
Pressure After Closure //~ psig
Pump incr. clos. pres. 200 psig
Full Charge Pr~ssure'Attained:
N2 17~,2~2~.Zd~/~ ~ psig
Controls: Master
Representative h~./~/~./~ '/ ~-//~ ~Z
f~ Casing Set 8 3Y Z/ ~C' ~
Representative ~1~ ~[)L~/~'
min~ sec.
min ~ sec.
Gas' Detectors
BOPE Stack
Annular Preventer
Pipe Rams
Blind Rams
Choke Line Valves
H.C.R. Valve
Kill Line Valves
Check Valve
.
Test Pressure
TeSt Results: Failures,
Blinds switch cover
Remote dN
Kell~ and Floor Safety Valves
Test Pressure
Test Pressure
Test PreSsure
Test Pressure
Test Pressure
O/<
Repair or Replacement of failed equipment to be made within
Commission office notified.
Remarks: ~ ny /~' &~ JZ) 7~n=~/- /
Upper KellM
Lower Kelly
Ball Type
Inside BOP
Choke Manifold
·
No. Valves /~
No. flanges ~
Adjustable Chokes ~z/~
Hydrauically operated choke~
Test Time ~ hrs.
days and Ins'~ector/
Distribution
orig. - A0&GCC
cc - Operator
cc - Supervisor
Inspector
September 12, 1985
Mr. J. B. Kewin
Area Drilling Engineer
ARCO Alaska, Inc.
P. O. Box 100360
Anchorage, Alaska 99510-0360
Re:
Kuparuk River Unit 3F- 1
ARCO Alaska, Inc.
Permit No. 85-225
Sur. Loc. 89'F%U~, !62'FWL, Sec. 29, T12N, R9E, IRM.
Btmhole Loc. 1078'FSL, 1083'FEL, Sec. 29, T12N, RgE, UM.
Dear Mr. Kewin:
Enclosed is the approved application for permit to drill the
above referenced well.
The permit to drill does not indemnify you~from the probable need
to obtain additional permits required by law from other
governmental agencies prior to commencing operations at the well
site.
To aid us in scheduling field work, please notify this office 24
hours prior to commencing installation of the blowout prevention
equipment-so that a representative of the Commission may be
present to witness testing of the equipment before the surface
casing shoe is drilled. Where a diverter system is required,
please also notify this office 24 hours prior to commencing
equipment installation so that the Commission may witness testing
before drilling below the shoe of the conductor pipe.
Ve3~v~tru!~ur~s,'
¢. V. Chatter~o~
Cha±rman of
Alaska Oil and Cas ConserTation Commission
BY ORDER OF THE COMMISSION
be Enclosure
CC:
Department of Fish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
Mr. Doug L. Lowery
ARCO Alaska, Inc.
Post Office B~. ~00360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
August 20, 1985
Mr. C. V. Chatterton
Commissioner
State of Alaska
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
SUBJECT' Kuparuk 3F-1
Dear Mr. Chatterton:
Enclosed are:
An application for Permit to Drill Kuparuk 3F-1, along
a $100 application fee
Diagrams showing the proposed horizontal and vertical
projections of the wellbore
with
o A proximity plot
o A diagram and description of the
system
surface .hole diverter
o A diagram and description of the BOP equipment
We estimate spudding this well on September 16, 1985. If you have
any questions, please call me at 263-4970.
Sincerely,
Regional Drilling Engineer
JBK/HRE/tw
PD/L155
Enclosures
RECEIVED
Alaska Oil & Gas Cons. Commission
Anchorage
ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany
STATE OF ALASKA
ALASKA L,,L AND GAS CONSERVATION CO,,,MlSSlON
PERMIT TO DRILL
20 AAC 25.005
la. Type of work.
DRILL I-~X
REDRILL []
DEEPEN []
lb. Type of well
EXPLORATORY []
DEVELOPMENT OIL E~X
DEVELOPMENT GAS []
SERVICE [] STRATIGRAP.~j~ L~
SINGLE ZONE ~¢' '1~'~__
MULTIPLE ZONE~ (p ~
9. Unit or lease name ~ ~/ _ ~
Kuparuk River Unit ~
2. Name of operator
ARCO Alaska, Inc.
3. Address
P. 0. Box 100360, Anchorage, Alaska 99510
4. Location of well at surface
89' FNL, 162' FWL, Sec.29, T12N, RgE, UM
At top of proposed producing interval
1454' FSL, 1452' FEL, Sec.29, T12N, RgE, UM
At total depth
1078' FSL, 1083' FEL, $ec.29, T12N, R9E, UN
5. Elevation in feet (indica~e.,K,~B,,..D~ F,,.etc.)
12. Bon~i~for~o~*(;~e'20 AAC 25.025)
6. Lease designation and serial no.
ADL 2564:3 ALK 2574
Federal Insurance Company
10. Well number
3F-1
11. Field and pool
Kuparuk River Field
Kuparuk River 0il Pool
Type Statewide
Surety and/or number #8088-26-27
13. Distance and direction from nearest town 14. Distance to nearest property or lease line
30 mi. NW of Deadhorse miles 897 ~ surface feet
16. Proposed depth (MD & TVD) 17. Number of acres in lease
8784' MD, 6259' TVD feet 2560
19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures
KICK OFF POINT 400 feet. MAXIMUM HOLE ANGLE 49 o (see 20 AAC 25.035 (c) (2)
Amount $500,000
15. Distance to nearest drilling or completed
2U-13well 2640' @ TD feet
18. Approximate spud date
09/16/85
2650 psig@ 80OF Surface
~__psig@ Kq66 ft. TD (TVD)
21
Weight
62.5#
36.0#
26.0#
Proposed Casing,
CASING AND LINER
SIZE
Hole Casing
24" 16"
12-1/4" 9-5/8"
8-1/2" 7"
Grade I Coupling
H-40 ~ Weld
1-55/HF-EIW BTC
1-55/HF-EIW BTC
Length
80'
iner and Cementing Program
SETTING DEPTH
MD TOP TVD
35' 35'
3873' 35' 35'
8750'
I
34' I 34'
MD BOTTOM TVD
1151 115'
3908'I 3068'
8784'1 6259'
I
QUANTITY OF CEMENT
(include stage data)
± 200 cf
1020 sx PF "E" &
400 sx PF "C"
330 sx Class G neat
22. Describe proposed program:
ARCO Alaska, Inc., proposes to drill a KuParuk River Field development well to approximately 8784' MD (6259'
TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16"
conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the
9-5/8" surface pipe. The stack and related equipment will be tested to 3000 psig upon installation and weekly
thereafter. Expected maximum surface pressure is 2650 psi. Pressure calculations are based on virgin reservoir
pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature
effects. Casing will be tested to 3000 psi prior to releasing the drilling rig. Non-freezing fluids will be
left in uncemented annuli through the permafrost interval. 3F-1 will be 2650' away from 2U-13 at total depth.
There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down
the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any
interruptions in the disposal process. (continued on attached sheet)
· 23. I hereby cer~*~)that the foregoing is true and correct to the best of my knowledge
SIGNED TITLE Regional Drilling Engr.
Thespace~JzCwfor¢~~~se '~ -
CONDITIONS OF APPROVAL
DATE
Samples required
[]YES ~NO
Permit number 3 /
? ~- -~
APPROVED BY ~R )~p~Z5
Form 10401
Mud log required I Directional Survey required
E]YES ~NO I J~t-Y E S I-1NO
Approval date
APl number
50- 0 ~-~/¢¢~¢
SEE COVER LETTER FOR OTHER REQUIREMENTS
,COMMISSIONER DATE September 12: 1985
by order of the Commission
Submit in triplicate
PERMIT TO DRILL
3F-1 (cont'd)
Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 200 sx cement
followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing.
Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A
subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has
moved off location, this well will be fracture stimulated.
RECEIVED
$ E? o 1985
Alaska 0il & Gas Cons. Cor~'lmission
Anchorage
2000 :3000
i." VERTICAL SECTION
i
4000 5000 6000
.
~- . ........................
. . ; ........ . . : . _ . ~ · . . -
............ .. ~ ; ~ ....
_ . ~
~oo
1.0Q
.0:
100
0 ~o0
,
~,00
ARCO ALASKA. INC.
~AO ~F. I,,~,LL NO, 1'2-~'4 PRoPP~[P
EASTHAN ~WHIP'STOCK., INC,.-
NOTE, ~L:L P~THS [XTEND BEYOND THIS VlE~
NORTH
~00
IN~. wI,m)ow
2.00
3~
300
2278
7'oo
8:00 '
· ,
400
500
2141
3D2
KUPARUK R T VER UNIT
'20" DIVERTER SCHEMATIC
7 6 7
DESCRIPTION
MAINTENANCE & OPERATION
.
I. UPON INITIAL INSTALLATI~ CLOSE
PREVENTER AI~ VERIFY THAT VALVES
HAVE OPENED PROPERLY.
2. CLOSE ~AR PREVENTER AI~ BLOW
AZ R THROUGH DI VERTER L I NE$
EVERY 12 HOURS.
CLOSE AI~JJLAR PREVENTER IN THE
EVENT THAT AN I~FLUX OF ~ELLB(]RE
FLUII~ OR GAS IS DETECTED. IF
NECESSARY, MAIMJALLY OVERRIDE AI~
CLOSE APPROPRIATE VALVE TO
ACHIEVE DOt'~NWlI~) DIVERSI01~
~ RECEIVED
DO NOT SHUT IN ~LL
UNDER ANY C I RCUMSTANCE$.
7
6
ACCL~TCR CAPACITY TEST
I. O-[CX .N~ FILL ~TCR RESE~OIR TO
~ WI~ ~IC ~UID.
4. ~~ ~ ~ ~, ~ A~~ L~ LIMIT
5
4
[ I
3
1~-~8' BC~ $TA(;:K TEST
I. FIlL BOa ETA(]( AI~ C~ I~F~ w'I'rl.i ARCTIC
DIF.~.
2. O-ECl( Tl~.AT ALL LO~ 01~ SO~ IN v~ AJ~
FIA. LY RE-.~ACTED. SE. AT TEST PLUG IN
WITH R~I~ ,jr AI~ RI~ IN LO~
LIl~ VALVES ADJACENT TO 8CP STAO(. ALL OT1-ER
4. PI~ U~ TO 2~0 J:~I A~ HQ.D FC~ I0 ~N. IN-
C~ P;~ TO ~4~ ;:~I A/~ HOD FCR I0 MIN.
~ ~--~'~St~ TO 0 ~I.
L~ vALvEz. O_O~ TC~ PZ~Z ~m A~O ~C~ VALvEs
CN ~ILL. A~D O-M3(E LI~.S.
6.TEST TO 2~0 PSI A~O ~ PSI AS IN STEP
?.03~KZNUE TESTING ALL VALVES, LI~ESo
WITH A ~ PSI LON A~O ~X)O PSI HI(~. TEST A8
~I~ T~ ~ ~T ~ ~ ~Y ~.
~ ~ ~I~ ~ TO~I ~ ~~I.
)0. ~ ~I~ ~ ~ ~T TO
~I.
PI~ ~ v~VE, ~ I~I~
~ ~I.
;3. ~ TEST I~~TI~ ~ ~~ ~~ TEST
F~, SI~, ~ ~ TO ~I~I~ ~I~.
14. ~~ ~ ~ ~ ~ NI~I~
~Y T~ ~I~Y ~~ ~ ~ILY.
RECEIVED
SEP 1 o ~gB5
Alaska Oil & Gas Cons. Commissio~
^ncnora.gs
00~4001 ;£V. 2
MAY 15o l!)85
CHECK LIST FOR NEW WELL PERMITS
Company
Lease & Well No.
ITEM APPROVE DATE
,,
(2 thru 8)
(8) ~'/' /'f~ 9
(3) Admin
(9 thru 12) 10.
(10 and 1~) / 12.
(4) casg ~.~, .~./~, (13 thru
(22 thru 26)
YES NO
th h
1. Is e permit fee attac ed .......................................... __
2. Is well to be located in a defined pool ........ , ,, ,,
3. Is well located proper distance froa, property '~l;,~ iii.ii.'...
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 wellbore plat included ................
7. Is operator the only affected party ................................. ~.~..
8. Can pe~it be approved before ten-day wait .......................... .,,.x.~..
13.
14.
15.
16.
17.
18.
19.
20.
21.
22.
23.
24.
25.
26.
27.
Does operator have a bond in force ..................................
Is a conservation order needed ......................................
Is administrative approval needed ...................................
Is the lease number appropriate .....................................
'7---
Is conductor string provided ........................................
Is.enough cement used to circulate on conductor and surface .........
Will cement tie in surface and intermediate or production strings
Will cement cover all known productive horizons .....................
Will surface casing protect fresh water zones ... .
Will all'casing give adequate safety in collapsel ;;~;~';~ ~;;;;.i
Is this well to be kicked off from an existing wellbore .............
Is old wellbore abandonment procedure included on 10-403 ............
Is adequate wellbore separation proposed ............................
Is a diverter system required ....... ................................ ~
,
Are necessary diagrams of diverter and BOP equipment attached · ... ~ ..
Does BOPE have sufficient pressure rating - Test to ~O~D ;;i; ,.
Does the choke manifold comply w/API RP-53 (Feb.78) ..................
Is the presence of H2S gas probable ................................. ~.~
Additional requirements ............................ , ................ ~/
REMARKS
Additional Remarks:
~Z
~'-~O
Geo logy~:. Engineering:
/ ,.cs .........
JAL ~"~ ....... ' ' ' "-
rev: 03/13/85
'6.011
INITIAL GEO. UNIT ON/OFF
POOL CLASS STATUS AREA NO. SHORE
,
Well Histo.ry 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 roadability 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.
'VER I ~'T,.C ~'t I 0~'? i,ISYYNG
I, VP Old.HO? VFPlP.I.~TinI~ L, TSTi~G PAGE
SERVTC~ ~A~E :~OIT
DATE :~5/Og/~'l
ORIGIN :70~3
TAPE
~ONTIN~A~ION ~ :O1
PR~3~ TO~S T~PE
CO~MEki~S :[,IRRARY TAPE
SERVTCF NAMg ~
VERSTO~ # :
DATE :
MAXIMU~ [,EMGTH : 1024
FILE TYPE :
PREV~O{~S Flb~ {
** INFnR~ATIQN R~CORD$ **
MN~M ~ONT~N~S
CN : ARCO ALASKA TNC,
FN ~ KUPA~tIK
RANG:
TOWN: 12N
SECT~
COUN:~ NORTH qbnPR
ST~T~ AG~.SKA
~N~N CON]:~N"rS
PR£S: ~
** C~NMENTS **
ooooooo,~i o~
ooooooo~, o~,
o00 000 008 06
000 000 002 065
000 000 004 065
000 000 002 06
5
000 000 012 065
000 000 006 065
000 000 00~ 065
UNIT TYPE CATE SIZE CODE
000 000 001 065
LVP 01, n.I"!O~ VEPlFICAT[~n~'J 'blSTING PAGE 2
~ RL, ASKA C_n~PUTING
CO~P~r~V = A~C~ ~b~SKA INC.
COUNTY = NO~TH ST,OPE BOROUGH
ST~Tw = A~,ASK~
JOB NUt, BMR AT ACC: 70~7
~UN Wi, DATE LOG~ED: 24 ~EP~. 19~5
LOP: RICK KRI!%~LL
CASING = 9.67b" ~ 3~71' ' i~IT SIZE = ~.5" TO ]971'
TYPE FI,U?!) : WTD. ~OLY,
DENSITY = 9 9 5~I~ R~ = ~,2 m 65 DF
VI$Cr~SITY : 3~ S R~F ~ 1..12 ~ 65 DF
PH = 9,4 ,R~C ~ 3.5 ~ 65 DF
F~I]I~ [,OSS = 5,6 C3 ~ AT BHT = 2.564 a S39 DF
~ATR~X SANDSTONE
*$*~* THIS DA.T.~ MAS NOT BE~!~ DEPTM SMIWTED - OVERI, gYS FI~,D PRINTS
*******************************************************************************
, , , , , , , , , , , , , , , , , , , , , , , , * , , , , *
, *
· SCUbUr,~BE~GF~R bOGS ~INC,~UOED W~]~N TMIS ~AG~ETIC TAPE~ *
· D~T~ ~V~ILRBbE~ 8633' TO 39~6' *
, *
· FORMATION DENSITY COmPENSaTED
· COMPENSATED NgUTRON LO~ (FDN) *
· DRT~ ~V~ABbM: 860g' T~I 52 3 *
· FDM DATA IS mISCONTIMUnUB FR~M 7824'TO 58ll~ *
******************************
** D~T~ FOR~,T RMCC)RD **
ENTRV ~bOCWS
TYPE SIZE REPR CODE ENTRY
2 1 66 0
4 1 ~$
~ 4 73 6O
9 4 ~5
~6 1 66
0 1 66 0
DATU~ SP~CIF%C~TIO~!
MN~M SMRVICg SERVICE
APT FILE SIZE SPb REP~
LVP OIO.HO~ VERIFICATIOi~ LISTING PAGE 4
DEPT
SFLU
ILO
SP nil
GR ~IL
~A[,! ~DN
DRHO FDN
NR~T FDN
RNRA FDN
NPH~ FOg
NCNb FDM
FCNL FDN
,~,'nG. TYP~ CL, AS$ ~Or)
O0 nO0 OO 0 0
OH~M O0 220
OH~ O0 120
.¥ 00 010
GAP! O0 310
CAPI no
~N OD 280
G/C3 O0 350
C/C] O0 356
O0 420
O0 000
PU DO R90
CPS O0 :~30
CPS O0 ]3O
4
01 0 0 4
4(-. 0 0 4
44 0 0 4
O1 0 0 4
01 0 0 4
O! 0 0 4
O1 0 0 4
02 0 0 4
01 0 0 4
O1 0 0 4
O0 0 0 4
O0 0 0 4
31 0 0 4
30 0 0 4
CODE fOetAL)
I 68 00000000000000
1 68 00000000000000
1 68 00000000000000
I 68 00000000000000
1 68 00000000000000
1 68 00000000000000
1 68 00000000000000
1 68 O0000000000OO0
I 68 00000000000000
I 68 00000000000000
1 68 00000000000000
1 68 O000000000gO00
I 68 0000000000 000
I 68 00000000000000
1 68 00000000000000
DEPT
SP
RHOB
NPH!
8654 0000
2 5081
44,7266
DEPT
SP
NPHI
8600 0000 SFt, U
40,234,4 NCNb
DEPT
RHOB
NPHI
DEPT
SP
RHOB
NPH I
t15!~273 ~R
0 1372 ~RA.T
1~89 6875 rC~b
DE:PT
RHOB
NPHI
2,91~4 IbD
113.5898 GR
0.0674 ~IRAT
2000.68~5 FCN6
DEPT
NPHI
9,5'i10 I6~
0,0146 NRAT
260].5000 rCNL
DEPT
SP
RHOB
NPH i
8400,0000 SFLO ~.g631 ThO
-18,?g~o ~R 112,3~q8 GR
2
.4709 D~ 0.0449 NRAT
42.~875 NCNb 1948,6875 FCNL
8300 0000 SFLU
-18 q482 Ga
~ 37,.52 DRMO
31. 0547 NCNb
8200.0000 SFLU
'2l.~119 ~R
2.]674 DRHU
2'7,0297 NCNI.
8!00 nO00
li0107
'22 7581 DRHO
41.7969
~,5020 ThO
g3.,OBqB G'R
0.00]4 MRAT
2577.5000 FCNL
5 3406
75.714B GR
0,02~5 NRAT
2485,5000 FCN5
234 0625 IGD
76 9023 GR
,0 0127 NRAT
2155 5000 FCMb
3.0~03
!.15,5273 CALl
, 5842 RN'RA
48 .6406
~ ,~ IbM
3.3362 ~NRA
5~7,8125
?,B875 IbP
3jgB CA,LI
9~'8694 RNRA
~ 9~90
11,213398 CAt, I
].4924 RNRA
509,8906
? 6140
9] 0898 CALl
~0~ ~18625 RNRA
6 :,:~750 I6~
75 148 CALl
1.11.5273
76,9023 CALl
3,4570 RNRA
3 3108
8:5020
3.9143
2,7698
,4551
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,,2207
3,4004
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7,5750
3,: 17
6,3796
8,6.1~3'
2,86 6
9648
I. 07,4
LVP Oln. HO~ V~:RIVI'CAT,Ir~,'~ LTSTiNG PAGE
SP -23.65~4
RHOB 9.~9~1
NPHI 45.5078
DEPT 7qO0.O00O SFt, U
SP -25.0396 GR
NPHI 4~.6035 ~CNh
DEPT 7800 0000 SFLU
SP -2626045
NP~I -q99.~500
DEPT 7700 0000 SFI,U
Sp -24i3389 GR
R~OB -999 ~500 DRHU
NPH1 -999 ~500 ~CNL
DEPT 7600 0000 SFI,U
SP .24i68~6 GR
RHOB -99:9 2500 DRHD
NPHI -999 ~500 NC~L
DEPT 7500.0000
Sp -20,1357
'RHOB -999,)500
~PHI -990.7500 NCnb
DEPT 7a00,O000 SF{,,t{
~p -~4,9~70 ~R
RHOB -999.~500 DRHO
NPHI -999,~500 ~C~II]~
DEPT 7300,O000
SP -24.9795
RHDB -999.~500 DRHO
NpHI -999,~500 NC~{b
DEUT 7~00,0000 SFt. U
Sp0 -25.,1.670 GR
NPHI -999.~500 NCNL
DEPT 7100.0000 SFLU
SP -25.4170 GR
RHOB .99q.~500 DRHO
NPHI -999.~500 ~CNi:
DEPT 7000.0000
~p -28 6357
RHOB -qgq:~500
gg?~ TL9
!.2R~56~b ~a T
0171 ~R~
1660;6~75 ~C~I!...
0.0190 ~RAT
1983,6875 FC~L
7776 TbD
~69.3906
-999.~500
-990.~500 FCNL
5 8328 IbD
10016523 gU
-990 ~500 NRAT
-ggq ~500 FCML
1.6827
!28.5625
3.6995
420.8906
2 ]928
126'
,3398
3.5959
537.S125
3.0113
149,5625
=999.2500
-999.2500
~,2112
-ggo. O0
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4,1804
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3' 98,46
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DEPT 6800 0000 SF[,U
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NPHI -99~ ~500 ~CNL
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RHOB 999.2500 D~HO
NpH! ~999.~500 NCNL
DEPT 6~00,0000 ~FI.,U
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Np~! -q99.~500 NCNb
DEPT 6500 0000 SF!,[J
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NPH1 -999 ~500 NCNb
DEPT 6]00,0000 SFLU
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2.6663
9.3926
-999,2500
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3.6077
9,5879
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9, ~54
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999.064.5
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2,3987
9,4004
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g. 5
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2,6936
8,~848
~999, 500
2,9885
8.6113
RHnh -99o.~5nO DR}~O
SP -27:7295 ~R 8~:
NPHI 35 9863 NCNb 2381,
DEPT 5500.0000 SFI,U 3.
SP -28.87nX ~R 106.
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NP~I ,.{q,1602 NCNb
DEPT 5400.00o0 SFL0 3
8P -27 6514 GR 117~
RHOB 2~756 DRHO 0
~'PHI 40.6738 NCNb 208]
2500
8538
214~
049~
6875
3367
1523
0459
5000
5471
7773
5000
3538
5273
0068
5000
8264
7773
0103
5000
5~00 0000 ~'FI.,U 2
HOB -099 ~.500 DRHO .,999
~.PHI ..qgg.~.500 NC~JL -999,
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EOF **********
EOF
