Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout204-201C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\BCJZ1PKL\2025-05-16_23078_KRU_1E-168L1_ProductionProfile_Transmittal.docx
DELIVERABLE DISCRIPTION
Ticket # Field Well # API # Log Description Log Date
23078 KRU 1E-168L1 50-029-23230-60 Production Profile 16-May-25
DELIVERED TO
Company & Address
DIGITAL FILE
# of Copies
LOG PRINTS
# of Prints
CD’s
# of Copies
1
AOGCC
Attn: Natural Resources Technician
333 W. 7th Ave., Suite 100
Anchorage, Ak. 99501-3539
Delivered By: CPAI Sharefile
______________________________ _____________________________________
Date received Signature
______________________________ ______________________________________
PLEASE RETURN COPY VIA EMAIL TO:
DIANE.WILLIAMS@READCASEDHOLE.COM
READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503
PHONE: (907)245-8951
E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM
204-201
T40438
5/21/2025
Gavin
Gluyas
Digitally signed by
Gavin Gluyas
Date: 2025.05.21
13:21:18 -08'00'
DSR-4/9/2020
VTL 4/10/20
THE STATE
°fALASKA
GOVERNOR MIKE DUNLEAVY
John Peirce
Sr. Wells Engineer
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510
Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E -168L1
Permit to Drill Number: 204-201
Sundry Number: 319-526
Dear Mr. Peirce:
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www. a o g c c. a l a s k a. g o v
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,
p V
e .Price
Chair q
DATED this` 1 day of November, 2019.
3BDMS-IL/w Nov 2 12019
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
WMEne
NOV 15 2019
f
1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown[-]
Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑
Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: RPPG MBE TRTM1171 -
2. Operator Name:
4. Current Well Class:
5. Permit to Drill Number:
ConocOPhllll s Alaska Inc.
Exploratory ❑ Development O •
Stratigraphic ❑ Service ❑
204-201
3. Address:
6. API Number:
P. O. Box 100360, Anchorage, Alaska 99510
50-029-23230-60-00
7. If perforating:
8. Well Name and Number:
!^'
What Regulation or Conservation Order governs well spacing in this pool? N/A
Will planned perforations require a spacing exception? Yes ❑ No O
KRU 1 E -168L1 '
9. Property Designation (Lease Number):
10. Field/Pool(s):
ADL 25651
Kuparu k River Field /West Sak Oil Pool -
11. PRESENT WELL CONDITION SUMMARY
Total DdhTotal Depth TVD (ft):
Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
3,583'
11888 35801500psi
Length
Size MD ND Surat Collapse
C 80'
20" 108' 108'
4,387'
103/4 4,415' 2,478'
P 7,351'
75/8 7,378' 3,714'
4574
4 112 1 11,927' 3,583'
Perforation Depth MD (ft):
Perforation Dept3582 h TVD (ft):
Tubing Size:
Tubing Grade: -
Tubing MD (ft):
7447-10673, 10645-10650,
3551--3552, 3553-3553, 3556•
4.500"
L-80
6,983'
Packers and SSSV Type:
NIA
Packers and SSSV MD (ft) and TVD (ft): t
.
V
12. Attachments: Proposal Summary Wellbore schematic
13. Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑
Exploratory ❑ Stratigraphic ❑ DevelopmentEl Service ❑
14. Estimated Date for 1211/2019
15. Well Status after proposed work:
Commencing Operations:
OIL 0 • 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: John Peirce John Peirce
Contact Name:
Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com
' r Contact Phone: (907) 265-6471
Authorized Signature: W g' Date: 1,i,�'�-��.
COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
req -5a
Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑
Other:
3MMS 1�NOV 2 12019
Post Initial Injection MIT Req'd? Yes ❑ No ❑
Spacing Exception Required? Yes ❑ No Subsequent Form Required:
APPROVED BY
Approved by: 0 r' (n y COMMISSIONER THE COMMISSION Date: 1 y`
! / 0 D [G� A L / Submit Form and
Form logIR ed4/201] Approved application is v li fills 2 f t C1C`e Of appf0V81. AttachmenU in Form and
C
Conocl3killips
Alaska, Inc.
KUP PROD WELLNAME 1E-168 WELLBORE 1E-168
IE -1a4 t1MYAla t22553PM
Last Tag
Ve.... hope,
Annotatbn Depth MB) End Data Wellbore
Last MOJ By
............... ... .........
Lest Tal:
1E-168
ImOs60r
...EB; 236
Last Rev Reason
AnnodBan
ellbo
End Data Wre
lest Maa ey
Rev Reason SE
LEM ISO SLEEVE
PE1 B-E
ERTER SLEEVE, SET TY D-
2/232019 1E-168
condiN'
Casing Strings
CGNIDGCR', MLO -109,0
NIPPLE;ao3.a
Casing neuriplion
CONDUCTOR
00 (in)
20
ID (in) ,P(me) hatel, RKB) Set Deph lTVo)._WGLen p... Grade
19.12 28.0 108.0 1080 62.50 H40
Tap TI mail
WELDED
GZMg Description
SURFACE
OD (in)
10314
ID lin) Top IflKB) em Game IflKB) Bat Oeral(1VD)... Tamen it.. Grade
9.95 27.6 4,414.5 2,477.6 45.50 L-80
Top Thread
BTC
GAS LIFT; 4LM2
Calling Description
PRODUCTION
OD fin) mlln) TopIMB) Set."" ler at Depth ITVD)... W8Len 0... GudetBTP
7518 6.87 2700 8,1578 3,]14,3 29.]0 LA0CmMa
Dmcan
0 -SAND Window
OD (In)
7518
10 (in) Toadies) SN Di dtKB) S t DepM jNS71 When 6... GradeW
8.00 7,031.0 7,043.0 3,465.5 2930 L-80
CKIIq Damnpleen
Window
OD(n)
7518
ID(in) Top RIKB) TO ptbMKB) SN neptM1 (TVG)... We h(I... GradeadBSAND
6.00 7,353.0 7,367.0 3,538.2 29.0 LA0
SURFACE: P. 60,tl1s
Ceaind D-.Obn
USAND LINER LEM
Go(In) ID(in) Top Me) Sat Oepb DIKG) Sel Depth flVID)... whlen(I... Gntlemd
4112 3.96 69]62 7,328.0 3,530.5 1260 L-80
Llner Details
GAS L6E S..t
Top lflKB) Top
jND)IrIKB)
Top Incl l°) Item nos Cam
Nominal IO
lin)
NIPPLE; Spoi
6,976.2
3,452.4
78.95 PACKER HRD 7XP LINER TOP PACKER w/HD SLIPS
38]0
6,995.2
3,456.0
It, II BBE CASING SEAL BORE EXTENSION
3.940
LOCATOR; sell 7-
7,020.1
3,46.8
78.43 1HANGER ITEM HOOK HANGERS
3,930
7,2823
3,521.]
]9,06 SEAL ASSY NON4-OCATING SEAL ASSEMBLY
38]0
TYPE 2 ISOLATION SLEEVE
GSIn00aectlptlan
"AN LINER LEM
OD(In
4112
I'D Top (flKB) Set neptM1 (ryKB) sat oeptblND)... wu1:n 9... GrMe
3.96 7,2968 ],479.9 3,562fi 12.60 LA0
iop TM1roYI
IBT
GL..: I,pred0
Liner Details
DS mWindux,7,D31.6
7043.0
Top LIKE) Top ITVDHKB) T.11-1 1) Item Des Com
NommallD
(In)
7,2968
3,5244
7895 PACKER MP LINERTOP PACKER
6.230
7,315.9
3,528.1
78.80 SBR 10937 CASING SEAL BORE RECEPTACLE
4.750
1
0. NO LINER; 7.L2d1
7,3347
3,5318
78.65 TO BUSHING XO BUSHING 55x4.5
3.910
D,pear
3,346,3
3,534.1
7856 HANGER LEM ABOVE HOOK HANGER
4.020
7,3531
3,535.4
78,50 HANGER LEM INSIDE HOOK HANGER
4020
7,404.2
3,545.9
]].82 NIPPLE CAMCO'DB-6'NIPPLE
3.562
D-tAND LINER LEM; ERRE.
.32-80
],4767
3,561.9
76.93 SEALASSY BAKER SEAL ASSEMBLY
3.890
rime l)esariPlion
A -SAND LINER
oo(I.)
41/2
mpn) rap It GS) last Depth(nNB) sat Deep( G.,, wuLen(IL-Grade
396 7,437.2 13,4730 3,763.1 1260 L-80
TOPTM1read
DWC
TYPE t ONERTER SLEEVE - O
Liner Details-
etails
-
ASM:
ASM;7,:=
BS.WD W.173W,0
7,aB7.D
TOP MB) ToP(TME)HI (BI
Topincl(°) IBM Des Cam
Nominal ID
(1n)
70437.2
3,553.0
77.30 PACKER HRD ZXP LINER TOP PACKER
4,970
BSAND LINER ,,a
l t6 8-
3,4562
3,55] 2
99
76.NIPPLE RS RACKOFF SEAL NIPPLE
4.875
3,459.1
3,557.9
7695 HANGER FLEXLOCK LINER HANGER
4.853
7,468.9
3,560.1
76,90 SBE 190-47 CASING SEAL BORE EXTENSION
4.750
7,487.8
3,5644
76.98 XO BUSHING XO BUSHING 5.5"x4.5"
3.830
Tubing Strings
TubinO Description
TUBING WO
Sting Ma.,
4.;
lO lin) iop(flKB) Set Depm(fl.. Set Deem lNn)(... WIIIhTf) Grade Top
w"t L-80 IS
39fi 23.1 6,983.4 s538
Ganneclion
Mod
BSAND LINER LEM: 7.29aa
Copletion Details
mTap
747A9_
(ND)
Top RIKED Me)
I Top Incl
p) Hem as Com
Nominal
ID (in)
23.123.1
0,00
HANGER VETCO GRAY TUBING HANGER
4.500
468.9 4625
11.82
NIPPLE CAMCO DB NIPPLE
3.875
6,943.2 3,445.9 I
]958
iNIPPLE CAMCO DBNIPPLE
3812
6,981.7 45341
79.02
I LOCATOR BAKER LOCATOR
3.860
PRoouCTION: 270-8,167.6
6,9834 3,453.8
7904
SEAL ABBY BAKER GBH -22 LOCATING SEAL ASSEMBLY(26.62 ft)
3880
IPERF', dA1.D'Inild
IPER5 s.12s.0eaaTo�
Other In Hole (Wireline retrievable plugs,
valves, pumps, fish, etc.)
--.A
Top SKB)
Top RVD)
(flKB)
TapIncl
l•)
Des
Cam
Run OaW
ID (in)
1,020.0
3,460.8
7948
TYPE
ISOLATION
SLEEVE -0.
BA ERTYP 21 IATIONSLEEVE, 4"GPRO
3.69"ODX UYL
22312019
2.590
LEM
IPERF; asz7GOESSu-
7,353.0
3,53567
78.50
TY
DIVERTER
SLEEVE -B-
BAKER TYPE 1 DIVERTERSLEEVE, 4 G PROFILE,
390"GOX 18.6'L
2/22/2019
3.WK
LEM
Perforations 8 Slots
snot
IPERF;S,PSAG10,7120� I
TOp (flKB) Btm IHKB)
TOP OVER
(flKB)
Oen
Bbn (P/D) (sllotsM
GRKB) LlnFed Zon¢ pNe ) Type Com
7571.0 8,819.0 3,725.0 3)25.5 WB A2, 1E-168 11/112004 32.0 WERE All A en SOaed Liner
IPERRIORel&ITere o �
PERES 25"Lon9z 125"
Wide, 4 d.L.f rows, 7
ranters staggered
18 del.
IPER5n a3a.o-+te3o.0-� 1 1
9,129.0 9,436.0
3,718.3
3,708. WS A2, 1E-168 11/112004 32.0 WERE
9,5270 9,653.0
7708.5
3,711.1 WS A2, 1E-168 11/112004 3.0 IPERE
IPERF:11=0312,ast0_
9964.0 10,]12.0
3,)1].9
3,744.2 WSA2 tE-168 11I11I2004 329 IPERE
10,961.0 11,086.0
3,745.2
3,741.1 WS A2, 1E-166 11/112004 32.0 IPERE
11,335,0 11,830.0
3,734.0
3,3413 AS 672, tE-168 11/112004 32,011P ERE
IPERr;IsMS13,13o.0- Ir
11,923,0 12,8510
Alan..
J"mil WSA2, 1E-188 11I11I2004 3201PERF
IPER51a,31a.o-13,w6.0� r
13,006.0 13, MA
3,7768
3,Jfi7.9 WS 672, 1E-168 111112004 32.0 IPERF
I
13,3430 13,436.0
3,761.8
J)l.b WSA2,tE-168 11/112004 320 IPERF
ARANO LINER', 7%2r0
4]3
AL KUP PROD WELLNAME 1E-168 WELLBORE 1E-168
COnoco r tulips +' ^ Well Attributes Max Angle & MD TD
FIIIa Name W�ellborepP^^WI ----re Stilus cl l°) MOIXKB) pct Btm IXKBI
AI95I(b, lK:. IWFCT CAY c mnnnm n ........ _ _
lE-15511/1 913'.M17PM
Last Tag
'sn_Otl
ll/1ti/LUW
WroaaleMenroadvocce)
Annotation
Deptn(nKB) Entl DeM WeIIMR
Last
LBEI Moa By.....
............. .......................... ._........................... _............._
Last Tag:
1E-168
Last Rev Reason
Rev Reason: BE
LEM ISO SLEEVE
PEI B -L-
An^otaW^
DIVERTER SLEEVE,ET
End Data We11Mre
TYPE D- 2/2312019 1E-168
Leat MW By
wntliw
)
Casing Strings
CONOUCIOR', Spi
NIPPLE; aeeR
GAS LIFT, 4r.2
Lading Oeunpti-
CONDUCTOR
o01m1 ID lml Top dMBl
20 19.12 280
Set Depth MIKSU set Depm (NO)... WE an p... G,aad
108D INTO 6250 ZO
Top mreaa
WELDED
Casing Prescription Do org to (in) TopM B) Set prop InKB) aN CePtM1 ITVBL.. WULen B... Grace
SURFACE 103I4 9.95 27.6 4,414.5 2,4]]6 45.50 L-80
Top TnreeE
BTC
Csin
ag Cesctlption OD (in) ID lint Top Mat Set DepM MKS) set Depth FROR... WULen ILL. Grade
PRODUCTION 518 6.87 27.0 8,157.8 3,J14.3 29.70 L -BD
Tap Tnreea
BTC -M
Z;7
Casing 0¢imiplion OD(in) to (in) Top MKS) set Do INMKB) SN Depth HVD)... MLen R Dome
D -SAND Wintlow 17518 600 7,031.0 7,043.0 3,4655 29]0 LA0
ToaThread
Casing Description
B-SANDWirod.
00(n) to (in) Top lKlcel
7518 6.00 7,353.0
Bet DePM IKKB) Set Death (NDI... WtlLen ILL. G,xle
7,367.0 3,538.2 29.70 L-80
Top Tnreatl
SURFACE a&ipu5
asing DeLariplion
0.6AND LINER LEM
OD ImI ID (In) Top lnleBl
412 3.96 fi,9]62
set DepM (nICBI set Depm lrv0)... WVLen O... c20e
],328.0 3,530.5 1280 L-80
Top rnrW
IRT
Liner DetaNa
GAS Ial. I
Top lXKal ENDS (I TOP and 1'1 Item Dee
6,9]62 3,452.4 ]8.95 PACKER
Cpm
HRD ZXP LINER TOP PACKER wMD SLIPS
Nominal lD
(,a)
3.870
NIPPLE: 6.943a
6,9952
3,456.0
79.17 SBE
CASING SEAL BORE EXTENSION
3.940
LOCATOR: %Ml7
7,020.1
3,460.8
78.47 HANGER
LEM HOOK HANGERS
3.930
7,282.3
3,521.]
79.06 SEAL ABBY
NONLOCATING SEAL ASSEMBLY
3870
TYPE 2 SOLATION SLEEVE-
DTpM;70m0
Casing Description
B -SAND LINER LEM
.0 (in) mlin) Top IXKBI
4112 396 ],2968
Setoepin lKKBI Sat OepM (NDL.. WlMnll... Greae
],479.9 3,562.fi 12.60 L-80
Top Tnraa
IBT
Liner Details
I Wlnmw l,Dv1 G
],049.0
Tap MMB) Tap HVDI GKB) Top Incl rl Item Des
Cpm
Nominate
(inI
7,2968
3,524.4
78.95 PACKER
ZXP LINER TOP PACKER
6230
7,315.9
3,528.1
78.80 SBR
10947 CASING SEAL BORE RECEPTACLE
4.750
o-sAND LINER],oza.a
,
7,334.7
3,531.8
78.65 XO BUSHING
NO BUSHING S.Sx4.5
3.910
1sv.a
],346.3
3,534.1
J85fi HANGER
LEM ABOVE HOOK HANGER
4.020
7,353.1
3,5354
78.50 HANGER
LEM INSIDE HOOK HANGER
4.020
7,404.2
3,5459
]]82 NIPPLE
CAMCODB-B NIPPLE
3,562
o ND LINER LEM: aumgB
mo
7,476.7
3,561.9
76.93 SEALASSY
BAKER SEAL ASSEMBLY
3.890
WPE 1 DIVERTER SLEEVE -B
Casing Description
AAND LINER
S
ODRIQ ID (in) Top IKKB)sm.
412 3.96 )4322
(n.B) Sar- IrvD1... wuLen p._ Grade
13,4]3.01260 L-80
TopTM1re9a
DWC
Liner Details
-LEM', 7 Si3.0
Top MKB) T^pIND)InKBI
TOp Ind P) @m Des7367C
Com
No'iln'l10
B 6PNa WinMx:Tgoo,
],43)2
3,553.0
]].30 PACKER
TUG ZXP LINER TOP PACKER
4.970
B swO LINER ',ZSS.&
ttsn0
7,4562
3,557.2
]6.99 NIPPLE
RB PACK FF SEALNIPPLE
4875
7,459.1
3,55].9
76.95 HANGER
FLEX LOCK LINER HANGER
1 4.853
7,468.9
3,560.1
]6.90 BBE
19047 CASINGSEAL BORE EXTENSION
4]50
],48].8
3,5644
]fi.98 XO BUSHING
XO BUSHING 55"x4.5"
3.830
Tubing Strings
BSANDLINERLEM,7,�&_
Tabmg Dcepnptipn string Ma...
TUBING WO 41/2
m(inI Tpp MR -1 set Depm(".. sd DepMliv 1... wtpoint Gmaa Tap epnnadmn
396 23.1 fi,983.4 3,453.8 12.30 L-80 T.IC-
Completion Details
T<Ta_B
TOP I
Top MKB) I.
23.1 23.1
TOPInd
1°I
0.00
arm Des
HANGER VETCO
Com
GRAY TUBING HANGER
Nominal
to (in)
4.500
468.9 467.5
11.62
NIPPLE CAMCO
DB NIPPLE
8875
6,9432 3,445.9
78.58
NIPPLE CAMCO
DB NIPPLE
3.812
6,9811 3,453.4
79.02
LOCATOR BAKER LOCATOR
3.880
PRODUCTION', VAB,Roe
6,983) 3,453.8
79.04
SEALASSY BAKER GBH-
22 LOCATING SEAL ASBEMBLY(2662 f)
3880
Other in Hole (Wireline retrievable plugs,
valves, pumps, fish, etc.)
IPERF', 5,5]108,0180 1T^PITVD)
(PERF; e,1a6B.a -i
Top mKB)
7,020.0
Mae)
3,4608
Lww (•I
78.48
Des
TYP 2
ISOLATION
SLEEVE-D-
Cpm
BAKER PE2150LAT1 NSLE VE, 4"GP FILE,
3,69" Do X HyL
Run Data
2232019
ID gn)
2.590
LEM
mERFI Ssn G9,esa.0-
7,353.0
3,535.4
]850
TYP
DIVERTER
SLEEVE-&
BAKER TYPE IIVERTER SLEEVE, 4'G PROFILE,
3.90"ODXHHyL
22212019
3.000
LEM
I
Perforations & Slots
Snot
IPENF;9,as4&IO.7120�
Top MKO) Bhn (aHB)
Top lTVDI
(nKB)
atm llv0l
MKB) Linke]Zone
Dens
hdgi
Date ) Type Co.
8,571.0 8,8190 3,]25.0 3,725.5 WB A2, 1E-168 111112004 320 WERE All A-Santl Slonetl Liner
IPERe 1Daeto-ry am.o
PERFS 25" Long x .125 -
Wide, d dateanf rows, 3 -
wERe n,asslsn.moo_ t t
centers staggered
18 deg,
9,129.0 8,436.0 3,]183 3,7087 WS A2, 1E-168 11/1112004 32.0 IPERF
8,527.0 9,653.01
3,706.5
3,711.1 AS A2, 1E-168
11/112004 1 32.0 1 PERF 11
NERF; I L923.0-12,11pi
9,964.0 1g712B
3,717.9
3,744.2 WSA,1E-168
11/1112004 32.0 WERE
10,961.0 11,086.0
3,]45.2
3,741.1 WS A2, 16168
11/112004 U.D IPERF
IPenP:1a'Bm.O1>,13xo-
11,335.0 11,830.0
3,]34.0
7,741. WS A2, 1ET68
111112004 320 IPERF
11,923.0 12,651.0
3,7488
3,]69.] WSA2, 1E-168
11/1112004 32.0 IPERF
PERE13.3a3CLA436o�
13,006.0 13,130.0
3,J7g.8
3,7629 WS A2, 1E-188
11/112004 3.0 IPERF
13,343.0 13,436.0
3,7618
3,]625 WS P2, 1E-168
11I11I2004 32.0 /PERF
hsNJO LINER;3.473 -
1 3Aia0
ConocrPPhillips KUP
Alaska, k1D.
PROD WELLNAME 1E-168 WELLBORE 1E-168
1E-168,1111 ID191225'.17 PM
Mandrel lnsJ
venwlenhanmMll
IN
MI
............
NAN3ER; i31
..............
en
ry
TopjN01 VeNe
La4N
(2,42 Meke MaC¢I OD pnl Sery Tye
jP.l.)-jTR(Ops.i)TOPME)nj
Ty(In
Run Ogle Lom
1 42702
2,423.5 JCAMCO KBMG 1 GAS LIFT GLV
BKS 0.188
1,5310 2/2012004
2 8,)08.1
3,3839 1 CAMCO KBMG 1 GAS LIFT OV
BK50250 0.0 2/201200]
Notes: General
& Safety
End Dale
Annomfon
CONDUCTOR. MD10Ba
1212312004
.DTETRI-LATERALWELL:1E-168(ASANO), tE-168L1(BSANDj,
1E -16812(D -SAND)
NIPPLE, 40B9
yp41200y
NOTE View Schematic wl Alaske SchemaGc90
BAS UFr; N.n69
SURFACE n6Q4145
DAS LIFT', s]W.1
NIPPLE SUNS
LOCATORS.
TYPE 2ISOLPTONSLEEVE -
O LEM; ],OM.O
D -SAND Wtr 7031D
7m3.D
D SPNO LINER; 7,0I9.1
n.2as
D DLINER LEM:0.R2-
TMC
TYPE I DIVERTER SLEEVE -8
-LEM; ],3 .
a SEND Wi.. 7 SPUD
],3670
8 MIND LINER ],ffiE-
1' 0
BbANO LINER LEM; ]958.8
7,4789
PRODUCTION, YI. De,1570
IPERF', B571 De,Sgo0
IPERF; 9, 2P 69436.0
IPERF; 8.597.68 EDtI
IPERF 8,964.61B71Z0�1
IPERF: IDM,D11,0EEC
r
IPERF: 11. 611,630.0-4
1
PERE: 1182.0.13651. D�
I
1
IPERF. 13.0Sa6131W.0�
IPERF. 13,% DlO.4S8,0�
ASANO LINER, 7.4373-_
13A7a0
KUP PROD WELLNAME 1E-168 WELLBORE 1E -168L1
Cbma;Phillips tL. Well Attributes Max AngleBMD TD
1" Fleltl Name WeMllb°e...n IWI %,Mre ablua ax gle&) !1°l abn (%HBI
Na$kP,IrIC. WFCT it 5 :aanAppun nenn .. ,..
ISAM1, 11N/N1912SE to PMLast
Tag -,.�� ........�vv.
wreal xbamroe semi
Annohtbn I Demp RrIU) I
End DabWallb°re Lint Marl By
.............................................._.................
Last Tag- 10,1040
22312019 1E-16811 Condilw
as ReV Reason
HANOEre YI.I
AnnO im
end Dab WaIINre
Lut Mail By
REV REASON: SET IBP, PERF .......
PUMP23BELS 8.6 PP L RALITE
CMT FOR MBE TREATMENT.
70W019 1E-16811
aappleh
Casing Strings
Canine 6esanppon OD in, Imnl Top(%KIR semepm(.KB) set Depen(TVD)...iNmen p._Orzde TOPTbread
B -SAND LINER 4112 3.96 7,3528 10 3,582) 12.60 L-80 OWL
Liner Details
CONDUCTOR; MOLISE0
NOminallD
Top (XKR) To, (rvm (XKa) I To, per I') I team Des Cam (in)
NIPPLE aea.9
7,352.8 3,53541 78.51 HANGER I BAKERMODEL B-1 FLANGED HOOK HANGER 4.500
7,3795 3,540.5 8028 SWIVEL BAKER TORGUE-THRU SWIVEL 3958
DAs uST;az7o.a
11,888.0 3,582.0 8873 BUSHING BAKER DRILLABLE PACKOFFBUSHING 3.958
11,906.1 3,5824 88.90 X045x35 3.500
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
T°I".K.l r°p mal
Top (XKB)
(flNB) ('1
Oes Cam
pun Oale
ID (in)
10,692.1
3,552.3 90.29
Intiatable plug TAM 1812.190"X)91'SETATI 700'CTMD
712512019
12512019
SURFACE: C7 Wp14S
Perforagons B Slots
Sba[
cas LIFT: aTml
Tap mKB)
Bim (XKB 1
Top [TVD)
MKB)
Bim (rvD)
(XKB)
Linked zone
..to
Den
(snOlsm
)
Tyce
Com
7,447.0
10,673.0
3,550.6
3,552.5
W B, 1E-
1111712004
320
(PERF
Slodatliner, .7 Lx 125"
16811
W, 4 circomf NN, 3"
NIPPLE; 6,e1M 2
centers staggered 18 deg
10,645.0
10,650.0
3,5532
3,553.0
WS 8,1 -
168L1
7/2512019
BO
APERF
2 p hmx 2"6 spf 5'
PERF GUN
LOCATOR.6.0817
10,8600
11,886.0
3,556.5
3,581.9
W 8,1 -
1111]12004
320
IPERF
Sorted Line,, 2."Lx.
16811
W.4 circpmf rows, 3"
centers staggered 18 deg
Cement
Squeezes
T"'T" to(rvD)
lYPE 21aOLA90N SLEEVE
Top (hKB) Bhn (XKB) (rtKB) (XKB)
Oes
abrt0ate
Com
DLEM: 7.000
10,150.0 10,]000 3,554.3 3,552.2
Liner Cement 1112512UI9
16.b PPG ULTRA LITE CRETE
Notes: General 8 Safety
o Mc Whew 7,C1.D
7,00.90
Em Dah Annamdon
12232004 NOTE: TRI -LATERAL WELL IE -168(A -SAND), 1E-16811(8-SAND),1E-168L2(D-SAND)
22412009 NOTE: View SChCmaticw/Alaska ScheNmbC9.0
7252019 NOTE: EXTENDED CEMENT PLUG IN LINER AND OPEN HOLE from 10,150 to Io,7w
o-SANCUNEE 7.Dids.
n.93e.
OSWO LINER LEM', 6, MLS.
7=0
TWE t DIVERTED SLEEVE -S
LEM; 7,39]0
6SANC Weswv],3SD
7.33! 0
L -SMD LINER LEM; 7,SM.6
r 9a
a7
PRODIMMON: n 06,1576
IPER07,'
1"'U" we
Icer Cemen[ 10,1"d0 we
Opan Ktla Cement; In IssO
MERi;10ars 61a.6W.0�
InPobde Mut, 10,m21
IPERF; tOEpi 1,88SO
&SAND LINER; 7.359.6
11.9Y10
Proposed 1E -114L1 to 1E -168L1 RPPG B MBE Treatment
1 E-1 14L Tri-Lat injector has 4.5" L-80 tubing & slotted liners set in West Sak D, B, and A sands. An
occurred 3/20/06 in 1E-1141-1 to producer 1E-1681-1. A 4/12/06 IPROF in 1E-1141-1 found B MBE at
—8690' RKB where all PWI exited the liner. An IBP intended for set in A Lat in preparation for a B MBE
treatment inadvertently entered & set in B Lat (without B Diverter), then became a fish —400' above B
MBE that we could not pull.
Attempts were made to seal the open B MBE by trying to pump treatments around the IBP fish.
Molten wax was pumped down CT 10/10/10 from above IBP fish, then CT pumped Crystal Seal
treatment on 7/27/12 from B Lat window because CT could not pass through B Diverter. Both of
these MBE treatment attempts failed most likely due to poor access to pump to the MBE and due to
the relatively small treatment volumes that were pumped.
The IBP fish was eventually POOH on 7/10/17 using CT hydroshock tool to free it, then a Plug was
set in the main -bore between B & D Lats to put 1 E-1141_2 D Lat on PWI until the Plug was pulled
4/18/18 to reconfigure 1 E-114 to current configuration with a B Diverter set, and a D Iso-Slv set. Due
to inability to successfully drift a Plug by the B Lat window, the A Lat has been left open. Efforts to set
Plugs in the A Lat continue to result in apparent entry into the B Lat without a B Diverter set.
It is now proposed that a fullbore RPPG treatment be pumped to seal the B MBE at 8690' RKB.
Procedure:
Coil Tubing ®rOXf41
1) RIH with Perf Gun & shoot a 5' OAL of perforations in 1 E -1 14L1 B Lat slotted liner at 8690 - 8695'
RKB, at 6 spf, 60 deg ph, to enable RPPG slurry to enter B MBE. POOH w/gun. Verify ASF. RD CT.
Pumping
2) At —12 hours before RPPG B MBE treatment, place 1 E-1141-1 on PWI at 1000 BWPD to displace
gas head and Diesel FP from tubing to open B MBE at 8690' RKB, and to lower WHP on tubing.
MIRU mixing van and pumping equipment on 1 E-114. When ready to pump RPPG job, SI 1E -114L1
and verify that 1 E-168 offset producer to open B MBE is also SI, then begin fullbore RPPG treatment:
a) 133 bbls of Lead ultraclean 2% KCL Brine at 1 to 4 bpm (depending on bpm needed to let the
pump keep up with the apparent Vac rate), to displace remaining gas & Diesel from wellbore to
open MBE and to flush all PWI (with any residual hydrocarbons) away, followed by
b) RPPG slurry mixed in ultraclean 2% KCL Brine at a steady rate within the range of 1.5 - 3.0 bpm.
Slurry will be mixed into Brine to keep —0.75 lbs/gal concentration while making slurry `on -the -fly'.
c) Continue pumping steady rate & slurry concentration until WHIP reaches 500 psi, then determine
when to call Flush based on monitoring rate of increasing WHP as RPPG seals MBE, then
d) Call Flush and swap to 82 bbls of 2% KCL Brine displacement pumped down tubing at the same
established constant rate (to continue monitoring WHP build at constant rate), followed by
e) 51 bbls Diesel FP / displacement at the established constant rate, followed by Shutdown.
Wait 48 hours for swollen RPPG particles to fully crosslink in B MBE to form a continuous stout
amalgamated non -flowing gel plug in the B MBE, before returning 1 E-114 and 1 E-168 to service.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑
Performed: Suspend ❑ Perforate 171 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑
Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: CEMENT MBE ISOLATION
2. Operator 4. Well Class Before Work: 5. Permit to Drill Number:
Name: ConocoPhillips Alaska, Inc. p Exploratory ❑ 204-201
Development ❑ Ex lorato
3. Address: P. 0. BOX 100360, Anchorage, Stratigraphic❑ Service ❑ E. API Number:
Alaska 50-029-23230-60-00
7. Property Designation (Lease ase Nu Number): e. Well Name and Number:
ADL 25651 KRU 1 E -168L1
9. Logs (List logs and submit electronic and printed data per 20AAC25.071y 10. Fieltl/Pool(s):
11. Present Well Condition Summary: N/A Kuparuk River Field / West Sak Oil Pool
Total Depth measured 11,969 feet Plugs measured None feet
true vertical 3,583 feet Junk measured
None feet
Effective Depth measured 11,888 feet Packer measured NONE feet
true vertical 3,580 feet true vertical NONE feet
Casing Length size MD TVD Burst Collapse
CONDUCTOR 80 feet 20 108' MD 108' TVD
SURFACE 4,387 feet 10 3/4 " 4,415' MD 2478' TVD
PRODUCTION 8,131 feet 7 5/8 " 8,158' MD 3714' TVD
B -SAND LINER 4,574 feet 4 1/2 " 11,927' MD 3583' TVD
Perforation depth: Measured depth: 7447-10673. 10§45.106$0.10860.11886 feet
True Vertical depth: 3551-3552, 3553-3553, 3556-3582 feet
Tubing (size, grade, measured and true vertical depth) 4.5 " L-80 6,983' MD 3,454' TVD
Packers and SSSV (type, measured and true vertical depth) N/A
12. Stimulation or cement squeeze summary:
Intervals treated (measured): N/A
Treatment descriptions including volumes used and final pressure:
13. Representative Daily Average Production or Injection Data
Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation: SHUT-IN _
Subsequent to operation: SHUT-IN _
14. Attachments (required per 20 A C 25.070, 25.071, 8 25.283) 15. Well Class after work:
Daily Report of Well Operations O Exploratory ❑ Development O Service ❑ Stratigrephic ❑
Copies of Logs and Surveys Run ❑ 16. Well Status atter work: Oil p Gas ❑ WDSPL ❑
Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑
[Autho�zed
ereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
319-294
zed Name: John Peirce Contact Name: John Peirce
Tide: Sr. Wells Engineer Contact Email: John,W.Peirce@cop.com
Authorized Signature: — Date:`r3Z / I, Contact Phone: (907) 265-6471
� �
!T/
Orm lU-41Llgaevised 4/2017' r/ -/ r 7 r L
"W$�` tt1 RBDMS Submit Original Only
4 AUG 131019
NIPPLE JOB JBI ILMM
I.-ne.ar Ia1Ra3s Aa
KUP PROD
WELLNAME 1E-168
WELLBORE
1E-168
/s��� 111
l.vr IaA.Vrt rIIIIpS
I"'I
Well Attribute.
Max Angle 8 MD
TD
N85k8. IVIG.
.
IiMl0 Name
WEST SAN
IW¢IIMre APNIWI IWallOera Slalus
500J923930N0 PR110
ncl-1 Mp'flK el
JR] ++ +a v
Ac[BIT MR.,
+nen
NIPPLE JOB JBI ILMM
I.-ne.ar Ia1Ra3s Aa
Last Tag
V^"uul ve-s.I ,
Anticipation DepMMe) i End Data ondleme
Last MW Be
.......,.. .__._.
.
Las1TB9:
tE-168 lorpostoor
ImxGER; m.1
Last Rev Reason
Rentaltllon EM DaM
WeIIMre
"at Moe Ry
Rev Reason: SET TYPE
LEM ISO SLEEVE
I B-LEM
DIVERTER SLEEVE, SEIYPE 2D- 92312019
1E-168
Ommarw
Casing Strings
C.Mc.h..gi
Rep.'. sane
C9emy Description
CONDUCTOR
oD (tn) ID(al Top of IDepth (fil sn Depth RVD)...wuLee(L.. G mae
20 1912 28.0 1080 VLSI 62.50
Top Timed
WELDED
Closed essential
SURFACE
nOlin) ID (in) Topl fee.) .1 Chon, Mi Bet DIN IN01... WOien IN.. Imes
10314 995 276 4,414.5 2.4]]6 45.50 L-80
Top Thread
BTC
GAS Ul a.=2
CasYd 0-,.tlan
PRODUCTION
0. (in) 10 (in) To it ) Ret Depth Mile Bet Death (PAN WtlLen ll... Grade
]518 6.87 270 8,157.6 3,7143 29.70 L-80
TaPTneeae
BTC -M
Casing Deacrlptbn
DSAND Window
OD (in) 1D had Top MB) set Depth (Man Ret Dada RVO)... WtlLsn 9... Onde
7518 600 7,031.0 7,043.0 3,4655 29.70 LSD
Tap Thread
CUIng Oex.p
BSANDWindow
OD(In) ID9n) Topn1KB) Bet Depth MKS) Bet Depth Pral WM1len(I... Grade
750H 60) 7,353.0 7,387 0 3,538.2 29.70 LSO
Top Topped
.RFACE; Val
Opened DMalimme
D -SAND LINER LEM
GD MI to (m) Thiel BN DepN lnxel 56 Depth IND)... Mail L_ Chase
4112 3.96 6,976.2 7328.0 3,530.5 12.60 L-80
Too Thread
IBT
Liner Details
GA5 un: e.]ae.+
Nominal ID
Top (WO) Top lrvD)Iro
Le)
rop lncH•) Iam Ods Co.
(in)
NIpPtE:a.p4a.Z
6,976.2
3,4524
78.95 PA KER PRD ZXP LINER TOP PACKER w/HD SLIPS
3.870
6995.2
34560
79.17 SBE CASING SEAL BORE EXTENSION
3.94
LOCATOR', pan?
7,020.1
3460.6
7847HANGER LEM HOOK HANGERS
3.930
7,82.3
3,521.7
79.Ofi SEAL ASSV NON -LOCATING SEAL ASSEMBLY
3.870
eacine Dexngion
oo(ln) IO (in) Top InKB) SN o6ldn lflKB) Ret DepinlNO)_. WVLen IL.. GrgleITopTimened
TYPE vsouTloN KEVE-
B -SAND LINER LEM
4112
3.96 7,296.8 7,479.9 3,562.6 1260 L-80
DIEM; Tomo
Liner Details
o ND Wrvlov, 7 O
Rommel to
TOO o-`
Top MKB) Top(1VD)IBKB)
Toppal Miami pee Com
(in)
7,296.8
3,524.4
78.95 PACKER ZXP LINER TOP PACKER
6,230
7.3159
3,528.1
78.80 TBR 109.47 CASING SEAL BORE RECEPTACLE
47K
7,334.7
,531.8
7865 To BUSHING XO BUSHING 55x45
3910
D DLINER; Tool
....e
73463
3.571
7855 HANGER LEM ABOVE HOOK HANGER
4020
7353.1
3,5 54
78.50 MANGER LEM INSIDE HOOK HANGER
4.020
7.4042
3 S457
7].82 NIPPLE CAMCO DBS' NIPPLE
3.562
e NOONERLM.g.M.Z.
mo
7,4767
1.
76.93 TEAL ABBY BAKER SEAL ASSEMBLY
3890
Casing oesarlgan
Dp 11n)
rolln) rop OIKBI Bet Depu nnt8) Bet DeptnlrvD)... Wmxn lL.. Dade
rop rn,eae
ASAND LINER
412
396 7,4372 134]30 3,>63t 12.80 L-80
DWC
TYPE I WVERTER RLEEVE-B
Liner Details
-LEM',].359.0
B3nNOWMc-, ],351,6
E99Zo
icpinNB) raplrvD)(n.e)
Top Incl ') Idem Dab Com
urinal lD
(in)
7d3>.2
3,5530
77.30 PACKER HED ZXP LINER TOP PACKER
4970
Bs411DUNER;1354B
TMO70
)4562
,55)2
76.99 NIPPLE RS RACKOFF SEAL NIPPLE
4.875
>,459.1
,5579
7695 HANGER FLE(LOCK LINER HANGER
4.853
),.68.9
3560.1
7690 SBE 190-0] CASING SEAL BORE EXTENSION
4.750
>d678
3,5644
76.98 XO BUSHING NO BUSHING 55x4.5'
3.830
Tubing Strings
TUEing Dascllpllon
TUBING WO
Rklny Ma...
412
IDNnj Top lflNBj Ret Depth lfl..Set Depth nevi I... 041 LonGmde
3.96 23.1 6.9834 34538 N, L-80 IBT
Top Conn¢C pan
Mod
B SAND LINER IEM 7.391
Completion Details
1488
Top TilTop
Incl
Nominal
sop PART pmt
V)
how One Co.
to(,,)
23.1 23.1
0.00
HANGER VETCO GRAY TUBING HANGER
4.500
468.9 467.5
1162
NIPPLE CAMCO DB NIPPLE
3.875
6,943.2 3,4459
78.58
NIPPLE CAMCO OR NIPPLE
3.812
6,9817 3,4534
79.02
LOCATOR BAKER LOCATOR
3.880
PRODUCTIONn0ILIUS
6,983.4 3,4536
79.04
SEAL ATTY BAKER GBH-22LOCATING SEAL ASSEMBLY (26.62 K)
3.880
Other In Hole (Wireline retrievable plugs,
valves, pumps, fish, sic.)
Top MKB)
TopIND)
Mil
Topind
I-)
Them
Cam
Run Den
ID9n)
IPERKRID1115.11h.
7,020.0
3,460.8
7848
TYPE2
BAKER TYPE 2150LATION SLEEVEP=
22312019
2.590
IPERF', O,1H 08,4%01
ISOLATION
SLEEVE -D-
3.69"OD X 19'L
LEM
7,353.0
,535.4
)8.50
TYPE 1
DIVERTER LEE IL
2/22/2019
3.000
IPERF.G.R210,9.6610
DIVERTER
SLEEVE -B-
3.90.OFT X 186'L
LEM
Perforations 8 Slots
shot
Dens
IPERL ORM110]120
�-
TWMa) .Meeh)
TOpnVD) Bon Dvo) phdmm
Ifil 91KB) HnMad Zore Doh ) Type Can
8,571.0 8,819.0 3,]250 3.725.5 WS A2, 1E-168 Un I20B4 32.0 PERE nd toned Liner
IPERF, Iace+on.oaao�
PERFS 2.5" Long x .125"
Wide, 4 aphl real 3"
Centers staggered
18 deg.
IPENFl+1.395pus0o�
I
129.0 9,436.0
3718.3
J, 708.7 WS A2, IEE -1 111112004 320 WERE
9,527.0 9,653.0
3,]085
)711.1 WS A2, 1E-188 1111112004 3201PERF
RF n
IPE,9ot.ol ZM10� 1
. 64.0 10.7120
3,7179
37 44.2 WSM 1E-188 7711117W 32.0 (PERE
t 0,9610 11,086.0
37452
3,]41.1 WSA2, 1E-168 111112004 320 IPERE
11,335.0 11,830.0
3,734.0
37413 tE-168 %nii 1111112004 320 IPERF
IPERF; I3,WRD13.13]0�
11, 3.512.8510
3,7488
37697 WS A2, 'E -hp, 111112L04 320 IPIRF
IPEBR 13,3un+3,n80-
13, .0 13.130.0
37708
,)6).9 WS A2, 1E-168 111111 32.(1 IPERF
13,343.0 134360
3761.8 3,762.5 046 AZ. 1E-168 1111112004 1 1 V 1111,.P
A,IAND LINER; p'
Tion
13. AT 0
KUP PROD WELLNAME 1E-768 WELLBORE 1E-168
COI10CciPhillips
Alaska, IRC.
WVIOER, 23.11
ws u".
3VRME: Pf
CME LIFP,
NIPRE:
'E2 VOIATION SLEEVE
O EM:].OA.
o.I)w.ec., 3.mu
B-VVIDLINER
IPERF,
IPERF: S.w Va.BS3.0�
IPERF:.. 0101120
IPERF', IDW O11,BB40�
IPERF: 11,33,0-1 I,= 0�
IPERF: II.3 l2.10��
IPERF: I3,M.0.13,130.0��
IPERF:13.3f30'130. 0�
Make I Maeal IOD(In)l Bery I Valve Nee I k
1 E-1 68L1
CEMENT MBE ISOLATION
DTTM JOBTYP SUMMARYOPS
START
7/24/19 ANN MIRU CTU. INSTALL BHA #12.25" OD DOWN JET NOZZLE
COMM WITH XVR INTO RISER AND BOPS. PT. RIH WITH 2.25" OD
DOWN JET NOZZLE WITH XVR. INTO LATERAL #1 TO 11,900'
CTMD PUMPING MI SAFELUBE. POOH. JOB IN PROGRESS
7/25/19 ANN RIH WITH TAM IBP, COULD NOT GET THROUGH THE B SAND
COMM
WINDOW, POOH RECONFIGURE TOOL STRING, TOOK OUT
ONE KNUCKLE JOINT AND PUP JOINT, RBIH SET IBP AT 10700'
CTMD, POOH. MAKE UP 2006 PF HMX 2" 6 SPF 60* 5' PERF
GUN, RIH LIGHTLY TAG IBP AT 10692' CTMD, PU AND PARK AT
10650', DROP .5" BALL TO FIRE GUN, SHOOT HOLES AT 10650'-
10645'. POOH, FREEZE PROTECT WELL. LAY DOWN PERF
GUNS(GUNS FIRED) . RDMO.
7/26/19 ANN
MI RIG UP. PERFORM WEEKLY BOP TEST. INSTALL TUBING
COMM
CONNECTOR. PULL TEST AND PRESSURE TEST. INSTALL
BHA #1 INFLATABLE CEMENT RETAINER INTO RISER AND
BOP. STAB ON WELL.
7/27/19 ANN
PARK AT 10150' CTMD, DROP .5" BALL TO SET ICR, AFTER 70
COMM
BBLS DID NOT SEE BALL GO ON SEAT, DROPPED SECOND .5"
BALL PUMPED 68 BBLS DID NOT SEE IT GO ON SEAT. STACK
DOWN -10K SURFACE WT. APPEARS ICR IS SET, GET A 5K
OVER PULL ON ICR. START INJECTIVITY TEST..5 BPM WHIP
320, CTP 399 PSI, IA 500, OA 142, 1 BPM 1000, WHP 330, IA 499,
OA 142. BATCHED UP 23.5 BBLS 8.6 PPG ULTRA-LITECRETE
CEMENT. PUMPED 22.8 BBLS THROUGH RETAINER, TRY TO
UN STING FROM RETAINER AND COULD NOT UN STING.
FINALLY GOT PIPE MOVING OUT OF HOLE. AT SURFACE WE
RECOVERED 2.5" BALLS AND HAD THE ICR STILL ATTACHED
AND NOT INFLATED. RDMO. LEAVE WELL SHUT IN FOR MIN 3
DAYS.
THE STATE
°fALASKA
GOVERNOR MIKE DUNLEAVY
John Peirce
Sr. Wells Engineer
ConocoPhillips Alaska, Inc.
P.O. Box 100360
Anchorage, AK 99510-0360
Re: Kupanrk River Field, West Sak Oil Pool, KRU 1E -168L1
Permit to Drill Number: 204-201
Sundry Number: 319-294
Dear Mr. Peirce:
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax 907.276.7542
www.00gcc.olaska.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, n �,
12: �hmielowski
Commissioner
DATED this 1 day of June, 2019.
RBDMSt-' JUN 18 2019
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
m "E-, EPE� U71H D
JUN 12p90019 p
AOG
1, Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑
Suspend ❑ Perforate p • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑
Plug for Redrill ❑ Perforate New Pool ❑ Reenter Susp Well ❑ Alter Casing ❑ Other: CEMENT MBE ISOLATION D
2. Operator Name:
4. Current Well Class:
5. Permit to Drill Number:
COnocoPhilli sAlaska Inc.
Exploratory ❑ Development o•
Stratigraphic ❑ Service ❑
204-201'
3. Address:
6. API Number:
P. O. Box 100360, Anchorage, Alaska 99510
50-029-23230-60-00
7. If perforating:
8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool? N/A
KRU 1E -168L1 '
Will planned perforations require a spacing exception? Yes ❑ No D
9. Property Designation (Lease Number):
10. Field/Pool(s):
ADL 25651 '
I Kuparuk River Field / West Sak 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):
11,969' 3,583' • 11888
3580
1500psi
NONE NONE
Casing Length Size
MD
TVD
Burst Collapse
Conductor 80' 20"
108'
108'
Surface 4,387' 103/4
4,415'
2,478'
Production 8,131' 75/8
8,158'
3,714'
Liner 7,353' 41/2
11,927'
3,583'
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Tubing Size:
Tubing Grade:
Tubing MD (ft):
7447-10673,10860-11886
3551-3552, 3556-3582
4.500"
L-80
6,983'
Packers and SSSV Type:
Packers and SSSV MD (ft) and TVD (ft):
PACKER - N/A
N/A
SSSV -NONE
N/A
12. Attachments: Proposal Summary Wellbore schematic
13. Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑
Exploratory ❑ Straligraphic ❑ DevelopmentE] . Service ❑
14. Estimated Date for 7/11/2019
15. Well Status after proposed work:
Commencing Operations:
OIL B 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: John Peirce Contact Name: John Peirce
Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com
9 ��_ Contact Phone: (907) 265.6471
— `%
Authorized Signature:, �'�ZJ Date: �0 12-1.
—COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑L✓�
Other:
Post Initial Injection MIT Req'd? Yes ❑ No ff-1, RBDMS 1 JUN 18 2019
Spacing Exception Required? Yes ❑ No Subsequent Form Required: pQ — gOy
APPROVED BY
Approved by:
COMMISSIONER THE COMMISSION Date: /
0 V7-1- 0// 3 // 9 M U I N A L
Submit Form and
Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate
KUP PROD WELLNAME IE -168 WELLBORE 1E-168
ConowPhillips
Alasia,lrlc
tE-18.9. &1PA19248S1 PM
Last Tag
Vwhalaclmuz ls0all
AnAola+bn
Oa FOM(B) 1 EMOab wMIW,eLast
Mod By
__... ._. .............
__......
Last Tag:
1E-168
ImwbOr
Last Rev Reason
HANGER:2T
AmroYlbn
IntlI
Wellbore
loci Mad By
Rev Ree0C, V
1B-LEM DIVERTER SLEEVE SET TYPE
2/2312019
1E-168
Coedilei
LEM ISO SLEEVE
Casing Strings
Cpine DORPOlbn
CONDUCTOR
OD (in)
20
101m) Top IM6) SATUEFOMNel SN Cn,or NOL, WARI 11... G. Top Tbmd
1912 280 108.0 108.0 62.50 HAD WELDED
CPNDVCTOR.m61mD
NIPPLE; 4611.0
Casing 0eaa,Waan
SURFACE
OD (in)
10314
mlin) Top(Mlel Set Depth MR.) SN cept11 mod SpU-R Grade Top OSSN"
9.95 27.6 4,4145 24]].6 4550 L40 BTC
GASUFT,4CRI
Casing DIPPARObn
PRODUCTION
OD (in)
7518
1011") Top(M161 Set Depth MKS) SN odpMEnd) .-wtlLen ll... G. Trip TM1rea]
687 27.0 8,157,6 3,714.3 29]0 1410 BTCW
Casing Ceec,IpWn
00(1.)
10(1.) Top ROUD SN MOO MKS) sM Depth ITVDI... wpLn ll... G,ade Top T;hs
DSANDWOdow
7518
6.00 7,0310 ],0430 3.465.5 29.70 LA0
Caainp Dii-1plion
B -SAND Window
00 (in)
75M
0(in) Top@Kel SO deptn ME) Bet OepN MCI-wMenO_. Gude iopT Non
(L00 7,353.0 7,3670 3,538.2 29.70 L40
CI D-Hrlion
wpn)
10 on) Top MRS) SO Depth genal Ba oeNomAd- wo-en(L Gude Top Thread
SURFACE: n 644x5
D -SAND LINER LEM
412
396 6,9762 7,3280 3530.5 1260 L40 IBT
Liner Details
WSDFT;B]09.1
N.-oRID
Top ROSS) Top (TVD)MKe)
Top bol P) 1Mm DES Com
(in)
NIPPLE; 6,9402
6,9762
3,452.4
]8.95 PACKER HRD ZXP LINER TOP PACKER wIHD SLIPS
3.870
6,995.2
3,456.0
]9.1] SBE CASING SEAL BORE EXTENSION
3.940
LOCATOR; 6Ev
7.020.1
3460.8
78.47 HANGER LEM HOOK HANGERS
3.930
],2823
3521]
]9.06 SEAL ASSY NON-LOCAT ING SEAL ASSEMBLY
3.870
Coning Desulptun
OO lin!
1011n1 Tap1aped SNDeghIMt01 Set DepN INDI-. WIIL in 11-jeoida Top TbrOd
TYPE21SOLATONSLEEVE-
l
8 -SAND LINER LEM
4112
396 ],296.8 ],4]99 3,562.6 12.60 L-80 ST
Liner Details
PLEM12ood. L
DSPND WrN-] Wt P
,00.o
Top MUST Top(TVC)MASI
Topindl°I Ittm Dea Com
Nominal IO
did
7,296.8
3,5244
78.95 PACKER ZXP LINER TOP PACKER
6.230
7,315.9
3,5281
7880 SBR 10947 CASING SEAL BORE RECEPTACLE
4.750
7,3343
3,531.8
7865 XO BUSHING XO BUSHING 55x4.5
3.910
DSANDUNFSJ.o
ns3s.a
7,3463
3,534.1
7856 HANGER LEM ABOVE HOOK HANGER
T.020
7,353.1
3,5354
78.50 FARM LEM INSIDE HOOK HANGER
4.20
7,4042
3,545.9
77,82 NIPPLE CAMCO'DBA'NIPPLE
3.
o-snxO USER IEM: ESRN2
7,4767
3,561.9
7693 SEAL A Y BAKER SEAL ASSEMBLY
3890
7,=0
Casing Oesc,.P+bn
ODllnl
ID lin) Tap (M(81 BM Dept"IKKBI SITDORU INDI WIILen 11... Glade Top Tr -d
A -SAND LINER
412
3.9fi ],43]2 134730 3,7631 1260 L-00 DWC
Liner Details
TYPE t DIVERTER SLEEVE -B
Nomina110
iEM: T3S1.0
B'SANDIAS ;2m9.P
To, IhNBI Top (Pird(
O)
Top Incl l-) Item Che Com
(In)
7'SoO
7,437.2
3,5530
7730 PACKER RED ZXP LINER TOP PACKER
4.970
62940 uxEq:2a2.P
7.4562
3,557.2
7.9 NIPPLE RS PACKOFF SEAL NIPPLE
4.675
IT Mo
7.459.1
3,5579
7695 HAN ER FLEXLOCK LINER HANGER
3
7,468.9
3,560.1
76.90 BE 19047 CASING SEAL BORE EXTENSION
4.750
7,487.8
3,5644
7698 X BUSHING XO BUSHING 5.6x4 S
3.830
Tubing Strings
TnMng Dempoon So -mg Ma...Mlb)
ropl(MID SN Drom(R..sdoept('.NL.wl 011e)
TOPCo.nectbn
TUBING WO 4112
loon.
39fi 231 6983.4 3,4538 1230 L-80
10T M0tl
Completion Details
b3ApDUNENUA,7.KdS
7.4]9.2
IF IN0)
Topbai
Nombal
SEA
TopIhKO) gIKBI
11
I+em CesgLOCATORCo.
IDDro
23.1 23.1
0.00
HANGER VETCOING HANGER
4.500
4689 467.5
11.62
NIPPLE E
3.875
6,941.2 3,445.9
70.58
NIPPLE E
3. 1
6,981.7 3,453.4
79.02
LOCATOR
3880
PROO.cnOx: Z]oE.15>S
6,9834 3,4538
7904 SEALASSY CATING SEAL ASSEMBLY (28620)
380
Other In Hole )Wireline retrievable plugs,
valves, pumps, fish, etc.)
Top MKel
Top ING)
pEd
Topincl
f)
Deo
eom
Foo
1D (in)
( PERF: B,S]1 pa.Blae�
7,020.0
3,460.8
7848
TYPEKEHPE
21S0(ATI N SLEEVE, 4EG PROFILE,
2/232019
2.590
IPERF, 81'p Pg,4%.D��
I
SLEEVE
$LEEVE D-
- D
369'ODX 19'L
LEM
7,3539
3,535.4
78.50
TYPE 1
BAKER T PE 1 DIVERTER SLEEVE. PROFILE,
2/22/2019
3.00
DIVERTER
39DE OD X 18.6'L
1PEgF: asnoe.m6a�
1
SLEEVE - O-
r
EM
111
Perforations 851ots
Ds"
D a
Tap
BtmlrvDl Islmwrt
IPFAF:Smp.P10]120�
Top lttKBl BM8190
ns)
13,721
(MKS) Linked 2dne ) Type
Com
8,571.0 8,8190
1now20
3,725.0 JJ25.5 AS A2, 1E-168 1111112004 320 [PERT All A and toLiner
PERFS
.
25 Long x'
IPERF: toms 0-11,01180-
Wide,,
cirrumlTaws, 3
Center,
staggered 18 deg.
IPEge n>u.P11axio-I
9,129.0 9,4360
3,7183 3,7 7 WS A2, 1E-168 1111112004 =0 WERE
9,52].0 9.6530
3708.5
3711.1 WS A2, 1E-168 1111112004 32.0 IPERF
PERF 11 M,6128510
I
9,984.0 10,7120
J, 717.9 ,744.2 WS A2, 1E-168 1111112004 2.0 III
1019810 11.006.0
37452
3,741.1 WS A2, 1E-168 1111112004 3.0 IPERF
11,335.0 11.830.0
3734.0
3413 WS A2, 1E-168 1111112934 32.0 IPERF
IPERF; +Oam.P131xio-
11,923.0 12.8510
3.)48.8
3789.7 WS A2, 1E-168 1111112934 32.0 IPERF
13,0060 13.130.0I
3787.9 WS 1, 1E-168 1111112009 32.0 IPERF
IPERCO,313.P134m.0--
13,343.0 13,436.0 1
3761.8 I 3762.5 WSA2, 1E-168 11111111TO i ZV 1PERF
ASAND LINER', 243]]
13,4730
ConocoPhillips !\1
AI55ke. me
KUP PROD WELLNAME 1E-168 WELLBORE 1E-168
1E-13.9dnrza1e z:4e:3. PM
Mandrel Inserts
vow w.,,.mn�al
81
AN
____. ........_.___.
__.
on T°p (ND)
Volae
—
Ped BW TRO Run
HANGER D1
N Tap(KKB) (-B) Make Motlel
006
IM,
Typo
Type
(In) IPSO Run OaR Dan
4.2)02 2,423.5 CAMCO KBMG
1
GAS LIFT
GLV
BK -5
0.188 1.5310 b20/2004
2 6.)081 1 3,383.9 JCANICU IKBMU I 1 GAS LIFT
OV
BK -5
1 025DI 0.0 21201400)
Notes: General & Safety
End Dal. An—.1—
S.D.rDN:Sw3E
1212312004 NOTE iRI-LATERALWELL'. ii, -168(A-SAND),1E-16BL1(B-SAND),
1E -1681-2(l)
SAND)
NIPPLE aeae
22412009 NOTE: View Schema EMAlaska Schemmic9.0
.UFT',anoz
SURFACE: V ERA145
G95 LIFT: %. .1
NIPPLE'88132
LOCATOR: Ren
rvPE 2ISDLATION "AM'E-
D..;I'm
D:vWD weWiv]mla
1as3D
P D LINER: 10291
n.939a
D'SAND LINER LEM169M2
13280
1VPEI DNERTER... -B
4.EM: 7.330
0 SAND W. ".9
13810
8 SAND LINER. 7.aD 0-
11'.D
8 SAND LINER LEM, ] 235.5
].4]99
PROW RIN. 2). 68.15).9
PERF:. S10E,8190�
PERF:
1
9,123.69,438 .0
��
IPERF: 9.5P.09,653.0�
(PERF: 99 a 1.610.1120
(PERF: 10SM1 11,0660�1
i I
WERF', 11,330A1830--
1 l
I
IPERF', II.B'8.61$310�
IRERF',13.=13-13.1WO
IRERF', 13.9A3.613.430�
M9PND LINER: 7. 2-
13. ] .
KUP PROD WELLNAME 1E-168 WELLBORE 1E -168L1
ConocoPhillips
Alaska, Inc.
71m31,enoadni 4.ssPM
Last Tag
vertrW vlmutic
L.,
Annolal-
Depth (I End oaw phnlpre Led Man av
........................ ............._.........................................._..___.
Lest Tag'
10,104.0 21232019 1E-168.1 c)n8ipv
I
Last Rev eason
xNrvGER: 2{.1
en
.1
End Data Weser,
lane No in,
Rev Reason: REMOVE SLEEVE IN
B LAT
4012015 11E -168L1
linpSon,
Casing Strings
enema DeaedpnonDD (1.)
/nor) mpRKel
awn.aho KR) sm Depm irvDl... WVLen O._cmee mp Tnreed
B -SAND LINER 4112
3.96 ),3528
11,927.0 3,582.) 12.60 L-80 DWC
Liner Details
xominIo
CONWCTOR.ID61C6.0
T., MKB) Top(WERMKID
ncli') M
ToplTDes
own iin)
7,3528 3,535.4
78.51 HANGER
BAKER MODEL B-1 FLANGED HOOK HANGER 4500
NIP1LE:46de
7379S 3,540.5
0.8 Swty
BAKER TORQUE-THRU SWIVEL 3958
11,888.0 3582,01
88.73 BUSHING
BAKER DRILLABLE PACKOFF BUSHING 3958
11906.1 3,562.4
88.90 %04.5x3.5
3500
ws LFT:4,M2
Perforations 8 Slots
Bnm
Done
rupirvDi
61m rvDi
IanmsM
ropi
L
ro
Dento
Co.
7,4410
,
.
W B.1E-
111170Kl
30
PERE
.5"3x.125 -
I,
LULL"
168.1
4circner,
4 circum( rows,
ce 8
censers staggered 18 seg
SURFACE n 8-4.4145
10.860.0
11,8860
3,5565
3,5819
W E-
111172004
32.0
(PERF
Staged Liner. 2 5"L x.t 5"
16811
W, 4 orcunl rows, 3"
Centers staggered 18 deg
ws LIfT; 67)31
Notes: General
B Safety
End Date
Anrwi
1223/2004 NOTE: TRI -LATERAL
WELL. 1E-168(A-SAND),1E-168Li(B-SAND),11&168L2(D-SAND)
wpPle: e.au.z
27242009 NOTE: View Scpernatic W A18M Se?renauce,
LOCATOR: AND ]
TYPE 21SOIATION 6LEEVE-
PIfM;]0200
..NDwinew. Toat_a
7.043)
0.&WO LINER, 7.NB.3
11.me8
D-SANDLINER.I.A 2-
7=0
TYPE 1 DIVFRTER SLEEVE -B
-LEN;'? A0
B S4N0 W-173536
&sABD LINER LEM; 7,216,6
7.ass
PROWCTIOx,9.00'V'a
(PERF: 7.M7 0.10.673.0
IPERF.10@63O11,6Il
&aPHO LINER. 7,952.&
I1,BP 0
Proposed 1 E -168L1 B Sand Toe MBE Isolation with 8.6 ppg Ultra -Light Cement Procedure
1E-168 West Sak Tri-lat producer was drilled & completed in 2004. 'IE -1681-1 B Sd horizontal
lateral has 4.5", L-80 tubing & liner set to 11927' MD. The 4.5" liner is almost entirely composed
of slotted joints except for a 188' blank section at 10672 - 10860' RKB, and a 62' blank section
at 7385' RKB just below the B LEM. Constrictors exist in Lnr x OH at the ends of the 188' blank.
A'B' MBE occurred 3/22/06 from 1 E-1141-1 injector to 1 E-1681-1. This MBE was treated 7/27/12
with Crystal Seal, but the treatment broke and the MBE is now open. A second MBE occurred
late Dec 2018 from toe of 1 E -1 68L1 to heel of 1 E-123 producer. The wells are only —800' apart
from toe of 168L1 to heel of 123. Currently 1 E-114, 1 E-168, and 1 E-123 are all LTSI. A 4/22/19
1E-1681_1 (PROF with 1E-1141_1 on PWI clearly showed entry of B MBE from 1E-1141_1 at
9000' RKB, with all inflow then moving down toward the toe of 1 E-1681-1. Because the IPROF
could only reach 10000', the down flow presumably goes to a toe MBE from 1E-1681_1 toe at
11927' RKB to the heel of 1E-123 'B' Sd lateral. The production behaviors of 168 and 123
noted at the time of the MBE occurrence also supports this theory.
Per this procedure, CT will first jet lubricant 1 E-1681_1 liner with an Agitator to deep as possible
while doing a Fluff & Stuff. This should help to drift & set inflatable equipment to as deep as
10700' RKB. If we can't attain 10700', we'll perform a Plan B design to set inflatable equipment
further up hole. Plan A is to have CT will set an IBP in 4.5" liner at 10700' RKB in blank liner,
then shoot 5' of perfs at 10645 - 10650'. CT would then set an inflatable Cement Retainer at
10150' RKB in slotted liner and pump 23.5 bbls of 8.6 ppg Cement through the Retainer to spot
—600' of Cement Plug in 4.5" liner and in 4.5 x 6.75" annulus adjacent to the straddle section.
Alternate Plan B job design is outlined if we need to spot a Cement Plug shallower in the liner.
1E-168 A Lat is isolated by a Plug, the B Lat is open with a Diverter set, and the D Lat is
isolated with an Iso-Slv. The well is ready to perform a B Lat F&S and then execution of a
Cement job to isolate the B Toe MBE.
Coil Tubing Procedure:
1) Fluff & Stuff and Lubricate Slotted Liner
RIH with Agitator & Nozzle BHA while jetting lubricant solution to perform Fluff & Stuff to deep
as possible to clear liner of fill to enable setting an IBP at 10700' RKB in 4.5" liner, if possible.
To enable Plan A, we need access to 10700' RKB, else we perform Plan B which reduces
retained liner length for future PWI. POOH with BHA to PU Bridge Plug.
2) Set Inflatable Bridge Plug
Perform Plan A if possible. else perform Plan B.
at "MI
RIH with Inflatable Bridge Plug. Locate Plug at 10700' RKB near top of Blank Liner section and
set Plug at 10700' RKB (optimal target). POOH.
Plan B
RIH & set IBP deep as possible if it can't be set at 10700' RKB. In this case the IBP will likely
get set inside across liner slots if it happens to set anywhere shallower than 10672' RKB.
However, IBP is designed to tolerate set in slots without compromising good set integrity. Aside
from this assurance, there are no other options but to set inflatable equipment in slots to
perform MBE isolation with a cement plug. The liner is all slotted above 10672' RKB. POOH.
3) Perforate Liner:
If Plan A was executed (in Step 3) to set an IBP at 10700' RKB, then:
RIH with Perf Gun to provide 6 spf, 60 deg ph, that yields largest avg hole diameter possible
and shoot 5' CAL of perforations at 10645 - 10650' RKB (target). Perfs can be shot +/- 25' of
target and be close enough to satisfy our objectives. Strict depth control is not required. POOH
with pert gun. Verify ASF.
If Plan B was performed in Step 3 to set IBP shallower than 10700' RKB, then:
RIH with Perf Gun to provide 6 spf, 60 deg ph, that yields largest avg hole diameter possible
and shoot 5' CAL of 'large hole' perforations at 275' above IBP set location. Perfs can be shot
+/- 25' off target and still be close enough to satisfy our objectives. Strict depth control is not
required. POOH with perf gun. Verify ASF.
4) Set Inflatable Cement Retainer (ICR) & Pump Cement:
If Plan A was executed and IBP was set at 10700' RKB, then:
RIH with Inflatable Cement Retainer BHA. Park ICR at 10150' RKB then pump ball with
Freshwater to set ICR at 10150' RKB in 4.5" slotted liner. Strict depth control is not required. If
ICR is within +/- 25' of 10150' RKB, it is close enough. Verify good ICR set and circ rate
through ICR, then batch mix 23.5 bbis of'pumpable' Neat 8.6 ppg Cement.
While cement is being mixed, pump 2 CT volumes (-100 bbls) Freshwater down CT at 1 bpm to
thoroughly displace all hydrocarbons from straddled liner section of the liner, and the adjacent
Liner x OH annulus before pumping cement to ensure no hydrocarbons (contaminant) are left in
this area during cement placement. This is our first 'producer' cement job for MBE isolation, so
displacing away all hydrocarbons from the horizontal area for the cement plug will be important.
After 100 bbls of Freshwater has been pumped away, swap to 23.5 bbls of 8.6 ppg Cement at 1
bpm (target), followed by 5 bbls of Freshwater Spacer, followed by 5 bbls of Biozan, followed by
Freshwater displacement.
Displace Cement through ICR. When 22.7 bbls Cement has passed through ICR, disconnect
CT from ICR, then POOH spotting the last 0.8 bbl Cement on top of ICR from 10150' to 10100'
in 4.5" slotted liner, then continue POOH slowly replacing voidage with Freshwater
displacement. There will be no pumping to well other than to replace voidage at 1:1 with
Freshwater while POOH to surface to avoid any displacement of Cement job before set.
Ensure Diesel FP in tubing to 2000' TVD. RD CTU. WOC at least 3 days.
If Plan B was execute and IBP was set shallower than 10700' RKB, and perfs were shot
shallower than 10645 - 10650' RKB, then:
RIH with Inflatable Cement Retainer and park ICR 275' shallower in liner than where
perforations were shot. Pump ball down CT with Freshwater to set ICR at XXXX' RKB in 4.5"
slotted liner at depth that is 275' shallower than the perfs. Strict depth control is not required. If
ICR is set within +/- 25' of target set depth, it is close enough.
Verify good ICR set integrity exists with good circ rate through ICR, then mix 23.5 bbls of
'pumpable' Neat 8.6 ppg Cement. While cement is being mixed, pump 2 more CT volumes
(-100 bbls) of Freshwater down CT at 1 bpm to thoroughly displace all hydrocarbons from
straddled liner section of the liner.
After 100 bbls of Freshwater has been pumped away, swap from Freshwater to pumping 23.5
bbls of 8.6 ppg ULTRA-LiteCRETE Cement at 1 bpm (target), followed by 5 bbls of Freshwater
Spacer, followed by 5 bbls of Biozan, followed by Freshwater displacement.
When total of 23.5 bbls of Cement has passed through the ICR, PU & disconnect CT from the
ICR, then POOH while pumping at 1:1 to replace voidage. This should leave -614' of annular
cement job adjacent to -550' of Cement filled straddle inside 4.5" Liner. Ensure tubing is Diesel
FP to 2000' TVD.
RD CTU. WOC.
If it is decided we want to flow test 1E-168 before doing a 1E -114L1 to 1E -168L1 MBE
treatment, 1E -168L1 will remain SI for at least 3 days to WOC before being returned to
production.
3
Originated:
Schlumberger
PTS - PRINTCENTER
6411 A Street
Anchorage, AK 99518
(907)273-1700 main (907)273-4760fax
Delivered to:
n
AOGCC
w ATTN: Natural Resources Technician II
l Alaska Oil & Gas Conservation Commision
t~
sy 333 W. 7th Ave, Suite 100
--y= Anchorage, AK 99501
20 x'2.01
30 45 4
• � • 14 -Mar -19
14Mar19-JW01
WELL NAME
1R-17
1E -168L7
1C-190
1J-164
1J-136
2M-21
API #
50-029-22212-00
50.029-23230-60
50-029.23136-00
50-029.23278-00
50.029-23331-00
50.103-20156-00
ORDERSERVICE
EA77-00002
E90U-00005
0U
E9-00006
E90U-00007
E90U-00009
E540.00062
—FIELD NAME
KUPARUK RIVERWL
KUPARUK RIVER
KUPARUK RIVER
KUPARUK RIVER
KUPARUK RIVER
KUPARUK RIVER
DESCRIPTIONDELIVERABLE
WL
WL
Memory
Memory
WL
DESCRIPTION
(PROF Vert
(PROF
]PROF
]PROF
(PROF
Caliper
DATA
FINAL FIELD
FINAL FIELD
FINAL FIELD
FINAL FIELD
FINAL FIELD
FINAL FIELD
Color
DATELOGGED
13 -Feb -19
23Feb-19
23--Feb-19
25 -Feb -19
26 -Feb -19
7 -Mar -19
r
1
1
1
1
1
1
6
Signature
return via courier or sign/scan and email a copy
Date
and CPAL
Schlumberger -Private
A Transmittal Receipt signature confirms that a package (box,
envelope, etc.) has been received and the contents of the
package have been verified to match the media noted above. "
specific content of the CDs and/or hardcopy prints may or may
not have been verified for correctness or quality level at this
point.
· .
Image Project Well History File Cover Page
XHVZE
This page identifies those items that were not scanned during the initial production scanning phase.
They are available in the original file, may be scanned during a special rescan activity or are viewable
by direct inspection of the file.
~a 't - ca 0 L Well History File Identifier
Organizing (done)
D Two-sided 1111111111111111111
D Rescan Needed 11111111I111111I111
RES CAN
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DIGITAL DATA
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D Other, NofType:
D Poor Quality Originals:
OVERSIZED (Non-Scannable)
D Other:
D Logs of various kinds:
NOTES:
D Other::
BY: ~
Date I f,¡/ (J 7
I I
/5/
WlP
Project Proofing
"11I11I//lI/! "III
BY: ~
Date 1/d-J07
---L- x 30 = 30
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~
Ó~
Scanning Preparation
BY:
Date:
+ a.~ = TOTAL PAGES
(Count does not include cover sheet)
/5/
p
Production Scanning
/1111111//1111 "II/
Stage 1
Page Count from Scanned File:
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(Count does include cover sheet)
V YES
BY:
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~ Date: 1/:;"/07
Stage 1 If NO in stage 1, page(s) discrepancies were found:
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BY:
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Date:
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11111111111I111111I
Scanning is complete at this point unless rescanning is required.
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/1111111//11111111/
BY:
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Comments about this file:
Quality Checked
11II11I1111111111I1
10/6/2005 Well History File Cover Page. doC
Robert Christensen/Darrell Humphrey
Production Engineering Specialists.
Greater Kuparuk Unit, NSK -69
PO Box 196105
Anchorage, AK 99519 -6105
ConocoPhill
Phone: (907) 659 -7535
Fax: 659 -7314
November 10, 2010
I�� `
Dan Seamount �
AOGCC Commissioner N 1 2 1010
State of Alaska, Oil & Gas Conservation Commission
33 W. 7`" Ave. Ste. 100 rolks if & Gn Cons. CGM'T" o p
Anchorage, AK 99501 Anchorage
Dear Mr. Seamount,
Enclosed you will find 10 -404 reports of Sundry Well Operations recordi%lke isolation
of the B sands for West Sak Well 1E -168, 168L1, 168L2 (PTD 204-200 1 204-
202).
P
If you have any questions regarding this matter, please contact myself or Robert D.
Christensen at 659 -7535.
Sincerely,
Darrell R. Humphrey NO NIL
Attachments
Sundry notification
Well schematic
Y STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSIR
REPORT OF SUNDRY WELL OPERATIONS
t. Operations Performed: Abandon ❑ Repair w ell ❑ Plug Perforations ❑ Stimulate ❑ Other ISO B SAND
Alter Casing ; Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑
Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑
2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number:
ConocoPhillips Alaska, Inc. Development � Exploratory ❑ ` 204-201
3. Address: 6. API Number.
P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic ❑ Service ❑ „ 50- 029 - 23230 -60
7. Property Designation (Lease Number): 8. Well Name and Number:
ALK 25651 1 E -168L1
9. Field /Pool(s):
w
Kuparuk River Field / West Sak Oil Pool
10. Present Well Condition Summary:
Total Depth measured 11969 feet Plugs (measured) None
true vertical 3583 feet Junk (measured) None
Effective Depth measured 11888 feet Packer (measured) 7353
true vertical 3580 feet (true vertucal) 3535
Casing Length Size MD TVD Burst Collapse
B -SAND LINER 4574 8.47 11927 3582 0 0
0 0 0
0 0 0
0 0 0
0 0 0
0 0 0
Perforation depth: Measured depth: 7447- 10673,10860 -11886
True Vertical Depth: 3550 -3552, 3556 -3581
NOV ]
Tubing (size, grade, MD, and TVD) 4.5, L -80, 6982 MD, 3453 TVD Td& Sr. Cons. Cgir..;s i0Q
Packers & SSSV (type, MD, and TVD) SLEEVE- ISOLATION SLEEVE SET IN B -LAT @ 7353 MD and 3535 TVD
11. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
12. Representative Daily Average Production or Injection Data
Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation 600 111 176 790 260
Subsequent to operation 144 462 700 859 273
13. Attachments 14. Well Class after work:
Copies of Logs and Surveys run Exploratory ❑ Development 17vo f Service ❑ Stratigraphic ❑
15. Well Status after work: s Oil W Gas ❑ WDSPL ❑
Daily Report of Well Operations _X GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG
16. 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:
N/A
Contact Darrell Humphrey /Bob Christesen
Printed Name Darrell R. Humphrey Title Production Engineering Specialist
Signature Phone: 659 -7535 Date t//10 t l D
a
Form 10-404 Revised 10/2010 Submit Original Only
1 E -168L1
DESCRIPTION OF WORK COMPLETED
SUMMARY
Date Event Summary
11103/10 PULLED ISO SLEEVE FROM D -LAT @ 7046' CTMD, PULLED IBP FROM A -LAT @ 7458'
CTMD,WELL LEFT SHUT IN, RETURN IN THE AM TO RE- INSTALL ISO SLEEVE (IN
PROGRESS)
11/05/10 SET ISO SLEEVE IN B -LAT LEM @ 7391' CTMD, WELL LEFT SHUT IN, TURN OVER TO
DSO (COMPLETE)
'
g
KUP 0 1E-1680
COI10C0P11llIP5 Well Attributes Max Angle & MD TD
Inc Welltlore APl /UWI Field Name We113taNs Intl ( °) MD(RKB) Act Btm (fIKB)
500292323060 WESTSAK PROD 93.48 8,635.76 11,969.0
Comment HIS (ppm) Date Annotation End Date K813R0 (R) Rig Release Data
••• Well Cont..- 1E- 768L111BrN107.58 A7 AM SSSV:NIPPLE 65 8/6/2009 Last WO: 2/10/2007 34.69 11/26/2004
Schemalk -AcNel Annotation DepN (ftKB) Entl Data Annotation Last M*d ._ Entl Data
Last Tag: Rev Reason: Set ISO SLV B Lateral, Pull IBP In105bOr 11/6/2010
Casing Strings
HANGER, 23 ' -� Casing Description String 0... String ID ... Top (rtKB) Sat Depth (f... Set Depth (TVD) ... String Wt... 5tling ... String Top ThrO
BSAND LINER 41/2 3.958 7,352.8 11,927.0 12.60 L -80 DWC
Liner Details
Top Depth
ITVD) Top lncl
Top(ftl(B) IRKB) (°) Item Description Comment 10 (in)
7,352.8 3,535.6 79.07 HANGER BAKER MODEL B -1 FLANGED HOOK HANGER 4.500
11,888.0 3,581.9 88.73 BUSHING 3.958
11,906.1 3,582.4 88.90 XO4.5x3.5 3.500
CONDUCTOR, Other In Hole Wireline retrievable plugs, valves pumps, fish etc.
28.108 Top Depth
(TVD) Top Inc,
NIPPLE, 469 Top(RKB) (RKB) (°) Description Comment Run Dab ID (In)
7,353.0 3,535.6 79.06 SLEEVE ISOLATION SLEEVE SET IN B -LAT 11/5/2010 2.590
Perforations & Slots
Shot
Top(TVO) Btm(TVDI Dens
GAS LIFT, _ Top IRKS) Stm (rtKB) IRKS) (nKB) Zone Data (sh... Type Comment
4. 270 7,447.0 10,673.0 3,553.6 WS B, 1 E -168L1 11/17/2004 32.0 IPERF Slotted Liner, 2.5" L x.125 W, 4
ciroumf rows, 3" centers staggered 18
deg
.. 10,860.0 11,886.0 3,553.5 3,581.9 WS B, 1E -168L1 11/17/2004 32.0 IPERF Slotted Liner, 2.5'L x .125" W, 4
circumf rows, 3" centers staggered 18
deg
Notes: General & Safety
End Data Annotation
SURFACE, 12123/2004 NOTE: TRI- LATERAL WELL: 1E- 168(A- SAND), 1E- 168L7(BSAND), 1E- 168L2(DSAND)
2%4,413 2/24/2009 NOTE: VIEW SCHEMATIC w /PJaska Schematic9.0REV
GAS LIFT,
6,708
NIPPLE, 6,943
LOCATOR,
1902
SEAL ASSY,
6,983
D -SAND —
Winda. -
7,D31 -7 043
D -SAND LINER
LEM,
8,9767 326
SLEEVE, 7,353
B -SAND
WM..,
73537,387
B -SAND LINER
LEM,
7,297 -7,480
PRODUCTION,
27-8,158
IPERF, Mandrel Details
7,447 -10673 Top Depth Top Port
(TVD) Incl OD Valve Latch Sire TRO Run
Stn Top(rtl(B) (RKB) 11 Make Model (in) Sery Type Type (in) (psi) Run Date Com...
1 4,270.2 2,423.4 66.45 CAMCO KBMG 1 GAS LIFT JGLV BK5 0.188 1,531.0 2/20/2004
I 2 6,708.2 CAMCO KBMG 1 GAS LIFT OV BK5 0.2501 0.0 2/20/2007
886
1D.eso- 11,886
B -SAND
L INER.
7,353 - 11,927
TD (1E- 1681.1),
11 969
• •
~:~~
MICROFILMED
03/0112x08
DO NOT PLACE
...
.~~ W
__
ANY NEW MATERIAL
UNDER THIS PAGE
F:1LaserFicheiC~rrPgs_Inserts~Miicmfilm Matkercbc
nc oraaÐ
1. Operations Performed: Abandon 0 Repair Well 0 I Plug Perforations 0 Stimulate 0 Other 0 !
Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0'
Change Approved Program 0 Operat. ShutdownO Perforate 0 Re-enter Suspended Well 0
2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number:
ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 204-201 1
3. Address: Stratigraphic 0 Service 0 6. API Number:
P. O. Box 100360, Anchorage, Alaska 99510 50-029-23230-60
7. KB Elevation (ft): 9. Well Name and Number:
RKB 28' 1 E-168L1
8. Property Designation: 10. Field/Pool(s):
ALK 25651, ADL 469/466 Kuparuk River Field 1 West Sak Oil Pool
11. Present Well Condition Summary:
Total Depth measured 11969' . feet
true vertical 3583' . feet Plugs (measured)
Effective Depth measured 11888' feet Junk (measured)
true vertical 3580' feet
Casing Length Size MD TVD Burst Collapse
Structural
CONDUCTOR 80' 20" 108' 108'
SURFACE 4387' 10-3/4" 4415' 2477'
PRODUCTION 8130' 7-5/8" 8158' 3715' ,0
SLOTTED LINER 4574' 4-1/2" 11927' 3582' R '\ If'. ~ ?fJ
~es .?P s-\
Perforation depth: Measured depth: slotted liner from 7447'-11886' ~OU· . ~(¿"c¡. 4:^~
I"'" '0!;;,,\\ø ~~..::> Ã)",
true vertical depth: 3550'-3582' \ iÇ'.. ~d;::~ ~4"t" "1\ ,,0
çp~
Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6983' MD.
Packers & SSSV (type & measured depth) HRD ZXP liner top pkr@ 7295CANNED JUL 1 1 2007
Cameo DB nipple @ 469'
12. Stimulation or cement squeeze summary:
Intervals treated (measured) not applicable
I reatment deSCriptions including volumes
used and final pressure:
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mef Water-Bbl Casino Pressure Tubina Pressure
Prior to well operation 680 269 197 -- 185
Subsequent to operation 528 291 636 -- 295
14. Attachments 15. Well Class after proposed work:
Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0
Daily Report of Well Operations _X 16. Well Status after proposed work:
Oil0 I GasO WAG 0 GINJO WINJO WDSPL 0
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
n/a
Contact Jill Long @ 265-1102
Printed Name Jill Long c'f>ôYWr Title Wells Group Engineer
Signature ~1 Phone Date 03/01/07
Pren~rerl hv Sharon Al/suD-Drake 263-4612
V U BfL JUl 1 1 2nD1 "'IS'
.
STATE OF ALASKA MAR 0 2 2007
ALASKA Oil AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Con· C . _I j
REPORT OF SUNDRY WELL OPERATIONS A h s.. OfflunSS on
.
REGt:IVi::D
.'
Form 10-404 Revised 04/2004
ORIGINAL
RBDMS
.~../J-. "',,.. ~LSubmit Original Only
~ /l'AD? ß :r·Z· ó>
,-
.
.
ConocoPhillips Alaska, Inc.
KRU
1 E-168L 1
API: 500292323000 Well Type: PROD AnQle @ TS: deQ@
TUBING SSSV Type: NIPPLE Orig 11/26/2004 Angle @ TD: 89 deg @ 11969
(0-6983. Completion:
00:4.500,
10:3.958) Annular Fluid: Last W/O: 2/10/2007 Rev Reason: WORKOVER
Reference Log: 28' RKB Ref LOQ Date: Last UDdate: 2/15/2007
Last Taa: TD: 11969 ftKB
LastTaa Date: Max Hole .e: 93 deg @ 8636
Description Size Top Bottom TVD Wt Grade Thread
CONDUCTOR 20.000 0 108 108 62.50 H-40 WELDED
SURFACE 10.750 0 4415 2478 45.50 L-80 BTC
PRODUCTION 7.625 0 8158 3576 29.70 L-80 BTC-M
7.000 7353 7354 3536 0.00
I Description Size I Top Bottom I TVD I Wt I Grade Thread I
SLOTTED LINER 4.500 I 7353 11927 I 3583 I 12.60 I L-80 DWC I
Size I Too I Bottom I TVD I Wt I Grade I Thread I
4.500 I 0 I 6983 I 3454 " 12.60 I L-80 I IBT I
11I1&1111111'
Interval TVD Zone Status Ft Date Tvoe
7447 - 10673 3550 - 3553 WS B,WS 3226 32 11/17/2004 ¡PERF Slotted Liner, 2.5" L x .125"
B W, 4 cireumf rows, 3"
centers staoaered 18 deg
10860 - 11886 3557 - 3582 WSB 1026 32 11/17/2004 IPERF Slotted Liner, 2.5" L x .125"
W, 4 cireumf rows, 3"
centers st ered 18 dea
PACKER
(7297-7316. 51 MD TVD Man Mfr Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv
00:7625) Cmnt
1 4270 2423 CAMCO KBMG SOV 1.0 BK-5 0.000 0 2/9/20CJl
SBR 2 6708 3384 CAMCO DMY 1.0 BK-5 0.000 0 2/9/20CJl
(7316-7335. lllil¡¡V·
OD:6.260) Deoth TVD rvoe ID
469 467 NIP CAMCO DB NIPPLE 2/9/2007 3.875
pUP Iii;' 6943 3446 NIP CAMCO DB-6 NIPPLE 219/2007 3.812
(7336-7353, 6983 3454 SEAL BGH-22 LOCATING SEAL ASSEMBLY & LOCATOR SUB 2/9/2007 3.880
OD:4.500) , ., 7029 3463 iiiir L2 BAKER MODEL B1 FLANGE HOOK HANGER FOR D-SAND L2 4.500
rl Depth TVD Tvoe Descriotion ID
7297 3525 PACKER ZXP LINER TOP PACKER 5.500
7316 3528 SBR 109-97 CASING SEAL BORE RECEPTACLE 4.750
7335 3532 BUSHING XO BUSHING 4.500
7336 3532 PUP 3.875
I 7346 3534 HANGER LEM ABOVE HOOK HANGER 4.500
7353 3535 HANGER LEM INSIDE HOOK HANGER 4.750
I I 7404 3544 NIP CAMCO 'DB-6' NIPPLE 3.562
~ 7477 3554 SEAL BAKER SEAL ASSEMBLY 3.875
Date I Note
SEAL n 1/17/2004 NOTE: TRI-LA TERAL WELL: 1 E-168(A-SAND\, 1 E-168L HB-SAND\, 1 E-168L2(D-SAND\
(7477-7478.
00:4.500) ... I ..
Perf . . . -
(7447-10673) 1 .-
= f=
= I 1=
== 1=
= f=
== 1::=
I I f--
I
Perf - I I 1==
== 1=
10860-11886) == I fC=
== r=
= I I 1=
===::. .r==
== I fC=
I::::::
== 1=
== . . fC=
=== I ê
=::::
=. I I 1::=
== t=
;) (~ DJL. c.-
DATA SUBMITTAL COMPLIANCE REPORT
11/27/2006
Permit to Drill 2042010
Well Name/No. KUPARUK RIV U WSAK 1E-168L 1
Operator CONOCOPHILLlPS ALASKA INC
)flv..J / JjÚov ÅH Y
API No. 50-029-23230-60-00
MD 11969 ~- rvD 3583 -- Completion Date 11/26/2004""'"
Completion Status 1-01L
Current Status 1-01L
UIC N
____...__~u__________
REQUIRED INFORMATION
Mud Log No
Samples No
Directional Survey Yes
DATA INFORMATION
Types Electric or Other Logs Run: GR/Res
Well Log Information:
Electr
Digital Dataset
Med/Frmt Number Name
Directional Survey
13157 Induction/Resistivity
(data taken from Logs Portion of Master Well Data Maint
Name
Interval
Start Stop
Log Log Run Interval OH/
Scale Media No Start Stop CH Received Comments
7355 11969 1/5/2005
25 Blu 108 11969 6/10/2005 Multiple Propagation
Resistivity Gamma Ray
25 Blu 108 11969 6/10/2005 Multiple Propagation ¡
I
I
Resistivity Gamma Ray i
I
108 11969 Open 6/10/2005 Multiple Propagation I
Resistivity Gamma Ray
6/10/2005 ~
Sample
Set
Sent Received Number Comments
13157 Induction/Resistivity
C Lis
13157 Induction/Resistivity
13157 LIS Verification
Well Cores/Samples Information:
ADDITIONAL INFORMATION
Well Cored? yID
Chips Received? ~
Formation Tops
~
®N
Daily History Received?
Analysis
Received?
"-¥-/-N-
Comments:
~)
Compliance Reviewed By:
Date:
..~ __--c=~,=.,=
~Cf
, . STATE OF ALASKA
AL~KA OIL AND GAS CONSERVATION COM'1VITŠSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1 a. Well Status: Oil 0 Gas U Plugged D Abandoned D Suspended D WAGD 1b. Well Class:
20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0
GINJ 0 WINJ D WDSPL D No. of Completions _ Other _X Pre-Produced Injector Service D Stratigraphic Test D
2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number:
ConocoPhillips Alaska, Inc. or Aband.: November 26, 2004 204-201
3. Address: 6. Date SPUddð?f~~~ 12.,}:I:¥>4 13. API Number:
P. O. Box 100360, Anchorage, AK 99510-0360 r..6b t. r. £,:ç 50-029-23230-60
4a. Location of Well (Governmental Section): 7. Date TO Reached: 14. Well Name and Number:
Surface: 207' FNL, 640' FEL, Sec. 21, T11 N, R10E, UM / 1E-168L1
November 15, 2004
At Top Productive 8. KB Elevation (ft): 15. Field/Pool(s):
Horizon: 619' FNL, 1619' FEL, Sec. 22, T11 N, R10E, UM 28' RKB Kuparuk River Field
Total Depth: 9. Plug Back Depth (MD + TVD): West Sak Oil Pool ,£l>
1303' FNL, 1208' FEL, Sec. 15, T11 N, R10E, UM 11888' MD 1 3580' TVD "61' S~ i4.+~4.1 "1,0>
4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation:
Surface: x- 549890 - 5959380 I Zone- 4 , 11969' MD 1 3583' TVD " ALK 25651
y-
TPI: x- 554194 y- 5958998 Zone-4 11. Depth where SSSV set: 17. Land Use Permit:
Total Depth: x- 554564 y- 5963596 Zone-4 n/a ADL 469/466
18. Directional Survey: Yes 0 NoU 19. Water Depth, if Offshore: 20. Thickness of
N/A feet MSL Permafrost: 1895' MD
21. Logs Run: -r/ {.IJ ,~. ./......,. t 7~$Ç' /?1p Á1> ô$'
GR/Res ,ß5~ " 7YÞ /·7'
22. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT
CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM CEMENTING RECORD
SIZE PULLED
20" 62.58# H-40 28' 108' 28' 108' 42" 250 sx AS I
10.75" 45.5# L-80 28' 4415' 28' 2477' 13.5" 720 sx AS Lite, 220 sx DeepCrete
7.625" 29.7# L-80 28' 8158' 28' 3715' 9.875" 422 sx DeepCrete
4.5" 12.6# L-80 7353' 11927' 3535' 3582' 6.75" slotted liner
23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD
Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET
4.5" 6158'
slots in liner from 7447'-10673', 10860'-11886' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
slots are 32 slots/ft n/a
26. PRODUCTION TEST
Date First Production Method of Operation (Flowing, gas lift, etc.)
December 12, 2004 Gas Lift oil- production shared with 1 E-168 and 1 E-168L2
Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-Oil RATIO
12/12/2004 7 hours Test Period --> 693 382 13 25 Bean 603
Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF W A TER-BBL OIL GRAVITY - API (corr)
press. 463 psi not available 24-Hour Rate -> 2323 1400 46 .... - ¡ßo!.avi.iJâQ \à "'''"'''''''_
27. CORE DATA rtr'i .t-. \/1-0, J
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). --
Submit core chips; if none, state "none". DEC 2 2 2004
RBDMS 8Fl JAN 0 7 2005 " 2..,-", oel Alaska Oil & Gas Cons. Commission
NONE ! Anchorage
Æ
Form 10-407 Revised 12/2003
CDNTtNUED ON REVERSEO RIG I N A L
28.
29.
GEOLOGIC MARKERS
',,-,,/
FORMATION TESTS
NAME
MD
TVD
Include and briefly summarize test results. List intervals tested, and
attach detailed supporting data as necessary. If no tests were
conducted, state "None".
1 E-168L1
West Sak B
7351'
3535'
N/A
30. LIST OF ATTACHMENTS
Summary of Daily Operations, Directional Survey
31. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact:
Steve Shultz @ 263-4620
Printed Na~ IbO~
Signature \ ioI-
Title:
RQQne
Kuoaruk Drillino Team Leader
-z. 6 5"b"8 ~o
Date
( ~( Z-2- (Cj '(
Prepared by Sharon Allsup-Drake
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 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water
supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with
production from each pool completely segregated. Each segregated pool is a completion.
Item 4b: TPI (Top of Producing Interval).
Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other
spaces on this form and in any attachments.
Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Item 20: True vertical thickness.
Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location
of the cementing tool.
Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item
23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to
be separately produced, showing the data pertinent to such interval).
Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection,
Shut-in, Other (explain).
Item 27: If no cores taken, indicate "none".
Item 29: List all test information. If none, state "None".
Form 10-407 Revised 2/2003
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-168
1E-168
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 10/27/2004
Rig Release: 11/26/2004
Rig Number:
Spud Date: 10/28/2004
End: 11/26/2004
Group:
Blow down steam and water lines, disconnect service loops and
prepare to move rig
Moved rig off 1 E-114 and moved to 1 E-168
Spotted sub base over well, set in rig complex's and RU, hooked up
service loops and completed rig acceptance checklist
Accepted Rig @ 12:00 hrs 10/27104
NU 21 114" 2M diverter system with 16" line, began mixing spud mud
and loading pipe shed with 5" DP & HWDP
Changed over top drive and iron roughneck from 4" to 5" DP
Slip and cut 106' of drlg line and serviced top drive
PU and stood back in derrick 38 stds of 5" DP and 10 stds of 5" HWDP
and Jars
Function test diverter system and checked ok, Chuck Scheeve
W/AOGCC waived witnessing of test
Began PU 13 1/2" BHA #1 to rig floor
MU 131/2" bit, mud motor with 1.8 deg bend on BHA #1and tagged ice
at 85'
Flooded conductor checking lines for leaks and pressure tested surface
equipment
Cleaned out ice and cement inside conductor from 85' to 108'
Spudded well and drilled 13 1/2" hole from 108' to 231', ART 1 hr
POOH to 53', MU MWD and oriented, then MU UBHO sub and
oriented, PU 3- NM flex DC's RIH to 231'
Drilled 131/2" hole per directional plan from 231' to 900' MD/865' TVD
(669') ART 1.7 hrs, AST 2.3 hrs, 10-15K wob, 40-60 rpm's, 140 spm,
592 gpm, off btm pressure 1,300 psi, on btm 1,400 psi, off btm torque
2K ft-Ibs, on btm 4K ft-Ibs, rot wt 85K, up wt 85K, dn wt 83K, took
2-gyro surveys on slickline at 279' and 369'
10.00 DRILL DRLG SURFAC Drilled 13 1/2" hole per directional plan from 900' to 2,034' MD/1 ,602'
TVD (1,134') ART 2.6 hrs, AST 4.5 hrs, 10-20K wob, 60 rpm's, 140
spm, 592 gpm, off btm pressure 1,600 psi, on btm 1,850 psi, off btm
torque 4K ft-Ibs, on btm 6K ft-Ibs, rot wt 80K, up wt 95K, dn wt 82K
Monitored well-static
Circ to clear BHA and pumped out of hole from 2,034' to HWDP at
1,110', pumped out at 300 gpm at 500 psi, monitored well at
HWDP-static
POOH on elevators from 1,110' to 650' to change out motor per
directional plan, no problems POOH
Fin POOH, stood back HWDPand MWD, LD 1.8 deg bend MM and bit
MU RR bit and 1.2 deg bend MM and oriented, RIH with MWD and
HWDP, MU ghostreamer RIH to 1,115'
RIH from 1,115' to 1,951', washed 83' to btm at 2,034 with no problems
Drilled 13 1/2" hole per directional plan from 2,034' to 3,061' MD/1 ,972'
TVD (11027') ART 4.2 hrs, AST .7 hrs, 5-25K wob, 110 rpm's, 165 spm,
700 gpm, off btm pressure 2,250 psi, on btm 2,350 psi, off btm torque
5K ft-Ibs, on btm 9K ft-Ibs, rot wt 86K, up wt 103K, dn wt 76K, 9.4 ppg
MW, 200 Vis
12.00 DRILL DRLG SURFAC Drilled 131/2" hole per directional plan from 3,061' to 4,361' MD/2,459'
TVD (1,300') ART 6.2 hrs, AST 1.7 hrs, 10-25K wob, 110 rpm's, 165
spm, 700 gpm, oft btm pressure 2,400 psi, on btm 2,600 psi, oft btm
torque 11 K ft-Ibs, on btm 14K ft-Ibs, rot wt 98K, up wt 147K, dn wt 63K,
9.4 ppg MW, 180 Vis
Began seeing gas hydrates at 3,800' MDI 2,236' TVD
1 0/27/2004 00:00 - 02:00 2.00 MOVE DMOB MOVE
02:00 - 06:00 4.00 MOVE MOVE MOVE
06:00 - 12:00 6.00 MOVE RURD MOVE
12:00 - 14:30 2.50 WELCT NUND SURFAC
14:30 - 17:00 2.50 DRILL RIRD SURFAC
17:00 - 18:30 1.50 RIGMNT RSRV SURFAC
18:30 - 23:00 4.50 DRILL PULD SURFAC
23:00 - 23:30 0.50 WELCT BOPE SURFAC
23:30 - 00:00 0.50 DRILL PULD SURFAC
1 0/28/2004 00:00-01:15 1.25 DRILL PULD SURFAC
01:15 - 01:45 0.50 DRILL CIRC SURFAC
01 :45 - 02:00 0.25 CEMEN COUT SURFAC
02:00 - 03:15 1.25 DRILL DRLG SURFAC
03:15 - 05:00 1.75 DRILL TRIP SURFAC
05:00 - 12:00 7.00 DRILL DRLG SURFAC
12:00 - 22:00
22:00 - 22: 15 0.2þ DRILL OBSV SURFAC
22:15 - 23:30 1.25 DRILL TRIP SURFAC
23:30 - 00:00 0.50 DRILL TRIP SURFAC
10/29/2004 00:00 - 02:00 2.00 DRILL TRIP SURFAC
02:00 - 03:30 1.50 DR-H±- PULD SURFAC
03:30 - 04:00 0.50 DRILL TRIP SURFAC
04:00 - 12:00 8.00 DRILL DRLG SURFAC
12:00 - 00:00
Printed: 12/10/2004 2:59:08 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-168
1E-168
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 10/27/2004
Rig Release: 11/26/2004
Rig Number:
Spud Date: 10/28/2004
End: 11/26/2004
Group:
0.25 DRILL DRLG SURFAC Drilled 13 1/2" hole per directional plan from 4,361' to 4,425' MD/2,481'
TVD (64') (Csg pt) ART .3 hrs, AST -0- hrs, 10-25K wob, 110 rpm's,
165 spm, 700 gpm, off btm pressure 2,400 psi, on btm 2,600 psi, off
btm torque 11 K ft-Ibs, on btm 13K ft-Ibs, rot wt 100K, up wt 150K, dn wt
63K, 9.4 ppg MW, 160 Vis
Circ hole to clear BHA, circ at 700 gpm, 2,400 psi
Monitored well-static
Backreamed out of hole from 4,425' to BHA at 1,115', backreamed out
at 110 rpm's, 550 gpm at 1,700 psi, last 2 stds pulled slower to circ hole
clean, no problems POOH
Monitored well at BHA-static, LD ghost reamer, POOH standing back
HWDP, LD std of NM flex DC's, MWD, motor and bit, cleared rig floor
RU Doyons 10 3/4" csg equipment with Franks fill up tool
Held PJSM with rig crew and tong operator on running of csg
MU 103/4" float shoe, 2 jts 103/4" 45.5# L-80, BTC csg and fit collar,
thread locked conn below FC and circ thru shoe track, RIH with 103/4"
csg to 2,030' (49 Jts & 1-10' pup jt), st wt up 117K, dn wt 77K
RIH circ csg down from 2,030' to 2,301' circ out heavy mud, circ hole
clean while RIH, staged pump rate up to 6 bpm at 375 psi
Cont RIH with 103/4" csg, MU hanger and landed csg with float shoe at
4,419' and float collar at 4,335', no problems RIH, Ran a total of 106 jts
(4,373') of 45.5#, L-80, BTC csg and 1-10' pup jt, total including float
equip, csg and hanger, 4,389', ran 15 bow spring centralizers and 2
stop rings per well plan, st wt up 215K, dn wt 62K
Began to circ and cond mud thru fill up tool, circ at 4 bpm 350 psi
While reciprocating pipe, csg hanger snagged riser causing the riser to
PU out of diverter causing 4 bbls of mud to spill into cellar, cleaned up
cellar and reinstalled riser
Cont to circ and condition mud thru fill up tool, staged pump rate up to 7
bpm at 490 psi, circ 2X btms up, st wt up 195K dn wt 66K
LD Franks fill up tool, blow down top drive and MU Dowell cement head
Fin circ and cond mud for cementing, circ at 7 bpm, 450 psi,
conditioned mud from 9.6 ppg, 83 vis, PV 23, YP 41 to 9.3 ppg, 39 vis,
PV 14, YP 12, Hanger was tagging 1" high, pulled hanger to rig floor
and looked ok with small area of scarring, held PJSM with Dowell, APC
vac truck drivers and rig crew while circ hole
1.25 CEMEN PUMP SURFAC Turned over to Dowell and pumped 10 bbls of CW 100 at 8.3 ppg,
pressure tested lines to 3,500 psi, pumped add. 40 bbls of CW 100 (50
bbls Total), then pumped 50 bbls of 10.5 ppg XL Mudpush, ave 5 bpm
at 200 psi, shut down and dropped btm plug, began mixing and
pumping lead cement, at report time have pumped 200 bbls of 570 bbls
of 10.7 ppg Arctic set lite cement, st wt up 195K, dn wt 67K
1.00 CEMEN PUMP SURFAC Cont to cement 103/4" csg, pumped an additional 370 bbls of lead cmt
(570 bbls total, 720 sxs) at 10.7 ppg and 4.45 yield with additives, ave 7
bpm at 150 psi, followed with 97 bbls, 220 sxs of tail cmt at 12.0 ppg
and 2.49 yield with add. ave 6 bpm at 320 psi, shut down and dropped
top plug.
NOTE: while reciprocating pipe and after pumping 475 bbls of lead cmt
and with 50 bbls of lead cmt out of shoe, pipe stuck off hanger 1',
attempted to work pipe down with no success, was able to PU on pipe,
but was unable to get back down into hanger, PU on pipe 5' to get
hanger and pup jt above landing ring, Landed csg with fit shoe at 4,414'
with fit collar at 4,330'
10/30/2004 00:00 - 00:15
00: 15 - 00:30 0.25 DRILL CIRC SURFAC
00:30 - 00:45 0.25 DRILL OBSV SURFAC
00:45 - 05:45 5.00 DRILL REAM SURFAC
05:45 - 09:00 3.25 DRILL PULD SURFAC
09:00 - 10:45 1.75 CASE RURD SURFAC
10:45 - 11 :00 0.25 CASE SFTY SURFAC
11:00 -14:15 3.25 CASE RUNC SURFAC
14:15 - 15:45 1.50 CASE RUNC SURFAC
15:45 - 18:30 2.75 CASE RUNC SURFAC
18:30 - 18:45 0.25 CEMEN SURFAC
18:45 - 19:15 0.50 CEMEN SURFAC
19:15 - 20:30 1.25 CEMEN SURFAC
20:30 - 21 :00 0.50 CEMEN SURFAC
21 :00 - 22:45 1.75 CEMEN SURFAC
22:45 - 00:00
10/31/2004 00:00 - 01:00
Printed: 12/1012004 2:59:08 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-168
1 E-168
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 10/27/2004
Rig Release: 11/26/2004
Rig Number:
Spud Date: 10/28/2004
End: 11/26/2004
Group:
01 :15 - 01 :45 0.50 CEMEN SURFAC
01 :45 - 05:00 3.25 WELCT SURFAC
05:00 - 06:00 SURFAC
06:00 - 09:00 3.00 WELCT SURFAC
09:00 - 12:00 3.00 WELCT SURFAC
12:00 - 13:45 1.75 DRILL RIRD SURFAC
13:45 - 14:30 0.75 RIGMNT RSRV SURFAC
14:30 - 15:30 1.00 WELCT SURFAC
15:30 - 18:15 2.75 WELCT SURFAC
18:15 - 23:00 4.75 WELCT SURFAC
23:00 - 23:30 0.50 DRILL OTHR SURFAC
23:30 - 00:00 0.50 DRILL PULD SURFAC
11/1/2004 00:00 - 00:30 0.50 DRILL RIRD SURFAC
00:30 ~ 04:00 3.50 DRILL PULD SURFAC
04:00 - 07:15 3.25 DRILL PULD SURFAC
07:15 - 07:45 0.50 DRILL RIRD SURFAC
07:45 - 11 :00 3.25 DRILL PULD SURFAC
11 :00 - 11 :30 0.50 DRILL TRIP SURFAC
11 :30 - 12:00 0.50 DRILL SFTY SURFAC
12:00 - 12:15 0.25 RIGMNT RGRP SURFAC
12:15 - 13:15 1.00 DRILL TRIP SURFAC
13:15 - 14:00 0.75 DRILL DEQT SURFAC
14:00 - 15:00 1.00 DRILL TRIP SURFAC
15:00 - 16:00 1.00 DRILL TRIP SURFAC
16:00 - 16:30 0.50 DRILL CIRC SURFAC
16:30 - 17:30 1.00 CASE DEQT SURFAC
17:30 - 20:45 3.25 CEMEN OSHa SURFAC
Dowell pumped 20 bbls FW and turned over to rig and rig displaced cmt
with 398 bbls of 9.4 ppg mud, ave 7 bpm, initial pressure 550 psi, max
pressure 800 psi, slowed to 4 bpm and bumped plugs on calc
displacement to 1,400 psi, ck floats and floats held, CIP at 01 :15, Had
178 bbls of 10.7 ppg lead cmt back to surface
NOTE: Had 1 Hr time change
Flushed CMT out of diverter system and flowline
NO diverter line and lifted up riser, diverter and starting head, set 10
3/4" emergency slips with 50K Ibs string wt, made rough cut on 10 3/4"
csg and set diverter back down
RD cement head, LD landing jt with hanger and cut-oft piece of 10 3/4"
csg
ND diverter and starting head, used crane to set out dverter system
over flow line of well 1 E-28. DSO had well shut in during operation.
Made final cut on 103/4" csg and GBR welder welded on Vetco/Gray
csg head adapter per Vetco/Gray procedure. VetcoGray rep present for
complete operation.
Changed out saver sub, bell guide and grabber on top drive to 4"
Serviced top drive and drawworks while allowing well head to cool
down, tested weld on adapter head to 2,000 psi for 10 min and ck ok
Oriented and NU Vetco/Gray 135/8" 5M# MB 222 wellhead, tested btm
wellhead sub to 5,000 psi for 10 min and ck ok
NU BOP stack
RU and tested BOPE, choke manifold, 4" and 5" floor valves, rams
including 7 5/8" csg rams to 250 psi low and 3,500 psi high, annular to
250 psi low and 2,800 psi high, John Crisp with AOGCC waived
witnessing of test
Installed wear bushing
RIH with 4 stds of 5" DP from derrick and POOH LD same
Changed out 5" handling tools over to 4" DP
PU and RIH with 72 jts (24 stds) of 4" XT-39 DP, POOH and stood back
PU and RIH with 63 jts (21 stds) of 4" XT-39 DP, POOH and stood back
Changed out 4" handling tools over to 5", cleaned rig floor
MU 9 7/8" BHA #3 with Autotrak tool, MPS, stop sub and float sub,
uploaded Autotrak, PU 3-NM flex Dc's & RIH with HWDP and jars, MU
ghost reamer
RIH with BHA #3 from 1,077' to 2,007' with 5" DP
Held tripping drill with rig crew and post drill discussion
Worked on Iron roughneck, top door latch wouldn't close, hydraulic ram
broke
POOH from 2,007' to BHA at 1,077' checking connections to ghost
reamer due to iron roughneck hydraulic ram breaking and ck ok
RIH to 1,160' and shallow tested Autotrak tool, staged pump rate up to
550 gpm, had MWD pulse but no confirmation
RIH from 1,160' to 2,007'
RIH from 2,007' to 4,324'
Circ hole evening MW in & out at 9.3 ppg for csg test, circ at 595 gpm,
2,400 psi, rot wt 90K, up wt 142K, dn wt 62K, 12K ft-Ibs torque at 60
rpm's
RU and tested 10 3/4" csg to 3,000 psi for 30 min, good test
RIH and tagged plugs above float collar, drilled out plugs, float collar at
4,330', shoe track, float shoe at 4,414' and cleaned out to btm at 4,425',
drilled 20' of new formation to 4,445' MOl 2,488' TVD, 5-30K wob, 60-90
Printed: 12/10/2004 2:59:08 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-168
1 E-168
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 10/27/2004
Rig Release: 11/26/2004
Rig Number:
Spud Date: 10/28/2004
End: 11/26/2004
Group:
21 :45 - 23:00
rpms, 595 gpm at 2,300 psi, ADT .2 hrs
Displaced out 9.3 ppg spud mud in hole with reconditioned 9.0 ppg
LSND
1.25 DRILL LOT SURFAC RU & performed LOT to 10.7 ppg EMW at 2,447' TVD with 9.3 ppg MW
and 220 psi, downlinked Autotrak and discussed LOT with town and
decision was made to drill ahead
1.00 DRILL DRLG INTRM1 Drilled 97/8" hole from 4,445' to 4,511' MD/2,512' TVD (66') ADT .4
hrs, 5-15K wob, 80 rpm's, 551 gpm, 1,900 psi, off btm torque 14K ft-Ibs,
on btm 14K ft-Ibs, rot wt 94K, up wt 160K, dn wt 57K, while drilling out
of shoe GRlResistivity tool failed on Autotrak tool.
1.00 DRILL CIRC INTRM1 Circ btms up while POOH from 4,511' to 4,414' to csg shoe, circ at 550
gpm, 1,900 psi and 40 rpm's
0.25 DRILL OBSV INTRM1 Monitored well at shoe-static, pumped dry job
0.75 DRILL TRIP INTRM1 POOH from 4,414' to 3,861', decision was made to RIH and drill ahead
thru curve section with Autotrak tool then POOH and PU mud motor
and MWD, back-up RNT/DIR tool had dead battery and would not be
able to use with Autotrak tool and also would allow time to put tools in
pipe shed to warm up
1.00 DRILL TRIP INTRM1 RIH from 3861' to 4,421', washed 90' to btm at 4,511' and downlinked
Autotrak to ribs on -
9.00 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan from 4,511' to 5,542' MDI 2,970'
TVD (1,031') ADT 5.3 hrs, 5-15K wob, 120 rpm's, 138 spm, 585 gpm,
off btm pressure 2,550 psi, on btm.2,600 psi, off btm torque 6K ft-Ibs,
on btm 7K ft-Ibs, rot wt 99K, up wt 120K, dn wt 82K, with 9.0 ppg mud,
clean hole ECD was 9.6 ppg, while drlg with 9.1 ppg mud, ECD ave
10.3 ppg, added 2% lubricants to mud, rig and camp off highline at
08:30 hrs
11.00 DRILL DRLG INTRM1 Drilled 9 7/8/1 hole from 5,542' to 6,941' MDI 3,445' TVD (1,399') ADT
6.4 hrs, 5-20K wob, 120 rpm's, 585 gpm, off btm pressure 3,075 psi, on
btm 3,125 psi, off btm torque 6K ft-Ibs, on btm 8K ft-Ibs, rot wt 100K, up
wt 128K, dn wt 84K, 9.2 ppg mud, ECD ave 11.0 ppg with no mud loss,
preparing to POOH to LD Autotrak tool, rig and camp back on highline
at 13:45 hrs
Circ for survey and clear BHA, downlinked Autotrak tool to backreaming
mode (steering mode w/-O- force), monitored well-static
Began backreaming out of hole from 6,941' to 6,564', backreaming out
at 120 rpm's, 585 gpm at 3,100 psi with no problems
Backreamed out of hole from 6,564' to 5,448', backreamed at 120
rpm's, 585 gpm, 3,000 psi, pumped out of hole from 5,448' to 4,327' to
inside 103/4/1 csg, pumped out at 585 gpm, 2,500 psi
Circ hole clean at 4,327', circ at 585 gpm, 2,400 psi
Monitored well-static, pumped dry job
POOH from 4,327' to BHA #3 at 1,077'
Repaired hydraulic leak on iron roughneck
Stood back HWDP, jars and NM flex DC's, download MWD/Autotrak
and LD same
MU 97/8" BHA #4,63/4" mud motor with 1.1 deg bend, MAP/MPR and
MWD, oriented and uploaded MWD, RIH with NM flex DC's, HWDP,
jars and ghost reamer to 1,113'
RIH from 1,113' to 2,041'
Shallow tested MWD at 2,041', circ at 490 gpm at 2,100 psi and tool ck
ok
RIH from 2,041' to 4,360', st wt up 115K, dn wt 76K
23:00 - 00:00
11/2/2004
00:00 - 01 :00
01 :00 - 01 :15
01:15 - 02:00
02:00 - 03:00
03:00 - 12:00
12:00 - 23:00
23:00 - 23:30 0.50 DRILL CIRC INTRM1
23:30 - 00:00 0.50 DRILL REAM INTRM1
11/3/2004 00:00 - 03:45 3.75 DRILL REAM INTRM1
03:45 - 04:15 0.50 DRILL CIRC INTRM1
04:15 - 04:30 0.25 DRILL OBSV INTRM1
04:30 - 05:45 1.25 DRILL TRIP INTRM1
05:45 - 06:15 0.50 RIGMNT RGRP INTRM1
06:15 - 08:30 2.25 DRILL PULD INTRM1
08:30-11:15 2.75 DRILL PULD INTRM1
11 :15 - 12:00 0.75 DRILL TRIP INTRM1
12:00 - 12:15 0.25 DRILL DEQT INTRM1
12:15 - 13:15 1.00 DRILL TRIP INTRM1
Printed: 12/10/2004 2:59:08 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-168
1 E-168
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 10/27/2004
Rig Release: 11/26/2004
Rig Number:
Spud Date: 10/28/2004
End: 11/26/2004
Group:
1113/2004 13:15 - 14:15 1.00 RIGMNT RSRV INTRM1 Slip and cut 65' of drlg line and serviced top drive
14:15 - 15:45 1.50 DRILL TRIP INTRM1 RIH from 4,360' to 6,885', washed down 56' to btm at 6,941' with no
problems
15:45 - 17:30 1.75 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan from 6,941' to 7,149' MD/3,490'
TVD (208') ADT 1.1 hrs, 5-10K wob, 120 rpm's, 138 spm, 585 gpm, off
btm pressure 3,150 psi, on btm 3,250 psi, off btm torque 9K ft-Ibs, on
btm 9K ft-Ibs, rot wt 101 K, up wt 135K, dn wt 78K
17:30 - 18:30 1.00 RIGMNT RGRP INTRM1 Changed out swivel packing on top drive
18:30 - 00:00 5.50 DRILL DRLG INTRM1 Drilled 97/8" hole per directional plan from 7,149' to 7,630' MD/3,595'
TVD (481') ADT 3.3 hrs, 5-20K wob, 90-120 rpm's, 138 spm, 585 gpm,
off btm pressure 3,250 psi, on btm 3,300 psi, off btm torque 12K ft-Ibs,
on btm 11 K ft-Ibs, rot wt 100K, up wt 137K, dn wt 75K, 9.3 ppg MW,
ave ECD 10.2 ppg, ave BGG 175 units, max gas 350 units
Est top of West Sak "0" at 7,029' MOl 3,463' TVD, Est top of "B" sand
at 7,353' MD/3,535' TVD
11/4/2004 00:00 - 06:00 6.00 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan from 7,630' to 8,158' MOl 3,715'
TVD (528') ART 1.4 hrs, AST 2.1 hrs, 5-15K wob, 90 rpm's, 138 spm,
585 gpm, off btm pressure 3,300 psi, on btm 3,400 psi, off btm torque
10K ft-Ibs, on btm 9K ft-Ibs, rot wt 100K, up wt 135K, dn wt 80K, 9.3
ppg MW, ave ECD 10.2 ppg, ave BGG 175 units, max gas 350 units
06:00 - 06:15 0.25 DRILL OBSV INTRM1 Monitored well-static
06:15 - 08:00 1.75 DRILL REAM INTRM1 Backreamed out from 8,158' to 7,072', backreamed out at 120 rpm's,
585 gpm, 3,300 psi with no problems
08:00 - 10:30 2.50 LOG DLOG INTRM1 Backreamed out and logged up from 7,072' to 6,250' to above K-13 top,
logged at 5-10'/min, 120 rpm's, 585 gpm 3,300 psi
10:30 - 13:15 2.75 DRILL REAM INTRM1 Cont to backream out of hole from 6,250' to 5,577', till ghost reamer
was at csg shoe then pumped out of hole from 5,577' to 4,360', 120
rpm's, 585 gpm, 2,750 psi, st wt up 128K, dn wt 77K
13:15 - 14:15 1.00 DRILL CIRC INTRM1 Circ hole clean at 4,360', circ at 585 gpm, 2,400 psi, 80 rpm's and 7K
ft-Ibs torque, circ 2X btms and was clean at shakers
14:15 - 15:00 0.75 DRILL CIRC INTRM1 POOH 1 std to 4,267' and hole taking proper fill, pumped 40 bbl EMI
920 lubricant pill and spotted in hole to 500'
15:00 - 18:00 3.00 DRILL PULD INTRM1 Dropped 5" DP wiper dart and POOH LD 102 jts of 5" DP
18:00 - 20:30 2.50 DRILL PULD INTRM1 POOH LD 5" HWDP, jars and ghost reamer, downloaded MWD and LD
BHA #4, cleared rig floor and pulled wear bushing
20:30 - 21 :30 1.00 CASE RURD INTRM1 RU Doyons 7 5/8" csg equipment with Franks fill up tool
21 :30 - 22:00 0.50 CASE SFTY INTRM1 Held PJSM with rig crew and tong operator on running of 7 5/8" csg
22:00 - 00:00 2.00 CASE RUNC INTRM1 RIH with 7 5/8",29.7#, L-80, BTC-M csg to 1,140', MU 75/8" Float
shoe, 3 jts csg and float collar, thread locked btm 4 conn's and circ thru
float equip and ck ok, RIH with 22 add. jts along with pup jts for spacing
out to 1,140'
11/5/2004 00:00 - 01 :15 1.25 CASE RUNC INTRM1 RIH with 7 5/8" csg from 1,140' to 2,002'
01 :15 - 01 :45 0.50 CASE CIRC INTRM1 Circ a csg capacity at 2,002', circ at 3 bpm at 300 psi
01 :45 - 04:15 2.50 CASE RUNC INTRM1 RIH with 7 5/8" csg from 2,002' to 4,380' to above 103/4" csg shoe
04:15 - 05:30 1.25 CASE CIRC INTRM1 LD Franks fill up tool, MU circ swedge and circ a csg capacity at shoe,
staged pump rate up to 5 bpm at 350 psi, st wt up 11 OK, dn wt 75K,
changed out rubber cup on fill up tool and made tool back up
05:30 - 10:15 4.75 CASE RUNC INTRM1 Fin RIH with 7 5/8" csg, RIH to btm at 8,158' with no problems. Landed
75/8" csg at 8,157' MOl 3,715' TVD with float collar at 8,026', ran a
total of 189 jts 7 5/8",29.7#, L-80 BTC-M csg with 5-pup jts (Total
8,165.95'), ran 58 tandem rise cent on 58 stop rings per well plan, 3/2
jts (every 30'), did not use hanger, will use emergency slips
1 0: 15 - 11: 15 1.00 CEMEN CIRC INTRM1 Circ btms up thru Franks fill up tool while conditioning mud, staged
Printed: 12/10/2004 2:59:08 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1E-168
1E-168
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 1 0/27/2004
Rig Release: 11/26/2004
Rig Number:
Spud Date: 10/28/2004
End: 11/26/2004
Group:
13:30 - 15:00
pump rate up to 6 bpm, 525 psi, st up wt 190K, dn wt 80K
LD Franks fill up tool and MU Dowells cement head
Cont to circ and cond mud for cementing, circ at 6 bpm at 425 psi, st wt
up 200K, dn 85K, initial MWout, 9.6 ppg, 78 vis, PV 32, YP 40,
Conditioned mud to final MW out of 9.2 ppg, 41 vis, 11 YP and 14 PV,
Held PJSM with Dowell, APC vac truck drivers and rig crew on
cementing csg while circ.
Dowell pumped 10 bbls CW 100 at 8.3 ppg, Pressure tested lines to
3,500 psi, Then pumped 40 add. bbls of CW 100, Pumped 50 bbls of
MudPush at 10.5 ppg, Dropped btm plug then pumped 168.2 bbls, (422
sxs) of DeepCrete cmt at 12.5 ppg, 2.26 yield with additives, ave 6.5
bpm at 250 psi, Reciprocated pipe with full returns, shut down, Washed
up and dropped btm plug.
1.25 CEMEN DISP INTRM1 Rig displaced cement with 9.3 ppg OBM, Bumped plug on calc
displacement after pumping 368.3 bbls OBM (96% pump eft.) ave 7.0
bpm while displacing cmt, Max pressure 1100 psi, Slowed pump rate to
3 bpm with 3 bbls left to pump and bumped plug to 1,600 psi, ck floats
and held CIP at 16:10 hrs, Reciprocated pipe until 73.0 bbls cmt was
around shoe when hole began getting tight and stopped reciprocating
w/ Shoe @ 8,157', Float Collar @ 8.026', Calc TOC @ 4,786', Had full
returns thru out job.
Tested 7 5/8" csg to 3,000 psi for 30 min, good test
RD cement head and used rig vacuum to drain landing jt
ND & PU on BOP stack
Set 7 5/8" csg slips with 135K block wt, 100K st wt, made rough cut
using cold cut saw and LD cut piece, made final cut and installed
pack-oft, Tested same to 3800 psi f/10 min.
NU BOP stack and choke line
RD Doyons 7 5/8" csg equipment, changed out elevator bales and
installed wear bushing
NOTE: at 21 :30 Pumped 30 bbls fresh water down 7 5/8" x 10 3/4"
annulus, ave 1 bpm at 720 psi
Tested choke line at 250 psi and 3,500 psi, due to breaking flange on
stack to set slips
Loaded pipe shed with 4" XT-39 DP and strapped
Cont. to load 4" DP into pipe shed and strap, Pumped 10 bbls add.
water down 75/8" x 10 3/4" annulus at 1 bpm, 680 psi
PU and stood back 4 stds 4 3/4" DC's, 9 stds hybrid push pipe (2-dc's,
1 hwdp), 11stds of 4" HWDP
NOTE: Finished flushing 7 5/8" x 10 3/4 H annulus with 135 bbls water
(175 total) after CIP 12 1/2 hrs and surface cement was hard, initial rate
1 bpm at 720 psi, final rate 2 bpm at 700 psi
2.50 DRILL PULD INTRM1 MU 63/4" BHA #5 with 4 3/4" MM with 1.2 deg bend and MWD,
oriented and uploaded MWD, MU 3-NM flex DC's and std of HWDP
with jars RIH to 251'.
NOTE: Little Red freeze protected 7 5/8" x 10 3/4" annulus with 90 bbls
diesel
RIH with BHA #5 from 251' to 4,835', PU singles of 4" XT-39 DP from
pipe shed, shallow tested MWD at 1,185'
Serviced top drive and inspected saver sub
Cont RIH with BHA #5 from 4,835' PU DP from pipe shed, tagged plugs
above float collar at 8,026'
Drilled out float collar at 8,026', shoe track, float shoe at 8,157' and 20'
15:00 - 16:15
16:15 - 17:00 0.75 CASE DEQT INTRM1
17:00 - 17:30 0.50 CEMEN RURD INTRM1
17:30 - 18:15 0.75 CASE NUND INTRM1
18:15 - 20:30 2.25 CASE OTHR INTRM1
20:30 - 21:15 0.75 CASE NUND INTRM1
21 :15 - 22:45 1.50 CASE RURD INTRM1
22:45 - 23:00 0.25 WELCT BOPE INTRM1
23:00 - 00:00 1.00 DRILL OTHR INTRM1
11/6/2004 00:00 - 02:00 2.00 DRILL OTHR INTRM1
02:00 - 08:00 6.00 DRILL PULD INTRM1
08:00 - 10:30
10:30 - 14:45 4.25 DRILL TRIP INTRM1
14:45 - 15:15 0.50 RIGMNT RSRV INTRM1
15:15 - 17:30 2.25 DRILL TRIP INTRM1
17:30 - 18:00 0.50 CEMEN DSHO INTRM1
Printed: 12/1012004 2:59:08 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-168
1 E-168
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 1 0/27/2004
Rig Release: 11/26/2004
Rig Number:
Spud Date: 10/28/2004
End: 11/26/2004
Group:
of new formation to 8,178' MD/3,716' TVD, ADT.1 hrs, 5-15K wob, 70
rpm's, 255 gpm, 2,200 psi, rot wt 84K, up wt 119K, dn wt 65K
18:00 - 19:30 1.50 DRI LL CIRC INTRM1 PU till bit was up into esg and cire hole clean evening MW in and out at
9.1 ppg, circ at 297 gpm, 2,350 psi, circ 2X btms up
19:30 - 20:15 0.75 DRILL LOT INTRM1 RU and performed LOT to 14.8 ppg EMW, 1,110 psi at 3,715' TVD and
9.1 ppg OBM
20:15 - 00:00 3.75 DRILL DRLG PROD Drilled 6 3/4" hole in "A" sand lateral from 8,178' to 8,500' MD/3,722'
TVD, (322') ART 1.5 hrs, AST .4 hrs, 2-5K wob, 120 rpm's, 73 spm, 310
gpm, off btm pressure 2,450 psi, on btm 2,500 psi, off btm torque 7K
ft-Ibs, on btm 6K ft-Ibs, rot wt 85K, up wt 137K, dn wt 53K, clean hole
ECD with 9.1 ppg OBM was 10.5 ppg, drlg with 9.1 ppg OBM, ave ECD
10.8 ppg, Est top of West Sak "A" 8,357' MD/3,719' TVD
1117/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Directionally drilled 63/4" hole in "A" sand lateral from 8,500' to 9,778'
MD/3, 711' TVD (1,278') ART 5.1 hrs, AST 1.7 hrs, 2-5K wob, 120
rpm's, 73 spm, 310 gpm, off btm pressure 2,550 psi, on btm 2,650 psi,
off btm torque 8K ft-Ibs, on btm 7K ft-Ibs, rot wt 85K, up wt 140K, dn wt
51 K, 9.0+ ppg OBM, ave ECD 10.9 ppg, ave BGG 250 units, max gas
650 Units from 8,500'
12:00 - 00:00 12.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "A" sand lateral from 9,778' t011, 136'
MD/3,739' rvD (1,358') ART 6.1 hrs, AST 1.1 hrs, 2-15K wob, 120
rpm's, 75 spm, 318 gpm, off btm pressure 2,900 psi, on btm 3,050 psi,
off btm torque 9K ft-Ibs, on btm 7K ft-Ibs, rot wt 84K, up wt 160K, dn wt
35K (blk wt, -0- dn wt), pumped weighted hi vis sweep at 10,900' and
had 10% increase in cuttings back, 9.1 ppg OBM, ave ECD 11.4 ppg,
max ECD 11.8 during sweep ave BGG 175 units, max gas 350 units, on
last stand unable to slide due to -0- dn wt, preparing to baekream out of
hole 15 stds, and RIH with 5 stds HWDP
11/8/2004 00:00 - 03:00 3.00 DRILL WIPR PROD Backreamed out of hole 15 stds to wipe hole from 11,136' to 9,781',
backreamed at 120 rpm's 318 gpm 2,700 psi, pulled 1st 13 stds to get a
btms up, pulled last 2 stds slow to get add. btms up and clean at
shakers
03:00 - 03:15 0.25 RIGMNT RGRP PROD Changed out hi-low drum clutch control valve on drillers console
03:15 - 04:00 0.75 DRILL TRIP PROD RIH with 10 stds 4" DP then RIH with 5 stds HWDP to 11,078' and
washed 58' to btm, no problems, st up wt 150K, dn wt 57K
04:00 - 12:15 8.25 DRILL DRLG PROD Directionally drilled 6 3/4" hole in II A" sand lateral from 11,136' to
11,927' (791'), ART 2.9 hrs, AST 1.4 hrs, 2-7K wob, 120 rpm's, 318
gpm, off btm pressure 3,150 psi, on btm 3,500 psi, off btm torque 8.5K
ft-Ibs, on btm 7.5K ft-Ibs, rot wt 92K, upwt 160K, dn wt 49K, 9.0+ OBM,
ave ECD 11.3 ppg, ave BGG 150 units, max gas 300 units, attempted
to slide and was unable to get wt to bit
12:15 - 12:45 0.50 DRILL TRIP PROD Pumped out of hole 3 stds of 4" DP from 11,927' to 11,700', RIH with 3
stds hybrid push pipe
12:45 - 14:15 1.50 DRILL DRLG PROD Directionally drilled 6 3/411 hole in "AII sand lateral from 11,927' to
12,073' MD/3,723' TVD (146'), ART .4 hrs, AST .4 hrs, 2-7K wob, 120
rpm's, 318 gpm, off btm pressure 3,300 psi, on btm 3,500 psi, off btm
torque 9K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 100K, up wt 177K, dn wt 40K,
9.1+ OBM, ave ECD 11.5 ppg, ave BGG 75 units, max 150 units
14:15 - 14:45 0.50 DRILL CIRC PROD Circ hole and evaluate logs for geology, decision made to backream out
of hole to shoe to wipe hole and PU Lo-Tads for add. st wt and appears
we drilled out of formation and will do a open hole sidetrack at +1-
11,725'
14:45 - 20:30 5.75 DRILL WIPR PROD Backreamed out of hole from 12,073' to 8,100' to inside 7 5/811 csg,
backreamed out at 120 rpm's, 318 gpm, 3,050 psi, no problems
Printed: 12/10/2004 2:59:08 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E -168
1 E-168
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 10/27/2004
Rig Release: 11/26/2004
Rig Number:
Spud Date: 10/28/2004
End: 11/26/2004
Group:
11/812004 20:30 - 21 :45 1.25 DRILL CIRC PROD Pumped weighted hi vis sweep and circ hole clean at 8,100', had no
increase in cuttings back from sweep and circ an add btms up and
clean at shakers, circ at 318 gpm, 2,450 psi, 80 rpm's and 6K ft-Ibs
torque
21 :45 - 23:00 1.25 DRILL TRIP PROD Monitored well-static, POOH wet from 8,100' to 6,698' to PU Lo-Tads,
cleaned rig floor
23:00 - 00:00 1.00 RIGMNT RSRV PROD Slip and cut 74' of drlg line
11/9/2004 00:00 . 00:30 0.50 RIGMNT RSRV PROD Service top drive and drawworks
00:30 - 05:30 5.00 DRILL TRIP PROD RIH from 6,698' to 11,725' installing Lo-Tads on 4" DP and HWDP (PU
61 Lo-Tads)
06:00 - 08:15 2.25 DRILL DRLG PROD Oriented to low side, time drilled and open hole sidetrack 6 3/4· hole
from 11,725' to 11,765' and drilled to 11,809', AST 1.4 hrs, 2-5K wob,
318 gpm, 3,250 psi
08:15 - 09:15 1.00 DRILL CIRC PROD Setting up MWD database for sidetrack
09:15 - 12:15 3.00 DRILL DRLG PROD Cont. to sidetrack well, drilling 63/4· hole from 11,809' to 12,073'
MD/3,753' TVD (At orig. hole depth) ART 1.1 hrs, AST .7 hrs, 2-5 k
wob, 120 rpm's 75 spm, 318 gpm, off btm pressure 3,100 psi, on btm
3,250 psi, off btm torque 7.5K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 89K, up
wt 145K, dn wt 55K, 9.0 ppg OBM, ave ECD 11.35 ppg, ave BGG 75
units, max gas 200 units
12:15 - 00:00 11.75 DRILL DRLG PROD Directionally drilled 6 3/4· hole in ·A· sand lateral from 12,073' to
13,106' MDI 3,767' TVD (1,033'), ART 4.6 hrs, AST 1.6 hrs, 2-8K wob,
120 rpm's, 318 gpm, off btm pressure 3,600 psi, on btm 3,800 psi, off
btm torque 8.5K ft-Ibs, on btm 8K ft-Ibs, rot wt 105K, up wt 183K, dn wt
40K, 9.1 OBM, ave ECD 11.55 ppg, ave BGG 150 units, max gas 325
units,
11/10/2004 00:00 - 03:45 3.75 DRILL DRLG PROD Directionally drilled 6 3/4· hole in ·A· sand lateral from 13,106' to
13,477 MDI 3,763' TVD (371'), (T.D.) ART 2.5 hrs, AST .1 hrs, 5-11K
wob, 120 rpm's, 318 gpm, off btm pressure 3,850 psi, on btm 4,050 psi,
off btm torque 9K ft-Ibs, on btm 8K ft-Ibs, rot wt 107K, up wt 174K, dn
wt 50K, 9.0+ OBM, ave ECD 11.6 ppg, ave BGG 200 units, max gas
375 units, pumped weighted hi vis sweep on last std
03:45 - 04:00 0.25 DRILL CIRC PROD Fin circ out weighted hi vis sweep and to clear BHA, had no increase in
cuttings from sweep, circ at 318 gpm, 4,000 psi and 120 rpm's
04:00 - 04:15 0.25 DRILL OBSV PROD Monitored well-static
04:15-11:15 7.00 DRILL REAM PROD Backreamed out of hole from 13,477' to 8,145' (75/8· csg shoe),
backreamed out at 120 rpm's, 318 gpm, 3,800 psi with no problems
11:15 -12:45 1.50 DRILL CIRC PROD Pumped weighted hi vis sweep and circ hole clean, had no increase in
cuttings back from sweep and circ an add btms up and was clean at
shakers, circ at 318 gpm, 2,450 psi, 80 rpm's with 6K ft-Ibs torque, rot
wt 89K, up wt 113K, dn wt 75K
12:45·16:00 3.25 DRILL TRIP PROD RIH from 8,145' to 13,379', washed 98' to btm at 13,477', while RIH set
down at 11,735', rotated string 180 deg and went thru spot, no other
problems RI H
16:00 - 18:30 2.50 DRILL CIRC PROD Circ btms up at 13,477' then displaced out 9.1 ppg MOBM with 9.1 ppg
SFMOBM, circ at 300 gpm, 3,600 psi, 120 rpm's and 10K ft-Ibs torque,
rot wt 107K, up wt 164K, dn wt 69K
18:30·18:45 0.25 DRILL OBSV PROD Monitored well-static
18:45 - 00:00 5.25 DRILL TRIP PROD Dropped 1 3/4" rabbit and began POOH on elevators from 13,477' to
6,511' with no problems, monitored well at shoe-static, removed 11
Lo-tads from HWDP to be installed on 11 stds of 4· XT-39 DP
11/11/2004 00:00 - 04:00 4.00 DRILL TRIP PROD POOH wet on elevators from 6,511' to BHA #5 at 67', stood back NM
flex DC's and installed 11 Lo-Tads on DP on trip out
Printed: 12/10/2004 2:59:08 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-168
1 E-168
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 10/27/2004
Rig Release: 11/26/2004
Rig Number:
Spud Date: 10/28/2004
End: 11/26/2004
Group:
Downloaded MWD and LD MWD and MM, cleaned rig floor, calc fill on
trip out of hole 91 bbls, actual fill 121 bbls with 9.1 ppg SFMOBM in
hole
RU Doyon's 4 1/2" liner running equipment
Held PJSM on running of liner
PU and ran 41/2" liner per well program to 5,980', ran 4 1/2" ROT silver
bullet guide shoe with no float, 192 jts, (5,943.11') of 41/2" 12.6#, L-80,
DWC liner, placed blank liners across shale sections per geology, ran
89 jts (2,751.19') of blank liner and 103 jts (3,191.92') of slotted liner,
ran 64- 41/2" x 6 1/4" spiralglide centralizers 1/jt jt #1 to Jt #54 and on
jts with restrictor packers, then ran 108,41/2" x 53/4" straight blade
centralizers 1/Jt on jts #55 thru #172 (csg shoe) ran 17 restrictor
packers placed on blank liner to isolate shale sections per geology.
MU Baker 190-47 seal bore ext, 5 1/2" x 7 5/8" Flexlock liner hanger
with, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH
to 6,047'
RIH with liner on 4" DP to 8,073' (csg shoe) estcirc at 2.5 bpm, 200 psi,
then rotated liner at 20 rpm's with 4K ft-Ibs torque, rot wt 80K, up wt
98K, dn wt 65K
Cont to run 41/2" liner in open hole, RIH from 8,073' and tagged btm at
13,477' with no problems, PU to 13,473', stwt up 172K, dn wt 67K
Note: RIH with 4" DP with Lo-Tads, HWDP, 4 stds 4 3/4" DC's and
Push Pipe to run and set 4 1/2" liner
0.75 CASE OTHR CMPL TN Dropped 1 3/4" ball and pumped down to seat, pumped at 2 bpm at 400
psi, with ball on seat pressured up to 2,000 psi to set Flexlock hanger,
slacked off 30K, cont to set packer, pressured up to 3,900 psi and set
ZXP packer, no problems setting hanger/packer, set "A" sand liner with
TOL @ 7,437' MD/3,553' TVD and shoe at 13,473' MD 3,763' TVD, st
wt up after setting liner 140K, lost 32K st wt
RU & tested annulus above ZXP packer to 1,000 psi for 5 min and ck
ok
PU out of SBE 45' to 7,392' and circ btms up, circ at 7.5 bpm at 2,550
psi
Monitored well-static
POOH wet from 7,392' and LD Baker setting tool, cleaned rig floor, clac
fill on trip out of hole 59 bbls, actual 64.5 bbls
MU Baker 7 5/8" whipstock assembly BHA #6 and RIH to 560', MU
milling assembly and LD same, PU seal assembly, locator sub, 3 1/2"
DP pup jt, unloader sub, then PU 1 jt of 31/2" DP for space out and
RIH with seal assembly, MU whipstock, milling assembly with MWD,
oriented and uploaded MWD and RIH with 4 stds 4 3/4" DC's to 560'
RIH with whipstock assembly from 560' to 6,440'
Made MADD pass from 6,440' to 6,466' (6,320' to 6,346' sensor depth)
and correlated MW D to K -13 sand
RIH with whipstock from 6,466' to 7,400', st wt up 135K, dn wt 90K
Oriented whipstock to 15 deg left of high side, RIH, tagged TOL at
7,437', set whipstock and sheared off from same, top of whipstock at
7,355'
Displaced out 9.1 ppg solids free MOBM with reconditioned 9.1 ppg
MOBM,
Milled window in 7 5/8" csg for "B" Lateral, top of window at 7,355', btm
of window at 7,367', drilled 63/4" hole to 7,386' MDI 3,542' TVD (31'),
2-10K wob, 70-120 rpm's, 295-315 gpm, 2,840 psi, rot wt 103K, up wt
11/11/2004 04:00 - 05:45 1.75 DRILL PULD PROD
05:45 - 06:15 0.50 CASE RURD CMPL TN
06:15 - 06:30 0.25 CASE SFTY CMPL TN
06:30 - 12:00 5.50 CASE PULR CMPL TN
12:00 - 12:45 0.75 CASE PULR CMPL TN
12:45 - 14:00 1.25 CASE RUNL CMPL TN
14:00 - 18:00 4.00 CASE RUNL CMPL TN
18:00 - 18:45
18:45 - 19:00 0.25 CASE DEQT CMPL TN
19:00 - 20:00 1.00 DRILL CIRC CMPL TN
20:00 - 20: 15 0.25 DRILL OBSV CMPL TN
20:15 - 00:00 3.75 DRILL TRIP CMPL TN
11/12/2004 00:00 - 02:30 ULD CMPL TN
02:30 - 07:45 CMPL TN
07:45 - 08:15 CMPL TN
08:15 - 09:15 CMPL TN
09:15 - 09:45 CMPL TN
09:45 - 10:30 CMPL TN
10:30 - 15:00 CMPL TN
Lf
J,
Printed: 12/10/2004 2:59:08 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1E-168
1 E-168
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 10/27/2004
Rig Release: 11/26/2004
Rig Number:
Spud Date: 10/28/2004
End: 11/26/2004
Group:
12:00 - 00:00
132K, dn wt 92K, 5-8K ft-Ibs torque, pumped weighted hi vi sweep
Circ out weighted hi vis sweep and circ hole clean, had 5% increase in
cuttings from sweep, circ at 340 gpm at 3,200 psi, worked mills thru
window with no problem
Monitored well-static, pumped dry job
POOH from 7,386' to 80', stood back 43/4" DC's
LD MWD and milling assembly and upper mill was in gauge, cleaned rig
floor
Pulled wear bushing and flushed out BOP stack
RU and began testing BOPE, valves, choke manifold and rams to 250
psi low and 3,500 psi high, tested annular to 250 psi and 2,800 psi, test
witnessed by Chuck Scheve W / AOGCC
Fin testing BOPE to 250 psi low and 3,500 psi high, test witnessed by
Chuck Scheve with AOGCC
Installed wear bushing and cleared rig floor
MU 6 3/4" BHA #7, 4 3/4" motor with 1.2 deg bend and MWD, oriented
and uploaded MWD, RIH to 251'
RIH from 251' to 7,338', (above window at 7,355') shallow tested MWD
at 1,652' and tool ck ok
Slip and cut 72' of drlg line and serviced top drive
Changed out XT -39 saver sub on top drive
Oriented and RIH thru window and washed 18' to btm at 7,386' with no
problems
Directionally drilled 6 3/4" hole in "B" sand lateral from 7,386' to 8,886'
MD/ 3,551' TVD (1,500'), ART 7.1 hrs, AST 1.7 hrs, 2-10K wob, 120
rpm's, 73 spm, 310 gpm, off btm pressure 2,450 psi, on btm 2,500 psi,
off btm torque 7K ft-Ibs, on btm 7K ft-Ibs, rot wt 85K, up wt 120K, dn wt
60K, 9.0 ppg MOBM, ave ECD 10.8 ppg, ave BGG 250 units, max gas
475 units
12.00 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in "B" sand lateral from 8,886' to 1 0,139'
MD/3,553' TVD (1,253'), ART 5.8 hrs, AST 1.2 hrs, 2-14K wob, 120
rpm's, 73 spm, 310 gpm, off btm pressure 2,700 psi, on btm 2,750 psi,
off btm torque 8K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 81 K, up wt 125K, dn
wt 58K, 9.0+ ppg MOBM, ave ECD 11.0 ppg, ave BGG 275 units, max
gas 430 units
12.00 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in liB" sand lateral from 10,139' to
11,145' MD/3,566' TVD (1,006'), ART 4.7 hrs, AST 2.1 hrs, 2-10K wOb,
120 rpm's, 73 spm, 310 gpm, off btm pressure 2,800 psi, on btm 2,900
psi, off btm torque 8K ft-Ibs, on btm 8K ft-Ibs, rot wt 90K, up wt 150K,
dn wt 48K, 9.0+ ppg MOBM, ave ECD 11.2 ppg, ave BGG 200 units,
max gas 420 units, Note: Drilled out of "B" sand from approx. 10,675' to
10,835' and drilled thru calcite stringers
8.25 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in "B" sand lateral from 11,145' to
11,969' MD/3,583' TVD (824') (T.D.), ART 3.9 hrs, AST .7 hrs, 2-14K
wob, 120 rpm's, 73 spm, 310 gpm, off btm pressure 3,500 psi, on btm
3,600 psi, off btm torque 9.5K ft-Ibs, on btm 9K ft-Ibs, rot wt 104K, up wt
151 K, dn wt 67K, 9.0 ppg MOBM, ave ECD 11.45 ppg, ave BGG 200
units, max gas 420 units. T.D. well using hybrid wt pipe, NOTE Phase 3
weather condition field wide at 00:30 hrs
1.50 DRILL CIRC PROD2 Pumped weighted hi vis sweep and circ out, had 10% increase in
cuttings back from sweep, circ at 310 gpm, 3,500 psi, 120 rpm's
0.25 DRILL OBSV PROD2 Monitored well-static
6.00 DRILL REAM PROD2 Backreamed out of hole from 11,969' to 7,330' ( Above window at
16:00 - 16:15 CMPL TN
16:15 - 19:00 CMPL TN
19:00 - 20:00 CMPL TN
20:00 - 21 :30 CMPL TN
21 :30 - 00:00 CMPL TN
11/13/2004 00:00 - 01 :30 CMPL TN
01 :30 - 02:00 0.50 DRILL OTHR CMPL TN
02:00 - 03:15 1.25 DRILL PULD PROD2
03:15 - 07:30 4.25 DRILL TRIP PROD2
07:30 - 08:30 1.00 RIGMNT RSRV PROD2
08:30 - 09:45 1.25 RIGMNT RSRV PROD2
09:45 - 10:00 0.25 DRILL REAM PROD2
10:00 - 00:00 14.00 DRILL DRLG PROD2
11/14/2004 00:00 - 12:00
11/15/2004 00:00 - 08:15
08:15 - 09:45
09:45 - 10:00
10:00 - 16:00
Printed: 12/1012004 2:59:08 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1E-168
1 E-168
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 10/27/2004
Rig Release: 11/26/2004
Rig Number:
Spud Date: 10/28/2004
End: 11/26/2004
Group:
11115/2004 10:00 - 16:00 6.00 DRILL REAM PROD2
16:00 - 17:30 1.50 DRILL CIRC PROD2
17:30 - 20:30 3.00 DRILL TRIP PROD2
20:30 - 00:00 3.50 DRILL CIRC PROD2
11/16/2004 00:00 - 08:45 8.75 DRILL TRIP PROD2
08:45 - 09:45 1.00 DRILL PULD PROD2
09:45 - 10:30 0.75 FISH PULD CMPL T2
10:30 - 12:00 1.50 FISH TRIP CMPL T2
12:00 - 14:00 2.00 FISH TRIP CMPL T2
14:00 - 15:30 1.50 FISH FISH CMPL T2
15:30 - 16:30 1.00 FISH CIRC CMPL T2
16:30 - 21:30 5.00 FISH TRIP CMPL T2
21 :30 - 23:30 2.00 FISH PULD CMPL T2
23:30 - 00:00 0.50 FISH OTHR CMPL T2
11/17/2004 00:00 - 00:30 0.50 CASE RURD CMPL T2
00:30 - 01 :00 0.50 CASE SFTY CMPL T2
01 :00 - 04:45 3.75 CASE RUNC CMPL T2
04:45 - 05:00
0.25 CASE
RUNC CMPL T2
05:00 - 05:45
05:45 - 12:30
0.75 CASE
6.75 CASE
CIRC CMPLT2
RUNL CMPL T2
7,355'), no problems, backreamed out at 120 rpm's, 310 gpm, initial circ
pressure 3,300 psi, final pressure 2,200 psi, NOTE: Phase 3 lowered to
Phase 2 at 11 :30 hrs
Pumped weighted hi vis sweep and circ out, had no increase in cuttings
back from sweep, circ additional btms up and clean at shakers, circ at
310 gpm, 2,200 psi, rot wt 85K, upwt 90K, dn wt 70K
RIH from 7,330' to btm at 11,969' with no problems
Circ hole 2 X btms up then displaced out 9.0 ppg MOBM to 9.1 ppg
SFMOBM, circ at 70 spm, 300 gpm, 3,400 psi, 100 rpm's, rot wt 100K,
up wt 150K, dn wt 60K, Phase 2 in effect
Monitor well. Static. POOH on elevators. Monitor well at window.
Static. No problems POOH. No tight hole noted. At TD, UP wt 165K,
DN wt 65K.
UD BHA. Download MWD. Clear rig floor. Hycalog 6-3/4" DSX146
rated O-O-NO-A-X-I-ER-TD.
P/U Baker Whipstock retrieving assembly. BHA # 8: Retrieving hook,
1 jt 3-1/2" HWDP, FS, BS, Oil Jars, 4 stds 4-3/4" DC's, & XO.
TIH to 2363' MD.
Continue TIH to 7360' MD. Drill string above BHA: 54 stds 4" DP wI
Lo-Tads, 11 stds 4" HWDP, & 7 stds Hybrid Push Pipe.
Latch & retrieve whipstock. Trip anchor sheared at 65K over.
PU 1 std & CBU @ 75 spm at 2250 psi. - Had a 2 ppg gas cut bubble
@ BU - Circu until fluid uniform out and in 9.1 ppg.
Observe well. Static. POOH to Whipstock retrieving assembly.
UD Baker Whipstock retrieving assembly, whipstock, debris barrier
sub, US, shear disconnect, btm trip anchor, DP XO, 1 jt 3-1/2" HWDP,
US, 3-1/2" pup jt, LS, & seal assembly.
Clear & wash rig floor. Prep to run 4-1/2" B-Lat Liner.
R/U equipment to run 4-1/2" liner.
Held PJSM on running 4-1/2" liner wI rig crew, casing hand, and
company rep.
PU & ran 4-1/2" liner per program to 4,542'. Ran 3-1/2" Baker guide
shoe, 3-1/2" bent jt, XO, 4-1/2" pup jt, Baker packoff bushing, XO, 145
jts (4,500.46') of 4 1/2" 12.6#, L-80, DWC liner. Placed blank liner
across shale sections per geology, ran 137 jts (4,250.50') of slotted
liner and 8 jts (249.96') of blank liner. Ran (141) 41/2" x 61/4"
spiralglider centralizers 1/jt jt except on the 2 jts with constrictor packers
(#34 & #39). Ran 2 constrictor packers placed on blank liner to isolate
shale sections per geology fl 10,678' MD to 10,833' MD. Up wt 66K, dn
wt 54K.
M/U Baker Model B 1 Flanged Hook Hanger & running tool. Up wt 70K,
Dn wt 55K.
RIH 1 std of DP & break circulation. ROT WT 63K, TQ 2K ft-Ibs torque.
RIH with liner on 4" DP to csg shoe at 7,355' MD. Up wt 95K, Dn wt
65K. Cont to run 4 1/2" liner in open hole. RIH from 7,355' to 11,927'
seeing 75% of centralizers exiting window fl 8,934' MD to 10,435' MD
(set dwn 15K max). Hook hanger on window on 2nd attempt. Unhook
and rehook to verify. Up wt 160K, dn wt 80K. Drop 1-3/4" ball & pump
to seat @ 3 BPM at 425 psi. Pressure up to 3500 psi to release
running tool. Liner Running String - 53 stds 4" DP with Lo-Tads, 11
stds 4" HWDP, 4 stds 4-3/4" DC's, & 9 stds Hybrids.
Printed: 12/10/2004 2:59:08 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-168
1E-168
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 10/27/2004
Rig Release: 11/26/2004
Rig Number:
Spud Date: 10/28/2004
End: 11/26/2004
Group:
11/17/2004 12:30 - 13:30 1.00 CASE CIRC CMPL T2 PU to verify release of liner & CBU @ 7.5 BPM at 2500 psi. Shut down
& Monitor well. Static.
13:30 - 17:00 3.50 DRILL TRIP CMPL T2 POOH fl 11,831' MD.
17:00 - 17:30 0.50 CASE RURD CMPL T2 UD liner running tool & clear rig floor.
17:30 - 18:30 1.00 CMPL TN PULD CMPL T2 M/U LEM assembly.
18:30 - 22:30 4.00 CMPL TN RUNT CMPL T2 TIH wI LEM assembly t/ 7480' MD. Up wt 140K, dn wt 95K. Latch LEM
& slack-off 60K. PU & pull 10K over to verify latch.
22:30 - 23:00 0.50 CMPL TN CIRC CMPL T2 Drop 1-3/4· ball & pump to seat at 3 BPM at 375 psi. Pressure up to
4000 psi to release lEM. Pusher tool sheared at 2400 psi, ZXP set at
2800 psi, & pusher tool neutrilized at 3400 psi. Bleed off pressure & PU
to verify release of running tool. Top of LEM at 7297' MD.
23:00 - 23:30 0.50 CMPL TN DEOT CMPL T2 Close Hydril & pressure test annulus (ZXP) to 1500 psi for 15 min.
Held OK.
23:30 - 00:00 0.50 DRILL TRIP CMPL T2 Blow down top drive. Monitor Well. Static.
11/18/2004 00:00 - 03:45 3.75 DRILL TRIP CMPL T2 POOH f/7,297' MD.
03:45 - 04:15 0.50 DRILL PULD CMPL T2 Make service breaks and UD Baker running tool & hydraluic setting
tool.
04:15 - 04:45 0.50 DRILL OTHR CMPL T2 Clear rig floor to run Whipstock.
04:45 - 07:00 2.25 WINDO ULD CMPL T2 M/U Baker 7 5/8" whipstock assembly. M/U seals & no-go, 3-1/2" pup,
US, 7 jts 3-1/2" DP, DP XO, btm trip anchor, shear disconnect, US,
debris barrier, 7-5/8" whipstock, starting mill, lower mill, flex jt, upper
mill, 1 jt 3-1/2" HWDP, FS, Orient & Upload MWD, jars, 4 stds 4-3/4"
DC, XO, & RIH to 742'.
07:00 - 07:45 CMPL T2 RIH with whipstock assembly to 830' & shallow test MWD. OK.
07:45 - 12:00 CMPL T2 Continue to RIH to 6,568' MD. Break circulation @ 7 BPM & 2100 psi.
12:00 - 12:30 CMPL T2 Made MADD pass from 6,619' MD to 6,643' MD and correlated MWD to
K-13 shale. Continue to RIH to 7,291' MD.
12:30 - 13:00 CMPL T2 RIH to 7,291' MD. Orient and set Whipstock. Sheared off same. Top
of Whipstock at 7,031' MD.
13:00 - 13:45 CMPL T2 Displaced out 9.1 ppg solids free MOBM with reconditioned 9.1 ppg
MOBM @ 7 BPM at 2100 psi.
13:45 - 18:00 CMPL T2 Milled window in 75/8" csg for "D" Lateral. Top of window at 7,031',
btm of window at 7,043'. Drilled 6 3/4" hole to 7,061' MD I 3,468' TVD
(31'), 2-10K WOB, 70-120 RPM, 295-315 GPM, 2000-2200 psi, 5-8K
ft-Ibs torque.
18:00 - 19:00 Pump hi vis sweep and circ hole clean. Circulate @ 7 BPM at 2100 psi.
Worked mills thru window with no problem. Monitor Well. Static.
19:00 - 22:00 3.00 WINDO CMPL T2 POOH fl 7,061' MD to BHA at 476' MD.
22:00 - 22:30 0.50 WINDO CMPL T2 UD Milling Assembly BHA. UD 4 stds 4-3/4" DC, jars, MWD, FS, 1 jt
3-1/2" HWDP, upper mill, flex jt, lower mill, & starting mill.
22:30 - 23:00 0.50 WINDO THR CMPL T2 Clear rig floor & pull wear ring.
23:00 - 00:00 1.00 WINDO THR CMPL T2 R/U & flushed BOP stack.
11/19/2004 00:00 - 00:30 0.50 WINDO OTHR CMPL T2 Install wear bushing & clear rig floor.
00:30 - 02:00 1.50 RIGMNT RSRV CMPL T2 Inspect saver sub, shim grabbers, & service top drive.
02:00 - 02:30 0.50 DRILL PULD PROD3 M/U 6-3/4" D-Lat BHA #10. P/U 6-3/4" bit, 1.2 deg motor, & MWD.
02:30 - 03:00 0.50 DRILL PULD PROD3 Upload MWD & Orient.
03:00 - 07:00 4.00 DRILL TRIP PROD3 RIH t/ 1,185' MD & shallow test MWD. Continue to RIH t/ 6947' MD
filling pipe every 10 stds.
07:00 - 08:00 1.00 RIGMNT RSRV PROD3 Slip & cut 70' drilling line.
Printed: 12/10/2004 2:59:08 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-168
1E-168
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 10/27/2004
Rig Release: 11/26/2004
Rig Number:
Spud Date: 10/28/2004
End: 11/26/2004
Group:
11/19/2004 08:00 - 08:30 0.50 DRILL TRIP PROD3 Orient & pass thru window with no problems. Wash & ream f/7046' MD
to 7061' MD.
08:30 - 12:00 3.50 DRILL DRLG PROD3 Drill 6-3/4" Lateral 'D' Section f/7,061' to 7,470' MD /3,498' TVD (409'),
ART 1.3 hrs, AST 0.8 hrs, UP 125K, DN 55K, Rot 83K, TO on/off
6K/6K, 310 gpm @ 2400 psi, 2-10K was, 120 RPM, avg ECD's 10.8
ppg, Max gas 210 units.
12:00 - 16:00 4.00 DRILL DRLG PROD3 Drill 6-3/4" Lateral'D' Section f/7,470' to 7,913' MD /3,489' TVD (443'),
ART 0.6 hrs, AST 2.3 hrs, UP 125K, DN 55K, Rot 83K, TO on/off
6K/6K, 310 gpm @ 2300 psi, 2-10K was, 120 RPM, avg ECD's 10.7
ppg, Max gas 290 units.
Geologist advised that after crossing fault @ 7475' MD we had not been
able to stay in the sand and had come out the top @ 7640'. After
conferring with the engineers in town the decision was made to back up
and do an OH side track.
16:00 - 16:30 0.50 DRILL DRLG PROD3 Pump out of hole tJ 7431' MD to sidetrack well.
16:30 - 19:00 2.50 DRILL DRLG PROD3 Perform OH sidetrack f/7,431' MD to 7,555' MD, ART 0.6 hrs, AST 2.3
hrs, UP 123K, DN 55K, Rot 82K, TO on/off 5.5K/6K, 310 gpm @ 2450
psi, 0-2K WOB, 120 RPM, avg ECD's 11.6 ppg, Max gas 190 units.
19:00 - 20:00 1.00 DRILL DRLG PROD3 Running shale at 7,555' MD. Circulate hole clean @ 310 gpm at 1475
psi while recip & rot string. Max ECD 11.1 ppg, Max gas 180 units.
20:00 - 00:00 4.00 DRILL DRLG PROD3 Drill 6-3/4" Lateral'D' Section f/ 7,555' to 7,913' MD /3,508' TVD (358'),
ART 1.9 hrs, AST 3.1 hrs, UP 115K, DN 65K, Rot 81 K, TO on/off
6K/6.5K, 310 gpm @ 2300 psi, 2-10K WOB, 120 RPM, avg ECD's 10.9
ppg, Max gas 260 units.
11/20/2004 00:00 - 12:00 12.00 DRILL DRLG PROD3 Drill 6-3/4" Lateral'D' Section f/ 7,913' MD to 9,074' MD /3,504' TVD
(1161'), ART 5.8 hrs, AST 1.6 hrs, UP 117K, DN 63K, Rot 82K, TO
on/off 7K17.5K, 305 gpm @ 2400 psi, 0-15K WOB, 100-120 RPM, avg
ECD's 11.0 ppg, Max gas 405 units.
12:00 - 00:00 12.00 DRILL DRLG PROD3 Drill 6-3/4" Lateral'D' Section f/9,074' MD' to 10,663' MD /3,499' TVD
(1589'), ART 9.0 hrs, AST 0.0 hrs, UP 125K, DN 55K, Rot 85K, TO
on/off 9K/9K, 304 gpm @ 2400 psi, 0-5K WOB, 120 RPM, avg ECD's
11.5 ppg, Max gas 440 units.
(NOTE: DWS costs from 11/8 to 11/18 were updated on today's
report. )
11/21/2004 00:00 - 12:00 12.00 DRILL DRLG PROD3 Drill 6-3/4" Lateral'D' Section f/1 0,633' MD to 11,683' MD (1,050'),
ART 6.7 hrs, AST 1.0 hrs, UP 145K, DN 60K, Rot 97K, TO on/off
10K/9K, 305 gpm @ 3200 psi, 0-15K WOB, 120 RPM, avg ECD's 11.6
ppg, Max gas 430 units.
12:00 - 15:00 3.00 DRILL DRLG PROD3 Drill 6-3/4" Lateral'D' Section f/11 ,683' MD to TD at 11,960' MD /
3,515' TVD (277'), ART 1.1 hrs, AST 1.0 hrs, UP 150K, DN 65K, Rot
100K, TO on/off 10K/10K, 305 gpm @ 3300 psi, 2-10K WOB, 120
RPM, avg ECD's 11.8 ppg, Max gas 280 units. Pump weighted Hi-vis
sweep on last connection.
15:00 - 16:00 1.00 DRILL CIRC PROD3 Pump sweep & circulate hole clean @ 70 spm at 3500 psi.
16:00 - 22:30 6.50 DRILL REAM PROD3 Back Ream out of hole at drilling rates V 7,140' MD. Pull thru window
with no problems.
22:30 - 23:00 0.50 DRILL OBSV PROD3 POOH to 6,947' MD. Monitor Well. Static.
23:00 - 00:00 1.00 DRILL CIRC PROD3 Pump sweep & circulate hole clean @ 72 spm at 2250 psi.
11/22/2004 00:00 - 03:00 3.00 DRILL TRIP PROD3 Observe well. Static. TIH to 11,867' MD (fill DP at 9752'). Wash last
std to btm at 11,960' MD.
03:00 - 05:30 2.50 DRILL CIRC PROD3 CBU @ 305 gpm at 3700 psi & 120 RPM. Displace entire mud system
to 9.0 ppg Solids-Free OBM @ 305 gpm at 3700 psi.
Printed: 12/10/2004 2:59:08 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1E-168
1 E-168
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 1 0/27/2004
Rig Release: 11/26/2004
Rig Number:
Spud Date: 10/28/2004
End: 11/26/2004
Group:
11/22/2004 05:30 - 12:00 6.50 DRILL TRIP PROD3 Shut down & monitor well. Static. Blow Down Top Drive. POOH wet
on elevators fl 11,960' MD to 2,493' MD.
12:00 - 13:00 1.00 DRILL TRIP PROD3 Continue POOH fl 2,493' MD to BHA.
13:00 - 15:00 2.00 DRILL PULD PROD3 UD BHA & Download MWD. UD all tools. Rerun Hycalog 6-3/4"
DSX146 rated 0-1-CT-G-X-I-NO-TD.
15:00 - 15:30 CMPL T3 Clear floor & P/U Whipstock retrieving assembly. P/U retrieving hook, 1
jt 3-1/2" HWDP, FS, bumber jar, oil jar, 4 stds 4-3/4" DC, & XO.
15:30 - 18:30 CMPL T3 RIH wI Whipstock retrieving assembly. Run 50 stds 4" DP wI Lo-Tads,
11 stds 4" HWDP, & 9 stds Hybrid Push Pipe.
18:30 - 19:00 CMPL T3 Hook whipstock on 2nd attempt & on depth. Sheared bolt at 35K over
& Pull60K over to unseat btm trip anchor. UP 140K, DN 88K.
19:00 - 20:00 1.00 WINDO CMPL T3 CBU @ 40 spm at 900 psi. Monitor well. Static.
20:00 - 00:00 4.00 WINDO CMPL T3 POOH wI D-Lat whipstock to retrieving assebmly at 692'.
11/23/2004 00:00 - 03:00 3.00 WINDO CMPL T3 POOH standing back 4 stds 4 3/4" dc's and LD whipstock anchor
assembly, cleaned rig floor
03:00 - 03:30 0.50 CASE RURD CMPL T3 RU Doyon's 41/2" liner running equipment
03:30 - 03:45 0.25 CASE SFTY CMPL T3 Held PJSM on running of liner
03:45 - 08:30 4.75 CASE PULR CMPL T3 PU & ran 4-1/2" liner per program to 4,875'. Ran 3-1/2" Baker guide
shoe, 3-1/2" bent jt, XO, 4-1/2" pup jt, Baker packoff bushing, XO, 156
jts (4,834.08') of 41/2" 12.6#, L-80, DWC liner, ran 154 jts (4,773.06')
of slotted liner and 2 jts (61.02') of blank liner. Ran (154) 41/2" x 6 1/2"
spiralglider centralizers, 1/jt on slotted liner none on blank liner
08:30 - 09:00 0.50 CASE PULR CMPL T3 M/U Baker Model B1 Flanged Hook Hanger & running tool. RIH 1 std
and broke circ, Up wt 69K, Dn wt 58K.
09:00 - 10:15 1.25 CASE RUNL CMPL T3 RIH with 4 1/2" liner on 4" DP from 4,919' to 7,326' and tagged up on no
go on liB" lat
10:15-11:00 0.75 CASE OTHR CMPL T3 PU to 7,017' and re-oriented and after 3rd attempt, RIH thru window
with bent jt and liner
11 :00 - 14:00 3.00 CASE RUNL CMPL T3 RIH with liner from 7,326' to 11,937' with no problems, st wt up 150K,
dn wt 75K
14:00 - 17:00 3.00 CASE RUNL CMPL T3 Hooked hanger on window on 1st attempt at 7,046'. Unhook and
rehook to verify setting 35K st wt down. Hooked window 3 times,
unhooked and went past window 10' then rehooked 4 more times Up
wt 150K, dn wt 75K. Drop 1-3/4" ball and pumped to seat @ 4 BPM at
900 psi, staged pump pressure up 3500,3700,4000, to 4,700 psi
working pipe per Baker rep procedure to release running tool with no
sign liner was released, rotated liner to safety off & release running tool,
appeared running tool was not released, Shut down and conferred with
town engineer and team leader. The decision was made to TOH and
replace Hook Hanger, After confrence call we PU and running tool had
released, st wt after releasing running tool 135K up and 90K dn wt.
Liner Running String - 50 stds 4" DP with Lo-Tads, 11 stds 4" HWDP, 4
stds 4-3/4" DC's and 9 stds Hybrids, TaL at 7,029' with shoe at 11,937'.
Went back down and tagged liner at setting depth Top.
17:00 - 18:00 1.00 CASE CIRC CMPL T3 POOH 1 std to 6,936' and circ hole clean, circ at 8 bpm at 2,600 psi, st
wt up 135K, dn wt 90K
18:00 - 18:15 0.25 DRILL OBSV CMPL T3 Monitored well-static
18:15 - 20:30 2.25 DRILL PULD CMPL T3 POOH with running tool from 6,936' to 5,736', LD hybrid push pipe and
4 3/4" DC's
20:30 - 23:00 2.50 DRILL TRIP CMPL T3 POOH from 5,736' to Baker running tool
23:00 - 00:00 1.00 CASE RURD CMPL T3 LD Baker running tool and cleared rig floor, NOTE: Running tool
appears to have released when safety released and not from pressure
11/24/2004 00:00 - 00:45 0.75 DRILL RIRD CMPL T3 RU to LD DP from mousehole
Printed: 12/10/2004 2:59:08 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-168
1 E-168
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 10/27/2004
Rig Release: 11/26/2004
Rig Number:
Spud Date: 10/28/2004
End: 11/26/2004
Group:
11/24/2004
11/25/2004
LD 18 stds 4" DP from derrick
Slip and cut 78' of drlg line and serviced top drive
Worked on pipe skate, got skate back into operation, will need to
change out electric switch on skate
Fin LD 4" DP & HWDP from derrick, LD an additional 87 stds of 4" DP,
61 stds with Lo-Tads and 11 stds of 4" HWDP
Clear and clean rig floor
RU to PU and stand back 41/2" completion tubing
PU & RIH with 130 jts of 41/2", 12.6#, L-80 IBTM tbg to 4,000'
Fin PU and RIH with 41/2",12.6#, L-80 IBTM-SCC tbg, RIH from
4,000' to 5,930' (PU a total of 192 jts)
POOH and stood back 64 stds of 41/2" tbg, changed out seal rings on
tri pout
Pulled wear bushing
RU Centrilift to run ESP completion assembly
Held PJSM with rig crew and Centrilift on running of ESP completion
PU Centrilift's ESP motor assembly, tandem seal section with screen
intake, filled motor with oil and connect ESP cable and checked same,
Installed 1/4" control line for pump gauge
Repaired Centrilift's protectorlizer clamp, clamp was used and had to
change out bolts
RIH with ESP assembly to 131', PU 2 jts 41/2",12.6#, L-80, IBTM SCC
tbg and MU well discharge pressure sub
Repaired Centrilift's air supply system for banding and clamping tools
Connected 1/4" control line to discharge pressure sub and checked
cable continuity
RIH slow with ESP completion assembly from 131' to 4,900', running
cable and installing cannon clamps on every other jt and checking cable
conductivity every 1,000'
2.00 CMPLTN RUNT CMPLT3 Cont to RIH slow with ESP completion assembly from 4,900' to 6,168',
running cable and installing cannon clamps on every other jt and
checking cable conductivity every 1,000'
4.00 CMPL TN RUNT CMPL T3 MU Hanger and Landing jt with TWC, spliced ESP Cable and MU to tbg
hanger, landed hanger and RILDS, Land string as per detail w/ Tail @
6,220', Pump guage @ 6,216', Motor @ 6,182', Seal Section @ 6,168',
screen intake @ 6,157' ( 68.3 deg), GLM #1 @ 5,390' MD ( 2,901'
TVD), GLM #2 @ 4,195' MD (2,396' TVD), GLM #3 @ 138' (138' TVD),
GLM #4 @ 89' (89' TVD), ran a total of 195 jts (6,024.66') of 4 1/2"
12.6#, L-80, IBTM tbg with special clearance collars, st wt up 90K, dn
wt 61K
Parts used on ESP cable;
3 - Protectolizer guards= OD 5.875"
2 - Flat guards= aD 5.625"
14 - Flat stainless steel bands
106 - Cannon clamps= 6.75"
ND BOP stack
NU Vetco Gray tree and tested adapter void and tree to 250 psi low and
5,000 psi high
Checked continuity on ESP cable and perform MEG test on penetrator
and checked ok
Pulled TWC and rig freeze protect well with 255 bbls diesel, Pumping
down 41/2" tbg thru screen intake @ 6,157' with returns up 7 5/8"
annulus, Had good diesel to surface. circ at 6 bpm at 800 psi
00:45 - 02: 15 1.50 DRILL PULD CMPL T3
02: 15 - 03:45 1.50 RIGMNT RSRV CMPL T3
03:45 - 06:45 3.00 RIGMNT RGRP CMPL T3
06:45 - 18:30 11.75 DRILL PULD CMPL T3
18:30 - 19:30 1.00 DRILL OTHR CMPL T3
19:30 - 20:15 0.75 CMPLTN RURD CMPL T3
20:15 - 00:00 3.75 CMPLTN RUNT CMPL T3
00:00 - 01 :30 1.50 CMPL TN PULD CMPL T3
01 :30 - 05:00 3.50 CMPL TN TRIP CMPL T3
05:00 - 05:30 0.50 CMPL TN OTHR CMPLT3
05:30 - 07:45 2.25 CMPL TN RURD CMPL T3
07:45 - 08:00 0.25 CMPL TN SFTY CMPL T3
08:00 - 13:30 5.50 CMPL TN PULD CMPL T3
13:30- 14:00 0.50 RIGMNT RGRP CMPL T3
14:00 - 15:00 1.00 CMPL TN PULD CMPL T3
15:00 - 15:30 0.50 RIGMNT RGRP CMPL T3
15:30 - 16:30 1.00 CMPL TN PULD CMPL T3
16:30 - 00:00 7.50 CMPLTN RUNT CMPL T3
11/26/2004 00:00 - 02:00
02:00 - 06:00
06:00 - 07:45 1.75 WELCT NUND CMPL T3
07:45 - 09:45 2.00 WELCT NUND CMPL T3
09:45 - 10:15 0.50 CMPL TN DEQT CMPL T3
10:15 - 12:30 2.25 CMPL TN FRZP CMPL T3
Printed: 12/10/2004 2:59:08 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 E-168
1 E-168
ROT - DRILLING
n1334@ppco.com
Doyon 141
Start: 10/27/2004
Rig Release: 11/26/2004
Rig Number:
Spud Date: 10/28/2004
End: 11/26/2004
Group:
15:30 - 16:30
16:30 - 18:00
RU scaffolding and lubricator, installed BPV, RD lubricator and
scaffolding
CMPL T3 Installed actuator valve on tree and secured well
CMPL T3 Used crane and changed out Baker Inteq's MWD shack to Sperry Sun
and fin cleaning mud pits. RELEASED RIG @ 18:00 Hrs 11/26/04 to
move to 1 E-104
Printed: 12/10/2004 2:59:08 PM
'"
Conoc~llips ConocoPhillips AI~a, Inc.,Slot #168
Pad 1 E,
Kuparuk River Unit, North Slope, Alaska
Wellb~: 168 L 1
Well path: MWD wI Mag-Sag <7378-
11969'>
Date Printed: 16-Dec-2004
.~.
BAKlR
IIUGIIE5
INTEQ
s- û - OJ.. q - .:(];¿ 10 - C; 0
;Z lJ t.-I - Â \}
Well bore
Name
J 68--'=1._______~___
-._--~-~
Created
i 14-Nov-2004
Last Revised
¡ 24-Nov-2004
Well
Name
168
I Government ID
!
I Last Revised
r 1-0ct-2004
Slot
Name
Slot #168
Latitude
I N70 17 59.2815
Lon itude
i W149 35 45.4169
Installation
Name
Pad 1 E
Eastin
Coord S stem Name
5959591.109 AK-4 on NORTH AMERICAN DATUM 1927 datu
Name
Ku aruk River Unit
Eastin
487754.6208
Field
All data is in Feet unless otherwise stated
Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #2 98.4ft above mean sea level)
Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees
Bottom hole distance is 6294.75 Feet on azimuth 48.33 degrees from Wellhead
Calculation method uses Minimum Curvature method
Prepared by Baker Hughes Incorporated
conocó'Phillips ConocoPhillips AI~a, Inc.,Slot #168
Pad 1E,
Kuparuk River Unit, North Slope, Alaska
Wellbðnr:" 168 L 1
Wellpath: MWD wI Mag-Sag <7378-
11969'>
Date Printed: 16-Dec-2004
.i.
BAKER
HUGHES
INTEQ
WellDath {Grid} ReDort
MD[ft] Inc[deg] Azi[deg] TVD[ft] Station Station ìDOg,eg Severi Vertical Easting Northing
Position{V\ Position{X\ Sectionrttl
~355J)JL__'~mJ8.49~_ __ 4.95 I 3535.81 i 406.24S 4301.50E 0.00 I -73.15 554193.68 i 5959002.37
i
7378.97 80.26 4.95 3540.23 I 382.76S 4303.53E 7.39 I -49.59 554195.55 : 5959025.85
-.-----Hl~9l____f____~3.5_~_ __ 6.00 3553.85 I 287.24S 4312.69E 3.60 ! 46.36 554204.08 i 5959121.43
I
~72.04_:---__ª5. 'UL~~ ___ 3.90 i 3563.24 I 191.94S 4320.94E 2.74 ! 142.02 554211.70 5959216.77 i
7668.53 I 86.67 2.77 : 3570.09 I 95.86S 4326.54E 1.93 i 238.24 554216.66 5959312.88 i
7764.77 i 87.44 5.34 3575.04 ! 0.01N 4333.34E 2.78 334.34 554222.81 5959408.78 !
-7862.62-~r---ã9~37-~- ---4.61--1 3577.76 I 97.45N 4341.82E 2.11 432.15 554230.65 5959506.26 i
7958.64 I 90.84 2.44 I 3577.59 I 193.28N 4347.73E 2.73 528.15 554235.91 5959602.12
8055.87 I 90.17 5.03 3576.73 I 290.29N 4354.06E 2.75 625.36 554241.60 I 5959699.16
I
8152.63 I 90.78 5.01 3575.93 ¡ 386.67N 4362.52E 0.63 722.11 554249.43 I 5959795.59
!
8248.52 1 90.78 ___ 5.64 3574.62 I 482.14N 4371.42E 0.66 817.98 554257.69 I 5959891.10
I !
8344.69 ! 90.90 5.86 i 3573.21 I 577 .82N 4381.06E 0.26 914.11 554266.69 5959986.83
8442.59 I 91.79____ 5.25 1 3570.91 I 675.23N 4390.53E 1.10 1011.96 554275.52 I 5960084.29
~ß8 ¡ 92.75 3.28 1 3567.07 771.97N 4397.75E 2.26 1108.97 554282.09 5960181.07 !
8635.75 93.48 0.39 3561.85 i 867.83N 4400.82E 3.10 1204.79 554284.52 5960276.94 I
8732.35 I 93.06 3.38 3556.34 964.21N 4403.99E 3.12 1301.13 554287.06 5960373.33 I
!
8829.53 E0.45 --- 5.51 3553.36 1061.04N 4411.52E 3.47 I 1398.25 554293.94 5960470.20 i
8926.49 _~____ 5.34 ! 3552.66 I 1157.57N 4420.69E 0.19 1495.19 554302.4 7 5960566.77 I
9022.42 I 89.74 5.03 I 3552.56 1253.10N 4429.35E 0.74 1591.11 554310.50 5960662.35
-~ --- i
9118.30 88.21 6.52 3554.27 1348.47N 4439.00E 2.23 1686.94 554319.51 5960757.78 I
9216.43 89.03 6.48 I 3556.63 1445.94N 4450.10E 0.84 1784.98 554329.97 5960855.31
9312.60 89.34 5.57 3558.00 1541.57N 4460.20E 1.00 1881.1 0 554339.42 5960950.99 I
9409.35 88.54 5.29 3559.79 1637.87N 4469.35E 0.88 1977.82 554347.94 5961047.34
9506.03 89.28 4.65 3561.63 1734.17N 4477.73E 1.01 2074.47 554355.67 5961143.68 [
9602.82 90.29 6.12 3561.99 1830.53N 4486.81E 1.84 2171.25 554364.11 5961240.09
9699.02 I 90.41 6.13 3561.41 1926.18N 4497.07E 0.13 2267.40 554373.74 5961335.80 I
9796.18 I 90.69 4.11 3560.47 2022.94N 4505.74E 2.10 2364.55 554381 .77 5961432.61 !
__9892.26 _~91.39 4.82 3558.73 2118.71N 4513.22E 1.04 2460.61 554388.61 5961528.41 I
.---91)89.83=-+-- 91.85 4.29 3555.97 2215.93N 4520.97E 0.72 2558.14 554395.71 5961625.68 I
I -1
10087.10 I 90.44 2.59 3554.03 2313.00N 4526.80E I 2.27 2655.37 554400.90 5961722.77 I
I I
3.83 I 3554.46 2410.86N 4532.29E 1.89 2753.36 554405.74 5961820.66 I
10185.12 t-- 89.06 I
10273.86 88.76 5.13 I 3556.14 2499.31N 4539.22E I 1.50 2842.08 554412.08 I 5961909.14 !
10364.61 I 88.~ 2.77 I 3557.97 2589.82N 4545.47E I 2.61 2932.81 554417.73 5961999.68 I
i i
1 0455.91 ~ 90.57 6.30 3558.36 I 2680.82N 4552.69E I 4.26 3024.09 554424.34 5962090.72
10546.71 i 91.89 7.37 I 3556.41 2770.95N 4563.49E 1.87 3114.78 554434.54 5962180.91 ¡
10636.64 I 92.17 7.68 I 3553.22 2860.05N 4575.26E 0.46 3204.52 554445.72 5962270.08
10727.62 89.09 5.35 3552.22 2950.42N 4585.58E 4.24 3295.42 554455.44 5962360.50 I
10820.03 ! 87.92 2.98 3554.63 3042.55N 4592.29E 2.86 3387.79 554461.53 5962452.66 I
10908.81 86.76 1.95 3558.75 I 3131.15N 4596.10E 1.75 3476.42 554464.76 5962541.28
11000.26 88.67 4.62 3562.40 [ 3222.36N 4601.34E 3.59 3567.77 554469.39 5962632.52
11093.08 87.72 3.88 3565.32 I 3314.88N 4608.22E 1.30 3660.54 554475.65 I 5962725.07 I
I
11185.73 i 88.26 6.65 3568.57 3407.07N 4616.71E 3.04 I 3753.11 554483.53 5962817.31 !
11272.00 ~.78 7.75 I 3569.30 3492.65N 4627.52E 3.19 3839.27 554493.78 5962902.95 I
I
11362.64 I 90.75 6.56 I 3568.09 I 3582.57N 4638.81E 1.31 3929.80 554504.4 7 5962992.93
--- I
11453.23 I 88.39 6.97 ¡ 3568.76 3672.52N 4649.48E 2.64 I 4020.30 554514.54 5963082.94
11544.02 i 86.64 6.77 ! 3572.70 I 3762.57N 4660.33E 1.94 I 4110.92 554524.79 5963173.05 1
I I
11634.87 I 89.83 7.33 I 3575.50 I 3852.68N 4671.48E 3.56 4201.62 554535.33 I 5963263.23 i
11724.45 I 88.39 6.01 3576.89 I 3941.64N 4681.88E 2.18 4291.12 554545.14 5963352.24 I
I
11814.36 I 88.05 5.54 3579.68 4031.05N 4690.92E I 0.64 4380.96 554553.59 5963441.70 I
11917.47 89.00 3.32 I 3582.34 4133.81N 4698.88E 2.34 ! 4484.03 554560.87 5963544.50 I
11969.00 L 89.00 -- 3.32 3583.24 4185.25N 4701.87E I 0.00 4535.54 554563.51 5963595.95
All data is in Feet unless otherwise stated
Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #2 98.4ft above mean sea level)
Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees
Bottom hole distance is 6294.75 Feet on azimuth 48.33 degrees from Wellhead
Calculation method uses Minimum Curvature method
Prepared by Baker Hughes Incorporated
ConocÓPhillips ConocoPhillips AI~a, Inc.,Slot #168
Pad 1 E,
Kuparuk River Unit,North Slope, Alaska
Wellb'ðn(: 168 L 1
Wellpath: MWD wI Mag-Sag <7378 -
11969'>
Date Printed: 16-Dec-2004
.a.
BAKER
HUGHES
INTEQ
Well bore
168 PB1
168 PB1
168 L 1
Casinas I
j
Name Top Top Top Top Shoe Shoe ¡Shoe Shoe Well bore I
~ftL TVOrftl Northrttl Eastrftl MOrftl TVOrttl Northrftl Eastrftl
20" Conductor 0.00 0.00 O.OON O.OOE 108.00 108.00 I O.OON O.OOE 168 PB1 I
10 3/4" Casin~ _ 0.00 0.00 O.OON O.OOE 4419.00 2479.18 i 1818.52S 2647.81E 168 PB1 i
7 5/8" Casina 0.00 0.00 O.OON O.OOE 8157.00 3714.22 i 371.36N 4373.61E 168 PB1 I
4 1/2" Liner 7297.00 3524.46 462.92S 4296.85E 11927.00 3582.50 i 4143.32N 4699.43E 168 L 1 !
4 1/2" Liner 7029.00 3462.61 723.10S 4280.64E 11937.00 3513.63 I 4163.90N 4664.77E 168L2 I
I
All data is in Feet unless otherwise stated
Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Datum #2 98.4ft above mean sea level)
Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees
Bottom hole distance is 6294.75 Feet on azimuth 48.33 degrees from Wellhead
Calculation method uses Minimum Curvature method
Prepared by Baker Hughes Incorporated
~1J&\1fΠlID~ ~~
~I
FRANK H. MURKOWSK' GOVERNOR
AI/ASIiA. OIL AlQ) GAS
CONSERVATION COMMISSION
333 W. ]TH AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Randy Thomas
Kuparuk Drilling T earn Leader
ConoeoPhillips Alaska, Inc.
P.O. Box 100360
Anchorage, Alaska 99510-0360
Re: Kuparuk 1E-168L1
ConocoPhillips Alaska, Inc.
Permit No: 204-201
Surface Location: 207' FNL, 640' FEL, SEC. 21, TI1N, RI0E, UM
Bottomhole Location: 1302' FNL, 1249' FEL, SEC. 15, TI1N, R10E, UM
Dear Mr. Thomas:
Enclosed is the approved application for permit to drill the above referenced development well.
The permit is for a new wellbore segment of existing well KRU lE-168, Permit No. 204-200,
API No. 50-029-23230-00. Production should continue to be reported as a function of the
original API number stated above.
This permit to drill does not exempt you from obtaining additional permits or approvals required
by law from other governmental agencies, and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the Commission
reserves the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the
Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure
to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska
Administrative Code, or a Commission order, or the terms and conditions of this permit may
result in the revocation or suspension of the permit. Please provide at least twenty-four (24)
hours notice for a representative of the Commission to witness any required test. Contact the
Commission's petroleum field inspector at (907) 659- 7 (pager).
BY ORDER OF THE COMMISSION
DATED this.J.l day of October, 2004
cc: Department ofFish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
STATE OF ALASKA
ALASKA Oil AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
RECEIVED~
OCT~ 82004 9'c¡(
Alaska Oil & Gu Cons.. Commissmn
1a. Type of Work: Drill 0 Redrill 0 1b. Current Well Class: ExploratoryU Development Oil L:d . 'J\IØlftiple Zone 0
Re-entry 0 Stratigraphic Test 0 Service D Development Gas D Single Zone 0
2. Operator Name: 5. Bond: L:d Blanket -0- Single Well 11. Well Name and Number:
ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1E-168L1
3. Address: 6. Proposed Depth: 12. Field/Pool(s):
P.O. Box 100360 Anchorage, AK 99510-0360 MD: 12015' TVD: 3560' Kuparuk River Field
4a. Location of Well (Governmental Section): 7. Property Designation: ~'þ lTd1"
Surface: 207' FNL, 640' FEL, Sec. 21, T11 N, R1 DE, UM ALK 25651!~ \0 I~--c,.., West Sak Pool
Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date:
696' FNL, 1613' FEL, Sec. 22, T11N, R1OE, UM ADL 469/466 11/10/2004
Total Depth: 9. Acres in Property: 14. Distance to
1302' FNL, 1249' FEL, Sec. 15, T11 N, R10E, UM 2560 Nearest Property: 8947'
4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest
Surface: x- 549890 y- 5959380 Zone- 4 (Height above GL): 28 feet Well within Pool: 665' @ '1E-123 ,
16. Deviated wells: 17. Anticipated Pressure (see 20 AAC 25.035)
Kickoff depth: 7476 ft. Maximum Hole Angle: 94.3° Max. Downhole Pressure: 1514 psig / Max. Surface Pressure: 1141 psig
18. Casing Program Setting Depth Quantity of Cement
Size Soecifications Top Bottom c. f. or sacks
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data)
42" 20"x34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete
13.5" 10.75" 45.5# L-80 BTC 4422' 28' 28' 4450' 2459' 710 sx ASLite, 205 sx DeepCrete
9-7/8" 7-5/8" 29.7# L-80 BTCM 8381' 28' 28' 8409' 3702' 51 0 sx DeepCrete
6.75" 4.5" 12.6# L-80 DWC 4689' 7326' 3514' 12015' 3560' slotted liner
I
19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)
Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured)
Casing Length Size Cement Volume MD rvD
Structural
Conductor
Surface
Intermediate
Production
Liner
Perforation Depth MD (ft): A. ) Perforation Depth TVD (ft):
20. Attachments: Filing Fee LJt1 BOP Sketch D Drilling Program 0 Time v. Depth Plot D Shallow Hazard Analysis D
Property Plat 0 Diverter Sketch D Seabed Report D Drilling Fluid Program 0 20 AAC 25.050 requirements 0
21. Verbal Approval: Commission Representative: Date:
22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Shultz @ 263-4620
Printed Name ~ Thomas Title Kuparuk Drilling T earn Leader
Signature?~ ~_ 1)-.- Phone Date /O/o'l/zÞø4
I g,VIJT' - PrenRred bv ShRron AlIsun-DrflkR
. "1/ Commission Use Only
Permit to Drill API Number: Permit Approval See cover letter
Number: J(:)'-\ - 'd-O \ 50- O:}~ - d 5:1-Š{)- bÐ Date: 10 III jOy' for other requirements
Conditions of approval : Samples required DYes 9lNO Mud log required DYes &L No
Hydrogen sulfide measures DYes ~o Directional survey required [8..J' es D No
Other: ~~ßf0 t:> -\€:"" \- OL"'> f \ö.",~ . ro\>~s ~\^'-\C r\..)C. \ L.... \ l{.~'f>
BY ORDER OF IOI'lI ~~ ---
Approved orn--I "A COMMISSIONER THE COMMISSION Date:
~~3~ 0 I I ,
Form 10-401 Revised 3/2 3 · Submit in du licate
RIGINAl
p
~~/~
ConocoPhillips
Alaska
Post Office Box 100360
Anchorage, Alaska 99510-0360
Randy Thomas
Phone (907) 265-6830
Email: Randy.L.Thomas@conocophillips.com
RECEIVED
OCT 0 6 2004
Alaska Oil & Gas Cons. Commission
Anchorage
October 1, 2004
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue
Suite 100
Anchorage, Alaska 99501
Re: Application for Permit to Drill, West Sak Producer, 1E-168 L1
Dear Commissioners:
ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for an onshore production wellbore, the
upper lateral wellbore of a multilateral horizontal well, in the West Sak "B" sand. The main bore of this
well will be designated 1E-168 and has been permitted under a separate application, submitted on
October 1, 2004. This application is for the upper lateral of that well, to be designated 1E-168Ll. The
expected date that operations will begin on 1E-168L1 is November 10, 2004.
Please find attached for the review of the Commission a Form 10-401 and the information required by 20
ACC 25.005 for each of this well bore.
Under separate cover, ConocoPhillips is applying for a spacing exception for this well bore, under the
terms of 20 MC 25.055
Please contact Steve Shultz at 263-4620 if more information is needed to issue a Permt to Drill for 1E-
168Ll.
Sincerely,
~~\~.
Randy Thomas .
GKA Drilling Team Leader
ORIGINAL
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
RE EIVED
OCT () 520'04
10. KB ElevatiØh 15. Distance to Nearest
4 (Height above -2- 28 feet Well within Pool: 665' @ '1 E-123 , ~
I I . .. n_ ure (see 20 AAC 25.035)
ft. ~ Hole Angle: 94.3° Maxpownhole Pressure: 15 :", -LM.ê2<. Surface Pressure: 1141 psig
/' / Setting Depth ~antity of Cement
/' Specifications ¡rop Bottom 'a. f. or sacks
Casi~ Weight Grade Coupling Length MÇÝ TVD MD TVD (including stgge1fata)
21" 94# K-55 Welded 80' ~8' 28' 108' 108' 260 c~Crete
1Q.75" 45.5# L-80 BTC 4154' .£,f8" ..Æ8' 4182' 2295' 7~SLite,189 sx DeepCrete
7~:>/8" 29.7# L-80 BTCM 8752' 1\ ~' 1<'1£ 28' 8780' 3~ 508 sx DeepCrete
4\?" 12.6# L-80 DWC 407qf \.¡~84"" "'1560' 1185ÿ """-3633' slotted liner
\ ~.-" .,...,.-
"- PRESENT WELL CONDITION SUMMAFyf '\ ~e completed for Redrill and Re-Entry Operations)
'~TVD (ft): Plugs (mea¡fJred)~~lve Depth MD (ft): Effective Depth TVD (ft): Junk (measured)
7~
Size / ßY Cement Volume
I /\...J
1_0
If"',. '\l
IE..-J "
V)
1a. Type of Work:
Drill 0
Re-entry 0
1b. Current Well Class:
Stratigraphic Test 0
Redrill U
2. Operator Name:
ConocoPhillips Alaska, Inc.
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
4a. Location of Well (Govemmental Section):
Surface: 207' FNL, 640' FEL, Sec. 21, T11N, R10E, UM /
Top of Productive Horizon:
696'FNL,1613'FEL,Sec.22,T11N,R10E,UM
Total Depth:
1302' FNL, 1249' FEL, Sec. 15, T11N, R10E, UM
4b. Location of Well (State Base Plane Coordinates):
Surface: x- 549890.1 y- 5959380 / Zone-
16. Deviated wells:
Kickoff depth: 7476'/
18. Casing Program
Size
Hole
Driven
13.5"
9-7/8"
6.75"
19
Total Depth MD (ft):
Casing
Structural
Conductor
Surface
Intermediate
Production
Liner
Length
Perforation Depth MD (ft):
J
/
/
Filing Fee 0 / BOP Sketch 0
Property Plat 0 / Diverter Sketch 0
21. Verbal Approval: Commission Repyfsentative:
22. I hereby certify that the fOregOinr true and correct to the best of my knowledge.
Printed Name þ j. ndy Thomas
Signature ~ l t ~~
I ~l '
/
Permit to Drill " , I
Number: 2Djf - 20 I 50-07-C(- 2-32-3D~6
conditiOOlrs of ap, roval: Samples required 0 Yes 3_NO
Hydrogen sulfide measures 0 Yes ~No
Other:
20. Attachments:
Drilling Program 0
Seabed Report 0
-
20 AAC 25 005 Alaska OU & Gas Cons. Commission
ExploratoryU Development Oil U Ant:lflwâgë:>ne 0
Service 0 Development Gas 0 Single Zone 0
5. Bond: ~ Blanket U Single Well 11. Well Name and Number:
Bond No. 59-52-180 1 E-168L1
6. Proposed Depth: 12. Field/Pool(s):
MD: 12015' TVD: 3560' Kuparuk River Field
7. Property Designation: . t
ALK 25651~~o ,ç.d West Sak Pool
8. Land Use Permit: 13. Approximate Spud Date:
ADL 469/466 11/10/2004
./
9. Acres in Property:.
2560
14. Distance to
Nearest Property:
8947'
MD
rvD
Perforation Depth TVD (ft):
Time v. Depth Plot 0
Drilling Fluid Program 0
Date:
Shallow Hazard Analysis LJ
20 AAC 25.050 requirements 0
Contact Steve Shultz @ 263-4620
Title Kuparuk Drilling Team Leader
Phone Z--~.J6ð5 ô Date to/er 1ð'1'
PreDared bv Sharon Al/suD-Drake
API Number:
Commission Use Only
Permit Approval
See cover letter
for other requirements
Date:
Mud log required
Directional survey required
o Yes ~ No
~Yes 0 No
BY ORDER OF
THE COMMISSION
Approved by:
COMMISSIONER
(JRIGINAL
Form 10-401 Revised 3/2003 ·
Date:
Submit in duplicate
Appli,,~!) for Permit to Drill, Well 1 E-168 L 1
Revision No.O
September 30, 2004
Permit It - West Sak Well #1 E-168 L 1 ("B" Sand)
Application for Permit to Drill Document
Ml)ximizE
We-II Iofell,l!;
Table of Contents
1. Well Name..................................................................................................................... 2
Requirements of 20 AAC 25.005 (f) .................................................................................................... 2
2. Location Sum mary ....................................................................................................... 2
Requirements of 20 AAC 25. 005(c)(2) ................................................................................................ 2
Requirements of 20 AAC 25.050(b) ........ ....... ........... ............. .... '" ... .... ............................................... 3
3. Blowout Prevention Equipment Information ............................................................3
Requirements of 20 AAC 25.005(c)(3) ... ......... .... ...... ..... ........ ............... ....... ...... ........ ....... ..... ...... ....... 3
4. Drill i ng Hazards Information ...................................................................................... 3
Requirements of 20 AAC 25.005 (c)(4) ............................................................................................... 3
5. Procedure for Conducting Formation Integrity Tests .............................................3
Requirements of 20 AAC 25.005 (c)(5) .. ........... ................ ....... ....... ...... ..... .................. ........ ....... ........ 3
6. Casing and Cementing Program .... ............................................................................4
Requirements of 20 AAC 25. 005(c)(6) ............................................................................ ....................4
7. Diverter System Information ...................................................................................... 5
Requirements of 20 AAC 25.005(c)(7) . ............... ........ ........ .......................... ..................... ............ ..... 5
8. Drilli ng Fluid Prog ram............................................... ............ ......................................5
Requirements of 20 AAC 25. 005(c)(8) ...................................................................... .......................... 5
Lateral Mud Program (MI FloPro NT) ..................................................................................................5
9. Abnormally Pressured Formation Information ........................................................5
Requirements of 20 AAC 25.005 (c)(9) ...............................................................................................5
10. Seismic Analysis .......................................................................................................... 5
Requirements of 20 AAC 25.005 (c)(10) .............................................................................................5
11. Seabed Condition Analysis .......... .......... ................. .......... ......................................... 6
Requirements of 20 AAC 25.005 (c)(11) ............................................................................................. 6
12. Evidence of Bon ding ................................................................................................... 6
Requirements of 20 AAC 25.005 (c)(12) ............................................................................................. 6
ORIGINAL
L 1 PERM/T IT RevO.doc
Page 1 of 7
Printed: September 30, 2004
'~
AppU"j() for Permit to Drill, Well 1 E-168 L 1
"-"" Revision No.O
September 30,2004
13. Proposed Dri Iii ng Progra m ........................................................................ .................6
Requirements of 20 AAC 25.005 (c)(13) ............................................................................................. 6
14. Discussion of Mud and Cuttings Disposal and Annular Disposal........................6
Requirements of 20 AAC 25.005 (c)(14) ... ..... ....... .................. ........ ........... ....... ....................... ........... 6
15. Attach ments.................................................................................................................. 7
Attachment 1 Directional Plan (8 pages) .............................................................................................7
Attachment 2 Drílling Hazards Summary (1 page)...............................................................................7
Attachment 3 Well Schematic (1 pages)............................................................................................. 7
1. Well Name
Requirements of 20 AAC 25.005 (f)
Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission
under 20 AAC 25.040(b). For a well with multiple well branche~ each branch must similarly be identified by a unique name and API
number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the
commission.
The well for which this Application is submitted will be designated as 1 E-168 Ll.
2. Location Summary
Requirements of 20 AAC 25.005(c)(2)
An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the
commission and identified in the application:
(2) a plat identifying the property and the property's owners and showing
(A}the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth,
referenced to governmental section lines.
(B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this
state as maintained by the National Geodetic SUNey in the National Oceanic and Atmospheric Administration;
(C) the proposed depth of the well at the top of each objective formation and at total depth;
Location at Suñace I
ASP Zone 4 NAD 27 Coordinates
Northings.· 5,959,380 Eastings.· 549,890
FNL:207', FEL:640', See 21, T11N/R10E, UM
I RKB Elevation I
I Pad Elevation I
,/
98.4' AMSL
70.4' AMSL
Location at Top of
Productive Interval FNL:696', FEL:1613', See 22, T11N/R10E, UM
(West Sak "8" Sand)
ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB,' 7326'
Northings..s,958,921 Eastings.· 554,200 Total Vertical Depth, RKB.· 3514'
Total Vertical Depth, 55,' 3416.0'
Location at Total Depth I FNL:1302', FEL:1249', See 15, T11N/R10E, UM
ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB,' 12015'
Northings.' 5,963,597 Eastings: 554,524 Total Vertical Depth, RKB,' 3560'
Total Vertical Depth, 55,' 3462.0'
,/
and
(D) other information required by 20 MC 25.050(b);
ORIGINAL
L 1 PERMIT IT RevO.doc
Page 2 of 7
Printed: September 30, 2004
Appli~iÎ for Permit to Drill, Well 1 E-168 L 1
Revision No.O
October 1, 2004
Requirements of 20 AAC 25.050(b)
If a well is to be intentionally deviateft the application for a Permit to Drill (Form 10-401) must
(1) include a pla~ drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200
feet of any portion of the proposed well;
Please see Attachment 1: Directional Plan
and
(2) for all wells within 200 feet of the proposed wellbore
(A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records,
and show that each named operator has been furnished a copy of the application by certified mail; or
(B) state that the applicant is the only affected owner.
The Applicant is the only affected owner.
3. Blowout Prevention Equipment Information
Requirements of 20 AAC 25.005(c)(3)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the
commission and identified in the application:
(3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 MC 25.035, 20 MC 25.036, or 20
MC 25.037, as applicable;
An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1E-168 L1.
Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission.
4. Drilling Hazards Information
Requirements of 20 AAC 25.005 (c)(4)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the
commission and identified in the application:
(4) information on drilling hazards, including
(A) the maximum downhole pressure that may be encountereft criteria used to determine i~ and maximum potential surface
pressure based on a methane gradien~'
The expected reservoir pressures in the West Sak sands in the 1E-168L1 area vary from 0.46 to 0.44
psi/ft, or 8.8 to 8.5 ppg EMW (equivalent mud weight). These pressures are predicted based on actual ./
bottom hole pressure data from the nearby West Sak wells.
The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a
methane gradient (0.11) and the deepest planned vertical depth of the West Sak D sand formation is
1141.336 psi, calculated thusly:
MPSP =(3442.4 ft)(0.44 - 0.11 psi/ft)
=1141.336 psi ./
Since the estimated pore pressure is well below the rating of a 3,000 psi BOPE system, we would like to
request permission to operate our 5,000 psi system as a 3,000 psi system which would allow us to
maintain a set of casing rams in the second pipe ram cavity and also permit us to test to only 3500 psi.
(B) data on potential gas zones;
The well bore is not expected to penetrate any gas zones.
and
(C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones
that have a propensity for differential sticking;
Please see Attachment 2: Drilling Hazards Summary.
5. Procedure for Conducting Formation Integrity Tests
Requirements of 20 AAC 25.005 (c)(5)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the
commission and Identified in the application:
ORIGINAL
L 1 PERMIT IT RevO.doc
Page 30f7
Printed: October 1, 2004
Applk . ,.1 for Permit to Drill, Well 1 E-168 L 1
~ Revision No.O
September 30, 2004
(5) a description of the procedure for conducting formation integrity test~ as required under 20 MC 25.030(f)/
The parent wellbore,lE-168, will be completed with 75/8" intermediate casing landed in the West Sak A-
Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance
with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the
Commission.
6. Casing and Cementing Program
Requirements of 20 AAC 25.005(c)(6)
An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the
commission and /öentified in the application:
(6) a complete proposed casing and cementing program as required by 20 MC 25. 03~ and a description of any slotted liner, pre-
perforated liner, or screen to be installed/
Casing and Cementing Program
See also Attachment 3, APD for 1E-168: Cement
Summa!)
Hole Top Btm
Csgfrbg Size Weight Length MOfrVO MOfrVO
00 (in) (in) (lb/ft) Grade Connection (ft) (ft) (ft) Cement Program
20 X 34 42 94 K55 Welded 80 28 / 28 108 / 108 Cemented to
surface with
260 cf
ArcticCRETE
10 3/4 13 1/2 45.5 L-80 BTC 4422 28 / 28 4450 /2459 Cemented to
Surface with
710 sx ASLite
Lead, 205 sx
DeepCRETE
Tail
7 5/8 9 7/8 29.7 L-80 BTCM 8381 28 / 28 8409 / 3702 Cement Top
planned @
4786' MD /
2595' TVD.
Cemented w/
510 sx
DeepCRETE
4 1/2 6 3/4" "A" 12.6 L-80 DWC 6051 7470/3535 13521/3771 Slotted- no
slotted Lateral (1 E- cement
/ -- '- 168) -. ~------ - --.... ~
4 1/2 63/4" 12.6 L-80 DWC 4689 7326/3514 12015/3560 Slotted- no
I slotted "B" Lateral cement /
\ ( 1E-168 Ll) ./
4'1..¡z-- ¡-- 6 3/4 12.6 L=80 5001 700ôi3~~L .......^^ ...... .. "-..oò"
uvv\.. I /( II _. oJoJVV
slotted "D" Lateral cement
(lE-168 L2)
ORIGINAL
L 1 PERMIT IT RevO.doc
Page 4 of 7
Printed: September 30, 2004
Applf... . )1 for Permit to Drill, Well 1 E-168 L 1
~ Revision No.O
October 1, 2004
7. Diverter System Information
Requirements of 20 AAC 25.005(c)(7)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the
commission and identified in the application:
(7) a diagram and description of the diverter system as required by 20 MC 25. 035, unless this requirement is waived by the
commission under 20 MC 25.035(h)(2);
No diverter system will be utilized during operations on 1E-168 L1
8. Drilling Fluid Program
Requirements of 20 AAC 25.005(c)(B)
An application for a Permit to Doll must be accompanied by each of the following items, except for an item already on file with the
commission and identified in the application:
(8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 MC 25.033;
Drilling will be done with muds having the following properties over the listed intervals:
Lateral Mud Program (VersaPro, Oil Base Mud)
Properties
Value
Density (ppg) 9.1
Funnel 30
Viscosity
(seconds)
Yield Point 18-28
(cP)
Electric Stability 650-900
Chlorides (mg/I) 40000
pH N/A
API filtrate <4
(cc / 30 min)
**HTHP filtrate <10
(cc /30 min)
MBT (Ib I gal)
/
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please
see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon
141 Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005 (c)(9)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the
commission and identified in the application:
(9) for an exploratory or stratigraphic test wel¿ a tabulation setting out the depths of predicted abnormally geo-pressured strata as
required by 20 MC 25.033(f);
Not applicable: Application is not for an exploratory or stratigraphic test well.
9. Seismic Analysis
Requirements of 20 AAC 25.005 (c)(10)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the
commission and identified in the application:
(10) for an exploratory or stratigraphic test wel¿ a seismic refraction or reflection analysis as required by 20 MC 25.061(a);
Not applicable: Application is not for an exploratory or stratigraphic test well.
ORIGINAL
L 1 PERMIT IT RevO.doc
Page 50f7
Printed: October 1, 2004
Applì\ ;/1 for Permit to Drill, Well 1 E-168 L 1
~
Revision No.O
October 1 , 2004
10. Seabed Condition Analysis
Requirements of 20 AAC 25.005 (c)(11)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the
commission and identified in the application:
(11) for a well drilled from an offshore platform~ mobile bottom-founded structure/ jack-up rig, or floating drilling vesse¿ an analysis
of seabed conditions as required by 20 MC 25.061(b);
Not applicable: Application is not for an offshore well.
11. Evidence of Bonding
Requirements of 20 AAC 25.005 (c)(12)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the
commission and Identified in the application:
(12) evidence showing that the requirements of 20 MC 25.025 {Bonding}have been me~'
Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission.
12. Proposed Drilling Program
Requirements of 20 AAC 25.005 (c)(13)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the
commission and identified in the application:
The proposed drilling program for lE-168 Ll is listed below.
Note: Previous operations are covered under the 1E-168 Application for Permit to Drill.
1. Run and set Baker WindowMaster whipstock system, at window point of 7326' MD / 3514' lVD, the top of
the B sand.
2. Mill 6 3/4" window. POOH.
3. Pick up 63/4" drilling assembly with LWD and MWD and PWD. RIH.
4. Drill to TD of "B" sand lateral at 12015' MD / 3560' lVD, as per directional plan.
5. POOH, back reaming out of lateral. POOH.
6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH.
7. PU and run 4 1/2" slotted liner.
8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger.
9. Release hanger running tool. Displace liner annulus and liner to 8.8 ppg weighted brine.
10. POOH and PU lateral entry module
11. RIH with module and latch into the "B" sand hook hanger
12. POOH and prepare to drill the "D" sand laterallE-168 L2.
'\~"ì~
G XX?fu\k \
13. Discussion of Mud and Cuttings Disposal and Annular Disposal
Requirements of 20 AAC 25.005 (c)(14)
An application for a Permit to Drill mustc be accompanied by each of the following items/ except for an item already on file with the
commission and identified in the application:
(14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the
operator intends to request authorization under 20 MC 25.080 for an annular disposal operation in the well.;
Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids
into a permitted annulus on 1 E Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings
generated will be disposed of either down a permitted annulus on 1E Pad, hauled to the Prudhoe Bay
Grind and Inject Facility for temporary storage and eventual processing for injection down an approved
disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on
pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska.
ORIGINAL
L 1 PERMIT IT RevO.doc
Page 6 of 7
Printed: October 1,2004
14. Attach ments
Attachment 1 Directional Plan
Attachment 2 Drilling Hazards Summary
Attachment 3 Well Schematic
ORIGINAL
AppH~n for Permit to Drill, Well 1 E-168 L 1
Revision No.O
September 30, 2004
L 1 PERMIT IT RevO.doc
Page 7 of 7
Printed: September 30, 2004
"""-'~
" .
~
lE-168Ll Drilling Hazards Summa~
63/4" Open Hole / 41/2" Liner Interval
Hazard
Abnormal Reservoir
Pressure
Stuck Pi pe
Risk Level
Low
./
Miti ation Strate
Stripping drills, Shut-in drills, Increased
mud wei ht.
Good hole cleaning, PWD Tools, Hole
o ener, Decreased mud wei ht
Reduced um rates, Mud rheolo LCM
Trip speeds, Proper hole filling (use of trip
sheets, Pum in out
Low
Lost Circulation
Hole Swabbing on Trips
Moderate
Low
ORIGINAL
1 E-168 Drilling Hazards Summary
prepared by Steve Shultz
9/1/2004 4:26 PM
Tie-In
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
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48
49
50
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52
53
54
55
56
57
58
59
60
61
'aker Hughes Incorporatl
Anticollision Report
GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 ofreference
Interpolation Method: MD Interval: 25.00 ft
Depth Range: 7325.86 to 12015.86 ft
Maximum Radius: 5280.00 ft
Reference:
Error Model:
Scan Method:
Error Surface:
Principal Plan & PLANNED PROGRAM
ISCWSA Ellipse
Trav Cylinder North
Ellipse + Casing
Survey Program for Definitive Wellpath
Date: 9/28/2004 Validated: No
ptanned From To Survey
ft ft
7325.85 12015.86 Planned: 1E-168L1 Ver#2V7
Version: 2
Toolcode
Tool Name
MWD+SAG
MWD + Sag correction
Casing Points
Pad 1 B 15 1B-15 VO 11998.22 6425.00 1667.25 366.10 1301.15 Pass: Major Risk
Pad 1 B 15 1B-15A VO Plan: 1B-15A 11992.00 6175.00 1678.36 409.32 1269.04 Pass: Major Risk
Pad 1 B 17 1 B-17 V2 11991.04 6425.00 974.65 237.11 737.54 Pass: Major Risk
Pad 18 18 1 B-18 VO 11940.31 5575.00 524.10 419.18 104.93 Pass: Major Risk
Pad 1 B 4 1 B-04 VO 10604.21 5925.00 1317.23 358.52 958.71 Pass: Major Risk
Pad 1 B 5 1 B-05 VO Out of range
Pad 1 B 6 1 B-06 VO 10695.17 6025.00 1247.62 337.95 909.67 Pass: Major Risk
Pad 1 E 114 1 E-114L 1 Vers#2 V3 Pia 7332.06 7150.00 300.73 268.01 32.72 Pass: Major Risk
Pad 1 E 114 1E-114L2 Vers#2 V3 Pia 7325.85 7200.00 373.52 225.47 148.05 Pass: Major Risk
Pad 1 E 166 1E-166 V14 Out of range
Pad 1 E 166 1E-166L1 V8 Out of range
Pad 1 E 166 1E-166L1PB1 V1 Out of range
Pad 1 E 166 1E-166L2 V6 Out of range
Pad 1 E 168 1E-168 Vers#2 V4 Plan: 9036.83 13521.48 4551.38 498.74 4052.64 Pass: Major Risk
Pad 1 E 168 1E-168L2 Ver#2 V2 Plan 11957.99 12009.38 17.75 132.69 -114.94 FAIL: Major Risk
Pad 1 E 170 170 A2-Lateral VO Plan Out of range
Pad 1 E 170 170 B-Lateral VO Plan: Out of range
Pad 1 E 170 170 D-Lateral VO Plan: Out of range
Pad 1 E 27 1 E-27 VO Out of range
Pad 1 E 28 1 E-28 VO Out of range
Pad 1 E 29 1 E-29 VO Out of range
Pad 1 E 8 1 E-08 V1 7325.85 7100.00 1336.35 166.80 1169.55 Pass: Major Risk
ORIGINAL
·
e
,..,/ .
ConocóPhillips ConocoPhillips Alaska, Inc.,Slot #168
Pad 1 E,
Kuparuk River Unit,North Slope, Alaska
PROPOSAL LISTING Page 1
Well bore: 168L 1
Well path: 168L 1 Ver#2
Date Printed: 29-Sep-2004
INTEQ
3-SeQ:2004
AK-4 on NORTH AMERICAN DATUM 1927 datu
All data is in Feet unless otherwise stated
Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 98.4ft above mean sea level)
Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees
Bottom hole distance is 6266.17 Feet on azimuth 48.08 degrees from Wellhead
Calculation method uses Minimum Curvature method
Prepared by Baker Hughes Incorporated
ORJGI~tAL
.
.
"'"
ConocòPhillips ConocoPhillips Alaska, Inc.,Slot #168
Pad 1 E,
Kuparuk River Unit, North Slope, Alaska
PROPOSAL LISTING Page 2
Well bore: 168L 1
Wellpath: 168L 1 Ver#2
Date Printed: 29-Sep-2004
...
----
INTEQ
.... ., ,.i...... ... > ......... ><
..... .. .. .... .... i· . ...... i ......
MO{ftl. [,-vDtftl 1\1..1'11(\"1 Nofthfttl..... [gast[ft} i5fation '$tatioll IllQ!,Ji7!,J IV~f['Pi 1 ..........
19":·......"
..... ILJ~~nþ;:). ..... .......
........ .... '··i North) East) loftf In 1<, .... ..... ........... .....
7325.86 80.00 4,43 3514,40 3416.00 487.238 4307.10E 5958921,42 ~54199.81 0.00 -153,47 Top Whipstock Face Tie on
7337.86 81.91 4,43 3516.29 3417.89 475,428 4308.01E 5958933.24 554200.65 15.90 -141.62 Base Whipstock Face End of Build
7355.86 81.91 4,43 3518.82 3420,42_ t-457.658 4309.39E 5958951.02 554201.91 0.00 -123.80 End Milled Hole End of Hold
7455.86 86.91 4,43 3528.56 3430.16 358,458 4317.07E 5959050.25 554208.92 5.00 -24.30
7475.88 87.91 4,43 3529,47 3431.07 338.518 4318.61E 5959070.20 554210.33 5.00 -4.30 30X8 Kick off Point
7500.00 88.63 4,40 3530.20 3431.79 314,478 4320,4º-J;, 59590ß.4.25 -º.94212Jt3_ . 3.00 19.80 --
7559.27 90,41 4.33 3530,69 343229 255 388 4324.97E 5959153.36 5542j~ ¡-~"ºº-- _79.07 End of BuildfTurn
7600.00 90,41 4.33 3530,40 3432.00 214.778 4328.05E .5959193.99 c-gM21~~ ¡--O.OO 119.80
7620.69 90.41 4.33 3530.25 3431.85 194.148 4329.61E 5959214.63 554220.38 0.00 140.49 End of Hold
7700.00 88.03 4.40 3531.33 3432.93 115.078 4335.65E ~92~3.73 55422589 3.00 219.79
...1704.06 87.91 4.41__ ~.31 .48 ~O8 111.038 4335.9º-E ~9297.77 _(254226.17 3.00 223.84 End of OropfTurn
7800.00 87.91 4.41 353498 3436.58 15.438 4343.33E 5959393.40 554232.90 000 319.72
_7900.00 87.91 4.41 3538.63 3440.23 84.21 N 4351.00E 5959493.08 554239.91 0.00 419.66 r-----
8000.00 87.91 4.41 3542.27 3443.87 183.85N 4358.68E 5959592.76 554246.93 0.00 519.59 .----.--
8100.00 87.91 4.41 3545.92 3447.52 283.49N 4366.3~ ~692.44 -º54253.94 000_ ~/53
8200.00 87.91 4.41 354957 3451.17 383.13N 4374.031:: 5959792.12 554260.95 0.00 719.46
8300.00 87.91 4.41 3553.22 3454.82 482.77N 4381,701- 5959891.80 554267.97 0.00 819.40
8400.00 87.91 4.41 3556.87 3458.47 582.41N 438938J;, ~.9Þ9991Aß.. -º54274.98 000 919.33
8414.57 87.91 4.41 3557.40 345900 596.93N 4390.49E 5960006.00 554276.00 000 933.89 W8 1 E C5 B-MDPT#1 RV8D090204,
----- r--' 3DJ Kick off Point
8500.00 90.47 4.44 3558.61 3460.21 682.09N 4397.09J::; ~60091.2º--- ~54282..P2.. ¡.---3.00 1019.31 --
8600.00 93.47 4.49 3555.17 3456 77 781.72N 4404.871: 5960190.86 554289.14 300 1119.24
8628.00 94.31 4.50 3553.27 3454.87 809.57N 4407.061: ~O218.72 554291.15 3.00 1147.18 I;:nd of BuildfTurn
8700.00 94.31 4.50 3547.85 3449.45 881.14N 4412.691: 5960290.33 554296.31 0.00 1218.97
8800.00 94.31 4.50 3540.34 3441.94 980.55N 4420.521: 5960389.77 55430Hª---. t-.O.OO 1318.69
8900.00 94.31 4.50 3532.82 3434.42 1079.96N 4428 35~: ~9604~ _.~5.4310.61L 0.00 1418.40 --
8918.88 94.31 4.50 3531.40 3433.00 1098.72N 4429.83E 5960508.00 55431200 0.00 1437.23 W8 1E C5 B-MDPT#2 RV8D090204,
-- ._-- I---- 3DJ Kick off Point
9000.00 91.88 4.46 3527.02 3428.62 1179.47N 4436.16E 5960588.78 554317.79 3.00 1518.23
9081.69 89.43 4.42 3526.09 3427.69 1260.91N 4442.48E; 5960670.25 554323.58 300 1599.91 Encj of DropfTurn
9100.00 89.43 4.42 3526.27 3427.87 1279.16N 4443.90E 5960688.51 554324.86 0.00 1618.21
9200.00 89.43 4.42 3527.27 3428.87 13?8.86N 4451.60E 5960788.24 55433:1-91 0.00 1718.21 --
9300.00 89.43 4.42 3528.27 3429.87 1478.56N 4459.311;, 5960887.98 554338.95 0.00 1818.20
9400.0Q 89.43 4.42 3529.27 3430.87 1578.25N 4467.01E ~96098ZR ~345.99 0.00 1918.20 '-
9500.00 89.43 4.42 3530.27 3431.87 1677.95N 4474.72E ~Ji1 087AQ.. _554353.04 0.00 .2QJ8.19 --
9600.00 89.43 4.42 3531.27 3432.87 1777.65N 4482.42E 5961187.19 554360.08 0.00 2118.19
9700.00 89,43 4.42 3532.27 3433.87 1877.35N ~/13E ~9612869:L 554367.12 0.00 2218.18
9800.00 89.43 4.42 3533.27 ~34.87 1977.05N 4497.84E 5961386.66 554374.16 000 2318.18
9900.00 89.43 4.42 3534~~ 3435.87 2076.74N 4505.54,1:: ~61486.40_ ...Q.Q4381.21 0.00 2418.17 .---
10000.00 89.43 4,42 3535.26 3436.86 2176,44N 4513.25E 5961586.14 554388.Zº---. _JLOO_ 2518.17
10100.00 89.43 4.42 3536.26 3437.86 2276.14N 4520.95E 5961685.87 554395.29 0.00 2618.16
10200.00 89.43 4.42 3537.26 3438.86 2375.84N 452ß.66E 5961785.61 .. 554402.34 0.00 271816
10300.00 89,43 4.42 3538.26 3439.86 2475.53N 4536.36E 5961885.35 554409.38 0.00 2818.15
10400.00 89.43 4.42 3539.26 3440.86 2575.23N 4544.07E 5961985.09 554416.42 0.00 2918.15
J050.Q",ºº- 89AL 4.42 3540.26 34418!L 2674.93N 4551.77E ~084..ß2.. í5~2MQ.. -.0..00 3018.14 --
10600.00 89.43 4.42 3541.26 3442.86 2i'74.63N 4559,48E 5962184.5.6 554430.51 0.00 3118.14 ---
10700.00 89.43 4.42 3542.26 3443.86 2874.32N 4567.19E 59622!¡;1..d!L ~4375_º---. 0.00 3218.13
10800.00 89.43 4.42 3543.26 3444.86 2974.02N 4574.89E 5962384.03 554444.59 0.00 331813
10900.00 89.43 4.42 3544.26 3445.86 3073.72N 4582.60E L 5962483. ZL 554451.64 0.00 3418.12 .--
11000.00 89.43 4,42 35452º- 3446.85 3173.42N 4590.30E. º-962583.51 554458.6.ß_ -------º.OQ_ 3518.12 -.
All data is in Feet unless otherwise stated
Coordinates are from 810t MD's are from Rig and TVD's are from Rig ( Datum #1 98.4ft above mean sea level)
Vertical 8ection is from O.OON O.OOE on azimuth 4.43 degrees
Bottom hole distance is 6266. '17 Feet on azimuth 48.08 degrees from Wellhead
Calculation method uses Minimum Curvature method
Prepared by Baker Hughes Incorporated
n. ) D."~ f ,~
,,--,¥ ! 'i. .' 1..< ¡.
í\ f A :
~\~ i ,t",
.
e
C~illips ConocoPhillips Alaska, Inc.,Slot #168
Pad 1 E,
Kuparuk River Unit, North Slope, Alaska
PROPOSAL LISTING Page 3
Well bore: 168L 1
Well path: 168L 1 Ver#2
Date Printed: 29-Sep-2004
.:
INTEQ
. ...... ...... . . < > . . / .......
'" ..... .. ..... .. .... < .... ..... /. .. ..... .... . .... ..·i> .
rMQtft} . ... . ...... ,"",..c, Eªs~ftl I :¡itat, on .n¡\t'llèd VE1~J;ar ... ......
IVYlTIj 'vU""",'
......
... ........ .. ..- if\!orthì .. Ëast\ ....... h'M'" tl········ > ..i/ .
.....
11100.00 89.43 4.42 3546.25 3447.85 32n..11f\!. ~9Itº1E c-_5962683.24 554465.72 0.00 3618.11
11200,00 89.43 4.42 3547.25 3448.85 3372.81N 4605.71E 5962782.98 554472.76 0.00 3718.11
11300,00 89.43 4.42 3548.25 3449.85 3472.51 N 4613.42E 5962882.72 554479.81 0.00 3818.10
11400,00 89.43 4.42 3549.25 3450.85 3572.21 N 4621.12E 5962982.45 554486.85 000 3918.10
11500.00 89.43 4.42 3550.25 3451.85 367191N 4628.83E 5963082.19 554493.89 0.00 4018.09
11600.00 89.43 4.42 3551.25 ~11_ ~c60N 463654E 5963181.93 554500.94 0.00 4118.09
11615.11 89.43 4.42 3551 .40 3453.00 3786.67N 4637.70E 5963197.00 554502.00 0.00 4133.20 WS 1 E C5 B-MDPT#3 RVSD090204,
-- 3DJ Kick off Point
11655.19 88.68 3.48 3552.06 3453.66 3826.64N 4640.46E 5963236.98 554504.49 3.00 4173.27 End of DroDfTurn
11700.00 88,68 3.48 3553.10 3454.70 3871.36N 4643.18E 5963281.72 554506.92 0.00 4218.06
11800.00 88.68 3.48 3555.41 3457.01 3971.15N 4649.25E 5963381.5~ --.lil54512.33 0.00 4318.Q2. -.
11900.00 88.68 3.48 3557.72 3459.32 4070.94N 4655.32E 5963481,35 554517.73 0.00 441798
12000.00 88.68 3.48 3560.03 346163 4170.73N 4661.40E 5963581,17 554523.14 0.00 4517.94
12015.86 88.68 3.48 3560.40 3462.00 4186.56N 4662.36E 5963597.00 554524.00 0.00 4533.80 TD, WS 1 E C5 B TOE RVSD090204,
End of Hold
All data is in Feet unless otherwise stated
Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 98.4ft above mean sea level)
Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees
Bottom hole distance is 6266.17 Feet on azimuth 48.08 degrees from Wellhead
Calculation method uses Minimum Curvature method
Prepared by Baker Hughes Incorporated
OR I G1NAL
·
e
~llips ConocoPhillips Alaska, Inc.,Slot #168
Pad 1 E,
Kuparuk River Unit, North Slope, Alaska
PROPOSAL LISTING Page 4
Wellbore: 168L 1
Well path: 168L 1 Ver#2
Date Printed: 29-Sep-2004
...
.,..
INTEQ
WS 1 E C5 3786.67N 4637. 70E 3551.40 N70 18 36.5090 W149 33 30.1475 554502.00
B-MDPT#3
RVSD090204
WS 1 E C5 B TOE 4186.56N 4662.36E 3560.40 N70 18 40.4417 W149 33 29.4211 554524.00 5963597.00
RVSD090204
WS 1 E C5 1098.72N 4429.83E 3531 .40 N70 18 10.0746 W149 33 36.2567 554312.00 5960508.00
B-MDPT#2
RVSD090204
WS 1 E C5 596.93N 4390.49E 3557.40 N70 18 5.1396 W149 33 37.4122 554276.00 5960006.00
B-MDPT#1
RVSD090204
All data is in Feet unless otherwise stated
Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 98.4ft above mean sea level)
Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees
Bottom hole distance is 6266.17 Feet on azimuth 48.08 degrees from Wellhead
Calculation method uses Minimum Curvature method
Prepared by Baker Hughes Incorporated
ORIGINAL
'Tubing Head Assy, 11" X 4-112"
'Insulated Conductor. 20" X 30"
(2) Gas Lift Mandrels, 4-1/2" X 1" KBG-2
G illips
West Sak
1 E-168 Producer
7 -5/8" Tri-Lateral Completion
Tubing String: 4-112" 12.6#, L-80, IBTM,
Speo. Clearanoe Couplings, (4.920" 00)
10-3/4" Casing,
40.6#, L-80, BTC
set @ +/- 4460' MO,
2469' TVO, 13-112"
hole
Eleotric Submersible Pump, Centra lift 418 HP Motor,
FCSOOO WL Deployed Pump
O·sand Window
at +1- 7008' MD, 3442' TVD
'D' Sand Lateral
4-112" 12.6#, L-80, DWe, Slotted
Liner Every Joint (.12$" X 2.5",
32 spf, 5.9% open area)
&-3/4" Lateral TD @
12009' MD, 3500' TVD
B-sand Window
at +1- 732&' MD, 3514' TVD
'B' Sand ]al
/ S-3/4" Lateral TO
12015' MD,
'A' Sand
Undulating Lateral
Liner Hanger I Paoker
Assembly Top at
+1- 8250' MD
$-112" X 7-$/8" Flex Lock
Liner Hanger
4-1/2" 12.6#, L-80, Dwe, slol$ over send,
blank over shales, constrictors for isolation,
(.i2SIt X 2.S" sfotst 32s:pf, 5.9% open area)
Casing, 7-5/8" 29.7#, L-80,
STCM, Set @ +/. 840S' MD,
3702' TVD, Set @ 80 deg,
S-7/8" Hole,
Rllœ,OilTools
S-3M" Lateral TO @
13621' MD, 3171' TVO.
""
o
o
N
"
É
~
'"
ro
o
(/)
2400
.-
-
Q)
.! 2800
-
iN'ír'(i'--
ConocoPhillips Alaska, Inc.
Slot: Slot #168
Well: 168
Wellbore: 168
Location: North Slope, Alaska
Field: Kuparuk River Unit
Installation: Pad 1E
1t-"f$> <¢9
~
1600
~~ø
ConocoPhiUips
TD- 41/2" Casing PI.
4800
5600 6000
6800 7200
KRU 1 E..168L 1
B-Sand
1..011 "PrÒposed
2042010
1 0/5/2004
Slotted Liner
~
N
.
.
TRANSMIT AL LETTER CHECK LIST
CIRCLE APPROPRlA TE LETTERIP ARAGRAPHS TO
BE INCLUDED IN TRANSMITTAL LETTER
WELL NAME
k;2¿¿ I E-/fog L/
2-Dtf-zol
PTD#
/DeVe]Opment
Service
Exploration
Stratigraphic
CHECK WßA T ADD-ONS ·'CLUE "-
APPLIES (OPTIONS)
MULTI Tbe permit is for tL n~w w~boresegment of
LATERAL existing weD þ:ß I (£ -I. .g
V' Permit No,1.P«I~~API No. 5ZJ~ó~-.z..3~Þ
(If API Dumber ProductioD. sbould continue to be reported as
last two. (2) digits a function - of tbe original API number. stated
are between 60-69) above.
PILOT HOLE In accordance witb 20 AAC 25.005(f), aU
(PH) records, data and Jogs acquired .for tbe pilot
bole must be dearly differentiated ID botb
name (name on permit plus PH)
.' and API Dumber (SO -
70/80) from records, data and logs acquired
for we)) (name on permit).
SPACING The permit is approved subject ·to fun
EX CEPTJ ON .' compliance with 20 AAC 25..0SS~ Approval to
perforate and produce is contingent upon
issuance of S'! conservation order approving a
spacing e:J ception.
(Company Name) assumes tbe liability of any
prot est to the spacing .e:Jception tbat may
occur.
DRY DITCH AU dry ditch sample sets submitted to tbe
SAMPLE Commission must be ip no greater -tban 30'
sample intervals from below tbe permafrost
or from where samples are first caugbt and
] 0' sample hiter:vaJs througb target ZODes.
.'
5D--á)
Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1 E-168L 1 Program DEV Well bore seg ~
COPHILLlPS ALASKA INC Initial Classrrype DEV 1 PEND GeoArea 890 Unit 11160 - On/Off Shore On ~r Disposal D
Administration Permit. fee attache,Ø. . - - - - ..NA · Mu/tiI<lterat wellsegme.nt; fe.ewaived per.20 MC .25.0Q5(e) - - - -
2 .leas.e .numberappropriat.e .. Yes · 40UorrnCJ)rrected; .eotire wellloc.atedjn.AOLQ25651 . .
3 .U.nlque weltn.arne.aod ol!.mb.er . . . . . . . . . . . . . . . . . . . . . . . .. . . . . .. .Yes - - - - - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - -
4 Well .located ina. d.efine,Ø pool. . Yes · KRU West 5akOj/ Pool, goyeroed. by.GonseNation. Order.No. 4Q6A.
5 Well .located prpperdistance from driJling unitb.ound.ary. . . Yes - - -- - - - - - -
6 WeJlJoC<lted prpper .distance. from otber welJs. . . Yes · . . Nomioal spacing within the pool is 10 .acres; w.eU is.665' fromKRU.1E-1.23..
7 S.utficient acreage.ayailab1e indriUiog unjt Yes
S .If. devi<lted, js weJ/bo.re pl<lUncJu,Øed . .Yes - - - - -
9 Operator only affected party. . .Yes - - - -
10 .Operator has.apprppr[ate.bond [nJorce . . . . . . . . . . . . . . . . . . ........ .Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- . ..
11 Permit. c.an be tssued witbout co.nservation order. Yes - - - -
Appr Date 12 Permit. c.an be issu.ed witbout <ld.ministrative.apprpvaJ . . . · Yes - - - -- - - - - . ..
SFD 10/5/2004 13 Can permit be approved before 15-day wait Yes
14 Well .located within area <ll1d.strata .authortzed by.lojection Ord.er # (Put 10# in. cprnrnents). (For. NA - - - - - - - - -- .
15 All wel!s.withtnJl4.mite.area.of reyieW identified (Fpr servjce.weU only). . . . . . . . . . . . . . . .NA - - - - - - - - - - - - - - - - - - - - - - - . - - - - - - - - - - -. - - - - - - - - - - - - - - - - - - - -- - - --
16 Pre-produ.ced injector; ,Øurat.ionof pre-pro,ØuGtion less th<ln. 3 montbs (For.servtce well Qn!y) . . NA - - -- - - - -
17 ACMP. finding .of Con.si.stency h.as been .issued. for. this project NA · Multil<lterat weJl.bore. . .
-
Engineering 1S .C.ondu.ctor stril1gpJQv[ded . . . - - - - - - NA · ConductQrjn.sta!/edin :lE-:l68 . . - - - -
19 .S.ud'acec<lsing.p.rQtects alLknown USOWs . . - - - -- NA · All aq.uifers exempt.ed,40 .CFR1~7.1Q2(b)(3).. .
20 CMT. v.ot adequate. to circulate. oncond.uctor. & su.rf. c.sg . . . · .NA · Surface casing im>talJedin 1E-168. . - - - - - - -
21 .CMT. v.ot adequ.ate. to tie-inJQng .string to.sud' csg. .. .NA · Intermedjate. casing installed jn. 1£.-16.S. .
22 .CMT. will coyer all I<no,Wn .pro.ductiye hQri~Qn.s. . - - - - N.o. · . . SlottedJioer.comp/etion planne,Ø.. Intermed.iate ca.sing cement pl<lnned aboye any/aU.hydroc.arbpo.. . . .
23 C.asiog designs adet1ua!e fpr C,T, B&.permafr.ost. · . .Yes - - - - --
24 Adequale.tank<lge.oJ re.serye pit Yes · . . Rig js.equippe.d.witl1.steel.pits.. No reserve.pjtplanoed. All w<lste to.approve.d.annuJu.s.or disposal welJs,
25 Jf.a.re-drilt has.a. 10-4.03 for abandonment beeo apPJQved . . . · . .NA. - - - - - - -
26 A,Øequate.wellboreseparation.Pfoposed. . . . . . . . . . . . . . . . . . . . . .. . .Y~s . . . . . !?r.o~imity an~/ysis performe.d. Neªrest welJb.ore.is A .s<ln.d./ateraL -.150' tvd .deep.er.
27 Jfdiverter Jequired, does it meet. reguJa.tions. . .NA · BO!? stack will alreadyb.ein plªce. . . - - --
Appr Date 28 DJilIing f!uid. program sc.hematic.& equip Jistadequate. . . · .Yes · BtlP expected. betwe.en 8.5-ScS.EMW.. !?/anned mud weigbt.9, 1. ppg.. .
TEM 1017/2004 29 BOPEs,.d.o .they meet. reguJation . . - - - - -- - - - - Yes - - - - -
~"4~ 30 .BOPE.press ra.tiog appropriate; .test to (put psig in.comments) . .Yes · MAS!? calc;u!ated.at 114.1 psi. 35QO.psLBQf'testplanoed. . .
31 .C.hokemanifold compJies w/APIRf'-53 (May 84) · . .Yes - - - - - - - - - - - - - - -
32 Work will occur withoutoperationshutdown. . · Yes
33 .Is presence. of H2S gas. prob.ab/e. . . - - - - - - - - - N.o. · 1:125 is nQtpresent in. offset wells.. Rig is equipped wtth sensors and.aJarms.. . .
34 Mecbanlcal.condjtion .of wells within AOR yerified (For. s.ervjc;e welJ on./yj NA - - - --
Geology 35 Permit c.ao be issued wlo. hYdrogen. s.utfide meaS.ures . Yes
36 .D.ata.PJesented on. pote.ntial ove.rpressure .zones. .Yes · Expected reservoir pre.ssu.re i.sS.5 - .8.S. ppg EMW; wiUbe .drilled witb 9.'1 ppg mud.
Appr Date 37 .Sei.srnican<llysjs Qf sbaJlow gasz.ooes. . . . . . . NA
SFD 10/5/2004 38 .Se<lbedconditioo survey (if off-shore) . . .NA.
- - - -
39 . CQntact nam.elphone.for.weekly progress reports [explor<ltoryon/y] NA
-
Geologic Date: Engineering Date Date West Sak Pool "B" sand horizontal multilateral well segment.
Commissioner Commissioner
DTS 16 ( /) 14- r~;Z
.
.
Well History File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process
but is part of the history file.
To improve the readability of the Well History file and to
simplify finding information, information of this
)ature is accumulated at the end of the file under APPENDIX.
No special effort has been made to chronologically
organize this category of information.
**** REEL HEADER ****
LDWG
05/06/09
AWS
01
**** TAPE HEADER ****
LDWG
05/06/09
01
*** LIS COMMENT RECORD ***
.
.
~¥-¿ol
-# IJ
J)?
!!!!!!!!!!!!!!!!!!! LDWG File Version 1.000
!!!!!!!! !!!!!!!!!!! Extract File: LISTAPE.HED
TAPE HEADER
KUPARUK RIVER UNIT
MWD/MAD LOGS
#
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
#
JOB DATA
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
MWD RUN 4
4
G. SUTING
D. GLADDEN
#
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION(FT FROM MSL 0)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
#
WELL CASING RECORD
1ST STRING
2ND STRING
3RD STRING
PRODUCTION STRING
#
REMARKS:
OPEN HOLE
BIT SIZE (IN)
42.000
13.500
9.875
6.750
1E-168L1
500292323060
ConocoPhillips Alaska, Inc.
BAKER HUGHES INTEQ
09-Jun-05
MWD RUN 7
7
C. WONG
D. GLADDEN
21
UN
10E
98.40
70.40
CASING
SIZE (IN)
20.000
10.750
7.625
MWD RUN
DRILLERS
DEPTH (FT)
148.0
4414.0
7367.0
11969.0
PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE
GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE
FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN
APPLIED.
INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR
.
.
TO DELIVERY FROM THE WELL SITE.
SURFACE LOCATION:
LAT: N 70 DEG 17' 59.2815"
LONG: W149 DEG 35' 45.4169"
LOG MEASURED FROM D.F. AT 98.4 FT. ABOVE PERM. DATUM
(M.S.L.) .
COMMENTS:
1) Baker Hughes INTEQ runs 1 & 2 utilized an 8"
directional only tool to drill from 148 to 4425 feet MD
(148 to 2481 feet TVD).
2) Baker Hughes INTEQ run 3 utilized a 6.75" ATK 2.5 to
drill from 4425 to 6941 feet MD (2481 to 3445 feet TVD).
The FE (Formation Evaluation) section of the tool failed
due to extremely high torque values while drilling out
the 10 3/4" casing shoe. No MWD data was acquired on
this run.
3) Baker Hughes INTEQ run 4 utilized a 6.75" directional
tool with a Multiple Propagation Resistivity (MPR), Gamma
Ray, along with Annular Pressure, to drill from 6941 to
8158 feet MD (3445 to 3714 feet TVD) .
4) Baker Hughes INTEQ run 6 utilized a milling assembly to
mill a window in the 7 5/8" casing and to drill from
7355 to 7386 feet MD (3536 to 3542 feet TVD) .
5) Baker Hughes INTEQ run 7 utilized a 4.75" directional
tool with a Multiple Propagation Resistivity (MPR), Gamma
Ray, along with Annular Pressure, to drill from 7386 to
11969 feet MD (3542 to 3583 feet TVD).
REMARKS :
1) Data from 6220 to 6842 feet MD (3228 to 3424 feet TVD)
was acquired with a MAD pass.
2) This lateral wellbore, lE-168Ll, was kicked off from
the parent wellbore, lE-168, through a window in the
7 5/8" casing.
Depth of 7 5/8" Casing Window - Top: 7355 feet MD
(3536 feet TVD).
Depth of 7 5/8" Casing Window - Bottom: 7367 feet MD
(3538 feet TVD).
3) The interval from 11938 to 11969 feet (3583 to 3583
feet TVD) was not logged due to sensor offsets at TD.
$
Tape Subfile: 1
86 records...
Minimum record length:
Maximum record length:
8 bytes
132 bytes
**** FILE HEADER ****
LDWG .001
1024
*** LIS COMMENT RECORD
***
!!!!!!!!!!!!!!!!!! !
!!!!!!!!!!!!!!!!!! !
FILE HEADER
FILE NUMBER:
EDITED MERGED MWD
Depth shifted
DEPTH INCREMENT:
#
FILE SUMMARY
PBU TOOL CODE
MWD
$
LDWG File Version 1.000
Extract File: FILE001.HED
1
and clipped curves; all bit runs merged.
.5000
START DEPTH
6200.0
STOP DEPTH
11969.0
· .
#
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
--------- EQUIVALENT UNSHIFTED DEPTH ---------
BASELINE DEPTH
$
#
MERGED DATA SOURCE
PBU TOOL CODE
MAD
MWD
MWD
$
BIT RUN NO
4
4
7
MERGE TOP
6200.0
6842.0
7367.0
MERGE BASE
6842.0
7367.0
11969.0
#
REMARKS:
MERGED PASS.
NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH
REFERENCE FOR THIS WELL.
$
#
*** INFORMATION TABLE: CONS
MNEM VALU
------------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
le-168Ll 5.xtf
150
ConocoPhillips Alaska, Inc.
lE-168Ll
Kuparuk River
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GR GR GRAM 0.0
RPD RPD RPD 0.0
RPM RPM RPM 0.0
RPS RPS RPS 0.0
RPX RPX RPX 0.0
ROP ROP ROP 0.0
FET FET RPTH 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 32 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
Frame spacing: 0.500000
Frame spacing units: [F ]
Number of frames per record is: 31
One depth per frame (value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE = 0.500 * F
ONE DEPTH PER FRAME
Tape depth ID: F
7 Curves:
Name Tool Code Samples Units Size Length
1 GR MWD 68 1 GAP I 4 4
2 RPD MWD 68 1 OHMM 4 4
3 RPM MWD 68 1 OHMM 4 4
.
4 RPS MWD 68 1 OHMM 4 4
5 RPX MWD 68 1 OHMM 4 4
6 ROP MWD 68 1 FPHR 4 4
7 FET MWD 68 1 HR 4 4
-------
28
Total Data Records: 373
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing
Tape File Depth Units
6200.000000
11969.000000
0.500000
feet
**** FILE TRAILER ****
Tape Subfile: 2 416 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG .002
1024
*** LIS COMMENT RECORD
***
!!!!!!!!!!!!!!!!!! !
!!!!!!!!!!!!!!!!!! !
LDWG File Version 1.000
Extract File: FILE011.HED
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
2
.
log header data for each bit run in separate files.
4
.2500
START DEPTH
6200.0
STOP DEPTH
7367.0
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG)
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DIR
PRES
MPR
GRAM
$
BOTTOM)
TOOL TYPE
DIRECTIONAL
PRESSURE
MULT. PROP. RES.
GAMMA RAY
#
04-NOV-04
MSB 18704
6.75 MPR
MEMORY
8158.0
6200.0
7367.0
o
74.5
85.8
TOOL NUMBER
90424
100009727
97378
5309
.
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TEMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
.
9.875
.4414.0
F.W. Spud
9.10
.0
.0
200
.0
.000
.000
.000
.000
96.0
.0
.0
.0
.00
.000
.0
o
BIT RUN 4 (MWD Run 4).
MPR/GR.
The Gamma Ray and Resistivity data from 6220 - 6842 feet
was recorded as a MAD pass at the beginning of this run.
Data from 6842 - 7367 (lE-168L1 kop) is MWD data from this
bit run.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
ROPA - RATE OF PENETRATION (FPHR)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPSL - MEDIUM PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM)
RPTH - FORMATION EXPOSURE TIME (MIN)
$
REMARKS:
#
*** INFORMATION TABLE: CONS
MNEM VALU
--------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
1e-168L1.xtf
150
ConocoPhillips Alaska, I
1E-168L1
Kuparuk River
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAM GRAM GRAM 0.0
RPCL RPCL RPD 0.0
RPSL RPSL RPM 0.0
RPCH RPCH RPS 0.0
RPSH RPSH RPX 0.0
ROPA ROPA ROP 0.0
RPTH RPTH RPTHM 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
.
.
Datum Frame Size is: 32 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
Frame spacing: 0.250000
Frame spacing units: [F ]
Number of frames per record is: 31
One depth per frame (value= 0)
Datum Specification Block Sub-type is:
1
FRAME SPACE =
0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
7 Curves:
Name Tool Code Samples Units Size Length
1 GRAM MWD 68 1 GAP I 4 4
2 RPCL MWD 68 1 OHMM 4 4
3 RPSL MWD 68 1 OHMM 4 4
4 RPCH MWD 68 1 OHMM 4 4
5 RPSH MWD 68 1 OHMM 4 4
6 ROPA MWD 68 1 FPHR 4 4
7 RPTH MWD 68 1 MINS 4 4
-------
28
Total Data Records: 151
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing
Tape File Depth Units
6200.000000
7367.000000
0.250000
feet
**** FILE TRAILER ****
Tape Subfile: 3 240 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG .003
1024
*** LIS COMMENT RECORD
***
!!!!!!!!!!!!!!!!!! !
!!!!!!!!!!!!!!!!!! !
LDWG File Version 1.000
Extract File: FILE012.HED
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
3
log header data for each bit run in separate files.
7
.2500
START DEPTH
7367.0
STOP DEPTH
11969.0
#
~
.
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME) :
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG)
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DIR
PRES
MPR
GRAM
$
BOTTOM)
TOOL TYPE
DIRECTIONAL
PRESSURE
MULT. PROP.
GAMMA RAY
RES.
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TEMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
.
15-NOV-04
MSB 18704
4.75 MPR
MEMORY
11969.0
7367.0
11969.0
o
74.5
85.8
TOOL NUMBER
90424
100009727
97378
5309
6.750
7367.0
OBM
9.05
.0
.0
5000
.0
.000
.000
.000
.000
105.0
.0
.0
.0
.00
.000
.0
o
BIT RUN 7 (MWD Run 7) .
MPR/GR.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
ROPA - RATE OF PENETRATION (FPHR)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPSL - MEDIUM PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM)
RPTH - FORMATION EXPOSURE TIME (MIN)
$
REMARKS:
#
*** INFORMATION TABLE: CONS
MNEM VALU
--------------------------------
WDFN
LCC
CN
WN
FN
COUN
le-168Ll.xtf
150
ConocoPhillips Alaska, I
lE-168Ll
Kuparuk River
North Slope
.
.
.
STAT Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAM GRAM GRAM 0.0
RPCL RPCL RPD 0.0
RPSL RPSL RPM 0.0
RPCH RPCH RPS 0.0
RPSH RPSH RPX 0.0
ROPA ROPA ROP 0.0
RPTH RPTH RPTHM 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 32 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
Frame spacing: 0.250000
Frame spacing units: [F ]
Number of frames per record is: 31
One depth per frame (value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE =
0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
7 Curves:
Name Tool Code Samples Units Size Length
1 GRAM MWD 68 1 GAP I 4 4
2 RPCL MWD 68 1 OHMM: 4 4
3 RPSL MWD 68 1 OHMM: 4 4
4 RPCH MWD 68 1 OHMM: 4 4
5 RPSH MWD 68 1 OHMM: 4 4
6 ROPA MWD 68 1 FPHR 4 4
7 RPTH MWD 68 1 MINS 4 4
-------
28
Total Data Records: 594
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing
Tape File Depth Units
7367.000000
11969.000000
0.250000
feet
**** FILE TRAILER ****
Tape Subfile: 4 679 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** TAPE TRAILER ****
LDWG
05/06/09
01
It· ( ".
**** REEL TRAILER ****
LDWG
05/06/09
AWS
01
Tape Subfile: 5
Minimum record length:
Maximum record length:
.
.
2 records...
132 bytes
132 bytes
