Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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MECHANICAL INTEGRITY RE?ORT
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:-SC?.ANIC;'~ INTEGRITY - ? ART ¡ 1
-;/;)~- 'ðCJ::::i:::.. Annulus Press Test:
Cø 1\ - J.w.) \\,,)\:>\NS'l- <.. '::.S ~Q..\c~ ~~\
COW!:!lent.s:
:1' ~ '-'dÙ i IS min?, S 'lS
SSOO '6l-\~D
30 min ~~S~.
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r
:ŒCHÞ_¡qICÞ--I,. INTEGRITY - PART /2
Cement Volumes:' Þ-.mt. :'i.ner
Csg
DV
Cwt 701 to cover ùer=s
~b.eoretical TOe
~ "i/ù\-dOca
Cement: Bond Log ~ or No) In AOGCC File . " S/~""-dcoa
CEL :::valuati.on, ::.one above perfs 1..»\\ o.ç. '\Irl\-~ "''Dr>~
\J..:)(¡'\\UL.\N\..<L."'-\-& s.Ct.<:...-\-\c~ .ç~c~ ~ \(),-\.s;c' Tc\\). S't--.~\'O~Cê..c:.\- ~{"O~Si
·''Ch.\Ç£L~\O~ 'Z..C~<L. \<'-,. ~ \O<6~ol_
Proåuc.tion Log: Type
Eva.lua.tion
CONCLUSiONS·" . ~ ~9YVJ~1 -QO
- ,I"¿. '\ ~\ <:.0.. ~cJ ~ö, \-\r-..«. û~'<"\~\~~ ú.~a\j<è ~ ~~\>t..'~~ \". . ( ~
? art : 1: M 1: ~~ \~<A~' çc'.-\-~ \0\6\~? <..C>.S\"'~ b«.\e:.....::, .1,4 ~ÓI2.., /B..'TY?~fs-oo
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SCA.NNED Ut~t; 1 ~~ ~002
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5-dJ-o I
199-023-0
CDI-19
50- 103-20294-00 PHILLIPS ALASKA INC
COLVILLE RIV UNIT
Roll #1: Start: Stop Roll #2:
MD lO~4ªL---TVD Q§JE9_~mpletion Date:
Start _ Stop
~ Completed Status: I-OIL
T/CfD
T Name Interval Sent Received
C 9152V' SCHLUM CDR/ADN/PDC OH 5/1 2/99 5/1 9/99
C 9386 ~ 2 SCHLUM CDR/ADN-PDC REV 2 OH I 1116/99 I 1123/99
L ADN-MD ~,. FINAL 9646-10456 OH 5/1 2/99 5/1 9/99
L ADN-MD ~ FINAL 9646- I 0456 R¥-.. ø l c'(( ~ l.. OH 2/5 11116/99 I 1/23/99
L ADN- TVD V-- FINAL 6500-6875 OH 5/12/99 5/1 9/99
L ADN- TVD L..----~ FINAL 6500-6865 f 1- fI' Ù I~ \.....{ r t.. l..- OH 2/5 I 1/1 6/99 11/23/99
L CDR-MD V" FINAL 2826-10511 OH 5/1 2/99 5/1 9/99
L CDR-TVD /' FINAL 2400-6875 OH 5/12/99 5/19/99
/
R SRVYCAL~ BHI 0-10548.13 OH 7/22/99 7/26/99
R SRVYRPT /""" SCHLUM 115-10548 OH 4/21/99 4/27/99
~
__..._..,.____.___ __.._.___ ,,_._ ..__.._,,_,__'''_,_''__"~_,____.._. .___ n___.. _,_
Current: P&A
C
C
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---"-"--"--" "'--_..._-,'--._---------~---,---_..,-,.._.,--".~.._..,.......-.,..,----------..--.--.----
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Page 1 of 1
Wednesday, March 28, 2001
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RECEIVED
JUL. 2 1 20CO
Alaska Oil & Gas Coos. Commission
Äm:.:horage
Phillips Alaska Drilling
Daily Drilling Report
AFC Nco. ID(\t~ Rpt No [:I!J Accept - hrs D;:¡y~ Sinç", Acc~ptfE~t: 3.25 1 0..5 Rig Relsge . hr5:
998C:!~ 04104/'000 4 O..f/OH200a 06:00:00
PM
W<:1I1: CD'-1Q,A D~Plh (MDITVD) 2625/2393 prç;¡v DI?P'" MO: 2825 ProQre3~: 0
Contractor: DOYON Daily CoSI ~ 136701 C\.Im Co:>! $ 327146 Esj Cost 1"0 Dale $ 100000
Ria Nl1m9: Doyon 19 last CSQ: 9 5.18" @ 2825' N8X1 Cso: 12086 StJOe T~st:
Or,P.1sti.,,, AI ~OO: Picking Up G"
Up!::Qm ¡nil OpE>ratlon$: TtIIg And dr"9 cement plug, prcl.!"!;Ur6 tE'r:lt egg to 2500 p~j.
MUD DATA DRILliNG DATA err DATA EH&S DRillS/BOP DATA
MUD TYPE DEPTH 5ITNO. BIT NO. A(:GI()!;:NT (non.\:pllll LAST BOP/O'V!;:~T LAST eOPfDr;:¡ILl
lSND N TST 03/27/2000
04103l:!OOO
WEIGHT ROT WT SIZI; SIZ~ eMPLOYER LAST H:::S t"~llL LAST FIRE DRilL
9.eccn 03/0712000 04/04/.?O~~
VISCOSI'I'Y PUWT MAKE MAKE SPill lAST CONFI NED lAST SPILL DRILL
4!;:;c¡ç 110 N SPACI: 04104/2000
03/07/2000
PV/Yp Som TYPE TYPI; TVPI: F=UEL ¡r, W.ATE~
11 / 23 105
GELS SERIAL NO '~,,",^ :1!i1 0
A. vG DRAG SE;FlIAL NO VOl UME (Qsnofls) FUEL USED
8/9/11
API Wl MAX DAAG DEPTH OUT OEPTH OUT l.AST SAFETY MTG DRill,.. WATI;R USEO . 190
1$.0 04/0312000 BBlS
I1THP WL TRQ 8TM DEPTH IN DEPTI-jIN PQTA¡;¡U; WAT~R 97
nçml/30 min INJECTION USED· BBLS
SOliDS TRQ OFF FOOT At:; I; F00TAGI: INJEr::mON WSLI., W"'^TH~~ !It
8.0% CD1-36 PER$QNN~I. DATA
HOLE VOLUME. PUMP p~!:S I\DT/A9T AOT/,4~T SOURCI2 WELL TI£MP oj: -27
Z07bbl I I I ! I CD1-19A
MeT PUMP NO W062 WOD ;! RATE (bpm; WINÇ7 SPEEO :9
5.0 I II 0
ph LINER 5Z RFM 1 Ht"M 1 P~ESSURE (PSi) WIND DIRECTION 5f)"
10,9 , II ()
~,GS $PM 1 TF=A TFA INJECTION FLUIDS CHII.L FACTOR "f -50.70
$.1% I II
0 n.."
PIT VOL GPM2 JETS JETS PH!Ü}PS 7-
753 I I I I I II I I II I I 0 PER$ONNl;:l
0
DAll v MUD SPS 1 61T COST BIT COST CONTRACTO~ 26
$"975 I I I 0 PERSONNEL
0
TOTAL MUD Spp 1 DULL DUll TO'Y',4L VOL (bl)l) Mise PERSONNEL !;
$55479 I III II I D
COMPANY MUD WT GRADE, GRADË 'TOT ¡::OR Wi:ll (bbl} SE,RVICE 18
MI 9.61 I I II I I I r 10162 PI:ASONNEl
TOTAL .__._._.__._-~.!.
BHA DESCRI PTION I
~_..._- DRILI.PIPF.: DATA
BHA NO 01) 10 WEIGHT GRADE CONNECTION ÇLA$$ :ë I,I:NG,TH
8HA LENGTH
DATE lAST
INspeCTED:
I-tOVR$ ON JARS:
TIME I END ~OUR.s OPS CODS ] HOL~ S6CT I P~ASi: OPS I OPEMTION$ FROM 0000.0000
1 '-:00 AM 01 :00 AM 1.00 KILl. P1 Othnr Pump '-03 bbh;l9 ppg ,"ud @ 4 bpm. !3hu~ in & monitor F/1S
min. (3(; bbl gain w/circ)
1:>1 :00 AM 03:30 AM :/.SO KILL P1 DUnn 91p.IC'd 9 bbls, sh\lt in.
M:30 AM 04~00 AM O.~O KILL þ, Q~hl'~ ""on¡~òr )ro!)áu""
O.t!DD A.M 06:45 AM 2.7'!> KILL P1 Oth~r Blo\!d.
Of",,!!> l\M 0~:30 ^M 1.71; po:lll P1 O,l1l1r Moni~or pr"5ðure.
08:31> AM 09:30 AM 1.00 ,çlll P1 O,h~r B IIIRd.
M;31) AM 10:30 AM 1.00 KILL Pi Other RIH,t~g up g "879, WII'.Ih Tr2962, pfllol<ing Olf, PilI! up tQ
"8~!O.
10!3D AM 01:00 :'OM 2,!;Q F'LlJ(;eAC~ P1 O~h01tr Cire. "fit! ¢(:"Id.
1:>1 :00 PM 01:30 PM 0.110 PlUGEI,A.CI( P1 Other PJSM on CMT jobpulnJI 5 H20 t~~t line!! 15 bbl~ H20 42
CNlT ~ 1ij,2 pp~ , H20 32 m\ (1.
1:>1:30 PM 02:30 PM 1.00 PlUGElACK Pi otMr Pull II !\td!l Tf~250 - clrc 2000 ~tk~ €I! 93 ~pm ~ 570 p~1.
Ot:3D PM 03:00 PM 0.50 F'lU~ÐACK ,.1 Olll~r Squ,,~7.~ 34 btl ! CMT.
Daily Drilling Report CD1-19A 04/04/2000
Þa!Js 1
j
Phlr
AI
k D 1r
D l
D "lr
R
rt
1 IpS as a rI 1"9 a_y rI InQ epo
AFC N~. IOEl'1? ApI No I :iQ ^occpl - hr: D:!y~ SinC::& Ac::c::epVE2t: ,1,;lS/1.75 RIgR¡:!::¡:;!: -l1r:;:
; 8C2~ D4/0~12000 ~ 04J01t:l000 06:00:00
PM
We-II: CD1-19A Ol'1pth (MDlTVD) 32~5f.7.t;4T Pr!:v D~Pth MD: 2825 F'rogr\l~~: 400
Contractor: DOYON Dailv CO~I $ 126450 Cum Cost S 4!!35!!6 E8t OO$! To D911? $ 3!íOOOO
Rig Nam~: ÞQ)'on 1t L::¡:¡I Csg: 9 5/8· Q 2825' Ne:!;1 Csc: 1208 !¡ ~hoe 1 est
OPQr;;¡lion At OSOO: Drlmrlø Q 4050.
lJpcC'mln¡¡ Op",r\\(Ions: Drill tD TD
MUD DATA DRILLING DATA BIT PA.TA EH&S DRILLS/BOP DATA
MUD TYPE DEPTH 8ITNQ. BIT NO. ACOIDENT (non-~pill) L.,AST BOPIDIVEAT LAST eOP/ORI1...L
LSND 3225 , N 1'ST 03l27/200U
04/031'.000
WEIGHT ROT wr SIZ~ SIZE EMPLOYER LAST H2S DRILL LAST I=IRE DRILL
9,'tppg 13!!i 8.5 0310712\)00 04/04/2.000
VISCOSITY PUWi MAKE M^ (~ SPILL LAST CONFINED LAST SPill DRIu..
41 ~QC 1S!ii HTC: N SPACE. 04/04(2000
03l07/~ooc)
PVrYP sam TYPE: TYPE TYPE FUel" WATER
9 11g 1~O
GELS AVG DRAG SERIAL NO SI:RIAL NO VOLUME (gf!IIQI'IS) FU~L usm .t60S
~r!:l/ 11 22656
APIWl MAX DRAG DEPTH OUT DEPTH OUT lAST SAFETY MTG ORlll WAT¡;;R USED· 390
10.0 04'04I20ò<l BBLS
HTHP WL TPQ BTM DEF'THIN OEPTHIN POTABLE. WATER 95
NAmV30 min 1850 2946 INJEC110N USED - BBlS
SOLIDS IRQ OFt: ¡:OOTAGI~ FOOTAGE INJ~çTlaN WELL WEATHEA ~
7.5% 1100 27IJ CD1..Je PERSONNEL DATA
HOLE VOLUME PUMP PRE;S ADTIAST ADT/Mf SOURCE W~LL fEMP 'F -20.9
209bbl 1850 I II 6.31/4.e3 I CD1-19A
M6T PUMP NO WOB¿ woe :! RATE (bpm) WIND SPI;ED 8
&.0 1 121 I 5·10 3.5
ph LINER SZ RPM 1 nÞM 1 :'P.ESSU~E (p~l) WIND OII=lECTIQN 40"
!U 5.5 6.0 I I 50·1!ii$ 1190
LGS SPM 1 TFA TFA INJEC:TION PlUIOS CHII"L FAÒTO~ '1= -:1!U.3
4.6% 6816811 0.557
Wetl?r 6<159 Mv(j\"
495
PIT VOl., GPM2 JI:I~ JETS OIt;\!;t;\1 PHilliPS 2
.d$~ 243 I 288 I I 11111111111111 II I II 50 pË~SONNEL
111 O\her
335
OAll V MUI) SPS 1 61T vO:'JT 151^1' COST CONTRAÇTOR 2~
$6141 30 I 40 I 30 I 40 102!iiQ I) pËRSONNI;L
0
'TOT Al MUO SPP 1 DULL DULL TOTtl.L VOL (btll) MISC FER5ÓNNËL ~
$&1620 200 I 250 1 22~ I I I III BUD
300 "'
COMPANY MUDwr GRAOE GRADE TOT FOR WELL (ObI) SERVIÇ~ 11
MI !3.71 I I I III 11042 PERSONNEL
TOTAl., ~O
9HA OESCRIPTION 18.5 OS7òFNPV, Mnch1XL 1.2, 51ab NM.FAT, MWD, NS MWD, Stab NM,3 DP Camel' SRV NM, XO, ~ HWDP JAf9, 26 HWDP
DP.lllPIPE DATA
BHA NO 1 00 10 WEIGI·IT GR.AOI: CONNECTIQN CI..ASS 2 L~NG'fH
I:1HA LENGTH 1100,83 5 4,ztn 19,' C;;¡105 4-1/~ IF
DA T~ LA51
IN$ÞI;CTED:
HOURS ON J.ARS~ &.31
TIME I END HOURS QP$ CQD~ I HOLE SEOT I PHASE OPS 1 OPERA11QN3 FROM oooò· 0000 ",--
12:00 AM 02::¡!O¡.\M 2l';O OTHER P1 Sideotr~clcing UD 1b9 6Q I'~ IVD.
02:30 AM 03:00 AM 1;],50 OTHER P1 S¡detr8clcing SDt "ð~' riflg.
D3:00 AM 07;~0 AM UO OTHER P1 $¡~etr~r;:king PIU & Btønd bnck S" DP.
07:30 AM 10:00 AM HO BHA P1 51~(ltr¡u;:~ing MIU K.O. A$SY (IMtall MW1) lJovrcn RIft 1 8ta HWOP
'.!\.Irf;'Q", 'è~t MWD (01'\) P/V IIII':; &. '2 HWDP,
10:00 AM 1i~OO AM 1.00 TRIP. IN p, $id~r;'at;k,in9 RIH ...,/HWDP PIU 28 g¡ngll¡'l!I (~I1t!t.1, '::19 !:1"ln~ g '-OO!!'.
11:00 AM 11:30 AM 0,511 CLN OUT P1 Side1racklng W~~h 1(2005 V201~.
11 :30 AM 01 :00 PM 1,50 RIGS P1 Sidetrseldn9 Slip and cU1 ~O' drillin9 line, se"'¡c~ top drlvl:t,
01 :00 PM Oi!:OO PM 1.00 TESt _C$<;t P1 $id ltmt:kir\~ "~'.It 9 §fa csg 1125(1) pili mO min.
02:00 PM M :30 pM 2.50 CLN_O~,.t Pi $ir;l~lr;sekin9 Wa.<;\h em! ~tringars 1/2015 '/?G80 dtill eml fli(iU!;) 1/2S5!J.
04:3D PM Ot;:OO PM 0,50 CIRC ~1 Sidòtracl<ing ceu
05:QO PM 08:30 PM 3,SQ DRll 1'1 Si6.1'M~I< ng K.O, ij 21( !¡;5 "/min.
O~:30 PM 1 ~~OI:J A,M UO DRll P1 M,dl,ing Hol~ Orilling f/2889-3225. AFlT=1.48 AST=4,83 ADT :::6.31.
Daily Drilling Report CD1-19A 04/05/2000
Page 1
~ \
PLuGGI~~ & ~O~~TION CLE~_~~CE REPORT
State of .Alaska
,;USXA or:. œ G:L.S C:=NSERVAT::ON COMMISSION
- .
...;cca.c:.cn
:'! e~:.·:; -= ::..:: ¿...=.. .~ ~ ::. ~ =: ..:..;.: ~'T 0 .
'''¡ e 11. ~rê.!1le
Cpe:-a:==
Abnd Date!::f · If - 2000
Spud: Lf ' l-fj TD: if) 5 LfE ' Completed ~ ' 2.0 · (?11
:::a c:::¡i; Îi Llrr:'¡ Jll ,:1. Î ó;t~ 3
:'ong Czg: _ (J"SS ~8J.6' cg~f) ~t ·Æ5~í ~~ J30..s'l.
~ine::': . .. & ~
-0·-
~er= ~:~er7als - CQ~S: ____
Rev:" ew t':'e well :::'1 e ,
well head
code.
sta.t~s,
~ell head ~~t of::
Mar~e= ?cst or plats:
~Qcat~on C:earance:
conClUSiQlJS:~t1ML! ê{¿u. C!i> (-/0/ A -IT}) ;lOCJ 0'/0
(03- .:tð~q'f - neJ
Code
r¡
OV-
'iG/YVYJ . Date
¡<)Y~/ -6J .
. lð'\' .
Signed
â mtM.~
17 ð uß¡ ~aot'
- - .---..--
- ---- --- .. .
. --. . - --- -- .. - ---------..-
'I
\
PHilliPS Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
Post Office Box 100360
Anchorage, Alaska 99510-0360
D. Chester
Phone (907) 263-4792
Fax: (907) 265-6224
June 29, 2000
Mr. Robert Christenson
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
3001 Porcupine Dri ve
Anchorage, Alaska 99501
Subject: Completion Report for CDl-19 P&A(199-23/300-071)
Dear Mr. Commissioner:
Phillips Alaska, Inc. (formerly ARCO Alaska, Inc.) submits the attached Completion Report for the
P&A operations on CDl-19. This well will be sidetracked and re-named to CDl-19A.
If you have any questions regarding this matter, please contact me at 263-4792 or Brian Robertson
at 265-6034.
Sinc~¡ ely,
¡(j
D. C I ster
Alpine Drilling Team Leader
PAl Drilling
rk:;1¡J
DC/skad
RECEIVED
,JUL 07 2000
Alaska Q¡'i & Gas Cons, COmmission
Anchorage
STATE OF ALASKA it
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of well Classification of Service Well
Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 0
2. Name of Operator 7. Permit Number
Phillips Alaska, Inc. 199-23 1 300-071
3. Address 8. API Number
P. O. Sox 100360, Anchorage, AK 99510-0360 50-103-20294-00
4. Location of well at surface 9. Unit or Lease Name
351' FNL, 2447' FWL, Sec. 5, T11 N, R5E, UM (ASP: 385873, 5975778) I;¡¡ Colville River Unit
At Top Producing Interval 10. Well Number
972' FSL, 69' FEL, Sec. 29, T12N, R5E, UM (ASP: 388714, 5982339) CD1-19
At Total Depth 11. Field and Pool
1159' FSL, 113' FEL Sec. 29, T12N R5E UM (ASP: 388671 5982526) Colville River Field
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No.
RKS 36 feet ADL 25558 1 ALK 4716 Alpine Oil Pool
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore 16. No. of Completions
April 7, 1999 April 18, 1999 April 4, 2000 (P&A'd) N/A feet MSL 1
17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 21, Thickness of Permafrost
10548' MD 16879' TVD 2680' MD 1 2307' TVD YES 0 No 0 N/A feet MD 896'
22. Type Electric or Other Logs Run
GR/Res/Neut/Dens
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
16" 62.5# H-40 Surface 114' 24" 10 cu yds Portland Type 3
9.625" 36# J-55 Surface 2825' 12-1/4" 860 sx AS III LW. 230 sx Class G
cement pluq at 2680' MD
cement Dlua at 9988' MD
24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
RECEtVED 4.5" 2190' N/A
N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
JUL 0 7 2000 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
2680'-2820' squeezed 34 bbls Class G cement
Alaska Or: & Gas Cons. Commission CIf Cf if' ' - J c:¡) "-4-'&' I 1.+0 bC.ts C.(o.S'S' G c..Q.\Ao1.~.
Anchorage p """4\ t;'CI.&\qecl w~ ISK.U,J ..
..
27. PRODUCTION TEST
Date First Production Method of Operation (Flowing, gas lift, etc.)
N/A Plugged & Abandoned
Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO
N/A Test Period>
Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr)
Press. 24-Hour Rate>
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips.
N/A ORIGINAL
Form 10-407 Rev. 7-1-80
CONTINUED ON REVERSE SIDE
Submit in duplicate
29.
(
I
30.
GEOLOGIC MARKERS
FORMATION TESTS
NAME
MEAS. DEPTH
TRUE VERT. DEPTH
Include interval tested, pressure data, all fluids recovered and gravity.
GOR, and time of each phase.
Alpine D
10350'
6835'
Base Alpine
10407'
6852'
N/A
31. LIST OF ATTACHMENTS
Summary of CD1-19 Plug & Abandonment Operations.
32. I hereby certify that the following is true and correct to the best of my knowledge.
Questions? Call Brian Robertson 265-6034
Signed
Alpine Drillina Team Leader
Date
o
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 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water
supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other
spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in
item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each
additional interval to be separately produced, showing the data pertinent to such interval.
Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location
of the cementing tool.
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection,
Shut-in, Other-explain. RECE!VED
Item 28: If no cores taken, indicate "none".
JUL 0 7 2000
Form 10-407
Alaska 0\) & \,ja~ \jOlts. Commission
Anchoraqø
Date: 06/15/00
ARCO ALASKA INC.
WELL SUMMARY REPORT
Page: 1
--------------------------------------------------------------------------------
--------------------------------------------------------------------------------
WELL:CDl-19A
STATE:ALASKA
COUNTY: NORTH SLOPE WEST
FIELD: COLVILLE RIVER UNIT
SPUD:04/01/00 START COMP:05/21/00
RIG:DOYON 19
WI: 0% SECURITY: 0
API NUMBER: 50-103-20294-01
BLOCK:
FINAL:
--------------------------------------------------------------------------------
--------------------------------------------------------------------------------
04/01/00 (Dl) MW: 10.0 VISC: 54 PV/YP: 45/ 0
TD/TVD: 2825/2393 (2825) MONITOR WELL. WT UP TO 11 PPG.
SUPV:DONALD LUTRICK
APIWL: 20.5
Move rig to CDl-19A. Spot and level rig. Ice plug in tree,
thaw. Weight up mud from 9.8 to 10 ppg.
04/02/00 (D2)
TD/TVD: 2825/2393 (
SUPV:DONALD LUTRICK
MW: 10.0 VISC: 56 PV/YP: 12/31
0) TEST BOP
APIWL: 21.0
PJSM. Dowell pumped 25 bbls diesel down tubing while taking
returns out annulus to outside kill tank. Displace well to
2190' w/10 ppg mud. Had diesel returns. Bullhead 50 bbls
10.0 mud to shoe. Monitor well. weight up system to 11.0
ppg. Displace well to shoe w/11.0 mud. Used drillers method
to displace to 2190'. Bullhead 70 bbls 11.0,ppg mud.
Bullhead 235 bbls 13.7 mud down tubing and annulus.. Mix and
pump 35 bbls 15.0 ppg mud down tubing. Monitor well. No
flow out tubing. PJSM.
04/03/00 (D3) MW: 9.0 VISC: 47 PV/YP: 9/17 APIWL: 17.4
TD/TVD: 2825/2393 ( 0) BLEEDING.
SUPV:DONALD LUTRICK/PAT REILLY
N/D tree. N/U BOPE and test to 300/3500 psi. Pump mud down
tubing take returns out annulus. Pump more mud, bleed off
10 bbls mud from annulus. Approx. flow .5 gal/min. Shut
well in. Pump mud down DP. Shut well in. PJSM. Pump 10 ppg
mud through choke. 200 bbls, shut in and monitor pressure.
Bleed 50 bbls back, shut in. Monitor pressure.
04/04/00 (D4)
TD/TVD: 2825/2393
SUPV:
MW: 9.6 VISC: 45 PV/YP: 11/23
0) PICKING UP 5"
AP IWL : 16. 0
DONALD LUTRICK/PAT REILL
Pump 203 bbls 9 ppg mud, shut in and monitor. Bleed, shut
in, and monitor pressure. RIH, tag up @ 2879', wash to
2962', packing off, pull up to 2820'. Circ and condition.
PJSM. Pump cement. Pull 6 stds to 2250'. Squeeze cement.
Bleed off pressure, check flow, none, open well, break
circ. and circ out thick mud, dry job.
RECE!VED
,JUL 072000
Alaska OJ) & Gas Cons, Commission
Anchorage
¡f
~~~
~q, J;}ê
CD~
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
1. Type of request:
APPLICATION FOR SUNDRY APPROVALS
Abandon _X Suspend _
Alter casing _ Repair well _
Change approved program _
2. Name of Operator
ARCO Alaska, Inc,
3. Address
P. 0, Box 100360
Anchorage, AK 99510-0360
4. Location of well at surface
351' FNL, 2447' FWL, Sec,5, T11 N, R5E, UM
At target (7" casing point in Alpine))
972' FSL, 69' FEL, Sec,29, T12N, R5E, UM
At effective depth
At total depth
1159' FSL, 113' FEL, Sec,29, T12N, R5E, UM
12. Present well condition summary
Total depth: measured
true vertical
10548
6879
9988
6704
Effective depth:
measured
true vertical
Casing
Conductor
Length
77'
Size
16"
Surface
2788'
9.625"
Operational shutdown _
Plugging _X
Pull tubing _
5. Type of Well:
Development _X
Exploratory _
Stratigraph ic _
Service
Re-enter suspended well _
Time extension Stimulate
Variance Perforate
6. Datum elevation (DF or KB feet)
RKB 56' feet
7. Unit or Property name
Other _
Annular Injection
Colville River Unit
8. Well number
CD1-19
9. Permit number / approval number
199-23
10. API number
50-1 03-20294-00
11. Field / Pool
Colville River Field/Alpine Oil Pool
feet
feet
top of cement plug covering Alpine sand, tagged with 15,000 Ibs.
feet
feet
Cemented Measured Depth
10 cu.yds, Portland Type 3 114
True vertical Depth
114
860 sx ASL3, 230 sx Class G 2825'
2393'
CD1-19 is presently suspended after having been used for injection of associated drilling wastes. There is a cement plug set and tested over the
Alpine sand. It is proposed that CD1-19 be abandoned by setting a shallow cement plug between 3200' and 2700'. This upper plug will act as both an
abandonment plug for CD1-19 and as a kick off plug for the Cd1-19A sidetrack.lts integrity will be confirmed as part of the sidetracking process.
13. Attachments Description summary of proposal
14. Estimated date for commencing operation
April 6, 2000
16. If proposal was verbally approved
ORIGINAL
RECEIVED
MAR 2 0 2000
Detailed operations program
15. Status of well classification as:
Oil
Suspended _X-
Gas
Name of approver Date approved Service
17. I hereby certify that th foregoing is true and correct to the best of my knowledge.
FOR COMMISSION USE ONLY
Conditions of approval: tify Commission so representative may witness
Plug integrity~ BOP TestK- Location clearance _
Mechanical Integrity Test _ Subsequent form required 10-~"1-
Signed
..... Title: Drilling Team Leader
Date 3//f; íOß
7/
Approved by order of the Commission
ORIGINAL SIGNED BY
Robt:irt N. Christenson
Date
Form 10-403 Rev 06/15/88 ·
Commissioner
;1-- d;)- Óð
APproved GOPY
Ret~ro~~.~ ./ () Ö
.~~
SUBMIT IN TRIPLICATE
!( Colville River Field (
CD1-19 Temporary Suspension Scnematic
Diesel Freeze protection in annulus
and tubing to 1960' TVD,
4-1/2" injection string at +/-
2190' MD (hung off from tubing
hanger)
10.0 ppg drilling mud in hole
Updated 3/07/00
Plu tagged wi 15 Ibs
~
...-_..........-
.. .. ..... - ... I '" .......
Suspension Date: 04/20/99
Wellhead installed with tubing
hanger and BPV set and pressure
~ tested to 2000 psi
16" Conductor to 1141
9-5/8" 36 ppf J-55 BTC
Surface Casing
@ 2825' MD / 2393' TVD
cemented to surface
RECEIVED
MAR 2 0 2000
Alaska 011 ~ Gas Cons. Commission
Anchorage
Top of cement plug at 99881 MD
/6704' TVD (+/- 67 deg inc,)
Top Alpine Reservoir at 103931
MD / 6849' TVD (+/- 70 deg inc.)
Well TD at 10548' MD / 6879'
TVD (+/- 75 deg inc,)
1\. Co I v i II e R i ve r Fie I d ~
CD1-19 Proposed Abandonment Scnematic
Last Updated 3-16-00
16" Conductor to 114'
9-5/811 36 ppf J·55 BTC
Surface Casing Shallow cement plug
@ 2825' MD / 2393' TVD from 3200' to 2700'
cemented to surface
.. '"1.1,, ...... .................
Planned KOP for well
CD1-19 A : 2946' MD.
10.0 ppg drilling mud in hole
PI g tagged wi 15 K bs
:--- ...1__-·1
Top of cement plug at 99881 MD
;' 6704' TVD (+1- 67 deg inc.)
Top Alpine Reservoir at 10393'
MD 1 6849' TVD (+1- 70 deg inc,)
-!..
j ..
.",,,,,, ...... ...,......
Well TD at 10548' MD 1 6879'
TVD (+1- 75 deg inc,)
RECE\VED
MAR 2 0 2000
Alaska Oil & Gas Cons. Commission
Anchorage
ARca Alaska, Inc. ,(;
Post Office sJ^ , J0360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
March 16, 1999
~~
~~
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Re: Application for Sundry Approval to Abandon well: CD1-19
Dear Sirs:
ARCO Alaska, Inc. hereby requests approval to plug well CD1-19 back to the surface casing
shoe. The Alpine reservoir interval has previously been plugged and this operation will effectively
abandon the original CD1-19 wellbore. After concluding this operation, the well down to the
surface casing shoe, will be re-used as part of well CD1-19A; a Class 2 disposal well that is
presently being reviewed by yourselves.
The proposed operations are as follows:
1. Move on Doyon 19.
2. Circulate the well (at the kill string depth of 2190') to 9.6 ppg LSND mud. Remove tubing head
adapter assembly.
3. Install BOPE. Remove BPV. Install 2-way check and test BOPE to 3500 psi. Recover the 2-way
check.
4, Unlock the tubing hanger and pull back to the rig floor. Remove the tubing hanger.
5, M/U a crossover to 5" drill pipe. Run in hole to 3200'. Circulate and condition mud. Spot a 500', 15.8
ppg Class G cement plug from 3200' to 2700'. Pick up and circulate clean. Pull out of hole and lay
down the tubing kill string.
6. M/U the 8-1/2" drilling assembly. RIH and tag the top of the cement plug. Pressure test the 9-5/8"
casing to 2500 psi. Continue with CD1-19A operations.
Please find attached form 10-403 and other pertinent information as follows:
1. Form 10-403
2. CD1-19 Current Well Status 1 Well Suspension Diagram,
3. CD1-19 Proposed Well Abandonment Diagram.
If you have any questions or require further information, please contact Brian Robertson at 265-
6034,
Sincerely,
o .y)."""", /
.,~t' /
Brian Robertson
Senior Drilling Engineer
cc.
RECEIVED
CD1-19 Well File
Sharon Allsup-Drake
Doug Chester
ATO-1054
ANO-382
MAR 2 0 2000
Alaska OU & GWd Cons, Q.unmlssion
Anchorage
ARCO Alm;kil. Inc:. il Suh,;"jiiHY 01 AII'H1ticRicllr¡"I(!Compiiny
..' Rc: Alpine Class 2 Injection
(
99 -0'23
Subject: Re: Alpine Class 2 Injection
Date: Tue, 14 Mar 2000 08: 11 : 51 -0900
From: Blair Wondzell <blair_wondzell@admin.state.ak.us>
Organization: State of Alaska, Dept of Admin, Oil & Gas
To: Michael DElWin <MERWIN@mai1.aai.arco.com>,
Tom Maunder <tom _ maunder@admin.state.ak.us>
Mike,
We don't require SSSVs in disposal wells, tho a surrface safety valve (SSV) is
required. However, I suggest you run a a nipple at a suitable depth that could
accept such a valve in the event the formation pressures up or some other
un-for-seen event occurs. If the requirement for a SSSV comes out in some
Commission order, please give me a call.
Regards, Blair Wondzell 3/14/00.
Michael D Erwin wrote:
> Folks,
> As we are developing our completion design for the proposed Class 2 injection
> well (CDl-19) we hit a dilema. Is a SSSV required? In reviewing our disposal
> order I see that we did not specify one in our request and it was not specified
> in the order. But in our pending request for the Area Injection Order amendment
> I inadvertently injected a statement which states Arco would be installing a
> SSSV in disposal wells (Well Construction section). Do you see this as
> necessary or prudent? If you do not, then then I'm sure your order will simply
> not speak to the issue. However, if that is not the case, then this
> inconsistency may need to be addressed and/or corrected.
>
> We are installing SSSVs or downhole check valves in all waterflood and producing
> wells at this time. However, there has been considerable discussion in our shop
> over the need in disposal wells. I am aware you see Alpine in a similar light to
> Northstar and Badami, and I'm not sure what your policy there has been and I
> know you will want to be consistent.
>
> I appreciate your timely consideration in this matter.
>
> mike
1 ofl
3/14/008:12 AM
A!pine Class 2 Injection
'I
9'7 ... ()2,3
Subject: Alpine Class 2 Injection
Date: Fri, 3 Mar 2000 10:29:02 -1000
From: "Michael DErwin" <MERWIN@mail.aai.arco.com>
To: Wendy _ Mahan@admin.state.ak.us, blair_ wondzell@admin.state.ak.us,
tom _ maunder@admin.state.ak.us
--
Folks,
As we are developing our completion design for the proposed Class 2 injection
well (CDl-19) we hit a dilema. Is a SSSV required? In reviewing our disposal
order I see that we did not specify one in our request and it was not specified
in the order. But in our pending request for the Area Injection Order amendment
I inadvertently injected a statement which states Arco would be installing a
SSSV in disposal wells (Well Construction section). Do you see this as
necessary or prudent? If you do not, then then I'm sure your order will simply
not speak to the issue. However, if that is not the case, then this
inconsistency may need to be addressed and/or corrected.
We are installing SSSVs or downhole check valves in all waterflood and producing
wells at this time. However, there has been considerable discussion in our shop
over the need in disposal wells. I am aware you see Alpine in a similar light to
Northstar and Badami, and I'm not sure what your policy there has been and I
know you will want to be consistent.
I appreciate your timely consideration in this matter.
mike
&DH:..oë'T" Z.. 0 2-{ f IB 'ßb -Ð 6 '3
SS~'V ~ J 5"'74
A'~ , -. S~v'12.t&'T~ NOï Ab~ EJ:J
þADAM. \ - f>' - t) I \"I":l-\ ~
HÐ\ÞGe ,v)){L LlM~ V'AuIG IN 'A "")f>ÞL.ÍJ ,dfJ 2.:2..11'
Dl 0 $1 z..... S~v J2¿G'TS N07 AÙb~é...D
lof!
3/3/00 1:37PM
II
(
(
Authority -
AS 31.05.030
20 AAC 25.265
AUTOMATIC SHUT-IN EQUIPMENT.
(a) A completed well with an offshore surface location and that is capable of
unassisted flow of hydrocarbons to the surface, must be equipped with a commission-
approved
(1) fail-safe automatic surface safety valve (SSV) system capable of preventing an
uncontrolled flow; and
(2) fail-safe automatic surface-controlled subsurface safety valve (SSSV) system
capable of preventing an uncontrolled flow, unless another type of subsurface valve with
that capability is approved by the commission; this valve must be in the tubing string and
located below the mudline datum or, if permafrost is present, below the permafrost.
(b) An operator may demonstrate by a no- flow test that a well is incapable of
unassisted flow of hydrocarbons to the surface. At least 24 hours notice must be given so
that a representative of the commission can witness the test.
(c) The commission will, in its discretion, require an SSV system, an SSSV
system, or both on a well with an onshore surface location, after notice and an
opportunity for hearing in accordance with 20 AAC 25.540.
(d) A representative of the commission shall witness operation and performance
tests at intervals and times as prescribed by the commission to confirm that the SSV
system, SSSV system, and associated equipment are in proper working condition. If an
SSV system, SSSV system, or associated equipment fails the performance test, the
system or associated equipment must be repaired within the time frame specified by the
commission or the well must be shut in.
History -
Eff. 4/13/80, Register 74; am 4/2/86, Register 97; am 11/7/99, Register 152
Authority -
AS 31.05.030
AS 31.05.095
20 AAC 25.270
INITIAL RESERVOIR PROPERTIES.
(a) The operator shall determine the initial reservoir pressure in each new pool
before regular production. The results must be reported to the commission on a Reservoir
Pressure Report (Form 10-412).
(b) The operator shall obtain fluid samples from each new pool at the time of
discovery or before regular production and determine
(1) the crude oil composition assay;
6/99
1
Sc~luII~ePleP
Alaska Oil & Gas Cons Comm
AUn: Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
12935
Company:
NO.
Schlumberger Technology Corporation, by and through is Geoquest Division
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Sherrie
--
Alpine
Color
Prints
Field:
_~o,
CD
1
1
~O.~'-'"~'f!'"
- ....
.., . /' ¿r~;J.; . . ~r j .£."
Sepia
1
1
1
1
BL
1
1
1
1
Date
990419
990419
990419
990513
990513
990513
Log Description
'1f-"ZI~~
~ _q~~r")
PDC)
(PDC)
CDR/ADN
ADN
ADN TVD
ADN/CDR
ADN
ADN TVD
Job#
99199
99199
99199
99218
99218
99218
Wel
qq . O?-:> CD 1-19 (REPROCESSED)
.J- CD 1-19 (REPROCESSED)
CD 1-19 (REPROCESSED)
ct q - ü?>l. CD1-35 (REPROCESSED
\ CD1-35 (REPROCESSED)
...Jr CD1-35 (REPROCESSED)
5IGN(X J~
1999
Alaska Oil & Gas Cons. Commissiof
Thank you.
23
Anchorage
i
"
DATE:
Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317.
(
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
July 23, 1999
Mr. Robert Christenson
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Subject: CDl-19 (Permit No. 99-23) Well Completion Report
Dear Mr. Commissioner:
Enclosed is the well completion report for the completion on CD 1-19.
If there are any questions, please call 263-4792.
Sincerely,
1¡d$r
D. Chester
Alpine Drilling Team Leader
AAI Drilling
DC/skad
"rÊ t~: 1: t. \1 t,
:J U L (~~) 1999
, C'\'t ò G\"~S Cons cmnmlsslof:\
,AJasKa ,!¡ c.t a ' "
Anchorage
~~
~~
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
\
:(
1. Status of well
Classification of Service Well
Oil 0 Gas 0
2. Name of Operator
ARCO Alaska, Inc.
3. Address
P. O. Sox 100360, Anchorage, AK 99510-0360
4. Location of well at surface
Suspended 0
Abandoned 0
Service 0
351' FNL, 2447' FWL, Sec. 5, T11 N, R5E, UM
At Top Producing Interval
972' FSL, 69' FEL, SEC 29, T12N, R5E, UM
At Total Depth
1159' FSL, 113' FEL, SEC 29, T12N, R5E, UM
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No.
RKS 36 feet ADL 25558 / ALK 4716
12. Date Spudded 13. Date TD. Reached 14. Date Comp., Susp. Or Aband.
April 7, 1999 April 18, 1999 April 20, 1999
17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey
10548' MD / 6879' TVD 10000' MD / 6707' TVD YES 0 No 0
22. Type Electric or Other Logs Run
GR/ReslNeut/Dens
23.
rëoú p~~;~'è;¡;-1
t" 4/, jJA:t~ ,~
I~~/~;
I ~ED ~
'~""""'PI"IIr-...~""t~~/I"l
I~~
..~.~.
Cuttings Disposal Well
7. Permit Number
99-23
8. API Number
50-1 03-20294
9. Unit or Lease Name
Colville River Unit
10. Well Number
CD1-19
11. Field and Pool
Colville River Field
Alpine Oil Pool
15. Water Depth, if offshore
N/ A feet MSL
20. Depth where SSSV set
N/A feet MD
16. No. of Completions
1
21. Thickness of Permafrost
896'
16"
WT. PER FT.
62.5#
36#
GRADE
H-40
J-55
CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
TOP BOTTOM
Surface 121'
Surface 2825'
HOLE SIZE
CASING SIZE
24"
CEMENTING RECORD
9 cu yds High Early
860 sx AS III LW, 230 sx Class G
AMOUNT PULLED
9.625"
12.25"
top of cement plug @ 10000'
24. Perforations open to Production (MD + TVD of Top and Bottom and
interval, size and number)
25.
SIZE
4.5"
TUBING RECORD
DEPTH SET (MD)
2190'
PACKER SET (MD)
N/A
26.
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
N/A
DEPTH INTERVAL (MD)
N/A
AMOUNT & KIND OF MATERIAL USED
1r'%! /r" ,~''''. ~¡.- .,'~, ""~_ ,",""
.lr~~,\,f:':lIJ1.Jj M 1'1)'1~' 't.:'
" ,),,, "'-. ~_ ß v .1-:: IHi o~,'
... !1r,.'!!I 'iI¡¡ ;.,:
- - .. .- .. .. A. ,U n ?.J) JQQO\
I I U If"': 11\ 1\ I t:: ,J "·1~~.qq
V I \ · V II' n.... Alask¡¡0ll, MÆ.C,Q~~~ G,Qmm~ ~l",..,.
WATER-BBL CHOKE SIZE GAS-OIL ''lfJ''lcriOf:!gê /I,l1IJ
27.
Date First Production
Date otTest
Hours Tested
PRODUCTION TEST
Method of Operation (Flowing, gas lift, etc.)
N/A
OIL-BBL
GAS-MCF
Flow Tubing
Casing Pressure
Production for
Test Period>
Calculated
24-Hour Rate>
OIL-BBL
GAS-MCF
WATER-BBL
OIL GRAVITY - API (corr)
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips.
N/A
Form 10-407 Rev. 7-1-80
CONTINUED ON REVERSE SIDE
Submit in duplicate
29.
30.
GEOLOGIC MARKERS
FORMATION TESTS
MEAS. DEPTH
TRUE VERT. DEPTH
Include interval tested, pressure data, all fluids recovered and gravity.
GOR, and time of each phase.
NAME
Alpine D
10350'
6835'
Base Alpine
10407'
6852'
31, LIST OF ATTACHMENTS
Summary of Daily Operations, Directional Survey
32. I hereby certify that the following is true and correct to the best of my knowledge.
Signed
AI cine Drillina Team Leader
Date-zþ-~ /.?L
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 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water
supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other
spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in
item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each
additional interval to be separately produced, showing the data pertinent to such interval.
Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location
of the cementing tool.
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection,
Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none".
Form 10-407
( Colville River Field (
CD1-19 Temporary Suspension Schematic
Diesel Freeze protection in annulus
and tubing to 1000' TVD,
4-1/2" injection string at +/-
2200' MD (hung off from tubing
hanger)
Injection Zone at +/- 2450' TVD.
9.9 ppg drilling mud in hole
Updated 4/19/99
Wellhead installed with tubing
hanger and BPV set and pressure
~ tested to 2000 psi
16" Conductor to 121'
9-5/8" 36 ppf J·55 BTC
Surface Casing
@ 2825' MD / 2393' TVD
cemented to surface
Top of cement plug at 10000'
MD / 6708' TVD (+/- 67 deg inc.)
Top Alpine Reservoir at 10393'
MD / 6849' TVD (+/- 70 deg inc.)
Well TO at 10548' MD / 6879'
TVD (+/- 75 deg inc.)
ft..·.... ~' ·E····~. '~."I: M ..~~.."" ··u.
~~t¡ :,'" . '~q' ~. .. J1
L ~. . ~ \ I "~ ~)17'¿."1!0' ",.'1..
¡I" ,:') (;"92.1 q
~ ~ a ~~,., ""' ;.'t¡ ~~,1 \,~'-
~.,.. ,~.\ I'
Alaska on &. Gas Cons. Commisslür:
Anchorage
Date: 5/17/99
ARCO ALASKA INC.
WELL SUMMARY REPORT
Page: 1
--------------------------------------------------------------------------------
--------------------------------------------------------------------------------
WELL:CDl-19
WELL_ID: 998B02 TYPE:
AFC: 998B02
STATE:ALASKA
AREA/CNTY: NORTH SLOPE WEST
FIELD: COLVILLE RIVER UNIT
SPUD:04/07/99 START COMP:
RIG:DOYON 19
WI: 0% SECURITY: 0
API NUMBER: 50-103-20294-00
BLOCK:
FINAL:
--------------------------------------------------------------------------------
--------------------------------------------------------------------------------
04/06/99 (D1)
TD : 12 l' ( 12 1 )
SUPV:
MW: 8.8 VISC: 180 PV/YP: 14/23
SPUDDED 12 1/4" HOLE AT 05:45
APIWL: 12, 8
Move rig to CDl-19. Accept rig @ 0830 hrs. 4/6/99. Diverter
flange not sitting level on 1611 conductor. Check and dress
cut level. Install diverter flange - unable to test. Seals
leaking. Seals damaged. Set diverter off 16" conductor.
Bevel and smooth up cut on 16" conductor. Set landing ring
in place. NU diverter and test seals to 4000 psi. Held. NU
diverter.
UPCOMING OPERATIONS:DRILL SURFACE HOLE
04/07/99 (D2)
TD: 1535' (1414)
SUPV:MIKE WHITELEY
MW: 9.6 VISC: 210 PV/YP: 26/47
DRILLING AT 2,050'
APIWL: 10.0
Function test diverter. Pre-spud safety meeting. Drill from
121' to 1535'. Ball mill had 5 bbls mud spill. Fire @ 1300
hrs, welding in pipe shed caught insulation underneath pipe
shed floor on fire. Made short trip to 370' Hole tight -
pumped and back reamed out from 1100'-550'. Slight packing
off. Lots of sand over shakers. Washed and reamed from
585'-1535'. Raised mud weight to 9.6 ppg. Slight packing
off. Lots of Sand and gravel over shaker. UPCOMING
OPERATIONS:DRILL TO 2,850' TD - CONDITION HOLE TO RUN CSG
04/08/99 (D3)
TD: 2836' (1301) LD BHA
SUPV:MIKE WHITELEY
MW: 9.7 VISC: 170 PV/YP: 27/46
APIWL: 8,0
Wash and ream from 700'-2836'. Pump hi vis sweep around.
Circ and condition mud and hole to run 9-5/811 casing.
UPCOMING OPERATIONS:RUN SURFACE CASING
04/09/99 (D4)
TD: 2 8 3 6' ( 0 )
SUPV:MIKE WHITELEY
MW: 9.8 VISC: 78 PV/YP: 17/31 APIWL: 7.0
PROBLEM - METAL SEAL DAMAGED ON HANGER - PREPARE TO SCREW LA
PJSM. Ran 9-5/811 casing. PJSM. Cementing. Ball mill
conveyor down (electrical) Test cement line from ball mill.
Repair leak in Dowell cementing line. Pump cement down
9-5/8" casing.
UPCOMING OPERATIONS:CUT OFF CONDUCTOR, SET SLIPS ON 9 5/8"
CSG AND WELD ON BELL NIPPLE
Date: 5/17/99
{
\1,
ARCO ALASKA INC.
WELL SUMMARY REPORT
Page: 2
04/10/99 (D5) MW: 9.4 VISC: 45 PV/YP: 8/16
TD: 2836' (0) TESTING BOP'S
SUPV:MIKE WHITELEY
04/11/99 (D6)
TD: 2 8 5 6 ' ( 2 0 )
SUPV:MIKE WHITELEY
04/12/99 (D7)
TD : 4 7 8 7' (19 3 1 )
SUPV:MIKE WHITELEY
04/13/99 (D8)
TD : 6 9 7 5' (2 18 8 )
SUPV:MIKE WHITELEY
APIWL: 8,6
ND diverter. Metal seal on 9-5/8" hanger damaged by wash
out jt while flushing cement out of diverter. Weld on bell
nipple onto 9-5/8" casing.
UPCOMING OPERATIONS:PU BHA - RIH TO DRILL OUT
MW: 9.6 VISC: 42 PV/YP: 10/20
DRILLING @ 3,300' - ROP 200 FPH.
APIWL:
8.0
NU BOP's. Pulled test plug. Pressure csg to 2500 psi to
internally test well head metal to metal seal. Held. Test
BOP's to 250/3500 psi. No leaks. Kick while tripping drill
followed by stripping drill followed by well kill drill.
Wash down from 2600' to 2723'. Soft cement. Drill plugs
F.C. @ 2736'. Drill out F.S. @ 2825' and 20' new hole to
2856'. RU to perform LOT.
UPCOMING OPERATIONS:DRILL
MW: 9 . 6 VISC:
DRILLING AHEAD AT 5,500'
48 PV/YP:
9/31
APIWL:
5,0
Performed LOT EMW=14.6 ppg. Drill 8.5" hole from
2856'-4596'. Sweep hole, circ clean for wiper trip. POOH.
Slight swabbing. Drill from 4596'-4787'.
UPCOMING OPERATIONS:DRILL / SHORT TRIP
MW: 9 . 6 VI SC :
DRILLING AHEAD AT 7,340'
44 PV/YP:
7/28
APIWL:
5,5
Drill from 4787'-6500'. Pump low/high sweep around, circ
clean. POOH to 4550'. No problems. Drill from 6500'-6975'.
UPCOMING OPERATIONS:DRILL TANGENT SECTION
04/ 14 / 9 9 ( D 9 ) MW : 9 . 7 VI SC : 48 PV / YP : 9 / 3 5
TD: 8309' (1334) DRLG AT 8570'.
SUPV:DONALD LUTRICK
04/15/99 (DI0)
TD: 9737' (1428) POH
SUPV:DONALD LUTRICK
APIWL: 4,8
Drilling from 6975' to 8119'. Circ hi vis sweep. Monitor
well. Wiper trip to 6400'. No problems. Drilling from
8119'-8309' .
UPCOMING OPERATIONS:BHA CHANGE AT 9700'
MW: 9.7 VISC: 48 PV/YP: 13/26
APIWL: 5,0
Drilling from 8309' to 9737'.
UPCOMING OPERATIONS:BHA CHANGE FOR KICKOFF
Date: 5/17/99
ARCO ALASKA INC.
WELL SUMMARY REPORT
04/16/99 (D11) MW: 9.9 VISC: 50 PV/YP: 11/27
TD: 9788' (51) DRLG AT 9950'
SUPV:DONALD LUTRICK
Page: 3
APIWL: 4,0
Circ hole clean. POH. Pump slug. POH. No problems. RIH. Mad
pass from 5371' to 5704'. Precautionary ream from 9653' to
9737'. Drilling from 9737' to 9788'.
UPCOMING OPERATIONS:TD WELL
04/17/99 (D12)
TD : 103 05' ( 51 7 ) DRLG
SUPV:DONALD LUTRICK
MW: 9.9 VISC: 52 PV/YP: 13/30
Drilling from 9788' to 10305'.
UPCOMING OPERATIONS:TD WELL
04/18/99 (D13) MW: 9.9 VISC: 55 PV/YP: 12/30
TD:10305' (0) RIH W/ MULESHOE
SUPV:DONALD LUTRICK
APIWL: 4,0
APIWL: 3.9
Drilling from 10305' to 10548'. POH wet. No problems. Pump
slug. tight at 8897' and 6188'.
UPCOMING OPERATIONS:SET PLUG OVER ALPINE SAND
04/19/99 (D14) MW: 10.0 VISC: 51 PV/YP: 12/24
TD:10548' ( 243) POH W/ DP
SUPV:DONALD LUTRICK
APIWL: 5.5
PJSM. Pump cement. Circ out contaminated mud. WOC.
UPCOMING OPERATIONS:RIH W/ 4 1/2" TBG FOR KILL STRING
04/20/99 (D15) MW: 0.0 VISC:
TD:10548' (0) RIG RELEASED
SUPV:DONALD LUTRICK
o PV/YP: 0/ 0
APIWL: 0.0
Tag cement @ 9988'. PJSM. Run 4.5" tubing. ND BOP. NU Tree.
Freeze protect well. Secure well.
UPCOMING OPERATIONS:
- - - - - - - - - - - - - - -
~ SURVEY CALCULATION AND FIELD WORKSHEET JobNo f)!5!~ ~i~ hr t ,~ ..
-- ~--- ---~~..,..-.....,. ~. -----,..."..
Company ARCO ALASKA, INC. Rig Contracwr & No. Doyon DrìI1ìnI - RîI: !.!___~____~___._ FftJ i
~'!._----- -- ----~ ----------------:
Well Name & No. CD#11l9 Survey Section Name ANADRß..L M"A'D BH1 .. _ S..\!. \' ATtEJtJl,.;, JoOLCH..\X
11w. e:Q WELL DATA
-
Target TVD (FT) Target Coord. N/S Slot Coord. N/S -350.20 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD ss C
Target Description Target Coord. EIW Slot Coord. E/W 2447.89 Magn. Declination 26.390 Calculation Method MINIMUM CURVATURE
Target Direction (DO) Build\Walk\DL per: 1ooftŒ: 30m 0 10m 0 Vert. Sec. Azim. 21.78 Magn. to Map COTTo 26.390 Map North to: OTHER
SURVEY DATA
Survey Survey Incl. Hole Course Total Coordinate Build Rate Walk Rate
Date Tool Vertical Build C + ) Right C + ) Comment
Type Depth Angle Direction Length TVD Section NC+)/SC-) EC+)/WC-) DL Drop C-) Left C-)
(FT) (DO) (00) (FT) (FT) (FT) (FT) (Per 100 FT)
0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT ---
-
07-APR-99 MWD 115.00 0.00 0.00 115,00 115.00 0.00 0.00 0.00 0.00 0.00 9 1/2" MIC 1.2 DEG AKa
07-APR-99 MWD 195.29 0.37 199.10 80.29 195.29 -0.26 -0.24 -0.08 0.46 0.46
07-APR-99 MWD 287.00 0.43 267.00 91.71 287.00 -0.70 -0.54 -0.53 0.49 0.07
07-APR-99 MWD 381.05 1.85 312.60 94,05 381.03 -0.31 0.47 -2.00 1.68 1.51
07-APR-99 MWD 467.90 3.74 316.40 86.85 467.77 1.37 3.47 -4,98 2.19 2.18
07-APR-99 MWD 557.90 5.94 314.60 90.00 557.44 4.40 8.86 -10.32 2.45 2.44 -2.00
07-APR-99 MWD 647.13 7.48 321.50 89.23 646.06 9.07 16.65 -17.23 1.95 1.73 7.73
07-APR-99 MWD 736.26 8.46 326.50 89.13 734.33 15.68 26.66 -24.46 1.35 1.10 5.61
07-APR-99 MWD 827.10 9.31 336.10 90.84 824.09 24.62 38.95 -31.12 1.88 0.94 10.57
-
07-APR·99 MWD 914.62 10.72 342.50 87.52 910.27 35.87 53.19 -36.44 2.05 1.61 7.31
07-APR-99 MWD 1004.80 14.02 346.30 90.18 998.35 51.26 71.80 -41.55 3:77 3.66 4.21
07-APR-99 MWD 1094.06 18.14 347.90 89.26 1084.10 71.61 95.90 -47.02 4.64 4.62 1.79 ~.::=..
07-APR-99 MWD 1187.71 22.79 349.20 93.65 1171.81 99.01 127.99 -53.48 4.99 4.97 1.39
07-APR-99 MWD 1283.40 24.20 351. 70 95.69 1259.57 131.60 165.61 -59.79 1.80 1.47 2.61
07-APR-99 MWD 1378.97 24.52 359.60 95.57 1346.65 166.93 204.83 -62.75 3.42 0.33 8.27
07-APR-99 MWD 1474.49 26.06 11.90 95.52 1433.08 205.98 245.21 -58.56 5.72 1.61 12.88
I
08-APR-99 MWD 1570.23 29.78 13.90 95.74 1517.66 250.27 288.89 -48.51 4.01 3.89 2.09
08-APR-99 MWD 1665.29 33.92 11.80 95.06 1598,39 299.80 337.79 -37.41 4.51 4.36 -2.21
08-APR-99 MWD 1760.19 38.29 13.00 94.90 1675.05 354.96 392.38 -25.38 4.66 4.60 1.26
08-APR-99 MWD 1855.50 40.37 14.20 95.31 1748.77 414.75 451.09 -11.16 2.32 2.18 1.26
08-APR-99 MWD 1949.67 - 41.53 15,70 94.17 1819,89 476.02 510.71 4,77 1.61 1.23 1.59 I
,-
08-APR-99 MWD 2041. 62 42.50 18.10 91.95 1888.21 537.34 569.58 22.67 2.04 1.05 2.61
08-APR-99 MWD 2140.47 43.47 20.60 98.85 1960.53 604.66 633.16 45.01 1.98 0.98 2.53
6
~t·s.,
Fdd ~"'E
--~-~~
BHJ Rep. S....LVATIERRA J MILCHAK
lfJi
~
P'it~
SURVEY cALCtUnQ~ ~1ftIÖittLÏJWöRKsøEÊT k6.~
·Riì C<mmctora:No. DöroaI>rilím,- Ri8= #19
SUJVey Section Name ANADRILL~.
WELL DATA
{)4 ~ f ~.......
~----~~~
Name & No.
Depths Measured From RKB ~ M5LO 550
Calculation Method MINIMUM CURVATURE
Map North to: OTHER
0.000
26.390
26.390
Grid Correction
Declination
to Map Carr.
Magn.
Magn.
-350.20
2447.89
21.78
N/S
E/W
Azim.
Slot Coord
Slot Coord.
Vert. Sec.
N/S
EfW
Build\ Walk\DL per
Coord,
Coord.
Target
Target
(FT)
TVD
Description
Direction
Target
Target
Target
10m 0
100ft~ 30mD
(DO)
Walk Rate
Right ( + )
Left (-)
7.50
Build Rate
Build (+ )
Drop (-)
1.78
SURVEY DATA
Total Coordinate
E(+) 1 W(-)
(~
72.53
Course
Length
(~
96.02
Hole
Direction
(D~
27.80
·Incl
Angle
(DO)
45.18
Survey
Depth
--º=!L
2236.49
Survey
Tool
Type
MWD
Comment
DL
(Per 100 FT)
5.53
N(+)/S(-)
(~
694.24
Vertical
Section
TVD
(FT)
2029,26
Date
08-APR-99
~~
.60
671
3.72
2.97
4.01
106.23
753.59
739.21
2093.89
94.01
31.30
47.97
2330.50
MWD
MWD
08-APR-99
-0.94
4.24
4.30
143.98
816.82
811. 94
2155.66
2212.96
96.14
30.40
52.05
2426.64
-2.00
1.66
2.30
13
181
882.63
886.83
94.84
28.50
53.62
2521.48
0.00
-0.26
0.26
217.53
949.68
962.60
2269.42
94.91
28.50
53.37
2616.39
-2.23
0.72
1.94
252.51
1017.03
1038.12
16
2325
94.17
26.40
54.05
53.62
2710.56
-0.95
-0.68
1.03
274.91
1062.76
1088.90
2362.38
63.08
25.80
2773.64
1.2 DEG AKO
M l/XL
63/4'
0.16
-0.50
0.51
319.32
1154.22
1190.31
2438.15
126.80
26.00
52.99
2900.44
MWD
MWD
MWD
MWD
MWD
MWD
08-APR-99
08-APR-99
08-APR-99
08-APR-99
08-APR-99
12-APR-99
0.73
-0.39
0.70
353.19
1222.59
1266.37
2496.06
95.78
26.70
52.62
2996.22
12-APR-99
0.10
-0.48
0.49
387.17
1290.02
1341.59
2554.23
95.32
26.80
52.16
3091. 54
MWD
12-APR-99
-2.30
0.68
1.95
420.07
1358.39
1417.28
2612.49
95.66
24.60
52.81
3187.20
MWD
59
-1
-0.15
1.27
450.41
1427.01
1492.27
2669.57
94.28
23.10
52.67
3281.48
~~'"-
0.00
-0,36
0.36
480.14
1496.72
1568.03
2727.72
95.52
23.10
52.33
3377.00
57
1
0.99
1.60
510.96
1566.42
19
1644.
2785.56
95.68
24.60
53.28
3472.68
0.43
0.56
0.66
542.70
1635.10
1719.74
2841.45
94.06
25.00
53.81
3566.74
0.00
-0.54
0.54
575.25
1704.91
1796.65
2898.34
95.76
25.00
53.29
3662.50
-0.2
-0.31
0.36
607.36
1774.08
1872.79
2955.52
95.31
24.80
52.99
3757.81
0.00
-0.10
0.10
639.27
1843.15
1948.77
3012.98
95.35
24.80
52.89
52.50
3853.16
-0.31
-0.41
0.48
670.97
1912.22
2024.67
3070.88
95.54
24.50
3948.70
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
12-APR-99
12-APR-99
12-APR':'99
12-APR-99
12-APR-99
12-APR-99
12-APR-99
12-APR-99
13-APR-99
2.00
0,18
1.60
703,33
980.21
2099,82
3128.49
94.81
26.40
52.67
4043.51
12-APR-99
0.53
-0.42
-0.01
-0.62
0.42
737.02
2047.35
2174.67
3185.79
94.48
26.90
52.66
4137.99
MWD
MWJ)
12-APR-99
12-APR-99
.05
1
-0.
1
1.25
0.26
0.71
1.50
0.28
771.24
805.60
840.82
2115.38
2182.81
2250.60
2250.54
2325.90
2401.93
3244.52
3302.27
3359.06
96.17
95.20
95.19
26.50
27.50
27.40
52.06
53.25
53.50
4234.16
4329.36
4424,55
MWD
MWD
12-APR-99
12-APR-99
_:.-- . .....-.....- - - - _. - - - - - -'
.. .
~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-04406 Sidetrack ~(). Page 3 of 6
- --.. --
Company ARCO ALASKA. INC. Rig Contractor & No_ Doyon Drilling - Rig: # 19 Field ALPINE
Well Name & No. CD#1119 Survey Section Name ANADRILL MWD BHI Rep. SALVATIERRA / MILCHAK
'IV . e:;Q. WELL DATA
Target TVD (FT) Target Coord. N/S Slot Coord. N/S -350.20 Grid Correction 0.000 Depths Measured From: RKB I8J MSL 0 SS 0
Target Description Target Coord. E/W Slot Coord. E/W 2447.89 Magn. Declination 26.390 Calculation Method MINIMUM CURVATURE
Target Direction (DO) Build\Walk\DL per: l00ft~ 30mD 10m 0 Vert. Sec. Azim. 21.78 Magn. to Map Corr. 26.390 Map North to: OTHER
SURVEY DATA
Survey Survey Incl. Hole Course Total Coordinate Build Rate Walk Rate
Vertical
Date Tool Depth Angle Direction Length TVD Section N(+)/S(-) E(+) / W(-) DL Build (+) Right (+ ) Comment
Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100FT) Drop (-) Left (-)
12-APR-99 MWD 4518.32 53.08 27.00 93.77 3415.11 2476.76 2317 .46 875.18 0.56 -0.45 -0.43 ~";:-~
12-APR-99 MWD 4614.74 52.91 27.30 96.42 3473.14 2553.42 2385.98 910.32 0.30 -0.18 0.31
12-APR-99 MWD 4709.23 52.69 26.90 94.49 3530.27 2628.36 2452.98 944.60 0.41 -0.23 -0.42
13-APR-99 MWD 4805.17 52.45 27.40 95.94 3588.58 2704.21 2520.77 979.37 0.48 -0.25 0.52
.
13-APR-99 MWD 4900.63 52.21 26.90 95.46 3646.92 2779.44 2588.00 1013.85 0.48 -0.25 -0.52
13-APR-99 MWD 4996.08 52.11 I 26.90 95.45 3705.48 2854.52 2655.23 1047.95 0.10 -0.10 0.00
13-APR-99! MWD 5091.45 51.95 26.80 95.37 3764.15 2929.41 2722.31 1081.91 0.19 -0.17 -0.10
13-APR-99 MWD 5186.05 51.79 27.20 94.60 3822.56 3003.51 2788.61 1115.69 0.37 -0.17 0.42
13-APR-99 I M\VD 5280.83 51.67 26.80 94.78 3881.27 3077.62 2854.91 1149.47 0.35 -0.13 -0.42
13-APR-99 MWD 5377.34 51.22 26.80 96.51 3941.42 3152.80 2922.27 1183.50 0.47 -0.47 0.00
13-APR-99 MWD 5472.06 51.97 26.20 94.72 4000.26 3226.77 2988.70 1216,62 0.93 0.79 -0.63
13-APR-99 MWD 5566.89 52.18 26.50 94.83 4058.55 3301.34 3055.73 1249.82 0.33 0.22 0.32
13-APR-99 MWD 5662.61 52.06 26.50 95.72 4117.32 3376.63 3123.35 1283.53 0.13 -0.13 0.00 ~-
13-APR-99 MWD 5757.97 53.65 26.30 95.36 4174.90 3452.40 3191.43 1317.33 1.68 1.67 -0.21
13-APR-99 MWD 5851.61 54.00 25.90 93.64 4230.17 3527.77 3259.31 1350.58 0.51 0.37 -0.43
!
13-APR-99 MWD 5947.00 53.72 26.30 95.39 4286.43 3604.59 3328.49 1384.47 0.45 -0.29 0.42 !
13-APR-99 MWD 6042.17 53.40 25.90 95.17 4342.96 3680.93 3397.24 1418.15 0.48 -0.34 -0.42 :
13-APR-99 MWD 6137.44 53.07 . 0.35 -0.35 0.00
25.90 95.27 4399.98 3757.05 3465.90 1451.49
13-APR-99 MWD 6231.61 52.82 26.00 94.17 4456.72 3832.01 3533.47 1484.38 0.28 -0.27 0.11
13-APR-99 MWD 6327.07 53.84 26.40 95.46 4513.73 3908.35 3602.17 1518.18 1.12 1.07 0.42
13-APR-99 MWD 6420.88 54.07 26.50 93.81 4568.93 3983.94 3670.08 1551.97 0.26 0.25 0.11
. 13-APR-99 MWD 6518,06 53.92 25.90 97.18 4626.06 4062.32 3740.62 1586.68 0.52 -0,15 -0.62
13-APR-99 MWD 6612.97 53.58 26.20 94.91 4682.18 4138.65 3809.39 1620.29 0.44 -0.36 0.32
.
13-APR-99 MWD 6708.94 52.97 26.00 95.97 4739.57 4215.35 3878.46 1 1654.13 0.66 -0.64 -0.21
6
t::Æ
MILCHAK
"
~
Field ALPINE
BHI Rep. SALVATIERRA
s~.
S~t
DrillIng - Rig: # 19
ANADRILL MWD
~ - - . - - - - - .- . - - -
SURVEy CALCULATION AND FlELDwollKSllEET
Company ARCa ALASKA, INC.
Well Name & No. CD#1I19
& No. Doyon
Section Name
Ríg Comncmr
Survey
RKB ~ MSLD SS 0
MINIMUM CURVATURE
Method
to OTHER
Depths Measured From
Calculation
Map North
0.000
26.390
26.390
Grid Correction
Declination
to Map Corr.
Magn.
Magn.
-350.20
2447.89
21.78
"'ELL DATA
N/S
E/W
Azim.
Slot Coord.
Slot Coord.
Vert. Sec.
N/S
E/W
Build\ Walk\DL per:
Coord.
Coord.
Target
Target
(FT)
TVD
Description
Direction
Target
Target
Target
10m 0
l°oftŒ 30mD
(DO)
Walk Rate
Right ( + )
Left (-)
-0.63
Build Rate
Build (+)
Drop (-)
-0.59
SURVEY DATA
Total Coordinate
E(+) /
(FT)
1686.93
Course
Length
<£:!L
95.09
Hole
Direction
(O~
25.40
Incl
Angle
(DO)
52.41
Survey
Depth
~
6804.03
Comment
DL
(Per 100 FT)
0.77
W(-)
N(+)/S(-
~
3946.61
Vertical
Section
TVD
(FT)
4797.21
4290.81
.~
0.42
-0.42
0.53
1719.53
4014.65
4366.09
4855.71
95.47
25.80
52.01
6899.50
-0.32
0.23
0.34
1751.92
4082.10
4440.74
4913.91
94.80
25.50
52.23
6994.30
0.00
0.54
0.54
1784.51
4150.43
4516.29
4972.03
95.44
25.50
52.75
7089.74
Survey
Tool
Type
MWD
MWD
MWD
MWD
MWD
Date
13-APR-99
13-APR-99
14-APR-99
14-APR-99
14-APR-99
-0.73
-0.22
0,62
1816.90
4219.41
4592.36
5030.20
95.87
24.80
52.54
7185.61
1
-0.
-0.14
0.16
1848.10
4287.10
4666.80
5087.44
93.98
24.70
52.4
7279.59
MWD
14-APR-99
0.2
-0.09
0.19
1880.04
4356.22
4742.83
5146.15
96.14
24.90
52.32
7375.73
MWD
MWD
MWD
14-APR-99
14-APR-99
14-APR-99
-0.2
-0.08
0.19
1911.33
4423.94
4817.33
5203.85
94.32
24.70
52.24
7470.05
-0.42
-0.31
0.45
1942.67
4492.71
4892.81
5262.70
95.78
24.30
51.94
7565.83
0.52
0.24
0.48
974.07
4561.45
4968.30
5321.63
95.84
24.80
52.17
7661.67
MWD
MWD
14-APR-99
14-APR-99
0.00
0.88
0,88
2005.79
4630.09
5043.81
5379.46
95.19
24.80
53.01
7756.86
-0.2
0.13
0.21
2037.42
4698.86
5119.40
5436.36
94.69
24.60
53.13
7851.55
MWD
14-APR-99
1
o.
-0.28
0.30
2069.03
4767.76
5195.12
5493.49
94.93
24.70
52.86
7946.48
MWD
~-o;.
-0.42
0.41
0.53
2100.41
4836.6
5270.69
5550.40
94.67
24.30
53.25
15
8041
0.10
0.3
0.33
2132.00
4906.40
5347.23
5607.29
95.43
24.40
53.55
8136.58
1
-0
-0.25
0.27
2163.44
4975.89
5423.42
5663.87
94.96
24.30
53.3
8231.54
I
-0.2
-0.50
0.53
2194.76
5045.56
5499.74
5721.29
95.56
24.10
52.83
8327.10
-0.21
0.16
0.23
2225.90
5115.51
5576.24
5779.18
95.99
23.90
52.98
8423.09
0.85
-0.12
0.69
2256.92
5184.22
5651.57
5836.15
94.50
24.70
52.87
8517.59
-0.3
0.74
-0.11
-0.27
0.36
0.41
0.37
0.69
0.42
2288.44
2320.07
5253.21
83
5321
5727.33
5802.79
5893.85
5951.25
6008.21
95.30
94.89
94.97
24.40
25.10
52.6
52.95
53.34
8612.89
8707.78
8802.75
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
14-APR-99
14-APR-99
14-APR-99
14-APR-99
15-APR-99
15-APR-99
15-APR-99
15-APR-99
15-APR-99
15-APR-99
-0.42
36
1
-0.22
-0.32
0.40
13
1
2352.25
2384.12
2416.64
5390.68
5459.66
5528.62
5878.65
5954.54
6030.64
6064.99
6122.50
94.86
95.50
25.00
24.60
25.90
13
52.82
53
8897,61
11
8993
MWD
MWD
15-APR-99
15-APR-99
, ',' ~ ..
= SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-04406 Sidetrack No. Page 5 of 6
- - -
Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling - Rig: # 19 Field ALPINE
Well Name & No. CD#1I19 Survey Section Name ANADRILL MWD BHI Rep. SALVATIERRA 1 MILCHAK
,,.. . e:;Q WELL DATA
Target TVD (FT) Target Coord. N/S Slot Coord. N/S -350.20 Grid Correction 0.000 Depths Measured From: RKB I8J MSL 0 SS 0
Target Description Target Coord. E/W Slot Coord. E/W 2447.89 Magn. Declination 26.390 Calculation Method MINIMUM CURVATURE
Target Direction (DO) Build\Walk\DL per: 100ftΠ30m 0 10m 0 Vert. Sec. Azim. 21.78 Magn. to Map Corr. 26.390 Map North to: OTHER
SURVEY DATA
Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate
Date Tool Depth Angle Direction Length TVD Section N(+)/S(-) E(+) 1 W(-) DL Build (+) Right ( + ) Comment
Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-)
15-APR-99 MWD 9089.25 52.62 24.80 96.14 6180.73 6106.99 5597.75 2449.40 0.93 -0.21 -1.14
15-APR-99 MWD 9183.50 53.49 26.10 94.25 6237.38 6182.16 5665.76 2481. 77 1.44 0.92 1.38 (
15-APR-99 MWD 9279.88 52.89 25.70 96.38 6295.13 6259.12 5735.17 2515.47 0.71 -0.62 -0.42
15-APR-99 MWD 9375,00 52.55 25.30 95.12 6352.74 6334.64 5803.48 2548.06 0.49 -0.36 -0.42
15-APR-99 MWD 9470.81 52.15 24.40 95.81 6411.27 6410.39 5872.31 2579.94 0,85 -0.42 -0.94
15-APR-99 MWD 9565.69 53.36 24.60 94.88 6468,69 6485.84 5941.04 2611.26 1.29 1.28 0.21
15-APR-99 MWD 9658.89 52.87 24.30 93.20 6524.63 6560.30 6008.90 2642.11 0,59 -0.53 -0.32
16-APR-99 MWD 9744.56 52.24 25.20 85.67 6576.72 6628.22 6070.67 2670.59 1.11 -0.74 1.05 63/4" MIX 1.4 DEG AKO
16- APR -99 MWD 9775.66 52.28 24.70 31.10 6595.75 6652.78 6092.97 2680.96 1.28 0.13 -1.61
17-APR-99 MWD 9808.35. 53.73 22.10 32.69 6615.42 6678.87 6116.93 2691.32 7.75 4044 -7.95
17-APR-99 MWD 9839.95 56.04 18.10 31. 60 6633.61 6704.70 6141.20 2700.19 12,67 7.31 -12.66
17-APR-99 MWD 9870.87 58.44 15.10 30.92 6650.34 6730.59 6166.11 2707.61 11.26 7.76 -9.70
17-APR-99 MWD 9904.33 61.37 12.40 33.46 6667.12 6759.25 6194.23 2714.48 11.20 8.76 -8.07
( -
17-APR-99 MWD 9935.76 63.77 11. 00 31.43 6681.60 6786.71 6221. 54 2720.13 8.60 7.64 -4.4 5
17-APR-99 MWD 9966.82 65.75 10.20 31.06 6694.84 6814.27 6249.16 2725.30 6.79 6.37 -2.58
17-APR-99 MWD 9998.92 67.07 10.20 32.10 6707.69 6843.09 6278.11 2730.51 4.11 4.11 0.00
17-APR-99 MWD 10030.63 66.99 9.70 31.71 6720.06 6871.66 6306.86 2735.55 1.47 -0.25 -1.58
17-APR-99 MWD 10062.05 67.74 8.00 31.42 6732.15 6899.92 6335.52 2740.01 5.53 2.39 -5.41
17-APR-99 MWD 10094.07 67.96 6.70 32.02 6744.23 6928.64 6364.93 2743.81 3.82 0.69 -4.06
17-APR-99 MWD 10128.12 68.06 4.70 34.05 6756.98 6958.98 6396.35 2746.94 5.45 0.29 -5.87
17-APR-99 MWD 10158.43 68.13 3.25 30.31 6768.29 6985.75 6424.40 2748.89 4.44 0.23 -4.78
17 -APR-99 MWD 10190.58 68.28 1.40 32.15 6780.22 7013.90 6454.22 2750.10 5.36 0.47 -5.75
-- -- .
17-APR-99 MWD 10221.04 68.98 359.30 30.46 6791.32 7040.30 6482.59 2750.27 6.82 2.30 -6.89
.. -"-.. - f----- --
............ 17-APR-99 MWD 10254.06 69.41 357.20 33.02 6803.05 7068.60 6513 .44 2749.33 6.09 1.30 -6.36
6
MILCHAK
of
6
Page
ALPINE
SALVATIERRA
Sidetrack No
Field
BHI Rep
0451-04406
Rig Contractor & No. Doyon Drilling - Rig: #19
Survey Section Name ANADRILL MWD
Job No
SURVEY CALCULATION AND FIELD WORKSHEET
INC.
Company ARCO ALASKA,
Well Name & No. CD#1I19
Depths Measured From
Calculation Method MINIMUM CURVATURE
Map North to: OTHER
SSD
RKB 181 MSLD
0.000
26.390
26.390
Grid Correction
Magn. Declination
Magn. to
-350.20
2447.89
21. 78
WELL DATA
Slot Coord. N/S
Slot Coord. E/W
Vert. Sec. Azim.
Target N/S
Target E/W
Build\ Walk\DL per:
Coord.
Coord.
(FT)
TVD
Description
Direction
Target
Target
Target
Map Corr.
IOmD
100ft æ: 30m D
(DO)
Walk Rate
Right ( + )
Left (-)
-5.95
Build Rate
Build (+ )
Drop (-)
1.82
SURVEY DATA
Total Coordinate
E(+) / W(-)
~
2747.37
Course
Length
(FT)
31. 92
Hole
Direction
(~
355.30
IncI.
Angle
(DO)
69.99
Survey
Depth
~
10285.98
Survey
Töol
Type
MWD
Comment
DL
(Per 100 FT)
5.87
N(+)/S(-)
~
6543.31
Vertical
Section
TVD
(FT)
6814
Date
17-APR-99
7095.61
13
~~~-"'I;
-6.27
2.35
6.36
2744.39
6573.20
7122.26
6824.85
90
31
353.30
70.74
10317.88
MWD
18-APR-99
-4.66
3.33
5.53
2740.72
6601.41
7147.10
6834.51
30.04
90
351
71.74
10347.92
MWD
-5.66
2.73
6.04
2735.98
6631.34
7173.13
6844.25
83
31
10
350
72.6
10379.75
MWD
MWD
MWD
-7.42
2.60
7.56
2730.02
6661. 69
7199.11
6853.70
32.35
347.70
73.45
I
10412.10
-7.65
6.06
9.54
2722.97
6691.06
7223.76
6862.13
36
31
345.30
75.35
10443.46
18-APR-99
18-APR-99
18-APR-99
8~APR-99
-~
4
Projected Data - NO SURVEY
-2.83
-1.24
¡
I
I
10.37
9.88
':
10.73
9.96
2714.86
2694.92
6720.99
6790.31
7248.55
7305.52
6869.29
11
6879
31.83
72.84
344.40
343.50
78.65
85.85
10475.29
10548.13
MWD
MWD
18-APR-99
18-APR-99
ANADRILL
SCHLUMBERGER q9 ·o~ :,
Survey report 19-Apr-99
Client ARca Alaska, Inc. -:R~DO
Field. Colville River -----
Well. . CDl-19
Spud date....... 07-April-99
API number 50-103-20294-00 Last survey date... . . l8-Apr-99
Engineer.. Dammeyer Total accepted surveys 127
MD of first survey.... 115.00 ft
RIG:...... Doyon 19 MD of last survey..... 10548.00 ft
~<-'STATE:... . Alaska
----- Survey calculation methods------------- ----- Geomagnetic data ------------------
Method for positions. ....: Minimum curvature Magnetic model........ BGGM version 1997
Method for DLS....... ....: Mason & Taylor Magnetic date.......... 01-Aug-1998
Magnetic field strength 1144.00 HCNT
----- Depth reference ----------------------- Magnetic dec (+E/W-)... 26.39 degrees
Permanent datum... .......: MEAN SEA LEVEL Magnetic dip........... 80.49 degrees
Depth reference..... .....: Drill Floor
GL above permanent... ....: 22.0 ft ----- MWD survey Reference Criteria ---------
KB above permanent... ....: Top Drive Reference G..............: 1002.68 mGal
DF above permanent... ....: 58.8 ft Reference H..............: 1144.00 HCNT
Reference Dip............: 80.62 degrees
----- Vertical section origin---------------- Tolerance of G...........: (+/-) 3.00 mGal
Latitude (+N/S-) .........: 0.00 ft Tole r an ceo f H........... : (+/-) 7.00 HCNT
Departure ( + E /W-) . . . . . . . . : 0.00 ft Tolerance of Dip... ......: (+/-) 0.30 degrees
----- Platform reference point--------------- ----- Corrections ---------------------------
_,sati tude (+N/S-) .........: -999.25 ft Magnetic dec (+E/W-) .....: 26.39 degrees
Departure (+E/W-) ........: -999.25 ft Grid convergence (+E/W-) .: 0.00 degrees
Total az corr (+E/W-) ....: 26.39 degrees
Azimuth from rotary table to target 21.80 degrees (Total az corr = magnetic dec - grid con v)
Sag applied (Y/N No degree: 0.00
31
32
33
34
35
2900.44
2996.22
3091.54
3187.20
3281.48
52
52
52
52
52
99
62
16
81
67
26
26
26
24
23
o
7
8
6
1
126.80
95.80
95.30
95.70
94.30
2438.13
2496.05
2554.21
2612.49
2669.58
1190.23
1266.30
1341.52
1417.24
1492.24
1154.20
1222.58
1289.99
1358.39
1427.03
319.30
353.17
387.15
420.06
450.41
1197
1272
1346
1421
1496
55
57
84
86
42
15.46
16.11
16.71
17.18
17.52
0.51
0.70
0.49
1.95
1.27
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
26
27
28
29
30
2426.64
2521.48
2616.39
2710.57
2773.64
52.05
53.62
53.37
54.05
53.62
30.4
28.5
28.5
26.4
25.8
96.10
94.90
94.90
94.20
63.00
2155.64
2212.97
2269.43
2325.18
2362.36
811.85
886.79
962.55
1038.10
1088.82
816.80
882.65
949.69
1017.06
1062.74
143.96
181.13
217.53
252.52
274.89
829.39
901.04
974.28
1047.94
1097.71
10.00
11.60
12.90
13.94
14.50
4.31
2.30
0.26
1.94
1.03
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
"--'
21
22
23
24
25
1949.67
2041.62
2140.47
2236.49
2330.50
41.53
42.50
43.47
45.18
47.97
15.7
18.1
20.6
27.8
31.3
94
91
98
96
94
20
90
90
00
00
1819.92
1888.20
1960.55
2029.27
2093.89
475.98
537.25
604.61
671.54
739.15
510.73
569.57
633.18
694.25
753.59
4.77
22.66
45.01
72.53
106.23
510.75
570.02
634.77
698.03
761.04
0.54
2.28
4.07
5.96
8.02
1.61
2.04
1.98
5.53
4.01
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
16
17
18
19
20
1474.49
1570.23
1665.29
1760.19
1855.50
26.06
29.78
33.92
38.29
40.37
11.9
13.9
11.8
13.0
14.2
95.50
95.70
95.10
94.90
95.30
1433.09
1517.64
1598.40
1675.06
1748.77
205
250
299
354
414
93
20
74
90
68
245.22
288.87
337.80
392.39
451.09
-58.56
-48.52
-37.41
-25.38
-11.16
252.11
292.92
339.86
393.21
451.23
346.57
350.47
353.68
356.30
358.58
5.72
4.01
4.51
4.66
2.32
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
11
12
13
14
15
1004.80
1094.06
1187.71
1283.40
1378.97
14.02
18.14
22.79
24.20
24.52
346.3
347.9
349.2
351.7
359.6
90.20
89.30
93.60
95.70
95.60
998.35
1084.14
1171.80
1259.57
1346.68
51
71
98
131
166
24
59
97
56
89
71.81
95.92
127.99
165.61
204.84
-41.55
-47.03
-53.48
-59.79
-62.76
82.96
106.83
138.71
176.07
214.24
329.94
333.88
337.32
340.15
342.97
3.77
4.64
4.99
1.80
3.42
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
"--~
6
7
8
9
10
557.90
647.13
736.26
827.10
914.62
5.94
7.48
8.46
9.31
10.72
314.6
321.5
326.5
336.1
342.5
90.00
89.20
89.20
90.80
87.50
557.44
646.03
734.37
824.08
910.25
4.40
9.06
15.67
24.61
35.85
8.86
16.65
26.67
38.95
53.18
-10.32
-17.22
-24.46
-31.12
-36.44
13.61
23.96
36.18
49.86
64.47
310.65
314.03
317.47
321.37
325.58
2.45
1.95
1.34
1.88
2.05
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
1
2
3
4
5
115.00
195.29
287.00
381.05
467.90
0.00
0.37
0.43
1.85
3.74
o
199
267
312
316
o
1
o
6
4
o
80
91
94
86
00
30
70
00
90
115.00
195.30
287.00
380.98
467.77
0.00
-0.26
-0.70
-0.31
1.37
0.00
-0.25
-0.54
0.47
3.47
0.00
-0.08
-0.53
-1.99
-4.98
0.00
0.26
0.76
2.05
6.07
0.00
199.10
224.06
283.15
304.84
o
o
o
1
2
00
46
49
68
18
Seq
#
Measured
depth
(ft)
------
------
Incl
angle
(deg)
------
------
Az imu th
angle
(deg)
Course
length
ft)
--------
--------
TVD
depth
(ft)
--------
--------
--------
--------
Vertical
section
(ft)
--------
--------
----------------
----------------
Displ Displ
+N/S- +E/W-
(ft) (ft
---------------
---------------
Total At
displ Azim
(ft) (deg)
---------------
---------------
DLS
(deg/
100f)
Srvy
tool
type
TIP
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
Tool
qual
type
------
------
66
67
68
69
70
6231.61
6327.07
6420.88
6518.06
6612.97
52.82
53.84
54.07
53.92
53.58
26.0
26.4
26.5
25.9
26.2
94.20
95.50
93.80
97.20
94.90
4456.72
4513.75
4568.95
4626.09
4682.20
3832.02
3908.39
3983.98
4062.38
4138.71
3533
3602
3670
3740
3809
47
19
10
65
41
1484.37
1518.19
1551.97
1586.68
1620.29
3832.59
3909.05
3984.75
4063.25
4139.68
22.79
22.85
22.92
22.99
23.04
0.28
1.12
0.26
0.52
0.44
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axìs
61
62
63
64
65
5757.97
5851.61
5947.00
6042.17
6137.44
53.65
54.00
53.72
53.40
53.07
26.3
25.9
26.3
25.9
25.9
95.40
93.60
95.40
95.20
95.20
4174.92
4230.17
4286.43
4342.98
4399.96
3452.43
3527.77
3604.60
3680.97
3757.04
3191.45
3259.30
3328.49
3397.27
3465.87
1317.33
1350.57
1384.46
1418.16
1451.47
3452.64
3528.04
3604.94
3681.38
3757.53
22.43
22.51
22.58
22.66
22.72
1
o
o
o
o
68
51
45
48
35
MWD
MWD
MWD
MWD
MWD
6-axìs
6-axis
6-axìs
6-axìs
6-axis
~~~
56
57
58
59
60
5280.83
5377.34
5472.06
5566.89
5662.61
51.67
51.22
51.97
52.18
52.06
26.8
26.8
26.2
26.5
26.5
94.80
96.50
94.80
94.80
95.70
3881.25
3941.40
4000.29
4058.55
4117.31
3077.59
3152.77
3226.81
3301.35
3376.64
2854.89
2922.25
2988.73
3055.74
3123.34
1149.46
1183.48
1216.63
1249.82
1283.52
3077.60
3152.80
3226.87
3301.45
3376.79
21.93
22.05
22.15
22.24
22.34
0.35
0.47
0.93
0.33
0.13
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axìs
6-axis
6-axìs
51
52
53
54
55
4805.17
4900.63
4996.08
5091.45
5186.05
52.45
52.21
52.11
51.95
51.79
27.4
26.9
26.9
26.8
27.2
96.00
95.40
95.50
95.40
94.50
3588.60
3646.91
3705.49
3764.19
3822.53
2704.23
2779.41
2854.53
2929.45
3003.47
2520.79
2587.98
2655.24
2722.34
2788.57
979.37
1013.83
1047.95
1081.92
1115.67
2704.36
2779.48
2854.56
2929.45
3003.47
21
21
21
21
21
23
39
54
67
81
0.48
0.49
0.10
0.19
0.37
MWD
MWD
MWD
MWD
MWD
6-axìs
6-axìs
6-axìs
6-axis
6-axis
46
47
48
49
50
4329.36
4424.55
4518.32
4614.74
4709.23
53.25
53.50
53.08
52.91
52.69
27
27
27
27
26
5
4
o
3
9
95.20
95.10
93.80
96.40
94.50
3302.30
3359.03
3415.10
3473.12
3530.26
2325.91
2401.86
2476.73
2553.38
2628.33
2182.84
2250.57
2317.45
2385.95
2452.96
805.61
840.79
875.17
910.30
944.59
2326.76
2402.50
2477.19
2553.70
2628 . 54
20.26
20.49
20.69
20.88
21.06
1.50
0.28
0.56
0.30
0.41
MWD
MWD
MWD
MWD
MWD
6-axìs
6-axìs
6-axis
6-axìs
6-axìs
""-..:~'
41
42
43
44
45
3853
3948
4043
4137
4234
16
70
51
99
16
52.89
52.50
52.67
52.66
52.06
24.8
24.5
26.4
26.9
26.5
95.40
95.50
94.80
94.50
96.20
3013.00
3070.88
3128.48
3185.80
3244.55
1948.77
2024.64
2099.78
2174.65
2250.54
1843.18
1912.22
1980.20
2047.36
2115.41
639.28
670.96
703.32
737.02
771.25
1950.89
2026.52
2101.39
2175.97
2251.62
19.13
19.34
19.55
19.80
20.03
0.10
0.48
1.60
0.42
0.71
MWD
MWD
MWD
MWD
MWD
6-axìs
6-axis
6-axis
6-axis
6-axis
36
37
38
39
40
3377.00
3472.68
3566.74
3662.50
3757.81
52.33
53.28
53.81
53.29
52.99
23.1
24.6
25.0
25.0
24.8
95.50
95.70
94.00
95.80
95.30
2727.72
2785.57
2841.43
2898.34
2955.51
1567.99
1644.17
1719.67
1796.61
1872.75
1496.72
1566.44
1635.07
1704.91
1774.07
480.13
510.96
542.68
575.24
607.35
1571.85
1647.67
1722.77
1799.34
1875.15
17.79
18.07
18.36
18.64
18.90
0.36
1.60
0.66
0.54
0.36
Seq
#
Measured
depth
(ft)
------
------
Incl
angle
(deg)
------
------
Azimuth
angle
(deg)
Course
length
(ft)
------
------
TVD
depth
(ft)
--------
--------
--------
--------
Vertìcal
section
(ft)
----------------
----------------
Displ Displ
+N/S- +E/W-
( ft ) ( ft)
----------------
----------------
---------------
---------------
Total At
displ Azim
( ft ) (deg)
---------------
---------------
DLS
(deg/
100f)
Srvy
tool
type
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
Tool
qual
type
------
------
101
102
103
104
105
9565.69
9658.89
9744.56
9775.66
9808.35
53.36
52.87
52.24
52.28
53.73
24.6
24.3
25.2
24.7
22.1
94.90
93.20
85.70
31.10
32.70
6468.69
6524.62
6576.73
6595.77
6615.44
6485.93
6560.39
6628.34
6652.90
6679.00
5941.06
6008.92
6070.71
6093.01
6116.97
2611.26
2642.11
2670.60
2680.97
2691.34
6489.60
6564.14
6632.16
6656.75
6682.86
23.73
23.74
23.75
23.75
23.75
1.29
0.59
1.11
1.28
7.74
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
96
97
98
99
100
9089.25
9183.50
9279.88
9375.00
9470.81
52
53
52
52
52
62
49
89
55
15
24
26
25
25
24
8
1
7
3
4
96.20
94.20
96.40
95.10
95.80
6180.75
6237.37
6295.13
6352.73
6411.25
6107.10
6182.23
6259.21
6334.73
6410.47
5597.79
5665.77
5735.19
5803.49
5872.32
2449.41
2481.76
2515.48
2548.05
2579.93
6110.23
6185.47
6262.59
6338.23
6414.06
23.63
23.65
23.68
23.70
23.72
0.93
1.44
0.71
0.49
0.85
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
.~~
91
92
93
94
95
8612
8707
8802
8897
8993
89
78
75
61
11
52.61
52.95
53.34
53.14
52.82
24
25
25
24
25
4
1
o
6
9
95
94
94
94
95
30
90
90
90
50
5893.86
5951.26
6008.18
6064.98
6122.48
5727.39
5802.86
5878.67
5954.60
6030.71
5253.22
5321.85
5390.64
5459.66
5528.62
2288.43
2320.07
2352.22
2384.11
2416.64
5730.03
5805.58
5881.49
5957.50
6033.72
23.54
23.55
23.57
23.59
23.61
0.37
0.69
0.42
0.40
1.14
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
86
87
88
89
90
8136.58
8231.54
8327.10
8423.09
8517.59
53.55
53.31
52.83
52.98
52.87
24.4
24.3
24.1
23.9
24.7
95.50
94.90
95.60
96.00
94.50
5607.31
5663.85
5721.29
5779.19
5836.16
5347.30
5423.44
5499.79
5576.31
5651.63
4906.42
4975.86
5045.56
5115.51
5184.23
2132.00
2163.42
2194.75
2225.89
2256.92
5349.61
5425.82
5502.23
5578.81
5654.19
23.49
23.50
23.51
23.52
23.53
0.33
0.27
0.53
0.23
0.69
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
81
82
83
84
85
7661
7756
7851
7946
8041
67
86
55
48
15
52
53
53
52
53
17
01
13
86
25
24.8
24.8
24.6
24.7
24.3
95.90
95.20
94.70
94.90
94.60
5321.66
5379.49
5436.39
5493.51
5550.37
4968.37
5043.89
5119.49
5195.18
5270.70
4561.48
4630.12
4698.89
4767.77
4836.57
1974.07
2005.79
2037.42
2069.03
2100.39
4970.31
5045.91
5121.59
5197.36
5272.95
23.40
23.42
23.44
23.46
23.47
0.48
0.88
0.21
0.30
0.53
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
>~
76
77
78
79
80
7185.61
7279.59
7375.73
7470.05
7565.83
52.54
52.41
52.32
52.24
51.94
24
24
24
24
24
8
7
9
7
3
95.90
94.00
96.10
94.30
95.80
5030
5087
5146
5203
5262
19
45
13
83
69
4592.39
4666.85
4742.84
4817.33
4892.83
4219.41
4287.11
4356.19
4423.91
4492.69
1816.89
1848.10
1880.02
1911.31
1942.65
4593.96
4668.49
4744.57
4819.13
4894.70
23.30
23.32
23.34
23.37
23.38
0.62
0.16
0.19
0.19
0.45
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
71
72
73
74
75
6708.94
6804.03
6899.50
6994.30
7089.74
52.97
52.41
52.01
52.23
52.75
26.0
25.4
25.8
25.5
25.5
95
95
95
94
95
90
10
50
80
40
4739.55
4797.19
4855.71
4913.92
4972.01
4215.35
4290.82
4366.12
4440.78
4516.29
3878.43
3946.59
4014.65
4082.10
4150.41
1654.11
1686.91
1719.52
1751.91
1784.49
4216.44
4292.00
4367.40
4442.16
4517.77
23
23
23
23
23
10
14
19
23
27
o
o
o
o
o
66
77
53
34
55
Seq
#
Measured
depth
(ft)
------
------
Incl
angle
(deg)
------
------
Azimuth
angle
(deg)
------
------
Course
length
(ft)
------
------
--------
--------
TVD
depth
(ft)
--------
--------
--------
--------
Vertical
section
(ft)
--------
--------
Displ Displ
+N/S- +E/W-
(ft) (ft)
----------------
----------------
===============
Total
displ
ft)
At
Azim
(deg)
DLS
(deg/
100f)
-----
Srvy
tool
type
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
Tool
qual
type
------
------
.,~
Last
127
Survey
10548.00
Projected to TD
85.85 343.5
72
70
6879.05
7305
47
6790.20
2695
08
7305
49
21
65
9.98
MWDM
126
121
122
123
124
125
10475.29
10317.88
10347.92
10379.75
10412.10
10443.46
78
70.74
71.74
72.61
73.45
75.35
65
344.4
353.3
351.9
350.1
347.7
345.3
31
31.90
30.00
31.80
32.40
31.40
80
6869.25
6824.81
6834.46
6844.20
6853.66
6862.10
7248
7122.38
7147.17
7173.18
7199.19
7223.87
63
6721
6573.24
6601.40
6631.30
6661.71
6691.11
02
2714
2744
2740
2736
2730
2723
99
51
85
11
15
08
7248
7123.19
7147.78
7173.60
7199.45
7224.00
67
22.00
22.66
22.55
22.42
22.29
22.14
10
6.36
5.53
6.04
7.54
9.53
74
MWD
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
-~-116
117
118
119
120
10158.43
10190.58
10221.04
10254.06
10285.98
68.15
68.28
68.98
69.41
69.99
3.5
1.4
359.3
357.2
355.3
30.30
32.20
30.40
33.10
31.90
6768.24
6780.19
6791.27
6803.03
6814.09
6985.82
7014.03
7040.38
7068.74
7095.73
6424.39
6454.26
6482.56
6513.49
6543.34
2748.95
2750.23
2750.40
2749.45
2747.49
6987.81
7015.78
7041.90
7070.01
7096.76
23.17
23.08
22.99
22.89
22.78
3.69
6.07
6.83
6.07
5.87
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
111
112
113
114
115
9998.92
10030.63
10062.05
10094.07
10128.12
67
66
67
67
68
07
99
74
96
06
10.2
9.7
8.0
6.7
4.7
32.10
31.70
31.40
32.10
34.00
6707.65
6720.02
6732.10
6744.21
6756.94
6843.16
6871.72
6899.96
6928.75
6959.04
6278.11
6306.85
6335.49
6364.98
6396.34
2730.50
2735.55
2740.00
2743.81
2746.94
6846.19
6874.56
6902.61
6931.19
6961.24
23.51
23.45
23.39
23.32
23.24
3.99
1.47
5.54
3.81
5.46
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
106
107
108
109
110
9839.95
9870.87
9904.33
9935.76
9966.82
56.04
58.44
61.37
63.77
65.79
18.1
15.1
12.4
11.0
10.2
31
31
33
31
31
50
00
40
SO
00
6633.57
6650.34
6667.09
6681.60
6694.81
6704.75
6730.70
6759.30
6786.83
6814.33
6141.17
6166.15
6194.21
6221.59
6249.15
2700.18
2707.61
2714.47
2720.14
2725.29
6708.57
6734.43
6762.88
6790.23
6817.56
23.73
23.71
23.66
23.62
23.56
12.71
11.23
11.22
8.58
6.92
Seq
#
Measured
depth
(ft)
Incl
angle
( deg)
------
------
Azimuth
angle
(deg)
Course
length
(ft)
------
------
TVD
depth
(ft)
--------
--------
Vertical
section
(ft)
----------------
----------------
Displ Displ
+N/S- +E/W-
(ft) (ft)
----------------
----------------
---------------
---------------
Total At
displ Azim
(ft) (deg)
---------------
---------------
DLS
(deg/
100f)
Srvy
tool
type
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
Tool
qual
type
------
------
'18 - 2 "- OJ
9'ò - z..1 9
.~C;. o'-~
:~ - 031
CWq (:,""04 jf
'''1':'1. 03~
~~ - c 4 ~
~8·o-:¡1
"ß C(~ Z.
<?¡'Ô- í) ';r 1-
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
~~
~~
July 27, 1999
Ms. Wendy Mahan
Natural Resource Manager
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501-3192
Re: Kuparuk Area Annular Injection, Second Quarter, 1999
Dear Ms. Mahan:
Please find reported below volumes injected into surface casing by production casing annuli during
the second quarter of 1999, as well as total volumes injected into annuli for which injection
authorization expired during the second quarter of 1999.
Annular Injection during the second quarter of 1999:
h(l) h(2) h(3) Total for Previous New
Well Name Volume Volume Volume Quarter Total Total
1C-15 34380 100 0 32195 16795 48990
2L-313 3779 100 0 3879 8654 12533
CDl-19 33933 100 0 34033 0 34033
1 C-25 34216 100 0 34316 0 34316
CDI-40 12071 100 0 12171 0 12171
1 C-23 9505 100 0 9605 0 9605
Total Volumes into Annuli for which b~jectioll Authorization Expired during the quarter
Total
Total h(l) Total h(2) Total h(3) Volume
Well Name Volume Volume Volume Injected Status of Annulus
1D-10 35473 100 0 35573 Open, Freeze Protected
2N-323 32696 100 0 32796 Open, Freeze Protected
2N -343 17895 100 0 17995 Open, Freeze Protected
2N -329 9 100 0 109 Open, Freeze Protected
Please call me at 263-4603 should you have any questions.
Sincerely,
J~'~ ;.....J.. ,'~'" :.... .
.' . ~ ., ~.' ~.... ......'..
rJ,' '~.iJJ,. :t)1W.' :~
,~ L.. \.' ~~, . :J
- 1-4 ~ ~.."
.: Ij / "":8 -
: -: .Ì'~ '--.. n.._.· lqQ(9
.J ~ , I :p'. 1~
':,;â!1kd Oì¡ &. ~ , ~,,~ . .,¡
'-1 /,( ,... u(!:; tAJni:: i"{·.~. ~'.,
~;asl\a Ou & aa!l;~õd ,,:.~. ··:~~"''''I·'.
111" \... .~. "I jl 1.',""...-
Ancnoraqs"
~fYl~
Paul Mazzolini
Drilling Team Leader
Ms. Wendy Mahan
AOGCC
Second Quarter 1999 Annular Injection Report
Page Two
cc: Mike Zanghi
Paul Mazzolini
Randy Thomas
Kuparuk Environmental: Engel/Snodgrass
Morrison and Winfree
Sharon Allsup-Drake
Well Files
.' -.. ......
.......".....
:..:3.3:(2 L:. .:.' :·:~'~r;~:·~;:';·'
2/99
5/
Alaska Oil & Gas Cons Comm
Attn: Lori Taylor
3001 Porcupine Drive
Anchorage, AK 9950
2572
Company:
NO.
GeoQuest
3940 Arctic Blvd
Anchorage, AK 99503
AnN: Sherrie
Alpine
Field:
CD-R
CD 1- 19 :;µ=- q\5~ 99199 CDRI ADN (PDC) 990419 1
CD 1-19 99199 CDR 990419 1 1
-
CD 1- 19 99199 CDR TVD 990419 1 1
CD 1- 19 99199 ADN 990419 1 1
CD 1- 19 99199 ADN TVD 990419 1 1
Sepia
BL
Date
Log Description
Job #
Wel
C?q. D'-'!:J
i~~ l= (: i'~~ i \, IF, t b
~ <,.,tI .....,.. ._ :'14.1
. , i () r)~j')
SIGNED: DATE: . ~.
ßJ8ske. 0:11 G3:; \>jn~. Cs:,:a::.,,,::;
Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. Ancl/jrJ~J\:"
(
I
Schlumberger
Anadrill
Schlumberger
Anadrill
3940 Arctic Boulevard
Anchorage, Alaska 99503
(907) 273-1700
(907) 561-8317 (Fax)
To whom it may concern,
The survey printout for CD1-19 that you received was labeled Ground Level for the Permanent
datum. It should be Mean Sea Level. Please replace the old file with this corrected copy.
Thanks,
Nate Rose
Anadrill Schlumberger
RECEIVED
MAY 1 1 1999
Alaska Oil & Gas Cons. Commission
And10rage
Schlumberger
Anadrill
<19 · 0)3
MWD/LWD Log Product Delivery
Installation/Rig
Arco Alaska, Inc. Dispatched To AOGCC
CD1-19 Date Dispatch 30-Apr-99
Doyon 19 Dispatched By Joey LeBlanc
Customer
Well No
LOG
Run No.
Scale
Ori inal Film No Of Prints No of Flo ies No of Ta es
Surveys (Paper)
.~::; .~_y""JI~ ~"""""':' 1~ I ~- "'~
~.,,~ ..~... I ~t: "-,, 'J
.~ h. r._ ~ bm/ 'Ln~
Oil & Gas' Con . ComrruS$OR
:~{!ho .
Received By:
Please sign and return to:
Anadrill LWD Division
3940 Arctic Blvd
Anchorage, Alaska 99503
Fax: 907-561-8417
LWD Log Delivery V1.1, Dec '97
ì
..' :~'~~ ~;:
~'
STATE OF ALASKA <
ALASKA OIL AND GAS CONSERVATION COMMISSION
~~
#ev
APPLICATION FOR SUNDRY APPROVALS
1, Type of Request: Abandon _ Suspend_
Alter casing _ Repair well _
Change approved program -2L
Operation Shutdown _ Re-enter suspended well _
Plugging -2L Time extension _ Stimulate
Pull tubing _ Variance Perforate Other X Cuttinas DisDosal
2, Name of Operator
5, Type of Well:
Development X_
Exploratory _
Stratigraphic _
Service
6. Datum elevation (DF or KB)
ARCO Alaska Inc.
3, Address
P. O. Box 100360, Anchorage, AK 99510
57' RKB feet
7, Unit or Property name
Colville River Field
4, Location of well at surface
351' FNL, 2447' FWL, See, 5, T11 N, R5E, UM
8, Well number
CD1-19
At target
1287' FSL,236'FEL,Sec,29,T12N, R5E, UM
At effective depth
At total depth
216' FSL,2464'FEL,Sec,20,T12N, R5E, UM
9, Permit number
99-23
10. API number
50-1 03-20294
11, Field/Pool
Colville River Field/ Alpine Oil Pool
12. Present well condition summary
Total Depth: measured
(approx) true vertical
Length
84'
2788'
1 0548' feet
6879' feet
1 0548' feet
6879' feet
Size
16"
9,625"
TD at base of the Alpine Sand
Effective depth:
(approx)
measured
true vertical
r' ",.
l. U
Casing
Structural
Conductor
Surface
Cemented Measured depth True verti9.WI~~iifÞ.
121' 121'
860 sx ASIIILW 2825' 2393'
& 230 Class G
Intermediate
Production
Liner
o i\.
¡. L
. ..\
Proposed Operations: A cement plug will be set from TD @ 1 0548'MD to 10000'MD. This will place the top of the plug 393' MD above the top of the
Alpine, This plug will cover the only zone of significant reservoir quality within the well bore, The plug will be weight tested to verify it position and quality.
A 4-1/2" injection string / kill string will be run to +/- 2200' and hung off from the wellhead with a tubing hanger. This string will be used to inject
associated drilling waste into the proposed 'annulus' injection zone at approximately 2450' TVD. All drilling waste injection operations will be carried out
as per the previously applied for annular waste disposal permit application (Le, with a maximum injected quantity of 35,O~bbIS).lt is then intended
that, when required, the well will re-used or fully plugged and abandoned, Both options will require setting of a~ (ent plug covering the 9-5/8"
surface casing shoe,
on..· £" 't''' i... I. J/'II / r ". S (.,,'X;
13, Attachments Description summary of proposal _ Detailed operation program ---X- BOP sketch
Contact Brian Robertson at 265-6034 with any questions, LOT test, surface cement details and casing detail sheets ..x..
14, Estimated date for commencing operation
ADril 19. 1999
16, If proposal was verbally approved I"'" JI'/\.. ..
ro'p~t~·~
Name of approver Blair Wondzell bate approved 4/18/99
17, I hereby rtify tha e foregoing is true and correct to the best of my knowledge,
15, Status of well classification as:
Oil --X- Gas
Suspended _
Service
Title AI ine Orillin Team Leader Date
FOR COMMISSION USE ONLY
Conditions of ap ova Notify Commission so repres§Jltative may witness IApRrové!/. No.
Plug int y L BOP Test Ý Location clearance _ I 4qC ... <::>6 "
Mechanical Integrity Test _ Subsequent form require 10-lfO"f , p,.~.-f ÂI1A:.c.Cø..r Þ"'I*'SéØ1
ORIGINAL SIGNED· BY 11 -"\ b .....0..
Commissioner Date r c;:j- -)
SUBMIT IN TRIPLICATE
Approved Copy
Retu rned
" )~ ~'3-~~ <l.
't1 .___~L...
(
ARCa Alaska, Inc.
Post OHice Bo){ -¡ 00360
Anchorage, Alaska 99S-¡ 0-0350
Telephone 907 276 12-15
{
~~
~~
April 19, 1999
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Re: Application for Sundry Approval to Abandon the Alpine Reservoir Section and
Enable Disposal of Drilling Waste on well: CD1-19
Dear Sirs:
ARCO Alaska, Inc. hereby requests approval that CD1-19 is abandoned over the Alpine
reservoir interval which has proved to be uneconomic at this subsurface location.
Furthermore ARCO Alaska, Inc. requests that we be permitted for pumping of fluids
occurring as a result of drilling operations, per regulation 20 ACC 25.080 into this
wellbore. A",,,<.t(ø, fØMf"'"
The abandonment of the Alpine reservoir section will commence this morning (19 April),
based on verbal approval from Mr. B. Wondzell (on 04/18/99). It is intended that
injection operations be commenced around 20 April 1999. This will allow disposal of
drilling waste from the CD1-24 development well.
This permit application replaces the application for sundry approval to allow annular
injection of drilling wastes submitted on 04/15/99.
Please find attached form 10-403 and other pertinent information as follows:
1 . Form 1 0-403
2. Surface Casing Description
3. Surface Casing Cementing Report
4. Casing and Formation Test Integrity Report
5. Detailed Program for Upcoming Operations
6. Proposed CD1-19 Well Suspension Schematic.
If you have any questions or require further information, please contact Brian Robertson
at 265-6034.
Sincerely, , ~. (\"-1
~
lOi .
't
Brian Robertson
Senior Drilling Engineer
cc.
CD1-19 Well File
Sharon Allsup-Drake
Doug Chester
ATO-1054
ANO-382
AHCO I\I:-,:~k;\, (111":, I:,; ;:1 Suh:',;lclldry 01 A¡!:ll\'!lcHkhli(::ir.!Cornp:.1f1Y
(
CD1-19 Suspension Procedure
~
\
1. Notify AOGCC 24 hours in advance of all pressure testing and well suspension
operations. Hold pre-job meeting with all personnel to discuss objectives, as well as
safety and environmental issues.
2. Mobilize and rig up D/S for well P&A operation.
3. Spot a balanced cement plug #1from TD @ 10548'MD to 10000'MD. This will place the
top of the plug 393' MD above the top of the Alpine. Note that the minimum acceptable
coverage of the Alpine is 100' MD. Based on a 9" hole diameter this will be +/- 45 bbls.
P/U 5 stands and circulate the drillpipe clean.
4. WOC. Tag cement plug with 10 Klbs. POH.
5. M/U 4-1/2" tubing kill string (with WEG on the end) and RIH to place the tubing tail at
approximately 2200'. Note, if possible usefYClass II/used tubing.
6. M/U, land and lock down the tubing hanger in the wellhead. Note that the tubing hanger
should have the metal to metal SBMS seals removed (with a spacer between the
elastomeric S seals). Pressure test the S seals to 2000 psi.
7. Pull landing joint. Install the 2-way check valve. Nipple down BOP stack
8. Install the tubing head adapter assembly. Test the tubing head adapter and tubing hanger
seals (from above) to 2000 psi /15 mins. Check that there is no trapped pressure under
the hanger. Pull test plug.
Note: The pop off on the cuttings injection pumps will be set at 1500 psi. Recommended test
pressure on the surface equipment is therefore 2000 psi.
9. Freeze protect the 'dead string' annulus / ID by pumping enough diesel into the annulus to
allow for 1000' TVD of freeze protection. Connect at surface to allow equalization of the
fluid columns. Do NOT pump excess diesel. 1000' TVD of diesel with 9.9 ppa mud is
re~uired to balance the formation pressure at the iniection zone under the casino shoe.
10. Verify surface tubing / 'annulus' pressure. Install the BPV using a lubricator.
11. Ensure all surface valves are in the closed position. Prepare hand over form. RDMO
Doyon 19.
Note: Check for surface pressure prior to rigaina UP on all future well operations (e.g.
cuttinas iniection\. Install BPV's usina a lubricator. Be aware that. with the diesel freeze
protection. the well bore hydrostatic is close to balancing the formation pressures in the
iniection zone beneath the casing shoe.
Note: REQUIRED WELL STATUS ON SUSPENSION
Barriers :
Comment
Kill weight fluid
Diesel plus 9.9 ppg mud
Surface:
Tubing Hanger and BPV (2000 psi tested)
Closed Wellhead and Tubing Head Adapter (2000 psi tested)
Colville River Field t
CD1-19 Temporary Suspension Schematic
Diesel Freeze protection in annulus
and tubing to 1000' TVD,
4-1/2" injection string at +1-
2200' MD (hung off from tubing
hanger)
Injection Zone at +1- 2450' TVD,
9.9 ppg drilling mud in hole
Updated 4/19/99
Plu tagged wI 10 Ibs
R
. ..
. .
.'
I
I
I... .... u......:......:.....,
. .
Wellhead installed with tubing
hanger and SPV set and pressure
~ tested to 2000 psi
16" Conductor to 121'
9-5/8" 36 ppf J-55 STC
Surface Casing
@ 2825' MD / 2393' TVD
cemented to surface
. .
Top of cement plug at 10000'
MD 16708' TVD (+1- 67 deg inc,)
. .
Top Alpine Reservoir at 10393'
MD 16849' TVD (+1- 70 deg inc,)
Well TD at 10548' MD I 6879'
TVD (+1- 75 deg inc,)
(
:(
Casing Detail
9.625" Surface Casing
WELL: CDl-19
DATE: 4-8-99
1 OF 1 PAGES
ARca Alaska, Inc.
Subsidiary of Atlantic Richfield Company
# ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH
TOPS
Doyon 19 RKB to landinQ rinQ = 36,77', RKB to GL = 36,451 36,77
FMC mandrel Hgr 2.34
jts #47-#74 9 5/8", 36#, J-55 BTC 1045,60
9 5/8" TAM port collar 3,00 1084.71
jts#3-#46 9 5/8" 36# J-55 BTC csa 1649.28
95/8" Davis Lvnch Float Collar 1,54 2736.99
its# 1-#2 9 5/8" 36# J-55 BTC csa 85,62
9 5/8" Davis L vnch Float Shoe 1.76
95/8" SET AND CEMENTED @ 2825.91
TD of 12 1/4" Hole 28361.
44 Gemeco Bow Serino CENTRALIZERS
Run centralizers in center of Jts. 1 ,2, over stoP collars
and over casino collars on Jts. 3-13 and over collars of
every 2nd it to surface.
Run 2 Ridged centralizers on jt.# 46& 47.
USE BEST-O-LlFE 2000 DOPE
Remarks: MADE CSG UP WITH +/- 8000 FT /LB TORQUE AND USE API MOD THREAD COMPOUND
Doyon 19
Drilling SupeNisor: MIKE WHITELEY
(
,.¡IJt...
~" ARCa Alaska, Inc.
Cementing Details
Well Name: CD1-19 Report Date: 04109/99 Report Number. 4
Ria Name: Dovon 19 AFC No.: 998b02 Field:
Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: I % washout:
95/8 12,25 2825 2736 ?
Centralizers State type used. intervals covered and spacing
Comments: BOW SPRING - RAN 44 CENTRALIZERS, CENTER OF JTS'1 & JTS'2, OVER CSG COLLARS ON JTS '3 THRU JTS'13 AND OVER
COLLARS ON IVER OTHER JT TO SURFACE.
Mud Weight: PV(prior cond): PV(after con d): YP(prior cond): YP(after cond):
Comments: 9.7 26 17 48 31
Gels before: Gels after: Total Volume Circulated:
45/65 15/25 1500 BBlS
Wash 0 Type: Volume: Weight:
Comments: ARCO 20 8.4
Spacer 0 Type: Volume: Weight:
Comments: ARCO Spacer 50 10.4
lead Cement 0 Type: Mix Wlr temp: No. of Sacks: Weight: Yield:
Comments: ASIII 70 860 10,7 4,4
Additives:
D053 - 30,0%.0046 - 0,6%.0079 -1,5%. l001 - 1,5%. D124 - 50%, D044· 9,0%
Tall Cement 0 Type: Mix Wlr temp: No. of Sacks: Weight: Yield:
Comments: G 70 230 15,8 1,17
Additives:
D046· 0,2%. D065 - 0,3%, S001 - 1%
Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str, WI. Up:
Comments: 9.0 9,0 165K
Reciprocation length: Reciprocation speed: Str. WI. Down:
20' 20FPM 135
Theoretical Displacement: Actual Displacement: Str, WI. In mud:
212 206 86000
Calculated top of cement: CP: Bumped plug: Floats held:
SURFACE Date:4-9-99 YES YES
Time:22"15
Remarks:CIRC 10,8 PPG CEMENT TO SURFACE (270 SX), CEMENT STOOD AT SURFACE.
Cement Company: Rig Contractor: Approved By:
DS DOYON MIKE WHITELEY
CASING TEST and FQRMA TION INTEGRITY TEST
-~
CASING TEST DATA
MINUTES
FOR
CSG TEST STROKES PRESSURE
-----------------------------r----.--------
~::::::::::::::f:::f~~::f:::!~~~=j
t::::::::::::::i:1~È~::i:::~~ª~~:j
L----------m~---~-~!~~--f---~-?~-P.~L-
~--------------t-- : ;i¡;--t---ã~õ-~;}--
t:::::::::::::I=f~~=t:;:~~::
~:=:::::::==~:t~~t4~~i~~!;:
r--------------....-------------....-----------·-
L-------------l.-~-~-~!~~-+-!!~-~~-P-~!-~
L____________j__~_~~!~~_J._!! 19_~J~~U
t:::::::::::~~B~:~~:H~i~¡:j
t::::::::=:::ii~~;È~:H:~~~~~¡:J
L____________j__~_~_~!~~j_!!~40 P_~!.
I 26 stks 2,490 psi
í~-~:õ~~~~t--------------~r~~~;õ~!!r-iE
..----------T-------------.....--------E.:---L
L-~:-º-~~~-l--------------f--------------- -
L_?.:.~_~~~__+______________ _______________ -
t::~fm~t=::::=:=t:::::::=:::::::
I 5.0 min I ' 2,500 psi
..--------------.....--------------..J.-----------.-
I 6.0 min ! I 2,500 psi
¡-- ------ -- -----...--------------...-------------
I 7,0 min I f 2,500 psi
'---------------+-------------- ------------
~--~~Õ-~f~--t--m--m----- -~~~~Õ-~;;-
..--------------....--------------1-------------
i 10,0 min ! 2,490 psi
r--------·-----....--------------I--------------
15.0 min ! 2,480 psi
[g[.Q~!!!iñr~~~~~~~~~~~~~r~~~fº~P-!!~
~-~~:~-~~~-t---------m-l~~~:~~;~-
L_______________--------------_____________._
MINUTES
FOR
LOT STROKES PRESSURE
---------------r---Õ-štï<š-I----õ-pšT----¡
¡-m-----------1---1-Štkš---1----¡õ-¡;š¡----1
¡---------------i---"2-štks --i---:¡¡Õ-p--š¡---f
, , ,
1--------------T--ã-štkš---r-2SÕ_p-š¡---¡
l-m-----------r-~fštks--r36õ_p-š¡--1
'---------------1--------------- 1-----------------,
¡ 5 stks 460 psi
I---------------~--------------~-------------- --
I I 6 stks ¡ 560 psi
'---------------'-------------.,..---------------,
I I 7 stks 630 psi '
I---------------~-------------..:..---------------I'
i I 8 stks i 640 psi
¡--------------¡---g- stks-I--64õ-p_š¡m
1---------------1---iÕ-šik-Š--l--64Õ-P-Š¡---
1--------------~-----------1-------------
i I 11 stks , 630 psi
I---------------l------------r--------~---I
I I 12 stks I 630 pSI ,
1---m---------r13- stkš--r-62ÕpŠ¡---¡
,_______________..____________"'-________________1
1-------m-----l--!~-~!~:!--~---~Q~1?-!!~---1
i---------------~---!~-~!~-!!--J--~Q~1?-!!!.--i
! i 20 stks i 590 psi I
¡---------------r"2s-siiiš--r-S9Õ-pŠr-¡
'---------------~--------------~-----------------t
1_______________L~~.!!~_!._L_~!!~1?_!!LJ
i i 35 stks I 580 psi I
!~~~~~~~=~~~~~~1~~~!~~ik~~t~~~~~isi _~~I
! ! ¡ I
---------------,---------------r---------------,
I I
I--------------l---------------¡---------------¡
LEAK-OFF DATA
Mike Whiteley
Supervisor:
o Initial Casing Shoe Test
o Formation Adequancy for Annular Injection
D Deep Test: Open Hole Adequacy for Higher
4/12/99
Date:
CD1-19
Reason(s) for test
Well Name:
Mud Weight
Casing Size and Description: 9 5/8" 36# J-55 BTC CSG -
Casing Setting Depth 2,825' TMD Hole Depth: 2,856' TMD
2,393' TVD - 2,41.!... TVD
Mud Weight 9.6 PPG Length of Open Hole: 31'
2,800 psi
2.700 psi
2.600 psi
2.500 psi
2.400 psi
2,300 psi
2,200 psi
2,100 psi
2.COO psi
1.900 psi
1.800 psi
1.700 psi
1.600 psi
1.500 psi
1.400 psi
1.300 psi
1.200 psi
1.1 00 psi
l.COO psi
900 psi
800 psi
700 psi
600 psi
SOOpsl
400 psi
300 psi
200 psi
100 psi
o psi
1
630 psi 9,6 PPG
- 0,052 x 2,411'
EMW = 14.6 ppg
TIME LINE
ONE MINUTE m
,/
+ Mud Weight
d Pumped = 3.83
BLED BACK = BBLS
HHHH.t+Á. -...-;f:-i+H.
630
0,052 x 2411
BPS
.101
EMW=
Pump output =
A
I
~
w
0=:
::)
en
en
w
0=:
Q.
SHUT IN TIME I SHUT IN PRESSURE
I------------~--------------,------------·---r
1--.9.:Q-~.!.~--J------------i--~1QJ?-~L-l
i 1.0 min I i 510 psi I
1-------------1---------------1---------------,
I 2.0 min I i 505 psi I
'---------------..---------------..-----------------t
1--~~Õ-~1~--1--------------+--~õ~~~~ml
i---5~õ-miñ-t--------------t-49Õ-p-šr-f
,---------------,---------------,--------------,
I 6,0 min I ! 490 psi I
1--7~Õ-mTñ--r------------T--49Õ-p_š¡--ï
,_____._________.._______________.._________________1
i 8,0 min i i 490 psi
1---- -------- ·--1- -------- ------i--·-·------------I
¡--~.:º-~~--~--------------¡--~~~1?-!!---t'
1__~g.:Q_~J!!.J______________L-~~~.P..!!~___.
NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY
f
JOJO
st st 0 2
k k st st
k k
~ LEAK-OFF TEST
~CASING TEST
LOT SHUT IN TIME
-.- CASING TEST SHUT
~ TIME LINE
50 52 54 56 58 60 62 6!. ~ C>ö IU U. 14 10 IIJ tIU IJ;¿ IJ4 110 IJIJ '>\J '¿ '14 YO
sf
k
IN TIME
st sl st st st st st st st st
kkkkkkkkkk
NOTE: STROKES TURN TO MINUTES DURING IISHUT IN TIMEII:see time line above
sf
k
st
k
st
k
st
k
-
st st sl st st st st sl
kkkkkkkk
STROKES
-
-
-I-
48
st
k
46
st
k
4244
st st
k k
--+-
40
st
k
34 36 38
st st sl
k k k
~
32
st
k
30
st
k
-
-+-
20 22 24 26 28
st st st st st
kkkkk
I
1618
st st
k k
I
o 2 4 6 8 JO 12 14
st st st st st st st st
kkkkkkkk
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Robert Christenson 1.1. ~ DATE: April 11,1999
Chairman ((}JJ-l
THRU:
Blair Wondzell, 4t~~,-
P. I. Supervisor If (l.t'1')Cj
Lawrence M~e
Petroleum Inspector
FILE NO:
armgdkgf. DOC
FROM:
SUBJECT:
BOP Test
Doyon 19
Alpine CD1-19
PTD 99-23
ADril11.1999: I headed out to Alpine to witness a BOP test on Doyon 19,
They were about three hours late as they had some maintenance to do on the
hanger. The rig is still relatively clean and orderly and the crews seemed to be
knowledgeable. The BOP test went across crew change and it was a bumpless
handoff. The only trouble that was encountered was the annular had to be
cycled to get it to hold.
SUMMARY: Witnessed a BOP test on Doyon 19, 0 failures, 4 hours.
Attachments: armgdkgf.xls
cc:
NON-CONFIDENTIAL
( (
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report
Workover: DATE: 4/11/99
Doyon Rig No. 19 PTD# 99-23 Rig Ph.# 263-3000
ARCO Rep.: Mike Whiteley
CD1-19 Rig Rep.: Willingham
Set@ 2,800 Location: Sec. T. 11N R. 5E Meridian Umiat
Weekly - - 350/3500
Other Test Pressures
OPERATION: Drlg: X
Drlg Contractor:
Operator:
Well Name:
Casing Size:
Test: Initial X
.., .,
:::::::::::,::::::::::::¡¡::::::::::::¡¡::::/::::::::::::::¡:/::::¡:::::::::::::::::,::::::::::::rJ;~rr:PAr:A::::::::if::::::::::::::::::::::::::::::::::::::::::::::: ..
.. '" .. .
........ . .
......... .
.. .. ..... ........
. ........... ....
. .... .. :::;:;:;:::;:;:;:;:;:::;:;:;:;:::;:::::;:::;=:::":'"
.... ,.... .
. ....... " .
. . . . . . . . . .
. . . . . . . . , . .
......, .. ,
Test
MISC. INSPECTIONS: FLOOR SAFETY VALVES: Quan. Pressure P/F
Location Gen.: ok Well Sign X Upper Kelly / IBOP 1 350/3500 P
Housekeeping: ok (Gen) Dr!. Rig ok Lower Kelly IIBOP 1 350/3500 P
PTD On Location X Hazard Sec. X .- Ball Type 1 350iJ500 P
Standing Order Pos~ -
X " Inside BOP 1 350/3500 P
BOP STACK: Quan. Test Press. PIF Test
Annular Preventer 1 350fJOOO P CHOKE MANIFOLD: Pressure P/F
Pipe Rams 1 350fJ500 P No. Valves 15 350fJ500 P
Lower Pipe Rams 1 350rJ500 P No. Flanges 38 350rJ500 P
Blind Rams 1 350fJ500 P Manual Chokes 1 Functioned P
Choke Ln. Valves 1 350rJ500 P Hydraulic Chokes --:¡- Functioned -p
- -
HCR Valves 2 350fJ500 P
Kill Une Valves 1 350/3500 P ACCUMULATOR SYSTEM:
Check Valve P System Pressure 3,000 t::
Pressure After Closure 1,550
MUD SYSTEM: Visual Alarm 200 psi Attained After Closure _ minutes .2!L sec.
Trip Tank X X System Pressure Attained 2 minutes 40 sec.
Pit Level Indicators X --X Blind Switch Covers: Mast~ Remote: X
--X 2000-2100-2100-2100 -
Flow Indicator X Nitgn. Btl's:
Meth Gas Detector X --X , Psig.
H2S Gas Detector X --X ""
-
:¡¡¡:::::¡:¡¡¡:::::: :¡¡ ::::: :::::¡¡::¡::::::~/:¡¡::!¡:¡:::::::¡::::::::::::::::¡</::::/:::::¡::::¡::: :::::::¡::¡:::¡:m$tt~~$Q~t:$)::::¡:¡::/::::¡¡:::::::¡:H::::::~:: ::::::¡¡::::::¡::::¡¡:::¡:::¡:¡/:¡:¡¡:¡)::!::¡:¡:::¡T:!¡T::::::: ::::¡¡:¡
Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves tested 21 Repair or Replacement of Failed
Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to
the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687
If your call is not returned by the inspector within 12 hours please contact the P, I. Supervisor at 279...1433
REMARKS:
Distribution:
orig-Well File
c - Oper.lRig
c - Database
c - Trip Rpt File
c - Inspector
STATE WITNESS REQUIRED?
YES X NO
Waived By:
Witnessed By:
Larry Wade
24 HOUR NOTICE GIVEN
YES X NO
FI-021 L (Rev.12J94)
armgdkgf.xls
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
James R. Winegarner, CPL
District Landman
ATO 1496
Phone: (907) 265-6914
Fax: (907) 263-4966
~~
~".
March 24, 1999
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Mr. Bob Crandall
Alaska Oil and Gas Conservation Commission
3001 Porcupine Dr.
Anchorage, Alaska 99501
Fax: (907) 276-7542
Re: Termination of
Request for Exception to 20 AAC 25.055
¿Alpine CDl-l~
Alpine .rleld, .Alaska
Dear Mr. Crandall:
ARCO Alaska, Ine, ("ARCO") applied for an exception to the provisions of 20 AAC 25.055
for the drilling of the Alpine CD 1-19. With the issuance of the Alpine Pool Rules said
exception is no longer needed. Please terminate ARCO's request for exception for CDl-19.
If you have any questions or require any additional information, please call me at 265-6914.
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TONY KNOWLES, GOVERNOR
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ALASKA. OIL A1Q) GAS
CONSERVATION COMMISSION
3001 PORCUPINE DRIVE
ANCHORAGE. ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
March 17, 1999
Doug Chester
Drilling Team Leader
ARCa Alaska, Inc.
p a Box 100360
Anchorage, AK 99510-0360
Re: CDI-19
ARCa Alaska, Inc.
Permit No: 99-23
Sur Loc: 351'FNL, 2447'FWL, Sec, 5, TIIN, R5E, UM
Btmhole Loc, 216'FSL, 2464'FEL, Sec. 20, TI2N, R5E, UM
Dear Mr. Chester:
Enclosed is the approved application for permit to drill the above referenced well,
Annular disposal of drilling wastes will not be approved for this well until sufficient data is
submitted to ensure that the requiremcnts of 20 AAC 25,080 are met. Annular disposal of drilling
waste will be contingent on obtaining a well cemented surface casing confirmed by a valid
Formation Integrity Test (FIT), Ccmenting records, FIT data, and an)' CQLs must be submitted
to the Commission on form 10-403 prior to the start of disposal operations,
Please note that any disposal of fluids generated from this drilling operation which are pumped
down the surface/production casing annulus of a well approved for am1ular disposal on Drill Site
CDI must comply with the requirements and limitations of 20 AAC 25,080, Approval of this
permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000
barrels through the annular space of a single well or to use that well for disposal purposes for a
period longer than one year.
Cement rinseate and clean-up fluids from mud and brine mixing operations at the Alpine mud
plant facility are considered wastes associated with the act of drilling a well and therefore,
authorized for disposal in this and all other wells on Drill Site CD 1 that have Commission
approval to conduct annular disposal opcrations,
ll1e permit to drill does not exempt you from obtaining additional permits rcquired by law from
other governmental agcncies, and does not authorize conducting drilling operations until all other
required permitting determinations are made,
Doug Chester
CD 1-19
2
March 17, 1999
Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035.
Sufficient notice (approximately 24 hours) must be given to allow a representative of the
Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given
by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607.
--
Robert N, Christenson, P.E.
Chainnan
BY ORDER OF THE COM1\1ISSION
dlf/Enc1osures
cc: Department ofFish & Game, Habitat Section wlo encl.
Department of Environmental Conservation wlo encl.
(
STATE OF ALASKA
ALASKA OIL A..~D GAS CONSERVATION COMMISSION
3001 Porcupine Drive
Anchorage Alaska 99501-3192
Re: THE APPLICATION OF ARCO
ALASKA, INC. to classify the Alpine
Oil Pool and establish rules for
development.
) Conservation Order No. 443
)
) Colville River Field
) Alpine Oil Pool
March 15, 1999
IT APPEARING THAT:
1, By letter dated October 9, 1998, ARCO Alaska, Inc. ("ARCO") requested a public hearing
to present testimony to define the Alpine Oil Pool and establish rules for development.
2. The Commission published notice of public hearing in the Anchorage Daily News on
October 16, 1998,
3. A hearing concerning the matter of the applicant's request was convened in conformance
with 20 AAC 25,540 at the Commission's offices, 3001 Porcupine Drive, Anchorage,
Alaska 99501 at 9:00 a,m. on December 3, 1998,
FINDINGS:
1. The Alpine Oil Pool ("AOP") is located adjacent to the National Petroleum Reserve-
Alaska, within the Colville River Delta, on Alaska's North Slope.
2. Working interest owners are ARCO, Anadarko Petroleum Corporation and Union Texas
Alaska, LLC. Landowners are the State of Alaska and the Arctic Slope Regional
Corporation, The owners have agreed to voluntarily integrate their respective interests to
provide for the unitized management, development and operation of the pool under the
Colville River Unit Agreement. ARCO is the operator of the Colville River Unit.
3, The currently known productive limits of the AOP lie entirely within the Colville River
Unit.
4. The AOP was discovered in 1994 with the drilling of the Bergschrund #1 exploratory oil
well. ARCO has subsequently delineated the pool with 11 exploratory wells, two
development wells and a 3-D seismic survey.
5, The AOP may be defined between 6876 feet and 6976 feet measured depth in the
Bergschrund #1 well, which appears to contain a typical and representative stratigraphic
section of the reservoir,
6, The AOP is contained within the Alpine Sandstone.
M:lco443.doc
19, The U,S. Environmental Protection Agency ("EPA"), in compliance with the provisions of
the Safe Drinking Water Act (SDW A), has authorized ARCO to inject non-hazardous
industrial waste through class I injection wells at the Colville Field of the Colville River
18. Calculated water salinity ranges from 15,000 to 18,000 milligrams per liter (mg/l) total
dissolved solids (TDS) throughout the Cretaceous and older stratigraphic section in the
Colville Delta area. Water samples collected from drill stem and production testing of
several wells in the Colville Delta area yielded 18,500 to 24,000 mg/l TDS.
17. Over 1000 feet of shales and siltstones of the Schrader Bluff F onnation will provide an
upper barrier for annular disposal. Marine shales and claystones of the Lower Cretaceous
Torok Fonnation will provide a lower barrier.
16. The intennediate casing annulus of a typical AOP well will be in contact with
approximately 1800 vertical feet of the Upper Cretaceous Seabee Formation, a
predominately mudstone interval with silt and sandstone interbeds. The sandstones are
very tine to tine-grained and range from unconsolidated to consolidated,
15. Typical AOP development wells will have surface casing set in the basal shales of the
Upper Cretaceous Schrader Bluff Fonnation and intennediate casing set in shales of the
Lower Cretaceous Miluveach F onnation,
14. ARCO proposes to dispose of drilling waste in the annuli of wells authorized by the
Commission for that purpose under 20 AAC 25.080,
13, In addition to the AOP, ARCO has identitied several other oil-bearing sandstone intervals
with possible productive potential in the Colville River Delta area. ARCO plans to
evaluate the commercial productivity of these intervals when developing the AOP.
12. None of the stratigraphic and structural discontinuities currently identified in the AOP
appear to have caused any compartmentalization of the reservoir.
11, Faulting currently delineated in the AOP is minor, consisting of several northwest trending,
down the west, normal faults with throws averaging less than 30 feet.
10. No oil-water or gas-oil contacts have been observed to date in the AOP,
9, The AOP appears stratigraphically trapped by pinch-out of Alpine Sandstone into time
equivalent shales of the Kingak Formation.
8, The Alpine Sandstone is an Ellesmerian, shallow marine sand deposited on a southerly
prograding shelf, elongated in an east-west direction. The interval consists of very tine to
fine-grained, moderate to well sorted quartzose sandstone with variable glauconite and clay
content. Bedding is almost horizontal, dipping about one to two degrees to the southwest.
Core porosity and penneability ranges are 15% to 230/0 and 1 to 160 millidarcies,
respecti vel y.
7. The Alpine Sandstone is a Late Jurassic-aged, informal member of the Kingak Formation.
It is stratigraphically the highest sandstone unit within the Kingak Formation in the Colville
Delta area,
Page 2
Conservation Order No 3
Alpine Oil Pool
March 15, 1999
{
~
Conservation Order No. ~....;
Alpine Oil Pool
March 15, 1999
(
Page 3
Unit. (EP A Alpine Class I well pennit, dated February 3, 1999,)
20. Petrophysical analysis indicates that thick sections of the Seabee Fonnation have less
mechanical strength than the basal Schrader Bluff Formation.
21, Data available at this time indicate that annular disposal into the Seabee Formation can
occur in AOP development wells, which have been authorized for that purpose by the
Commission under 20 AAC 25,080, without causing fractures proximal to the surface
casing shoe.
22. Development drilling to the Alpine Oil Pool is projected to begin in the first quarter of
1999. Commercial production is expected to begin in June 2000.
23. ARCO plans to drill a large number of high departure horizontal wells, with interwell
spacing dictated by reservoir perfonnance,
24. ARCO proposes to establish the Alpine Participating Area within the Colville River Unit
next year. ARCO will seek additional pool rules regarding drilling and completion
practices, production practices, reservoir monitoring and other topics, as appropriate,
following the completion of initial development wells and prior to commercial production.
25, Initial reservoir pressure of the AOP is 3175 psig at 6864 feet TVDss. Average reservoir
temperature is 1600 F. Fluid samples indicate the reservoir is undersaturated with a bubble
point pressure of 2454 psig. Solution GOR is 850 SCF/STB. Oil gravity and viscosity at
reservoir conditions are 400 API and 0.46 cp" respectively.
26. Volumetric estimates of original oil-in-place range from 900 to 1100 M:M:STB.
27. ARCO has divided the scope of currently planned AOP development into two phases,
Phase one provides for 50 wells and phase two for 42 additional wells. Under the plan,
total development will include 32 horizontal wells and 60 vertical wells (through the
reservoir), with well spacing of275 acres per horizontal well and 160 acres per vertical
well. ARCO may revise the development plan following assessment of miscible-water-
alternating-gas (MW AG) for EaR throughout the field. Under a revised MW AG
development plan, well spacing could be reduced to 135 acres per well, with as many as
140 wells throughout the field, in order to take full advantage of the MW AG process,
28, ARCO'S plan for secondary oil recovery includes water and gas injection, beginning
concurrently with production startup. ARCO will conduct studies to optimize depletion
plans based on initial production and injection performance, and will consider the viability
of miscible gas injection.
29, ARCO proposes to measure reservoir pressure periodically in injection wells with static
measurements and other industry standard techniques at a datum level of 7000' TVDss.
ARCO does not propose to take pressure measurements in producing horizontal wells
because production models show these wells take an inordinately long period of time to
stabilize.
30. ARCO requests authorization to test production wells less frequently than once per month
as required under statewide regulation, 20 AAC 25,230,
\1:co443.doc
"1: \co44.1.doc
R4E Sections 24, 25, 26, 27, 33, 34, 35, 36.
TI2N
R5E Sections 1,2,3,4,5,6,7,8,9,10,11,12,13,14,15,16,17, 18, 19,20,21,
22, 23, 24,29, 30,
TIIN
R4E Section 1,2,3,4,5,7,8,9,10, 11, 12, 13, 14, 15, 16,21,22,23,24,25,26,
27.
TllN
Umiat Meridian
NOW, THEREFORE, IT IS ORDERED THAT the rules hereinafter set forth, in addition to
the statewide requirements under 20 AAC 25, apply to the following affected area referred to in
this order.
A minimum of two well tests per month will help ensure that accurate well test data is
available for reservoir management and production allocation.
9.
Reservoir pressure should be measured in wells using standard industry practices on a
regular basis to manage production and monitor reservoir perfonnance,
8,
Exception to the gas-oil ratio limitations of 20AAC 25.240 is appropriate provided a
pressure maintenance project is begun within six months of regular production and the
requirements of20 AAC 25.240(c) are met.
7.
The depth and thickness of the proposed receiving zone and confining zone are sut1icient to
demonstrate confinement of drilling waste,
6.
There are no freshwater aquifers in the Colville River Unit. .
5.
Statewide spacing requirements under 20 AAC 25.055, which limit drilling one well per
government quarter section, may not provide adequate flexibility in well locations to
optimally develop the AOP.
4.
Recovery methods to enhance and maximize ultimate recovery from the AOP are currently
being evaluated.
,...,
,).
The Alpine Oil Pool is not completely delineated at this time.
2.
Defining the AOP and establishing rules for initial development is appropriate at this time.
1.
CONCLUSIONS:
32. Reservoir model simulation will be used to allocate production to participating tracts in the
Colville River Unit. Accurate well test data is necessary to calibrate the reservoir model.
31. The Alaska Department of Natural Resources requests that a minimum of two well tests per
month per well be required as the initial testing frequency in order to ensure that the well
tests accurately represent oil, gas and water production rates and production volumes from
the various tracts that comprise the AOP. (Kenneth A. Boyd, letter dated Dec. 16, 1998)
Page 4
Conservation Order No. 3
Alpine Oil Pool
March 15, 1999
¡(
Conservation Order No, 443
Alpine Oil Pool
March 15, 1999
(
Page 5
T12N
R5E Sections 13, 14, 15, 19, 20, 21, 22, 23, 24, 25, 26, 27, 28, 29, 30, 31, 32, 33,
34, 35, 36.
Rule 1 Field and Pool Name
The field is the Colville River Field. Hydrocarbons underlying the affected area within the
defmed pool interval of the Kingak Formation constitute a single oil and gas reservoir called the
Alpine Oil Pool.
Rule 2 Pool Definition
The Alpine Oil Pool is defined as the accumulation of hydrocarbons common to and correlating
with the interval between the measured depths of 6876 feet and 6976 feet in the Bergschrund
No, 1 well.
Rule 3 Well Spacing
Development wells may not be completed within 500 lineal feet of another Alpine Oil Pool
development well nor closer than 500 feet from the exterior boundary of the affected area.
Rule 4 Drilling and Completion Practices
(a,) After drilling no more than 50 feet below a casing shoe set in the Alpine Oil Pool, a
formation integrity test must be conducted. The test pressure need not exceed a
predetermined pressure.
(b.) Casing and completion designs may be approved by the Commission upon application and
presentation of data that demonstrate the designs are appropriate and based upon sound
engineering principles.
(c.) Permit(s) to Drill deviated wells within the Alpine Oil Pool shall include a plat with a plan
view, vertical section, close approach data and a directional program description in lieu of
the requirements of20 AAC 25.050(b).
(d.) A complete petrophysical log suite acceptable to the Commission is required from below
the conductor to TD for at least one well on each drilling pad in lieu of the requirements of
20 AAC 25.071(a). The Commission may, in its discretion, require additional wells on a
pad to be logged using a complete petrophysical log suite.
Rule 5 Automatic Shut In Equipment
(a.) All production wells must be equipped with a fail-safe automatic surface safety valve
(SSY) and a surface controlled subsurface safety valve (SSSY),
(b.) Injection wells must be equipped with a double check valve arrangement.
(c,) Safety Valve Systems (SYS's) must be tested on a six-month frequency. Sufficient notice
must be given so that a representative of the Commission can witness the tests,
(d,) Subsurface safety valves may only be removed after demonstrating to the Commission that
the well is not capable of unassisted flow of hydrocarbons, Sufficient notice must be given
so that a representative of the Commission can witness the tests.
M:\co443.doc
M:\co441.doc
(a.) All wells must be tested at least twice per month.
(b.) The operator shall optimize stabilization and test duration of each test to obtain a
representative test.
(c.) The operator shall record well and field-operating conditions appropriate for maintaining an
accurate field production history.
(d,) The operator shall install and maintain test separator meters and gas system meters in
conformance with the API Manual of Petroleum Measurement Standards.
(e.) The operator shall maintain records to allow verification of approved production allocation
methodologies.
Rule 9 Well Testing
(a.) Progress of enhanced recovery project(s) implementation and reservoir management
summary including engineering and geotechnical parameters.
(b.) V oidage balance by month of produced tluids and injected fluids,
(c.) Analysis of reservoir pressure surveys within the pool.
(d.) Results and where appropriate, analysis of production log surveys, tracer surveys, and
observation well surveys.
(e.) Future development plans
A surveillance report is required after one year of regular production and annually thereafter. The
report shall include but is not limited to the following:
Rule 8 Reservoir Surveillance Re£ort
Wells producing from the Alpine Oil Pool are exempt from the gas-oil-ratio limits of 20 AAC
25.240(b) so long as the provisions of20 AAC 25.240(c) apply.
Rule 7 Gas-Oil Ratio Exem£tion
(a.) Prior to regular injection. an initial pressure survey shall be taken in each injection well.
(b,) A minimum of six bottom-hole pressure surveys shall be measured annually, Bottom-hole
surveys in paragraph (a) may fulfill the minimum requirement.
(c,) The reservoir pressure datum shall be 7000 feet TVD subsea.
(d.) Pressure surveys may consist of stabilized static pressure measurements at bottom-hole or
extrapolated from surface. pressure fall-off, pressure buildup, multi-rate tests, drill stem
tests, and open-hole formation tests,
(e.) Data and results from pressure surveys shall be reported annually on Form 10-412,
Reservoir Pressure Report. All data necessary for analysis of each survey need not be
submitted with the Form 10-412 but shall be made available to the Commission upon
request.
(f.) Results and data from special reservoir pressure monitoring tests or surveys shall also be
submitted in accordance with part (e) of this rule.
Rule 6 Reservoir Pressure Monitoring
Page 6
Conservation Order No, .-:-3
Alpine Oil Pool
March 15, 1999
~
Conservation Order No. '~43
Alpine Oil Pool
March 15, 1999
Page 7
Rule lO Administrative Action
Upon proper application or its own motion, the Commission may administratively waive the
requirements of any rule stated above or administratively amend this order as long as the change
does not promote waste, jeopardize correlative rights, or compromise ultimate recovery and is
based on sound engineering principles.
DO NE at Anchorage, Alaska and dated March 15, 1999.
d38~
Robert N, Christenson, P.E., Chainnan
r _ '
~~~.'
Camillé Oechsli, Commissioner
AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person atIected by it may tile
with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following
the date of the order, or next working day if a holiday or weekend, to be timely tiled. The Commission shall grant or refuse the
application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day
period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an
order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for
rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which
the request is deemed denied (i.e., 10th day after the application tòr rehearing was filed).
M:\co443.doc
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ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
James R. Winegarner, CPL
District Landman
ATO 1496
Phone: (907) 265-6914
Fax: (907) 263-4966
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March 11, 1999
Hand Delivered
Mr. Robert N. Christensen, Chainnan
Alaska Oil and Gas Conservation Commission
3001 Porcupine Dr.
Anchorage, Alaska 99501
Re:
RequesiillfOr E tion to 20 AAC 25.055
Alpine
Colville Iver Unit, Alpine Field, Alaska
Dear Chainnan Christensen:
ARCO Alaska, Inc. ("ARCO") hereby applies for an exception to the provisions of 20 AAC
25.055 for the drilling of the Alpine CDI-19 (the "Well"). The Well will be drilled as a
directional hole having the following locations:
Surface Location:
Target Location:
Bottomhole Location:
351' FNL, 2447' FWL, Section 5, TIIN, R5E, UM;
1287' FSL, 236' FEL, Section 29, TI2N, R5E, UM;
216' FSL, 2464' FEL, Section 20, TI2N, R5E, UM.
The Well is located on ADL-25538, ADL-25558, and ADL-25559 which are owned by ARca
(56%), Anadarko Petroleum Corporation (22%) and Union Texas Petroleum Alaska
Corporation (22%).
The attached Exhibit 1 shows the location of the Well and all other adjoining governmental
quarter sections and wells. There are no other completed or drilling wells on the property.
The names and addresses of all owners and operators of the governmental quarter sections
directly and diagonally offsetting the Well are set forth in the attached Exhibit 2. Included
in the attached Exhibit 3 is the verification required by the referenced provisions, a copy of
the notice sent to the other owners listed in Exhibit 2, and the date such notice was mailed.
If you have any questions or require any additional infonnation, please call me at 265-6914.
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EXHIBIT "1"
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Well Name: Alpine CD1-19
Suriace Location: 351' FNL, 2447' FWL,Sec. 5, T11N, R5E, UM
Target Location: 1287' FSL, 236' FEL, Sec. 29, T12N, R5E, UM
Bottomhole Location: 216' FSL, 2464' FEL, Sec. 20, T12N, R5E, UM
Scale: 1" = 2,000' 3-8-99 99030801AOO
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EXHIBIT 2
List of all owners and operators of governmental quarter sections directly and diagonally offsetting
the Alpine CDI-19 well.
Operator:
ARCO Alaska, Inc.
P.O, Box 100360
Anchorage, AK 99501-0360
Non-Operators:
Anadarko Petroleum Corporation
Post Office Box 1330
Houston, TX 77251-1330
Attn: Mr. Todd L. Liebl
Union Texas Alaska, LLC
700 G Street
Anchorage, AK 99501
Attn: Mr. James M. Ruud
Royalty:
State of Alaska
Department of Natural Resources
Division of Oil and Gas
3601 C Street, Suite 1380
Anchorage, AK 99503-5948
Attn: Mr. Ken Boyd
Overriding Royalty:
Chevron USA Inc,
P.O. Box 1635
Houston, TX 77251-1635
(
~,
EXHIBIT 3
TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION
Before the Commissioners of the
Alaska Oil and Gas Conservation
Commission in the Matter of the
Request of ARCO Alaska, Inc. for
an Exception to the Provisions
of 20 AAC 25.055 for ARCO
Alpine CD1-19
STATE OF ALASKA
VERIFICATION OF FACTS AND
AFFIDAVIT OF JAMES R.
WINEGARNER
§§
THIRD JUDICIAL DISTRICT
James R. Winegarner, being first duly sworn, upon oath, deposes and states as follows:
1.My name is James R. Winegarner, I am over 19 years old and have personal
knowledge of the matters set forth herein.
2, I am a District Landman for the well operator, ARCO Alaska, Inc. ("ARCO"),
3. I am acquainted with the facts associated with the drilling of Alpine CD1-19.
4. I have reviewed the application submitted for the exception to 20 AAC 25.055.
To the best of my knowledge and belief all facts therein are true and accurate.
5. I have reviewed the plat attached as Exhibit "1" and it correctly portrays
pertinent and required data,
6. Pursuant to 20 AAC 25.055 (b), ARCO, the well operator, prepared a Notice of
Request for Exception to the Provision of 20 AAC 25,055. A copy of this notice is attached
hereto.
7. On March 11, 1999, pursuant to 20 AAC 25,055 (b), ARCO sent a copy of said
notice by certified mail to the last known address of all owners and operators of governmental
quarter sections directly and diagonally offsetting the governmental quarter section of the
proposed location of ARCO's Alpine CD1-19. These names and addresses are set forth on
Exhibit 2 attached to ARCO's Request for Exception to Provisions of 20 AAC 25.055 dated March
11, 1999.
Subscribed and sworn to this March 11, 1999,
STATE OF ALASKA
THIRD JUDICIAL DISTRICT
This instrument was acknowledged before me this Mar: h 11, 1999, by James R, Winegarner.
~~~4~~
Notary ~ubiic, State of Alaska
My Commission Expires: ~ /e¿ /99
. I
State of Alaska
NOTARY PUBLIC
Kay H. La Bau
My Commission expires 8-8-99
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ARca Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
James R. Winegarner, CPL
District Landman
Land Department, ATO 1496
Phone (907) 265-6914
Fax: (907) 263-4966
~~
~".
March 11, 1999
CERTIFIED MAIL
Mr. Ken Boyd, Director
Department of Natural Resources
Division of Oil and Gas
550 West 7th Ave., Suite 800
Anchorage, AK 99501-3510
Anadarko Petroleum Corporation
Post Office Box 1330
Houston, TX 77251-1330
Attn: Mr. Todd L. Liebl
Chevron USA Inc,
P,O. Box 1635
Houston, TX 77251-1635
Attn: Todd Kratz
Union Texas Alaska, LLC
700 G Street
Anchorage, AK 99501
Attn: Mr. James M, Ruud
Re: Notice of Request for Exception to the
Provisions of 20 AAC 25.055
Alpine CDl-19
Colville River Unit, Alpine Field, Alaska
Pursuant to the provisions of 20 AAC 25.055 (b), ARCO hereby gives notice of a request to the
Alaska Oil and Gas Conservation Commission ("AOGCC") for an exception to the well spacing
requirements of 20 AAC 25.055 for the drilling of the Alpine CD 1-19, Alpine Field, Alaska,
ARCO's request, if approved, will permit the drilling of the Alpine CD 1-19 as a directional hole
having the following locations:
Surface Location:
Target Location:
Bottomhole Location:
351' FNL, 2447' FWL, Section 5, TIIN, R5E, UM;
1287' FSL, 236' PEL, Section 29, TI2N, R5E, UM;
216' FSL, 2464' PEL, Section 20, TI2N, R5E, UM,
The Well is located on ADL-25538, ADL-25558, and ADL-25559 which are owned by ARCO (56%),
Anadarko Petroleum Corporation (22%) and Union Texas Petroleum Alaska Corporation (22%).
Please do not hesitate to contact me with any questions you may have,
.......
ARca Alaska, Inc. Is a Subsidiary of AtlantlcRlchfleldCompany
~~~
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FROM: R
FRX NO.: 9072634966
03-24-99 03:54P P.01
ARca Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
James Fl. Wlnøgarner, CPL
District Landman
ATO 1496
Phone: (901) 265006914
F8X~ (907) ~63-4966
~~
~"'"
March 241 1999
Mr. Bob Crandall
Ala~ka Oil and Gas Conservation Commission
300 1 Porcuptne Dr.
Anchorage, Alaska 995Q I
Fax: (907) 276·7542
Re;
Termh.atioh of
Request for Excepti,on to 20 AAC 25.055
Alpine CD1..19
Alpine Field, Alaska
RECEIVED
MAR 2 4 1999
A!~ "",, !,
......,¡I\.d v¡j ~ l¡d.;j GUliS. Commission
Anchorage
Dear Mr. Crandall:
ARca Alaska. Inc. (" ARCO") applied for an exception to the provisions of 20 AAC 25.055
for the drilling of the Alpine CD 1-19. With the i~~oance of the Alpine Pool Rules said
exception is no long needed. Please terminate ARCQ' s r~quc~t fot" exception for CD 1 19.
If you have any questions or require any additional jnfonnation, please call me ¡It 265-69 t 4.
(
ARCO Alaska, Inc.
Post Office Box 1 û0360
Anchorage Alaska 99510-0360
Telephone 907 276 1215
~~
~".
March 09, 1999
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Re: Application for Permit to Drill
CD1-19
Dear Sirs:
ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from
the Alpine CD1 drilling pad. The intended spud date for this well is March 20, 1999. It is
intended that Doyon Rig 19 be used to drill the well.
The well will be drilled to horizontally penetrate the Alpine reservoir. It is intended that
operations on this well be split into two distinct phases. The first visit by the drilling rig
will drill the well down to the 7" intermediate casing point. The well will then be
suspended and the rig moved onto other operations. At a later date, estimated at March
2000, the rig will return and the horizontal reservoir leg will be drilled prior to completion.
Upon completion, the well will be closed in awaiting field start up.
Please find attached the information required by 20 ACC 25.005 (a) and (c) for you
review. Pertinent information attached to this application includes the following:
1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a).
2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1).
3. Plat, identifying the property and location of the proposed CD1-19 well.
4. A proposed drilling program, including a request for approval of annular pumping
operations.
5. A drilling fluids program summary and description of the drilling fluids handling
system.
6. Proposed suspension diagram.
7. Proposed completion diagram.
8. Pressure information as required by 20 ACC 25.035 (d)(2).
9. Proposed cementing program and calculations.
10. A diagram and description of the BOP equipment as required by 20 ACC 25.035 (a)
(1 ).
11. A diagram and description of the diverter equipment as required by 20 ACC 25.035
(b).
12. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b
No over-pressured strata are predicted for well CD1-19. Prediction of over-pressured
strata as required by 20 ACC 25.033 (e), was fully covered under the drilling permit
submission for well CD1-22, dated December 19, 1997.
Seismic refraction and reflection analysis, as required by 20 ACC 25.061 (a), was
submitted under the drilling permit submission for well CD1-22.
Please note, ARCO does not anticipate the presence of H2S in the formations to be
encountered in this well. However, there will be H2S monitoring equipment operating on
well CD1-19.
ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company
AR3B-6003-C
( l
If you have any questiolls or require further information, please\JUfltact Brian Robertson
at 265-6034 or Doug Chester at 263-4792.
Sincerely,
/.) 0 ),ðf'^ /
'\?¥
Brian Robertson
Senior Drilling Engineer
Attachments
cc:
CD1-19 Well File
Doug Chester
Sharon Allsup-Drake
Mike Erwin
Lanston Chin
AND 382
ATD 1054
AND 384
Kuukpik Corporation
;(
1a. Type of Work Drill X Redrill '1b Type of Well Exploratory Stratigraphic Test Development Oil X
Re-Entry Deepen Service Development Gas Single Zone X Multiple Zone
2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool
ARCO Alaska, Ine, DF57' feet Colville River Field
3. Address 6. Property Designation .2...S' S' 5 ç;_ Alpine Oil Pool
P, 0, Box 100360, AnehoraQe, AK 99510-0360 ADUé559, ~ /J/y
4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025)
351' FNL, 2447' FWL, See,5, T11 N, R5E, UM Colville River Unit Statewide
At top of productive interval (@ TARGET) 8. Well number Number
1287'FSL,236'FEL,See,29, T12N, R5E,UM CD1-19 #U-630610
At total depth 9. Approximate spud date Amount
216'FSL,2464'FEL,See,20,T12N, R5E,UM 3/20/99 $200,000
12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD)
Property line Alpine CD1-22 15,473' MD
Crosses line feet 30' @ 100' feet 2560 6,802' TVD feet
(T11 N to T12 N)
16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2))
Kickoff depth 300' feet Maximum hole angle 95° Maximum surface 2402 psig Allolal deplh (TVD) 321 5 at psig
7000'
TVD.SS
18. Casing program SettinQ Depth
size Specifications Top Bottom Quantity of cement
Hole Casing Weight Grade Couplina Lenath MD TVD MD TVD (include staQe datat
42" 16" 62.5# H-40 Weld 84' 37' 37' 121' 121' Pre-installed
12,25" 9,625" 36# J-55 BTC 2831' 37' 37' 2868' 2407' 410 Sx Aretieset III L &
230 Sx Class G
8.5" 7" 26# L-80 BTC-M 10666' 37' 37' 10703' 6817' 170 sx Class G
N/A 4,5" 12,6# L-80 IBT-M 1 051 6' 37' 37' 10553' 6829' Tubinq
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured feet Plugs (measured)
true vertical feet OR\G\NAL
Effective depth: measured feet Junk (measured)
true vertical feet
Casing Length Size Cemented Measured depth True Vertical depth
Structural '[J
Conductor
Surface
Intermediate
Production
Liner
Perforation depth: measured ('.n' :, :rW) 'i. '.; ,~¡ fj r'
true vertical ;r~ . ".",0
';\~'" ,h -I ~~. h .:~\ It ~;~ ¡.r'~ ':'~:',
20. Attachments Filing fee X Property plat X BOP Sketch X Diverter Sketch X . " . ~ '. Drilling program X
Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X
21. I hereby ce~ 1hat the foregoing is true and correct to the best of my knowledge 7/e¡ J?9
Signed A '-W cl. 5/.., Title Drilling Team Leader Date
V vvv v'"
// Commission Use Only I ,
per~~~~e~ ~ I API number <; £f I APprov~~ate g ,,(.~ c: See cover letter for
50- /ð'? - ¿OZ- .' --I 7 -, Other requirements
Co~ditions of approval Samples required Yes @ Mud log required Yes ~
Hydrogen sulfide measures Yes ® Directional survey required @ No
Required working pressure for BOPE 2M @ 5M 10M 15M
Other:
ORIGINAL SIGNED· BY
Robert N. Christenson by order of ''3 -¡ [) {" 9
Approved by Commissioner the commission Date "'-.00 .- 1
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
Form 10-401 Rev. 7-24-89
Submit in tnplicate
ARca Alaska, Inc. ~ j
a.c.tdIry rI £~ld~ri
EXHIBIT "1" ( CONFIDENTIAL
Well Name: Alpine CD1-19
Surface Location: 351' FNL, 2447' FWL,Sec. 5, T11N, R5E, UM
Target Location: 1287' FSL, 236' FEL, Sec. 29, T12N, R5E, UM
Bottomhole Location: 216' FSL, 2464' FEL, Sec. 20, T12N, R5E, UM
Scale: 111 = 2,000' 3-8-99 99030801AOO
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Mar-D2-99 1'6:42 ' Frem-DOYON RIG lî
ALPINE FACILITY
VICIN "fY MAP
I
,
NOT TO SCALE
/
1 0
30°2
50°'4
70°6
90°8
11 0 °10
130°'2
150°14
~··17 016
/ 190 O~8
210°20
/ (Typ.) / 230-22
Not To Scale / 1 o~~ 250024
/' 'tð".,270 026
290028
31 0030
.'530032
.350034
370036
.:590 0 :SB
410 °40
430042
450 °44
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/
/
/
/
/
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9~'/
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LEGQI!L
. EXISTING CONDUCTORS
o NEW CONDUCTOR LOCA TJON
/
"
/
'"
/
~ LOUNSBURY
&: ASSOCIATES, INC4
E~NEERS PLANNERS SURVEYORs
"
/
ARca Alaska, Inc. ~~
Subsidiary of Atfantic Richfield Company
CACD FILE NO. DRAWING NO:
LK660D45
ALPINE PROJECT
CD1 WELL CONDUCTORS
AS-STAKED LOCATIONS
SHEET: REV:
SK 6.60 - d45 1 OF ;3 0
Uar-02-99 16:42
From-DOYON RIG 1l +901-263-3140 .,
] ilf
. ~ .
ALl. CONDUCTORS ARE LOCATED IN SEC 5f T- 11 ~t R 5 Et UMIAT MERIDIAN
See Une O/S
T-991 P.04
F-692
Well ry' ·X' Let. (N) Lona. (W) FNL FWL Gnd Pad
CD1-1 5.975.905.0 386.000.0 70· 20' 34.92" , 50· 55· 30.8711 222· 2.572' 1.3.0' 19.5'
CD' - 2 5 975 897.9 385.992.9 70· 20' .34.85" 150· 55· 31.07·' 229' 2565' 1.3.0' 19.51
CD' -3 5.975 890.9 385.985.9 70· 20' .34.78" 150· 55· 3' .27'· 236· 2 558· 1 3. 1 ' 19.5·
CD' -4 5.975 883.8 385.978.8 70· 20' 34.71·' '50· 55' 31.48" 243' 2.551 " 13.2' 19.5·
CD1- 5 5.975 876.7 385.971.7 70· 20f 34.64B 150· 55' 31.58'· 25'- 2 544· 13..3· 19.5"
CD1....6 5 975.869.6 385L964.6 70· 20' 34.57" , 50· 55· 31.88" 258' 2 537· 13.41 19.5'
CD' - 7 5.975 862.6 385.957.6 70· 20' 34.50" 150· 55' 32.09" 2S5· 2.530" 1.3.3· 19.5'
CD' -8 5.975.855.5 385.950.5 70· 20' 34.43" 150· 55' 32.29" 272" 2.523· 13.2' 1 9.5f
CD' -9 5 975.848.4 385.943.4 70· 20' 34.36" , 50" 55' 32.49" 279' 2 51 7· 13.1 ' 19.5'
CD1....10 5 975.841.4 385.936.4 70· 20' 34.2911 150· 55' .32_70" 286" 2.510' 1.3.0· 19.5"
CD 1 -" 5.975 834.3 l3B5.929.3 70· 20· 34. 22~' 150· 55' 32.90° 294' 2.503' 12.9' 19.5'
CD1-12 5.975 827.2 385.922.2 70· 20' .34.15- 150· 55' 33.1 au 301' 2.496 ' 12.8' 19.5·
CDl-13 5.975.820.1 385.915.1 70· 20' .34.08- 150· 55' 33.31" 308' 2.489' 12. 7' 19.5·
CD1-14 5.975.81.3.1 385.90B.' 70· 20' 34.00" 150" 55' 3.3.51" 315' 2.482' 12.6' 19.5'
CD1-15 5.975.806.0 385.901 .0 70· 20' 33.93" 150· 55' 3.3.72- 322' 2.475' 1 2.51 19.5'
CDl-16 5.975.79B.9 385.89.3.9 70· 20' 33.86" 150· 55' 33.92- .330· 2.468' 12.4' 19.5·
CD1-17 5.975 791.9 385,886.9 70· 20' 33.79" '50· 55' 34.12" 337' 2.461· 12.3· 19.5'
C01"1a 5.975 784.8 385,879.8 70·' 20' 3.3.72M '50· 55' 34.33" 344" 2.454' , 2.2' 19.5'
CD1-19 5.975.777.7 .385.872.7 70· 20' 33.85-- 150· 55' 34.53" .351' 2 447' 12.1 ' 19.5'
CD1-20 5.975. 77C. 7 385,865.7 70· 20' 33.58N 150· 55' 34.73- 358' 2.440' 12:0' 19.5'
CD1- 21 5.975.763.6 3B5.B5B.6 70· 20· 33.51" 150· 55' 34.94" 365' 2.433' 11.9· 19.5"
·CD1-22 5.975.756.46 385 851.10 70· 20' 33.440" 150" 55' 35.151" 37.31 2.426' 11.9' 19.5'
CO 1 - 23 5.975.749.4 385.844.4 70· 20' 33.37" 150· 55' 35..34" 3ao' 2.419' '12.0' 19.5·
CD1-24 5.975.742.4 .385.B37.4 70·' 20' 33.3Qu 150· 55' 35.55" .387' 2.412' 12.2' 19.5'
CD1-25 5.975.735..3 385.B30.3 7D· 20' 3.3.2.3- 150· 55' 35.7511 394' 2.405 ' 1 2.4' 19.5'
CD1-26 5.975 728.2 385.B23.2 70· 20' 33.16" 150· 55' 35.95" 4011 2.398' 12.8' 19.5'
CD1-27 5.975.721.2 385.816.2 70· 20f .13.Ô9" 150· 55' .36.16"' 408' 2..3911 12.a' 19.5'
CD1-2B 5.975.714.1 385.809.1 70· 20' 336D2" 150· 55' 36..36" 416' 2..384' 13.0' 19.51
CD1-29 5.975 707.0 385.802.0 70· 20' 32.95" 150· 55' 36.56" 423' 2.377· 13.2' 19.5'
CD1-JO 5.975.699.9 .385,794.9 70· 20' .32. aall 150" 55" 36.77" 430' 2.370' 13.4' 19.5'
CD1-.31 5.975.692.9 385.787.9 70· 20' 32.80" , 50· 55' 36697'" 4.37' 2.363' 13.3' 19.5'
CD1-32 5.975 685.8 385.780.8 70· 20' 32.7.3- 150· 55' 37.17" 444' 2.356' 13.2' 19.5'
CD 1 - 33 5 975.678.7 385__77.'3.7 70· 20' .32.66R 150· 55' 37..38" 452' 2..349' 13. 1 " 19.5·
CD1-34 5.975.671.7 .385.766.7 70· 20· 32.59B 150· 55' 37.58- 459' 2.342" 13.0' 19.5"
CD 1- 35 5.975 664.6 385.759.6 70· 20' 3~t52" 150· 55' .37.78" 466' 2..335' 12.9' 19.5·
CD1-J6 5 975.657.5 385 752.5 70· 20' 32.45" 150· 55' 37.99'" 47.3' 2.328' 12.8" 19.5'
CD1-37 5.975.650.4 385. 745.4 70· 20' 32.38" 150· 55' 38.19B 480' 2.321· 12. 7· 19.5'
CD 1 - 38 5-975.643.4 385.738.4 70· 20· 32..31 N 150" 55" .38.394' 487' , 314' 12.6' 19.5'
CD 1- 39 5 975.636.3 385__731.3 70· 20' 32.24" 150· 55' 38.60" 495' 2 307' 12.5' 19.5'
CD1-40 5 975.629.2 .385 724.2 70· 20· 32.17" 150· 55' 38.80- 502' 2 300' 12.4' 19.5'
CD1-41 5.975.622.2 .385,717.2 70· 201 32.10" 150· 55' 39.00P 509' 2.293' 12..3" 19.51
CD1 -42 5.975.615.1 385. 71 O. , 70· 20' 32.03" 150· 55' 39.21 fI 516' 2.286' 12.2' 19.5·
CD1....43 5.975.608.0 385.703.0 70· 20' 31.96- 150· 55' .39.41N 5231 2.279' 12.1' t 9.5'
CD 1 - 44 5.975.600.9 .385.695.9 70· 20' 31.89" '50· 55' 39.61 b 531' 2.272' 12.0' 19.5'
CD1-45 5.975.59.3.9 J85L688.9 70· 20· .31.B2R '50· 55' 39.8211 538' 2.2ô5' 12.01 19.5'
· CD1-22 CONDUCTOR WAS AS-BUILT 2/11/98.
Øl LOUNSBURY
& ASSOCIATES, INC.
ENCINURS fUNNERS SURVEYORS
""
..._ _~....u _.__
-I
ARca Alaska, Inc. <>
Subsidiary of Atlantic Richfield Company
CAëD fiLË NO. rDRAWlNC NO:
.;(;f;I'ltt,; I
ALPINE PROJECT
CD1 WELL CONDUCTORS
AS-STAKED LOCA~ONS
\I~ 6.60 ~"d45·"--· .·.-'-lsH.~~~~~..ºf J-·.I.·REV:~t
, ..._ _._.._ . . "._ ., ., .", .
Mar-02-99 16:42 '
I I
From-DOYON RIG tr
I I I ~
+901-263-3140
I I I ~.
T-991 P,05
I I
F-a92
NOTES
1. THIS DRAWING SHOWS THE LOCATIONS FOR A TOTAL OF 45 CONDUCTORS.
CD1-22 WAS INSTALLED AND DRILLED IN MARCH, 1998.
2. CELLARS ARE IN PLACE AT THE TIME OF THE ISSUANCE OF THIS DRAWING.
REFERENCE F'OINTS ARE IN PLACE FOR ALL CONDUCTORS AND
ASSISTANCE WILL 8E GIVEN BY LOUNSBURY & ASSOCIATES IN ALIGNING
THE KELLY BAR FOR CONOUCTOR DRILLING OPERA TJONS AS NEEDED.
.3. ALL COORDfNA rES ARE ALASKA STATE PLANE, ZONE 4, NAD 27.
4. ELEVATIONS ARE BRITISH PETROLEUM MEAN SEA LEVEL.
.ORICINAL GRpUND ELEVATIONS ARE INTERPOLATED FROM MICHAEL BAKER JR.
DWG. CE--CD10-102, SHT 1, REV.. O.
5. BASIS OF LÓCA -nON AND ELEVA nON ARE TEMPORARY ALPINE MONUMENTS
.3 &: 1 BY LOUNSBURY &: ASSOCIATES.
~ LOUNSBURY
& ASSOCIATES, INC.
~N1ŒRS PLANNERa $URVBYOaS
ARca Alaska, Inc. <~
Subsidiary of Atlantic Richfield Company
C^D~K~~~~5 2/16/99 I DRA\\1NG NO:
ALPINE PROJECT
CD1 WEJ.L CONDUCTORS
AS-STAKED LOCA1l0~S
NSK 6.60 -- d45 , SHEET: J OF .3 I REV: 0
Alpine: CD1-19
PROPOSED DRilLING PROGRAM
f
(
Procedure
1. Move in drilling rig. Install diverter and function test. (16" conductor pre-installed)
2. Drill 12 1/4 inch hole to the surface casing point as per the directional plan.
3, Run and cement 9 5/8 surface casing,
4. Install and test BOPE to 3000 psi.
5. Pressure test casing to 2500 psi.
6. Drill out 20' of new hole, Perform leak off test.
7. Drill 8 1/2 hole to the intermediate casing point in the Alpine Reservoir. Note LWD will be run over this
section.
8. Run and cement 7 inch casing as per program. Displace cement with brine. Top of cement 500 feet above
Alpine reservoir as per Rule 20 AC 25.030. Freeze protect casing annulus and casing.
9. Suspend well and move off rig.
10. Move in drilling rig. Install and test BOPE to 3500 psi.
11. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test.
12. Drill 6 1/8" horizontal section to well TO.
13. Contingency - set ECP scab liner or slotted liner if required (due to unconsolidated formation or wellbore
having moved out of the Alpine reservoir sand). - See Note 1.
14. Displace well to weighted brine and pull out of hole.
15. Run liner hanger (without liner) with flapper valve and 2 7/8" displacement string. Displace horizontal section
to diesel. POH.
16. Run 4 V2, 12.6 #, L-80 tubing and sting into liner hanger. Freeze protect completion with diesel.
17. Test tubing and tubing-casing annulus separately to 3500 psi.
18. Nipple down BOP,
19. Nipple up x-tree. Pressure test to 5000 psi.
20. Set BPV and secure well.
21. Move rig off.
Note1: The Alpine development wells will have open hole completions. Rock mechanic studies have indicated that
there is sufficient rock strength to maintain wellbore stability throughout the life of the well. However this assumes
that a. the 6-1/8" horizontal well stays within the sand section over it's full length and b. the well does not cross any
weaker formations (e.g. faulted or fractured zones). In the event that the conditions described in either a. or b. are
seen while drilling the horizontal section, it will be necessary to cover these sections. The proposed method for
doing this is utilizes a 'scab' ECP liner assembly. The assembly will consist of ECP's (open hole packers) to anchor
the assembly and provide formation isolation plus the necessary length of 4 V2" tubing to span the weak zone.
Well Proximitv Risks:
(
('
Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in
following attachments. CD1-22 will be the closest well to CD1-19 (30' at surface from the proposed well
path). The only other well in the area at the time of drilling will be WD-2 (389' at 2800').
Drillina Area Risks:
There are no high-risk events (e.g. overpressured zones) anticipated in well CD1-19.
The surface hole is extremely soft and unconsolidated. CD2-35 encountered tight hole problems during a
wiper trip at section TD (worst around the base of the West Sak). Drilling practices will be modified to
ensure that hole cleaning is optimized.
The proposed annular injection zone at 2450' TVD may be gas bearing. On the offset wells, mud weights in
the range of 9,6 - 10 ppg have always been sufficient to provide only minor surface gas readings. The mud
weight will be 9.6 ppg before drilling out of the shoe.
Lost circulation : Mud losses within the Alpine reservoir have been recorded in some offset wells. Faulting
within the reservoir is considered to be the most likely reason for these losses having been encountered.
Although no faults in the vicinity of the CD1-19 well path have been identified, it is recognized that sub-
seismic faulting may still be present. An addition of loss circulation material to the drilling fluid has cured
past losses. Good drilling practices will be stressed to ensure that mechanically induced losses are kept to
a minimum.
Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally
as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed
kicks.
There is potential for differential sticking in the reservoir. The BHA design and 9.2 ppg mud weight have
been developed to minimize this potential. However vigilance through careful adherence to the directional
plan will be required to ensure that wellbore geometry does not aggravate the potential for differential
sticking.
Annular PumpinQ Operations:
Incidental fluids developed from drilling surface and intermediate hole on well CD1-19 will be hauled to the
Class II injection facility on 1 R pad of the KRU. After the rig returns to drill the 6-1/8" horizontal section it is
intended that the incidental fluids be disposed of via an available well annulus (either CD1-19 or another
permitted well). The open annulus will be left with a non-freezing fluid during any extended shut down (> 4
hr) in pumping operations.
The CD1..19 surfacelintermediate casing annulus will be filled with diesel after setting intermediate casing.
The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the
top of the Alpine as per regulations.
We request that CD1..19 be permitted for annular pumping of fluids occurring as a result of drilling
operations, per regulation 20 AAC 25.080 (including clean up from mud and brine mixing operations at the
Alpine mud plant facility). We also request that cement rinseate be included in the list of permissible
injection fluids. As stated above, any zones containing significant hydrocarbons will be isolated prior to
initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells
within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation
markers in this well.
Surface casing will be set at the base of the Schrader-Bluff Formation (C-30). These 450-500' thick shales
are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas.
The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl
without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0
ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of
1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by:
( (
Max Shoe Pressure = (12.\.1 ¡Jpg) * (0.052) * (Surf. Shoe TVD) + 1 ,500 ~~..
= (12.0 ppg) * (0.052) * (2407') + 1,500 psi
= 3,002 psi
Pore Pressure = 1,089 psi
Therefore Differential = 3002 - 1089 = 1913 psi.
The internal casing pressure is conservative, since frictional losses while pumping have not been taken into
consideration. The surface and intermediate casing strings exposed to the annular pumping operations
have sufficient strength by using the 85% collapse and burst ratings listed in the following table:
Wt Connection 85°,10 of 85% of
OD (ppf) Grade Range Type Collapse Collapse Burst Burst
9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2.992 psi
7" 26 L-80 3 BTC-Mod 5,410 psi 4.599 psi 7,240 psi 6,154 psi
CD1-19
DRilLING FLUID PROGRAM
(
SPUD to Intermediate hole to Production Hole
9-5/8"surface casing 7" casing point - 8 Y2" Section - 6 1 18"
point -12 %"
Density 9.5 - 9.8 ppg 9.5 - 10.0 ppg 9.2 ppg
PV 1 0 - 25 12 -18
YP 20 - 60 15 - 25 35 - 45
Funnel Viscosity 120 - 200
Initial Gels 4-8 18 - 22
10 minute gels <18 23 - 27
AP I Filtrate NC - 10 cc I 30 min 4 -12 cc/30 min
HPHT Fluid Loss at 160 8.5- 9,0 9.0 -10.0 <10 cc/30 min
pH 9.0- 9.5
Surface Hole:
A standard high viscosity fresh water I gel spud mud is recommended for the surface interval. Keep flowline
viscosity at ± 200 seclqt while drilling permafrost and gravel, then reducing to 100-120 seclqt by casing
depth. Pump hi-vis sweeps if needed for supplemental hole cleaning. Maintain mud weight < 9.8 ppg by use
of solids control system and dilution where necessary.
Intermediate Hole Section:
Fresh water gel I polymer mud system. Ensure good hole cleaning by maintaining low end rheology and
pumping of regular sweeps, Maximize fluid annular velocity. There is potential for lost circulation,
particularly after the Alpine is penetrated. Maintain mud weight at or below 10 ppg and be prepared to add
loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids will all be
important in maintaining wellbore stability.
Production Hole Section :
The horizontal production interval will be drilled with aM-I Flo-Pro drill-in fluid. The base fluid will consist of
6% KCI, with ± 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer
and Flo- Trol starch will be used for viscosity and fluid loss control respectively.
DrillinCl Fluid System :
3 - Derrick 4 panel Hi-G Shale Shakers
Demco Desanders
Derrick 20 cone Desilter
Derrick DE-1000 Centrifuge
Pit Level Indicators, Trip Tank, Fluid Flow Sensor, Fluid Agitators
Pit ConfiCluration :
Pit 1
Pit 2
Trip Tank
Mini-trip Tank
Water Tank
Pit 3
Pit 4
Pit 5
Pill Tank
Pit 6
Capacity
(BBLS)
183
171
137
22
247
175
172
139
47
156
~(
('
Alpine Field
CD1-19 Temporary Suspension Schematic
Wellhead installed with tubing
hanger and BPV set and pressure
~ tested to 3500 psi
Diesel Freeze Protection
in casing and annulus to
1200' TVD.
16" Conductor to 1211
9-5/8" 36 ppf J-55 BTC
Surface Casing
@ 2868' MD / 2407' TVD
cemented to surface
10.0 ppg drilling mud in annulus
9.0 ppg brine with diesel freeze
protection to 1200' TVD.
TOC at 9714' MD /
6559' TVD (500' MD
above top Alpine
Casing pressure tested to 3500 psi
on plug bump.
U pd ated 3/8/99
7" 26 ppf L-80 R3 BTC-Mod
Production Casing at 10703' MD / 6817' TVD
@ 90 deg
I{
i
Alpine Field
CD1-19 Proposed Completion Schematic
16" Conductor to 121'
4-1/2" Camco TRM-4PE-CF (6.937" aD, 3.812" ID) SSSV
and DB-6 Lock (3.812" ID)
with single 1/4" x 0.049" s/s control line
@ +/- 1,000' MD
9-5/8" 36 ppf J-55 BTC
Surface Casing
@ 2868' MD / 2407' TVD
cemented to surface
Cameo KBG-2 GLM (3.909" ID)
at 4505' MD 1 3400' TVD for
E Dummy with 1" BK-5 Top Lateh
4-1/2" 12.6 ppf L-80 IBT-Mod
tubing run with Jet Lube Run'n'Seal
pipe dope
Cameo KBG-2 GLM (3.909" ID)
at 7472' MD 1 5200' TVD for
E Dummy with 1" BK-5 Top Lateh
Cameo KBG-2 GLM (3.909" ID)
& 1" Cameo DCK-2 Shear Valve
Pinned for easing side shear @ 2900 psi
set 2 joints above the X landing nipple
TOC at 9714' MD /
6559' TVD (500' M D
above top Alpine
Baker ZXP/HMC
4-1/2" liner hanger
with 12' TBR seals
50' above 7" shoe
HES "X" (3.813" 10)
Set at 10000' MD 1 6718'
TVD (60-65 deg)
7" 26 ppf L-80 R3 BTC-Mod
Production Casing at 10703' MD / 6817' TVD
@ 90 deg
Packer Fluid mix:
9.2 ppg KCI Brine
with 1200' diesel cap
4-1/2" Liner Assembly:
- 1 joint blank liner below hanger
- HES "XN" (3.725" ID) landing nipple
- blank 4-1/2" liner
- 4-1/2" KOIV (3.81" 10)
- 1 jt 4-1/2" blank liner
- Guide shoe
Contingency Scab Assembly:
- 6" ECP
- 4-1/2" liner - length as required
- 6" ECP
, .-
..l\.
%
,'<,
, I
. I'>''. . I' .
~.
- - - ,. .
, I
.. .../~,...
Updated 3/3/99
CD1-19
PRESSURE INFORMATION AND CASING DESIGN
('
~.
(per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2))
The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of the Alpine
CD1-19 well :
Casing Size Csg Setting F ractu re Pore pressure ASP Drilling
(in) Depth Gradient (Ibs. I (psi) (psi)
MDfTVD(ft) gal)
16 121 1121 10.9 52 56
9 5/8 2868 I 2407 14.2 1089 1537
7" 10703 I 6817 16.0 3084 2402
NIA 15473 I 6802 16.0 3077 NIA
· NOTE: Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3000 psi.
PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP)
ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas
gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as
follows:
1) ASP = [(FG x 0.052) - 0.1]D
Where: ASP = Anticipated Surface pressure in psi
FG = Fracture gradient at the casing seat in Ib./gal
0,052 = Conversion from Ib./gal to psi/ft
0.11 = Gas gradient in psi/ft
D = true Vertical depth of casing seat in ft RKB
OR
2) ASP = FPP - (0.1 x D)
Where; FPP = Formation Pore Pressure at the next casing point
ASP CALCULATIONS
1. Drilling below conductor casing (16")
ASP = [(FG x 0.052) - 0.1} D
= [(10.9 x 0.052) - 0.1] x 121 = 56 psi
OR
ASP = FPP - (0.1 x D)
= 1089 - (0.1 x 2407') = 848 psi
2. Drilling below surface casing (9 5/8")
ASP = [(FG x 0,052) - 0.1} D
= [(14.2 x 0,052) - 0.1] x 2407 = 1537 psi
OR
ASP = FPP - (0.1 x D)
= 3084 - (0.1 x 6817') = 2402 psi
3. Drilling below intermediate casing (7")
ASP = FPP - (0.1 x D)
= 3084 - (0.1 x 6817') = 2402 psi
0 - / I J =,
-f- \.
_~ 111~
_~~W,~
II ~
-1 000 I I I 11_
II
II
II
II
-2000
- I
ri~
1I!¡iI
IIIIII
-3000 "
::I: /17
I-
a.
w PO RE
C PR :~~UD
C
~
-4000
-5000
-6000
I~
l-
811III
-7000
8
9
Alpine CD1-19
ANTICIPATED PORE PRESSURE, MUD WEIGHT,
AND FRACTURE GRADIENT
"IIii,....
"'Ii, !¡¡".
,~
"I
\
~
\
~
\
1\
-.,--."
---
n_ .
M J[ \II. EIG~ T
/"
.v
10
11
12 13
EQUIVALENT MUD WEIGHT
14
(
1
,
,
I R '\ C ;-C RE
.- - .-..-
¡..t, 'L. ,'- ..-r
v[7
¡~
1\
,
\
,
~~
IC,
.. ,:,
15
16
17
-+- Bergscrund #2
(MD)
-&-Bergscrund #1
(TVD)
Alpine #1
(TVD)
Fiord #3 (TV D)
('
OFFSET WELLS - ACTUAL MUD WEIGHTS
o
._~ .m,.-.-- ._ - -
- - \ ~-t~-
~ :(. ~~ '\~
\> ~~ 1:,..1 '1\
It~~
~ -f-î ~iN
. >~\
~ ,,}
" :,.. < ¡ \ 1).
,,~ ~l /
\ ,'\, ;"\:
, \~.)
\' ~ \ ""¡ ~,
.\:., ..
\ ~ ')~
\ ' ~ ;~.r,(
^. ~l/\ Æ\
\ ,,/. ~'·'··,'r",
~ ~ ;r
~
.
-1 000
-2000
-3000
-4000
-*- Nechelik #1
(TVD)
.-
C -5000
--- Neve #1 (TVD) Ë
J:
l-
-+- Alpine #3 a.. -6000
LU
(TVD) C
-+-CD1-22 (TVD)
-7000
CD2-35 (TVD)
-8000
^
-9000
~/
,/
,
-1 0000
-11 000
8.0
9.0
10.0
MUD WEIGHT (PPG)
-¡
I
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I
¡
¡
¡
¡
I
¡
I
I
i
¡
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tr
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11.0
AIPiÁt:. CD1-19 Well Cementing RequirJ~..ðnts
95/8" Surface Casing run to 2868' MD /2407' TVD, TAM port Collar @ +/- 1000' MD
Cement from 2868' MD to 2368' MD (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2368' MD
to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50%
excess below the permafrost.
Lead slurry:
System:
Tail slurry:
System:
(2368' - 896') X 0.3132 fe/ft X 1.5 (50% excess) = 691,5 fe below permafrost
896' X 0.3132 fe/ft X 4 (300% excess) = 1122.5 ft3 above permafrost
Total volume = 691.5 + 1122.5 = 1814,0 fe => 410 Sx @ 4.44 ft3/sk
410 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% 0053 thixotropic
additive, 0.6% 0046 antifoamer, 1.5% 0079 extender, 1.5% S001 accelerator, 50% 0124
extender and 9% BWOW1 0044 freeze suppressant
500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 fe annular volume
80' X 0.4341 fe/ft = 34.7 fe shoe joint volume
Total volume = 234.9 + 34.7 = 269.6 fe => 230 Sx @ 1,17 ft3/sk
230 Sx Class G + 0.2% 0046 antifoamer, 0.3% 0065 dispersant and 1 % S001 accelerator
@ 15.8 PPG yielding 1.17 fe/sk
7" Intermediate Casing run to 10,703' MD /6817' TVD
Cement from 10703' MO to +1- 9714' MO (minimum 500' MO above top of Alpine formation) with Class G +
adds @ 15.8 PPG. Assume 40% excess annular volume.
Slurry:
System:
(10703' - 9714') X 0.1268 fe/ft X 1.4 (40% excess) = 175.6 fe annular volume
80' X 0.2148 fe/ft = 17.2 ft3 shoe joint volume
Total volume = 175.6 + 17.2 = 192.8 fe => 170 Sx @ 1.15 ft3/sk
170 Sx Class G + 0.2% 0046 antifoamer, 0.25% 0065 dispersant, 0.25% 0800 retarder
and 0.18% 0167 fluid loss additive @ 15.8 PPG yielding 1.15 fe/sk
1 By Weight Of mix Water, all other additives are BWOCement
21 %" 2,000 psi WP
DRilLING SPOOL
wI 16" Outlet
(
CD1-19
Diverter Schematic
Doyon 19
(
L
Flowline ~
21 %" HYDRIL MSP 2,000 psi WP
ANNUlARPREVENTER
16" 150psi WP
HYDRAULIC KNIFE VALVE
16" OD DIVERTER LINE
16" 62 ppf CONDUCTOR PIPE
t
J'~
~
CD1-19
DOYON 19
13-5/8" 5,000 PSI
BOP COMPONENTS
13-5/8", 5000 psi WP,
Hydril Type GK Annular
Preventer, studded top I
flanged bottom.
3" CHOKE LINE
Single 13-5/8", 5000 psi
WP, Hydril MPL BOP wI
blind I shear rams
3 1/8", 5000 psi Manual
Gate Valve
Single 13-5/8", 5000 psi
WP, Hydril MPL BOP wI
pipe rams
3 1/8", 5000 psi HCR
Valve (actuated)
3 1/8", 5000 psi Manual
Gate Valve
13-5/8" Drilling Spool wI
two 3", 5000 psi WP
outlets
I Drilling Spool
Single 13-5/8",5000 psi
WP, Hydril MPL BOP wI
pipe rams
I Wellhead ~
:~'
IARca Alaska, Inc.
Created by michoel FOR: ROBERTSON I
Datoo plotted : 25-Feb-11111i I
Plot Roof_ Ia CDI-19 Version 14.4. ,
Coorcfnota 0.. 'n fHt ..frene:_ eIot 119. i
, I
IT..... V..&aI Depu. en ~_ Estimated RKB.I
I .ami I
I ~ I
500
0
500
1000
1500
2000
'"'"
-+- 2500
0)
0)
't-
.........
.3000
...c:
-+-
C-
O)
0 .3500
0
0 4000
:¡::
....
0)
>
4500
0)
:J
....
I- 5000
I
V.
5500
6000
6500
7000
7500
8000
Struatu.. : CDI'
w.n: 19
Fl.ld : Alpine Fr.ld
Looatfon : Nart... Slop.. Ala.ka
I RKB ELEVATION: 57'
21.78 AZIMUTH
7380' (TO TARGET)
.....Plane of Proposal...
KOP
3.00
9,00
14.27Begin Build/Turn
Permafrost
17,06 West Sak
21,18
26,02
31,24
.36,68
42.26
47.92
EOC
C-40
C-.30
9 5/8
DLS: 3,00 deg per 100 ft
Casing. Pt
C-20
K-,3
K-2
TANGENT ANGLE
52.65 DEG
Albian 97
Albian 96
Begin Build/Turn To Target
K-1
DLS: 9.00 deg per 100 ft
TARGET -EOC-7 Casing pt
TARGET ANGLE
89.3 DEG
..;~
'. ~ Ji ~;;¡~
.~~~.-
~~.... ~.~mv
';-, ~
'.if
HRZ
500
500
1000 1500 2000 2500 ':3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 BODO
o
Vertical Section (feet) ->
Azimuth 21.78 with reference 0.00 S. 0.00 E from slot # 19
JL
;,~;1 L;;:-~·-
;".¿:-:a . "'(!y.
~~..._.;t::\:..___,_..
,.~'.'~:., ~':}s:· '.r
'tj.,..;.¡;]. ~';f.'!/<~
'''i~ ~..."
\~ ;
~RCO Alaska, Inc.
Struc1ure : COil w.n: 19
Fleld : Alp!ne Fl.1d locatIon : North Slope, AIa.kG
Creatød by michael FOR: ROBERTSON
DGle platted: 24-Feb-li99
Relerence is CDI-19 Version '4A.
Plat
Coordinates are in feet reference slat 119.
True Vertical Depths are reference Estimated RKB.
...
...
INDQ
~
5100
...............""
«'
.~Oj
CP~""
,\Ç) "
~
---4
---,¡¡
Ç)é~
.~
<¢edf <yOV
.~ò
<¢v""
.~
<¢edf <y&
.~e
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<¢o~e
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~
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CP~""
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e' '\ Or;;)
'\ (§~ e(.
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,\v~ r;;)O Òe
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o..edf '\ .... 1\. "Î
v " r .~ "
+: CJ-0 oèPÇ) «0" C'\<..oç ~OCJ
v ~'li e ~, v A"
~~vi:J'f"~e ~e(~,~~ \:J~-
~.¡:.ç" Ç)e0<yO""oe '\~
~
--q
TARGET ANGLE
89.3 DEG
5400
5700
6000
6.300
6600
6900
7200
7500
~
-
Q)
a>
-
"-'
.s::
-
0-
a>
o
o
u
:;:
L-
a>
>
a>
::J
L-
I--
I
V
7600
8100
3600 3900 4200 4500 4800 5100 5400 5700 6000 6300 6600 6900 7200 7500 7600 6100 6400 6700 9000 9300 9600 9900 10200
Vertical Section (feet) ->
Azimuth 331.94 with reference 0.00 N, 0.00 E from slot # 19
¡ARC a Alaska, Inc. ! ;'~
i i';'f~:'
I Created by mlchoel FOR: ROBERTSON Struatu.. : CD" Well: 19 I '~!4...~
¡ Dot. plotted : 26-Feb-1 gill I :~:i.~ ..",':: i~~~~
I Plot ReI__ Ie CDI-Ig v....... f4A.. Fleld : Alpine Fl,ld Loaatlan : Nort... Slope. AlQ.kQ i >,:, .',",
¡Coordinate. 0.. In '.l ~.. aIot ftg. ~ ~ !~t)~
I Tf\Ie Vertical Depths a.. ..,__ Estimated RKB.
I _
I ....
i
I INTI:Q
East (feet) ->
2800 2100 1400 700 0 700 1400 2100 2800 3500 4200 4900 5600
11900 11900
TO LOCATION:
11200 216' FSL, 2464' FEL 11200
SEC, 20, T12N, R5E
10500 10500
9800 9800
9100 9100
8400 8400
7700 7700
7000 TARGET -EOC-7 Casing pt 7000
8e~in Drop
^ TARGET LOCATION: E C . ^
1287' FSL, 2.36' FEL £e~pest Pomt
I 6300 SEC, 29, T12N, R5E A'fpli~~ D 6300 I
LCU Mlluveach A
....-.... K-1 Begin Build/Turn To Target Z
-
CD HRZ 0
CD .,
'I- 5600 Albion 96 5600 -
'--" :r
...t: r--.
- ......
I... 4900 4900 CD
0 CD
Z -
'--'"
4200 4200
3500 3500
2600 2800
2100 2100
1400 1400
Co sing Pt
700 700
ESTIMATED
SURFACE LOCATION:
0 .351' FNL, 2447' FWL 0
SEC, 5. T11 N, R5E
700 700
2800 2100 1400 700 0 700 1400 2100 2800 3500 4200 4900 5600
East ( feet) ->
(
(
ARCO Alaska. Inc.
COIl
19
slot #19
Alpine Field
North Slope. Alaska
PRO P 0 S ALL 1ST I N G
INCLUDING POSITION UNCERTAINTIES
by
Baker Hughes INTEQ
Your ref: CD1·19 Version #4A
Our ref : prop3253
License:
Date printed: 24·Feb·99
Date created : 22-Dec-98
Last revised: 24·Feb-99
Field is centred on n70 20 37.100.w150 51 37.53
Structure is centred on n70 20 37.100.w150 56 46.041
Slot location is n70 20 33.652.w150 55 34.529
Slot Grid coordinates are N 5975777,721. E 385872.721
Slot local coordinates are 350.20 S 2447.89 E
Projection type: alaska - Zone 4. Spheroid: Clarke· 1866
Reference North ;s True North
(
ARCO Alaska. Inc. PROPOSAL LISTING Page 1
CO#l.19 Your ref: C01·19 Version #4A
Alpine Field.North Slope. Alaska Last revised : 26-Feb-99
Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert
Depth Degrees Degrees Depth COO R DIN ATE S Oeg/100ft Sect
0.00 0.00 0.00 0.00 0.00 S 0.00 E 0.00 0.00
100.00 0.00 321.00 100.00 0.00 S 0.00 E 0.00 0.00
200.00 0.00 321.00 200.00 0.00 S 0.00 E 0.00 0.00
300.00 0.00 321.00 300.00 0.00 S . 0.00 E 0.00 0.00 KOP
400.00 3.00 321.00 399.95 2.03 N 1.65 W 3.00 1.28
500.00 6.00 321.00 499.63 8.13 N 6.58 W 3.00 5.11
600.00 9.00 321.00 598. 77 18.27 N 14.80 W' 3.00 11.48
700.00 12.00 321.00 697.08 32.43 N 26.26 W 3.00 20.38
766.67 14.00 321.00 762.04 44.09 N 35.70 W 3.00 27.70 Begin Build/Turn
800.00 14.27 324.94 794.36 50.59 N 40.60 W 3.00 31.91
895.81 15.38 335.32 887.00 71. 80 N 52.69 W 3.00 47.13 Permafrost
900.00 15.44 335.74 891.04 72.82 N 53.15 W 3.00 47.90
1000.00 17.06 344.80 987.05 99.11 N 62.47 W 3.00 68.86
1068.17 18.35 350.00 1052.00 119.33 N 66.96 W 3.00 85.97 West Sak
1100.00 19.00 352.19 1082.15 129.40 N 68.53 W 3.00 94.74
1200.00 21.18 358.19 1176.07 163.59 N 71.31 W 3.00 125.46
1300.00 23.54 3.08 1268.55 201.60 N 70.81 W 3.00 160.94
1400.00 26.02 7.10 1359.34 243.32 N 67.02 W 3.00 201.09
1500.00 28.60 10.46 1448.19 288.64 N 59.97 W 3.00 245.79
1600.00 31.24 13.30 1534.86 337.42 N 49.65 W 3.00 294.92
1700.00 33.94 15.73 1619.11 389.55 N 36.12 W 3.00 348.35
1800.00 36.68 17.84 1700.70 444.87 N 19.39 W 3.00 405.92
1900.00 39.46 19.70 1779.42 503.23 N 0.47 E 3.00 467.49
2000.00 42.26 21.35 1855.05 564.48 -N- 23.43 t" 3.00 532.88
2100.00 45.08 22.83 1927.38 628.44 N 49.40 E 3.00 601.92
2200.00 47.92 24.17 1996.21 694.94 N 78.34 E 3.00 674.41
2300.00 50.77 25.39 2061. 36 763.80 N 110.14 E 3.00 750.16
2365.88 52.65 26.15 2102.18 810.37 N 132.63 E 3.00 801.74 EOC
2500.00 52.65 26.15 2183.54 906.08 N 179.61 E 0.00 908.05
2522.19 52.65 26.15 2197.00 921. 92 N 187.38 E 0.00 925.64 C·40
2851. 89 52.65 26.15 2397.00 1157.20 N 302.88 E 0.00 1186.99 C·30
2868.37 52.65 26.15 2407.00 1168.97 N 308.65 E 0.00 1200.05 9 5/8" Casing pt
3000.00 52.65 26.15 2486.85 1262.91 N 354.77 E 0.00 1304.39
3478,31 52.65 26.15 2777.00 1604.25 N 522.32 E 0.00 1683.55 C-20
3500.00 52.65 26.15 2790.16 1619.73 N 529.92 E 0.00 1700.74
4000.00 52.65 26.15 3093.46 1976.56 N 705.08 E 0.00 2097.08
4500.00 52.65 26.15 3396.77 2333.38 N 880.23 E 0.00 2493.42
~OOO.OO 52.65 26.15 3700.08 2690.21 N 1055.39 E 0.00 2889 . 77
5176.25 52.65 26.15 3807.00 2815.99 N 1117.14 E 0.00 3029.48 K-3
5500.00 52.65 26.15 4003.39 3047.03 N 1230.55 E 0.00 3286.11
5555.41 52.65 26.15 4037.00 3086.57 N 1249.96 E 0.00 3330.03 K·2
6000.00 52.65 26.15 4306.70 3403.86 N 1405.70 E 0.00 3682.45
6500.00 52.65 26.15 4610.01 3760.68 N 1580.86 E 0.00 4078.79
7000.00 52.65 26.15 4913.31 4117.51 N 1756.02 E 0.00 4475.14
7500.00 52.65 26.15 5216.62 4474.33 N 1931.17 E 0.00 4871.48
8000.00 52.65 26.15 5519.93 4831.16 N 2106.33 E 0.00 5267.82
8473.23 52.65 26.15 5807.00 5168.88 N 2272.11 E 0.00 5642.95 Albian 97
8500.00 52.65 26.15 5823.24 5187.99 N 2281.49 E 0.00 5664.16
8967.78 52.65 26.15 6107.00 5521.82 N 2445.35 E 0.00 6034.97 Albian 96
9000.00 52.65 26.15 6126.55 5544.81 N 2456.64 E 0.00 6060.51
All data is in feet unless otherwise stated.
Coordinates from slot #19 and TVD from Estimated RKB (57.00 Ft above mean sea level).
Bottom hole distance is 11131.60 on azimuth 1.70 degrees from wellhead.
Total Dogleg for wellpath is 143.02 degrees.
Vertical section is from wellhead on azimuth 21.78 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
(
ARCO Alaska. Inc. PROPOSAL LISTING Page 2
CO#l.19 Your ref : CD1·19 Version #4A
Alpine Field.North Slope. Alaska Last revised : 26-Feb-99
Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert
Depth Degrees Degrees Depth COO R 0 I N ATE S Deg/lOOft Sect
9500.00 52.65 26.15 6429.85 5901. 64 N 2631.80 E 0.00 6456.85
9528.26 52.65 26.15 6447.00 5921.81 N 2641. 70 E 0.00 6479.25 HRZ
9777.80 52.65 26.15 6598.37 6099.89 N 2729.12 E 0.00 6677.06 Begin Build/Turn To Target
9800.00 53.48 23.87 6611.71 6115.97 N. 2736.61 E 9.00 6694.77
9822.56 54.35 21.60 6625.00 6132.78 N 2743.66 E 9.00 6713.00 K-1
9900.00 57.67 14.20 6668.33 6193.83 N 2763.29 E 9.00 6776.97
10000.00 62.53 5.46 6718.24 6279.12 N 2777.90 E 9.00' 6861.60
10003.83 62.72 5.14 6720.00 6282.51 N 2778.22 E 9.00 6864.86 LCU
10099.42 67.85 357.53 6760.00 6369.21 N 2780.12 E 9.00 6946.08 Miluveach A
10100.00 67.88 357.48 6760.22 6369.75 N 2780.09 E 9.00 6946.57
10162.64 71.43 352.81 6782.00 6428.24 N 2775.10 E 9.00 6999.03 Alpine 0
10200.00 73.60 350 .11 6793.23 6463.47 N 2769.80 E 9.00 7029.79
10213.70 74.40 349.14 6797.00 6476.42 N 2767.43 E 9.00 7040.93 Alpine
10300.00 79.56 343.18 6816.45 6557.99 N 2747.29 E 9.00 7109.20
10400.00 85.66 336.50 6829.33 6650.96 N 2713.11 E 9.00 7182.87
10470.50 90.00 331.87 6832.00 6714.35 N 2682.44 E 9.00 7230.35 Deepest Point
10470.52 90.00 331.87 6832.00 6714.37 N 2682.43 E 9.00 7230.36 CD1-19 DeepstPt Rvsd 2-Dec·98
10500.00 92.65 331.87 6831.32 6740.35 N 2668.53 E 9.00 7249.34
10527.88 95.16 331.87 6829.42 6764.88 N 2655.42 E 9.00 7267.25 EDC
10637.72 95.16 331.87 6819.54 6861.36 N 2603.85 E 0.00 7337.71 Begin Drop
10700.00 89.56 331.94 6816.97 6916.23 N 2574.55 E 9.00 7377.80
10702.79 89.31 331.94 6817.00 6918.69 N 2573.24 E 9.00 7379.60 TARGET-EOC·7" Casing pt
10702.81 89.30 331. 94 6817.00 6918.71 N 2573.23 E 9.00 7379.61 CD1·19 Heel Rvsd 2-Dec-98
10800.00 89.30 331.94 6818.18 7004.4t W- ' 2527. 5t-E' 0.00 7442.29
10900.00 89.30 331. 94 6819.40 7092.71 N 2480.48 E 0.00 7506.78
11000.00 89.30 331. 94 6820.61 7180.95 N 2433.45 E 0.00 7571.28
11100.00 89.30 331.94 6821.83 7269.19 N 2386.41 E 0.00 7635.77
11200.00 89.30 331. 94 6823.04 7357.43 N 2339.38 E 0.00 7700.26
11300.00 89.30 331.94 6824.26 7445.67 N 2292.34 E 0.00 7764.75
11400.00 89.30 331.94 6825.47 7533.91 N 2245.31 E 0.00 7829.24
11500.00 89.30 331.94 6826.69 7622.14 N 2198.27 E 0.00 7893.74
11600.00 89.30 331.94 6827.90 7710.38 N 2151. 23 E 0.00 7958.23
11690.45 89.30 331. 94 6829.00 7790.20 N 2108.69 E 0.00 8016.56 Begin Drop
11690.46 89.30 331.94 6829.00 7790.21 N 2108.68 E 0.00 8016.57 CDl-19 Pt.#l Rvsd 18-Dec-98
11697.68 89.16 331.94 6829.10 7796.57 N 2105.29 E 2.00 8021.22 EOC
12000.00 89.16 331. 94 6833.53 8063.33 N 1963.10 E 0.00 8216.19
12236.37 89_16 331. 94 6837.00 8271.90 N 1851.93 E 0.00 8368.63 Base Alpine
12500.00 89.16 331.94 6840.87 8504.52 N 1727.94 E 0.00 8538.65
i3000.00 89.16 331.94 6848.20 8945.71 N 1492.78 E 0.00 8861.11
13190.61 89.16 331.94 6851.00 9113.90 N 1403.13 E 0.00 8984.04 Begin Build
13190.62 89.16 331.94 6851.00 9113.91 N 1403.13 E 0.01 8984.05 CD1·19 Pt.#2 Rvsd 18·Dec-98
13200.00 89.35 331.94 6851.12 9122.18 N 1398.72 E 2.00 8990.09
13300.00 91.35 331. 94 6850.52 9210,42 N 1351. 68 E 2.00 9054.59
13400.00 93.35 331.94 6846.42 9298.59 N 1304.69 E 2.00 9119.03
13404.25 93.43 331.94 6846.17 9302.34 N 1302.69 E 2.00 9121.77 EOC
13500.00 93.43 331.94 6840.44 9386.68 N 1257.74 E 0.00 9183.41
13991.77 93.43 331.94 6811. 00 9819.88 N 1026.85 E 0.00 9500.04 Begin Drop
13991.79 93.43 331. 94 6811.00 9819.89 N 1026.84 E 0.00 9500.05 CD1·19 Pt.#3 Rvsd 18·Dec-98
14063.38 92.00 331.94 6807.61 9883.00 N 993.21 E 2.00 9546.17
14154.95 90.17 331.94 6805.87 9963.80 N 950.14 E 2.00 9605.23 EOC
All data is in feet unless otherwise stated.
Coordinates from slot #19 and TVD from Estimated RKB (57.00 Ft above mean sea level).
Bottom hole distance is 11131.60 on azimuth 1.70 degrees from wellhead.
Total Dogleg for wellpath is 143.02 degrees.
Vertical section is from wellhead on azimuth 21.78 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
il
I(
ARCO Alaska. Inc.
CD#I.19
Alpine Field.North Slope. Alaska
PROPOSAL LISTING Page 3
Your ref : CDl·19 Version #4A
Last revised : 26-Feb-99
Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert
Depth Degrees Degrees Depth COO R DIN ATE S Deg/l00ft Sect
14500.00
15000.00
15472.71
15472.73
90 . 17 331. 94
90.17 331. 94
90.17 331. 94
90.17 331. 94
6804.86
6803.39
6802.00
6802.00
10268.29 N
10709.53 N
11126.69 N
11126.70 N .
787.85 E
552.68 E
330.35 E
330.34 E
0.00 9827.78
0.00 10150.29
0.00 10455.19 TO . Casing pt
0.00 10455.20 CDI-19 Toe Rvsd 18·Jun-98
All data is in feet unless otherwise stated.
Coordinates from slot #19 and TVD from Estimated RKB (57.00 Ft above mean sea level).
Bottom hole distance is 11131.60 on azimuth 1.70 degrees from wellhead.
Total Dogleg for wellpath is 143.02 degrees.
Vertical section is from wellhead on azimuth 21.78 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
.~
ARCO Alaska. Inc.
CO#l.19
Alpine Field.North Slope. Alaska
PROPOSAL LISTING Page 4
Your ref : CD1·19 Version #4A
Last revised : 26·Feb·99
MD
TVD
Rectangular Coords.
Comments in wellpath
Conment
...-........................--.......................-......-.....-........------.-------------.------..........
300.00 300.00 0.00 5 0.00 E KOP
766.67 762.04 44.09 N 35.70 W. Begin Build/Turn
895.81 887.00 71. 80 N 52.69 W Permafrost
1068.17 1052.00 119.33 N 66.96 W West Sak
2365.88 2102.18 810.37 N 132.63 E EOC
2522.19 2197.00 921. 92 N 187.38 E C·40
2851.89 2397.00 1157.20 N 302.88 E C·30
2868.37 2407.00 1168.97 N 308.65 E 9 5/8" Casing pt
3478.31 2777.00 1604.25 N 522.32 E C·20
5176.25 3807.00 2815.99 N 1117.14 E K·3
5555.41 4037.00 3086.57 N 1249.96 E K·2
8473.23 5807.00 5168.88 N 2272.11 E Albian 97
8967.78 6107.00 5521.82 N 2445.35 E Albian 96
9528.26 6447.00 5921.81 N 2641. 70 E HRZ
9777.80 6598.37 6099.89 N 2729.12 E Begin Build/Turn To Target
9822.56 6625.00 6132.78 N 2743.66 E K·1
10003.83 6720.00 6282.51 N 2778.22 E LCU
10099.42 6760.00 6369.21 N 2780.12 E Miluveach A
10162.64 6782.00 6428.24 N 2775.10 E Alpine D
10213.70 6797.00 6476.42 N 2767.43 E Alpine
10470.50 6832.00 6714.35 N 2682.44 E Deepest Point
10470.52 6832.00 6714.37 N 2682.43 E CD1·19 DeepstPt Rvsd 2·Dec·98
10527.88 6829.42 6764.88 N 2655.42 E EOC
10637.72 6819.54 6861.36 N 2603.85 E Begin Drop
10702.79 6817.00 6918.69 N 2573.24 E TARGET-EOC·7" Casing pt
10702.81 6817.00 6918.71 N 2573.23 E CD1·19 Heèl'Rvsd 2-Dec·98
11690.45 6829.00 7790.20 N 2108.69 E Begin Drop
11690.46 6829.00 7790.21 N 2108.68 E CD1·19 Pt.#l Rvsd 18·Dec·98
11697.68 6829.10 7796.57 N 2105.29 E EOC
12236.37 6837.00 8271.90 N 1851.93 E Base Alpine
13190.61 6851.00 9113.90 N 1403.13 E Begin Build
13190.62 6851.00 9113.91 N 1403.13 E CDl·19 Pt.#2 Rvsd 18·Dec·98
13404.25 6846.17 9302.34 N 1302.69 E EOC
13991. 77 6811.00 9819.88 N 1026.85 E Begin Drop
13991.79 6811.00 9819.89 N 1026.84 E CD1·19 Pt.#3 Rvsd 18·Dec·98
14154.95 6805.87 9963.80 N 950.14 E EOC
15472.71 6802.00 11126.69 N 330.35 E TO . Casing pt
15472.73 6802.00 11126.70 N 330.34 E CDl-19 Toe Rvsd 18·Jun-98
Casing positions in string 'A'
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing
..........................................................................................................-............ -........- ..-...... ---.. -.............. -----.... --.... ---- ---.. .-...
0.00
0.00
0.00
0.00
0.00
0.00
0.005
0.005
0.005
O.OOE 2868.37 2407.00
O.OOE 10702.80 6817.00
O.OOE 15472.70 6802.00
1168.97N
6918.70N
11126 .68N
308.65E 9 5/8"
2573.24E 7"
330.35E 4 1/2"
Targets associated with this wellpath
Target name
Geographic Location
T.V.D.
Rectangular Coordinates Revised
................................................................................................................................. __.._............ __.. __......._.. .a................... _... ._...... ...__..
CDl-19 DeepstPt Rvsd 388659.000.5982449.000.0.0000
CDl-19 Heel Rvsd 2·D 388553.000.5982655.000.0.0000
CD1·19 Pt.#l Rvsd 18 388102.100.5983533.540.0.0000
CD1·19 Pt.#2 Rvsd 18 387417.270.5984867.940.0.0000
CDl·19 Pt.#3 Rvsd 18 387052.040.5985579.630.0.0000
CDl·19 Toe Rvsd 18-J 386376.000.5986897.000.0.0000
6832.00
6817.00
6829.00
6851.00
6811.00
6802.00
6714.37N
6918.71N
7790.21N
9113.91N
9819.89N
11126.70N
2682.43E
2573.23E
2108.68E
1403.13E
1026.84E
330.34E
18·Jun-98
2·Dec-98
22·Dec-98
22·Dec-98
22-Dec-98
18-Jun-98
-
-
.~
{
ARCO Alaska. Inc.
CO#l
19
slot #19
Alpine Field
North Slope. Alaska
SUM MAR Y C LEA RAN C ERE paR T
by
Baker Hughes INTEQ
Your ref : C01·19 Version #4A
Our ref : prop3253
License:
Oate printed : 24-Feb-99
Oate created : 22-0ec·98
Last revised : 24·Feb·99
Field is centred on n70 20 37.100,w150 51 37.53
Structure is centred on n70 20 37.100.w150 56 46.041
Slot location is n70 20 33.652,w150 55 34.529
Slot Grid coordinates are N 5975777.721, E 385872.721
Slot local coordinate~f'àre 350.20 S ·2447.89 E .
Projection type: alaska· Zone 4. Spheroid: Clarke· 1866
Reference North is True North
.. _ ItJ~ ílA't1i::S cV~ 11of~ WiLL ~E" PA-¡~ WHI3V c.f)'-/~ /r þ/l/l. L c:1)
Object wellpath Closest approach with 3-0 Minimum Oistance method
Last revised Oistance M.O. Oiverging from M.O.
24·Sep-98 158.9 566.7 14027.6
6-Jan-99 140.0 322.2 10137.6
8·Jan-99 521.5 3300.0 3300.0
12·Jan-99 150.0 200.0 200.0
11·Jan-99 50.0 322.2 322.2
20·Jan-99 20.0 300.0 13190.6
4-Nov-98 120.0 200.0 200.0
28-Jan·99 120.0 200.0 200.0
28·Jan·99 89.0 1311.1 1311.1
28·Jan·99 79.8 400.0 400.0
5-Aug-98 39.7 433.3 433.3
22·Jul-98 100.0 300.0 12160.0
4·Nov·98 140.0 300.0 300.0
26·Jan-99 129~9 344.4 13460.0
1·Feb·99 150.0 300.0 13262.5
4·Aug-98 10.0 300.0 12380.0
3-Sep-98 99.9 388.9 388.9
26·0ct·98 129.1 544.4 10253.5
2·Feb·99 220.0 300.0 300.0
17·Sep-98 230.0 300.0 300.0
28-Sep-98 260.0 300.0 300.0
11-Jan-99 170.0 300.0 300.0
19·Feb·99 170.2 1700.0 1700.0
19·Feb-99 170.0 311.1 8940.0
19·Feb-99 180.0 200.0 200.0
19·Feb·99 388.5 2800.0 2800.0
27·Jul·98 30.3 100.0 7400.0
COl-3/21 Verso #4..3/21.CD#l
C01·5/26 Verso #2..5/26.CD#l
WO-1 Version #5.,W01,CD#l
C01·4 Trunk Vers.#4,.4.CD#l
C01·14/22 Vers.#2..14/22.CD#l
COl-21 Version #2..21.CD#l
C01·31/75 Vers.#1.,31/75.CD#l
C01·7 Vers.#3.,7,CD#l
COl-8 Version #4..8.CO#l
C01-11 Version #2,.ll.CD#l
COl-15/119 Vers.#1.,15/119.CD#l
COl-29/6 Vers.#1.,29/6.CD#l
COl-33/74 Vers.#3,.33/74.CD#l
COl-32 Version #3,.32.CD#l
COl-34 Version #3..34.CD#l
C01·20/13 Vers.#1,,20/13,CD#l
C01·9/78 Vers.#1.,9/78.CD#l
C01·6/79 Vers.#3,.6/79.CD#l
C01·41 Version #4,.41.CD#1
C01·42/9 Vers.#3..42/9.CD#l
C01·45/19 Verso #3..45/19.C0#1
COl-36/20 Verso #3..36/20.CD#l
C01·1 Version#4.,l,CO#l
COl-2/14 Verso #4,.2/14.CD#l
C01·37 Verso #4. ..37,CO#l
~' WO·2 Version #5,.W02,CO#l
~ PMSS <0-9714'>..C01-22.CO#l
WELL PERMIT CHECKLIST
FIELD & POOL
COMPANY
~~ 0;'91
ENGINEERING
fl:ll:Z~
--
GEOLOGY
APPR p" ~EL
4c- 1,LJ)p?
ANNULAR DISPOSAL
APPR
DATE
~~D)
--
1, Permit fee attac ed, , . . . . . . . . , .. ...'...
2, Lease number appropriate. . . , , , . ., ......,
3, Unique well name and number. .. . , . . , . . . . . . . . . ,
4. Well located in a defined pool., , . . . . . . . . . . . . . . ,
5. Well located proper distance from drilling unit boundary. , , .
6, Well located proper distance from other wells.. . , . . . , , .
7, Sufficient acreage available in drilling unit., . . . . . . . . , ,
8. If deviated, is wellbore plat included" . . . . , , . , . , , . .
9. Operator only affected party., . . . , . , . . . . . . . , . , .
10. Operator has appropriate bond in force. . . . . . , . . . , .
11. Permit can be issued without conservation order. , . . . . , ,
12, Permit can be issued without administrative approval.. .
13. Can permit be approved before 15-day wait.. .
14. Conductor string provided . . . . . . . . , . , . . . , . , . ,
15. Surface casing protects all known USDWs. . . . . . . . . , .
16. CMT vol adequate to circulate on conductor & surf csg. . . . ,
17, CMT vol adequate to tie-in long string to surf csg. . . . . . . .
18, CMT will cover all known productive horizons. . . , . . . , . .
19. Casing designs adequate for C, T, B & permafrost. . . . . . .
20. Adequate tankage or reserve pit., . , . . . . . . . . . . . . ,
21, If a re-drill, has a 10-403 for abandonment been approved. . .
22. Adequate well bore separation proposed.. . . . . . , . . . . ,
23, If diverter required, does it meet regulations . . . . . . . . . .
24, Drilling fluid program schematic & equip list adequate. . . , ,
25. BOPEs, do they meet regulation . . , . , . . . . . . . , . . .
26, BOPE press rating appropriate; test to 5ðcð psig.
27. Choke manifold complies w/API RP-53 (May 84). . . , . . . .
28, Work will occur without operation shutdown. . , . . . . , . , ,
29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . .
30. Permit can be issued w/o hydrogen sulfide measures,
31, Data presented on potential overpressure zones . . .
32, Seismic analysis of shallow gas zones. , . . . . . . .
33, Seabed condition survey (if off-shore). . . . . . . . .
34. Contact name/phone for weekly progress reports [explora
35. With proper cementing records, this plan I}NFJ"JJl.AfI:.. tJ. Þr:~~; )tf:c;.,~tJS¡;::ßr,.A'" D~POSAl.l'o"'~ ADDe6SS~ r,. ~7 CJ!>,.:1Lt43
(A) will contain waste in a suitable receiving zone; . . . . , ø N <=> QV I
(B) will not contaminate freshwater; or cause drilling waste, " \D N ~u'6S1 ApP~"At- fðll,.. IJ\It\E.c.:1Jof'l ð;-"ruH.D.s FU>JII\ TH1.S lJJt:u, 11\170 THol..s WE:.L-L 0i-
to surface; ~(\\gn.\þ.", ~\1""6Þ..D W~ ~o f!.l:GVe:.j7 At>i'P-oJ'{:u... ~A- (,£M6N7 /?..1rv.SA.1~ I'\~
(C) will not impair mechanical integrity of the well used for disposal; (Y) N /../.-£:J'.~\)4> P'wlO$ Ç'"M. Mv.n ~ 8.t.,~ M'~II\Ic... Of'S. A7 MUt) fl.A1'\7.1 R.J:tLJM~
(D) will not damage producing formation or impair recovery from a C!J N A.pÿfL€>"l.p.J... oP "ít+E::.&E.. -rLUJöS . wM
pool; and
(E) will not circumvent 20 AAC 25,252 or 20 AAC 25.412.
GEOLOGY: ENGINEERING: UIC/Annular COMMISSION:
RP~ BEW~ 1{¡~icrrWM W~ ~'1,,19' DWJ ~-
JDH~ ~ RNC~
CO ('n ~hr\q~
WELL NAM
I/o
INIT CLASS .L/.,L.J /-..-1..
c:\msofflce\wordian\diana\checklist
PROGRAM: exp
GEOL AREA
dev ~ redrll serv
?-9/":) UNIT#
ann, disposal para req
ON/OFF SHORE ð /"\)
wellbore seg
Y N
Y N í,I (~o~~)
Y N '7
Y N
Y N
Y N
Y N
Y N
Y N
Y N
Y N
Y N
i~
Y N
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Comments/Instructions:
2. p~ -hw- ~ ~ i \l;. ~ ~ a\t...- ~ ~ 6k cu-.....¡aJ-
~ ~ ilI:;?-c-ê...... t: .(J a...J'
~: ~~ ~1'~r~t-~~~
a..:t-tL-~~~~ 0
NOTICE
The following well logs and oversized
documents have been placed in offsite
storage. If you would like to view the
original documents, please contact the
AOGCC librarian.
AOGCC
3/4/2005
tit d-d-
. :.. . : ,I.,~ :,', ,;'.' 'I "", J " . .
~9' D/-~
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LL
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0
iï u: -.J :s:
Depth logged:
Date logged:
f"- ---- -_.- ----...----.,-- ,--.
, '
, '
~
Anadri II
True Vertical Depth Log
Composite FINAL PRINT
Scales: 1/600 and 1/240
o
c
c
o
~
>
Q)
w
K.B.
G.L.
D.F.
Top Drive
22.0 ft
58.8 ft
Oft
10548 ft
7 April 1999
2 To 3
. M~al1_~eªLey~J
Elev.:
Total depth:
ccl'
~ Spud date:
« ð Runs:
o ~
o 0
a:: 0
<t: -.J
Permanent datum:
Log measured from:
Depth reference:
58.8 ft above Perm. dat ,
DríILÐoOL.,
. Driller's Pip~ Tª"y
Longitude
150.926258 W
Latitu de
"...__?~.~~6811 N :;
>-
c
("(
E API serial no.
o
o ,5,0-103:2029+0 Sec. 5, T 1_1,~I~~§'~ M
2826 ft To 10511 ft Mag decl: 26,39 deg
11-Apr-99 To 19-Apr-99 Mag dip: 80.49 deg
Sectio n:
.. ,.,_._._, _,.__....n'_
Other services:
0&1
Bore hole record
Hole size from
Surface equipment
Unit Doghouse
Depth system BEl
T e
Spud
LSND
to
Size
Software record
!:~~..
IDEAL Wis 5.Oc 01
SPM 5.0c 01
LWD 5.1/4.0
MWD 5.0
j±
l :})--
C('9 ~ o~~
__J
~ U
LL c
f-...
(¡) ..;;t ccl'
..;;t ~
> N ¡g
æ iÏ
--I ~ C
~ Z æ 0
c LL ..- a 1ti
0 "S; I
>. - ..- a
0 ..- a 0
0 lO IT: 0
a a C") a <t: --I
Measured Depth Log
FINAL PRINT
Scales: 1/600 and 1/240
Anadrill
c
o
~
>
Q)
w
Total depth:
Spud date:
Runs:
Permanent datum:
10548 ft
7 April 1999
3 To 3
_ M~ªJ1__$~ª ,~~y_~1
D[ill FI90L
K.B.
G.L.
D.F.
Top Drive
22.0 ft
58.8 ft
Elev.: 0 ft
58.8 ft above Perm. datu
Log measured from:
Depth referen ce:
. .
c
0
"0 ~
(j) Q) 0 Q)
iI ü: 0 5
....J
>.
c
('(
E API serial no.
o
a 50~.103::20294:Q Sec.5 T11_~_I.R5E,UM
9646 ft To 10456 ft Mag decl: 26.39 deg
15-Apr-99 To 19-Apr-99 Mag dip: 80.49 deg
Other services:
0&1
D[iller'~ pipe T ªlly"
Longitude
150.926258 W
Latitu de
70.3426811 N
Sectio n :
Depth logged:
Date logged:
Bore hole record
Ho Ie size fro m
Casing record
Density from
Size
to
to
T
Spud
LSND
1 1!J ft
2837 ft
28J I tt
10548 ft
0.0 deg
51.2 deg
53.6 deg
85.9 deg
115ft
2826 ft
2831 t1
10548 f
Surface equipment
Unit Doghouse
Depth system BEl
Software record
ID~L
~."..-=
IDEAL Wis 5.0c 01
SPM 5.0c 01
LWD 5.1/4.0
MWD 5.0
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Date logged:
I '
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o
c:::
of Total depth:
m 'Spud date:
«.5 Runs:
~ ~ Permanent datum:
Log measured from:
>.
c::: Depth reference:
cd
g-, API serialno, ' Section:
8
Measured Depth Log
Revision 2
Scales: 1/600 and 1/240
10548 ft
7 Apri/1999
3 To 3
Mean Sea Level
RKB
Driller's Pipe Tallv ' '
Õ KB. sa.8 ft
~
ã> G,L. ' 22.0 ft
ill D,F. 58.8 ft
Elev.: 0 ft
, 58,8 ft above Perm. datun'
t Latitu de
70.3426811 N
Seç.5.T11N.R5E UM
9646ft "Tö,'10456ft, Mag decl: 26,39deQ
15-Apr-99 To, '19:-Apr-99 Mag dip: 80.49 deg ,
Bore hole record., "
from
"'-
Surface equipment
Un~ Doghouse
Software record
Depth system
BEl
IDEAL Wis
SPM
LWD
MWD
5,Qc 01
5,Qc 01
5,1/4,0
5,0
Alaska Oil & Gas Cons. Commission
Anchorage
:Þ1=.
()-:Þ
Company: ARCOAlaska, Inc.
Well: CD1-19 AD'N*
Field: Colville Riv;er FINAL
Rig: ,poyon 19 State: Alaska
-
r--
~
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c:
True Vertical Depth Log
Revision 2
Scales: 1/600 and 1/240
.m
0) .~
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8,8
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LL
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C\I, ",13 . Spud date:'
i 0). «.9 Runs:
LL ,..., 0 10
ú) 5 0 8 Permanent datu~:
(1) 0 . ~...J Lòg measured fròm:,
, ~ Dépth reference:
a. '
E API serial no. Section:
8
Latitu de
70.3426811 N
§ KB. 55,8 ft
~
> G,L. 22.0 ft
Q)
W D,F, 58,8 ft
Elev.: Oft
58.8 ft above Perm, datu.
,10548 ft
7 April 1999
3 To, 3
Mean Sea Level
-Bl<B
Driller's Pipe T allv
Long itude
150.926258 W
..c:
.2
, , .. -ü 10'
'{l ~ '.§'~
Depth logged:
Date logged:'
Sec.5,T11 N,R5E,UM
10456 ft Mag decl: '26,39 deg
19-Apr-99 Mag dip: 80.49 deg
Other services:
D&I
, Surface equipment
Un~ Doghouse
Software record
IDEAL Wis
SPM
LWD
MWD
5. Oc_01
5,Oc 01
5,1/4,0
5.0
Depth system
BEl
Alaska Oil & Gas Cons. Commission
Anchorage
1J:
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Date logged:
Anadrill
Measured Depth Log
Composite FINAL PRINT
Scales: 1/600 and 1/240
ü
c
c
o
~
>
Q)
w
Total depth:
cd'
~ Spud date:
« § Runs:
o ~
o 0
a:: 0
« _J
10548 ft
7 April 1999
2 To 3
K.B. Top Drive
G. L. 22.0 ft
D.F. 58.8 ft
Elev.: 0 ft
58.8 ft above Perm. datum
Permanent datum:
Log measured from:
Depth reference:
\I1ea.o .$~ak~v~I,
Drill Floor .
Driller's Pip~Tally
»
c
<tl
E- API serial no.
o
o 50-103-20294-0 Sec.5,T11 N,R5E,UM
2826 ft To 10511 ft Mag decl: 26.39 deg
11-Apr-99 To 19-Apr-99 Mag dip: 80.49 deg
Sectio n:
Longitude
150.926258 W
Latitu de
70.3426811 N
Other services:
DSS
Bore hole record
Hole size from
Casing record
Den sity fro m
Size
to
to
T e
Spud
LSND
Unit
Surface equipment
Doghouse
IDEAL Wis 5.0c 01
SPM 5.Oc 01
LWD 5.1/4.0
MWD 5.0
Software record
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Measured Depth Log
Composite FINAL PRINT
Scales: 1/600 and 1/240
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5: Ò
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.q cd'
~ ~ æ Spud date:
~ a: :d (D « Õ Runs:
c: _IP. LL '7 0 1ø
g. ~ ìõ á () g Permanent datum: __M.~.Q._~J".~l__".._.._.._ Bev.: ....,.QJL.,..,.,..,............_...__,._
8 8 (''} 0 ~ -J Log measured from: __QJiJLE1º-ºL,__...,._._._,_.__,_._ 58.8 ft above Perm. datum
c: 5 Depth t'eferenœ: ,._ºd!'IDJ:,~..Iª'J1L__,..______._._____,___._......._.,___..________
'.º \U
Ö> :Q ~ ~ ~. API serial no. Section: '. . . .. . I Longitude Lati11Jde
tE ~ Š s: 8 . _ Sec.5a T'11N,R5E,UM J 150.926258 W 10.3426811 N
.........,._......,.,.,'...,......_..,...,..._....,_. ..,_OO:1œ~ . .__. __,___~__._~____. ...-___ _____._____,.___._.______
Depth logged: 2B26 ft To 10511 ft Mag docl: 26,39 degOther services:
Date logged: 11-Apr-99 To 19-Apr-99, Ma,g dip: 80AB deg DSS
Bore hote rec.."Ord
from
1 0548 ft c: K8. Top Drive
0
7 April 1999 1ä G.L. 22.0 ft
>
(I)
2 To 3 jjj D.F. 58.8 ft
Surface equipment
Software record
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SPM 5.0: 01
LWD 5.1/4.0
MWO 5.0
Doghouse
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Surface equipment
Unit Doghouse
Depth system BEl
Software record
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SPM 5.Oc 01
LWo 5. 1/4.0
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,_, 'FINAL PRINT "
~ ,.ô '~,,:S,caJes: 1/600 and 1/24{}
f.., , ~ 'Total dePth: "10548 ft 5 KB. Top DrNe
:J j2 , . -, ' -:¡;;
"._ ! ~",:'=",~,~, . "....?,AprU 1999 ,~ : G.L 22.0.1
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FINAL PRINT
Scales: 1/600 and 1/240
10548 ft: ~ K,8. Top Drive
7 April 1999 ~ G.L 22.0 ft
11>
3 To 3 ,w D.E 58..81:
BeY.: _º!t_.____...___.__
58.8 ft aboIre PErm. dæum
Scftware record
- -
IDEAl WIS 5'()C _ 01
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SPM 5.Oc_01
lWD 5. 1/4.0
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Unit Doghouse
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