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Scanned by: ~ Dianna Vincent Nathan Lowell
TO RE-SCAN
Notes:
Re-Scanned by: Be~edy Dianna Vincent Nathan Lowell Date: Is~
PTD I671 —)7 D
•
Ferguson, Victoria L (DOA)
From: Ferguson,Victoria L(DOA)
Sent: Wednesday,April 30, 2014 10:54 AM <r
To: 'Dai,Weifeng' .._,v/ fl�
Cc: 'aogcc.inspectors@alaska.gov'; Regg,James B(DOA)
Subject: Doyon 19 BOP closure:CD1-03 (PTD 199-120) 5/4.
0. `�74 5�
Weifeng, ,. ,� t� "d �L
,7- ,-,..„ -/-' �� /�" �2 gcf3
BOP components utilized must be tested first trip OOH. � `� - 4ektt , '' ' D A c°�'
k/)
/e J` O 3b - -
C\� cK`' ��— 1 _{. (5� ufi
Victoria Ferguson c`d �` 1 t 2�I2
Senior Petroleum Engineer �u`'S p;%; =\
��� v�o vA
State of Alaska ea s"'''OA
Oil&Gas Conservation Commission b.e/i v'e holt- e k I c ii?u c
333 W.7th Ave,Ste 100 4,rd,, - 7 vl a b o✓t 15 r c cJJ
Anchorage,AK 99501I'''''t,7
Work: (907)793-1247 y •S �3�p� • 1 a.5 r '�`2 e' 3
victoria.ferguson(« alaska.gov IvCZi U,ln,ot4_ w_5 v5tc1 F"'
J�� ci,vt vti t- v1- Gl -5 05 I
v
CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil
and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may
contain confidential and/or privileged information.The qua tbar+ked"review, use or disclosure of such information may
violate state or federal law. If you are an in ended recipient of this e-mail, please delete it,without first saving or
forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Ferguson at(907)793-
1247 or Victoria.Ferguson@alaska.gov
vph (v ��►pe �a �S r'lv �d
SHED SAY 0 5 201 . i 1 a via vC
SCII hi- +o r2--•2--z P i)
Original Message ry I A CNV s ,}-
From: Dai,Weifeng (mailto:Weifeng.Dai@conocophillips.com] C ��
Sent:Tuesday,April 29, 2014 7:17 PM r�55 ✓ e I �
To: Ferguson,Victoria L(DOA) o : (
Subject: Fwd: BOP use 0 Aim- e Dp
Hi,Victoria,
Please be kindly notified that BOP on rig Doyon 19 was closed today during de completion, refer note below for details,
please let me know if further info needed.Thanks.
00p C fa_ 6v, 0 ,, st
Sent from my iPhone Vlviu le'^
v (p tIPr
Begin forwarded message: i ` "
l o w-e✓ p ,
From: Doyon 19 Company Man<doyonl@conocophillips.com<mailto:doyonl@conocophillips.com»
Date:April 29,2014 at 6:47:29 PM AKDT
1
To:'"Dai,Weifeng"<Weifeng.Dai@conocophillips.com<mailto:Weifeng.Dai@conocophillips.com»,Alpine Field Drilling
'Supervisor<a1p1969@conocophillips.com<mailto:a1p1969@conocophillips.com», "Herbert, Frederick 0"
<Frederick.O.Herbert@conocophillips.com<mailto:Frederick.O.Herbert@Jconocophillips.com»
Subject: BOP use
Weifeng,
Heres info for AOGCC notification. Call if any questions.
Upper rams closed 1600 hrs,4/29/14
CD1-03A,Alpine,WNS, PTD#213-165
Doyon 19
Cut 7"casing in prep for pulling and sidetracking with 10.9 ppg brine,circ out gas in IA after second cut made,observe
well static,displaced out diesel FP from OA to tiger tank,shut in OA,observe gas on OA with pressure increasing, line up
and circ 1.5 BU thru OA and choke/gas buster,shut down observe OA open to gas buster,slight returns diminished to
near nothing in approx 10 min.Check for pressure under rams, no pressure,open rams,circ 1.5 BU, no gas,good wt all
around at 10.9 ppg. Shut down observe well, IA,fluid level dropped slightly initialy,then slowly began running down
flowline.Checked OA,40 psi, bleed a little gas off,fluid level dropped in IA.Tied OA to IA to monitor both sides
simultaneously,observed gas breaking out actively,fluid level held near static with gas breaking out then began running
down flowline over approx.5-10 min watched.Shut in OA and rams. Monitored pressure while prepping to viscosify and
wt up brine. Over 2.5 hrs pressure climbed slowly to 50 psi on DP and 80 PSI on OA.Will wt up in stages and monitor
well after each stage.
Closed upper VBR's,3.5"x 6"
Shut in to prevent flow of fluids from wellbore and evaluate Last BOP test finished 4/28/14
Thanks,
Ken Harding/Adam Dorr
Rig Supervisors
Doyon 19
670-4300 camp office
670-4350 rig floor office
2
II
f
CD1-03
Pre and Post Plug Back for Redrill
Ati)
/1"--jfir(-1/
Current Completion ProPosed Pre Rig ST PM t/ v
I
1.)Drift and Pull A•1 Inj
Valve.
r.••••••••• Camco Ball-O Nipple @ 1,781'KB
w/A-1 Injection Valve 2.)li rift and B&F
nip le @ 7,510'KB.
® I® 9 518"36#J-55 Casing @ 2,523'KB j" 3.)• nch tubing hole
e packer at 7,366
6 i 4.)Set cement retainer
in nipple @ 7,510'KB. (�.,
A[itiSiljl \IA
Tubing (� V�7
5.)Pump 132 bbl class G
cement through retainer. C- 1 B P
�( \ 6.)Unsling and lay in 18 bbl
Vof cement into tubing.
7.)Open IA and displace 19
// bbl of cement into the IA.
IO to, f" NOTE: TOC in both A an
tubing is estimated toa d
(-kr' /'i 6,466"KB.
L r
I I.f / Id
8.)Tag cmt top and PT.
Provide AOGCC 24 hrs
Baker S 3 Packer @ 7,466'KB notice prior.
t l / f 9.)Punch tubing hole above
TOC and circ.In KWF.
� 10.)Cut tubing @ approx.401 3,500'KB.
I ! XN Nipple @ 7,510'KB mom
/ 4.5"12.60#L-80 Tubing @ 7,521'KB ��
Wireline Entry Guide @ 7,521'KB /�
® ® 7"26#L-BO Casing CO 7,816'KB
/ i
/ /0 01-1%6,
a*/ ,
:431/661°141f
'///1; I S 2-c-44.‘54.9r-4-
6-118"OH.TD 10,867 KB i
— —
'L;OL--- __/...________l MD 10-13-2013
J • •
w\�0 ��jj's9 THE STATE Alaska Oil and Gas
� °fALAS�
Conservation Commission
GOVERNOR SEAN PARNELL 333 West Seventh Avenue
Anchorage, Alaska 99501-3572
ALAS Main: 907.279.1 433
<f rN`) Fax: 907.276.7542
Mick Davasher sN
Wells Engineer r 7 0
ConocoPhillips Alaska, Inc. O�-
P.O. Box 100360
Anchorage, AK 99510
Re: Colville River Field, Alpine Oil Pool, CD 1-03
Sundry Number: 313-596
Dear Mr. Davasher:
Enclosed is the approved Application for Sundry Approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown, a person affected by it may file with the
AOGCC an application for reconsideration. A request for reconsideration is considered timely if
it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working
day if the 23rd day falls on a holiday or weekend.
Sincerely,
ryki
Cathy P Foerster
Chair, Commissioner
54-
DATED this A day of November, 2013.
Encl.
• STATE OF ALASKA 0 %,,&
RECEIVED
ALASKA OIL AND GAS CONSERVATION COMMISSION i �,‘Z NOV 15 2013
APPLICATION FOR SUNDRY APPROVALS %t?
20 AAC 25.280 AOGCC
1.Type of Request: Abandon r Plug for Redrill F.. Perforate New Pool r Repair w ell r Change Approved Program r
Suspend r Rug Perforations ' Perforate r Pull Tubing r Time Extension r
Operational Shutdown r Re-enter Susp.Well r l •1 Stimulate r Alter casing r Other r-
2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number:
ConocoPhillips Alaska,Inc. Exploratory r Development r 199-120 •
3.Address: 6.API Number:
Stratigraphic r Service rI
P.O.Box 100360,Anchorage,Alaska 99510 50-103-20319-00 •
7.If perforating, 8.Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Will planned perforations require spacing exception? Yes r No J CD1-03
9.Property Designation(Lease Number): 10.Field/Pool(s):
ADL 25559,25558 Colville River Field/Alpine Oil Pool •
11. PRESENT WELL CONDITION SUMMARY
Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured):
10897 7007 10897' 7007' none none
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 77 16 114' 114'
SURFACE 2486 9.625 2523' 2370'
PRODUCTION 7782 7 7817' 6970'
Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft):
open hole completion from 7816-10897'. open hole from 6970'-7007' 4.5 L-80 7521
Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft)
PACKER-BAKER S-3 PACKER MD=7466 ND=6881 •
NIPPLE-CAMCO DS NIPPLE MD=1781 TVD=1694 - ,Qs
12.Attachments: Description Summary of Proposal r/ 13. Well Class after proposed work: �` ��
Exploratory r Stratigraphic r Development ; ' Service ��
Detailed Operations Program r BOP Sketch r
—
14.Estimated Date for Commencing Operations: 15. Well Status after proposed work:
12/15/2013 Oil r Gas r WDSPL r Suspended (iI
16.Verbal Approval: Date: WIN J r GINJ r WAG r Abandoned r
Commission Representative: GSTOR r SPLUG r
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mick Davasher @ 265-6870
Email: Mick.J.Davasher(a conocophillips.com
Printed Name Mick D vasher Title: Wells Engineer
Signature 1,44- / Phone:265-6870 Date ,7//?/2 y)
Commission Use Only
Sundry Number:
Conditions of approval: Notify Commission so that a representative may witness 3\7.3—5CL.14_,
Plug Integrity BOP Test r✓MechanicalI�ntegrityTest r Location Clearance r
RBDMS NOV 2 5 �,�' �
Other: 4- 3 JQD D 60/ ty
St' GeS7
Spacing Exception Required? Yes ❑ No [v( Subsequent Form Required: /0 —Li O 7
APPROVED BY l/_ /_ /
Approved by: / COMMISSIONER THE COMMISSION Date: ( Z
roved trom the date of approval. ,Z�.�pp i'/A4d IIitg113 // .3 Form 10-403(Revised 10/2012) Submit Form and Attach is in Duplicate
• •
Conoco Phillips
Alaska
P.O.BOX 100360
ANCHORAGE,ALASKA 99510-0360
November 13th, 2012
State of Alaska
Alaska Oil&Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage,Alaska 99501
Re: Sundry Permit—Request to plug back well for Rotary Side Track
Dear Sir/Madam:
ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to plug back
well CD1-03(PTD#: 199-120) in order to prepare the well for an upcoming rotary sidetrack.
The objective of the proposed CD1-03 Plug Back is to prepare the well for a rotary side track
planned for the first half of 2014.
CD1-03 was originally completed in 1999 as a C Sand injector supporting CD1-10 and CD1-28.
These two wells have watered out and CD1-03 has been shut-in since Q4 2012. The proposed
side track will provide injection support to CD1-22B which currently is not supported.The
sidetracking procedures will be covered in a separate/application for a Permit to Drill CD1-03A.
The attached plug back proposal illustrates the plan forward. If you have any questions or require
any further information, please contact me at 265-6870.
Sincerely,/
Mick Davasher
Wells Engineer
CPAI Drilling and Wells
tr // des d ro /cfs rAD /G" A)11
lu/i r k V`'A ter Cd71 l t1 a Kt,e$f D'
•
CD1-03 Pre Rig Plug Back for Rotary Side Track
Permit to Drill#: 199-120
The objective of this procedure is to abandon the current lateral and to set the well up for a rotary side
track.The rig will sidetrack from just below the surface casing shoe. In preparation for the sidetrack this
work will be completed to isolate the formation from the wellbore, load the well with inhibited fluid,
and cut the tubing at 3500'MDRT.
Well Suspend Procedure:
Slickline/Little Red:
1. RIH and drift tubing to the A-1 injection valve at 1,781' MDRT. Pull A-1 valve.
2. Drift tubing to XN nipple at 7,510' MDRT to confirm tubing is open.
3. RIH with tandem gauges and obtain 30 min SBHP at 7510' MDRT(end of tubing). Pull up hole
100'TVD and obtain another 30 min SBHP. •
4. Brush and flush the nipple at 7510' MDRT.
5. Confirm ability to pump into the well+/-2 BPM.
6. RIH with tubing punch and punch a hole in the in the tubing at^'7366' MDRT(^'100'above
packer at 7466'MDRT).Confirm hole in the tubing by circulating in 40 bbl diesel(or crude)from
IA to tubing. (Ensure able to get+/-2 BPM or consider punching another hole).
Coil Tubing
7. Ensure that the 10-403 Sundry has been approved by the AOGCC.
8. RIH and set the 3.75"cement retainer in the XN nipple at 7510' MDRT. (OK to use alternative
but ensure that there is a check valve in the retainer top prevent cement from backflowing after
unstung). DO NOT unsting from retainer once set.
9. Perform injectivity test to ensure adequate rates for cementing operations. (+/-2 BPM).
10. Pump 132 bbls of 15.8 ppg Class G cement through the retainer.
11. Unsting from retainer and lay in 18 bbl of 15.8 ppg Class G cement,taking 1:1 returns from the
tubing.
12. Open the IA and squeeze another 19 bbl of 15.8 ppg Class G,taking 1:1 returns from the IA.
13. POOH and rig down.Cement tops should be near 6466' MDRT in both tubing and IA.
Slickline/Little Red
14. WOC minimum 24 hours prior to tag and test.
a. Notify AOGCC inspector 24 hours prior to tag and test.
15. RIH and tag TOC at approximately 6466' (1000'cement plug above packer).
16. Test cement plug(MIT-T)to 2000psi for 30 minutes.Test IA(MIT-IA)to 2000psi for 30 minutes.
Ensure both tests are charted and documented using CPAI MIT form. /(Jet'
17. Perform drawdown test on the tubing and IA. A-a ei Cc. 41
• •
18. RIH with tubing punch and punch a hole in the tubing 100' above cement tag.Confirm hole in
the tubing by circulating fluid from tubing to IA. If unable to circulate, PUH 500'and punch
tubing again.
19. Circulate 150 bbl corrosion inhibited KWF (ppg from SBHP)down the tubing and up the IA
followed by 68 bbl of diesel(or crude)freeze protect. U-tube and equalize the tubing and IA.
E-line
20. RIH with tubing cutter and cut the 4.5"tubing at+1-3500' MDRT.Cutter type is not critical as we
do not need to overshot the stub.
21. If unable to confirm positive cut,move uphole 15'and cut again.
22. RD E-line, RU FMC and set BPV in hanger.
• •
CD1-03
Pre and Post Plug Back for Redrill
Current Completion Proposed Pre Rig ST P&A
4111i i,
?`=
1.)Drift and Pull A-1 Inj
L. Valve.
Camco Ball-0 Nipple @ 1781'KB �•
w/A-1 Injection Valve 2.)Drift and B&F
nipple @ 7,510'KB.
9 5/8"36#J-55 Casing @ 2,523'KB 3.)Punch tubing hole
above packer at 7,366
KB.
4.)Set cement retainer
in nipple @ 7,510'KB.
Tubing Cut
5.)Pump 132 bbl class G
cement through retainer.
6.)Unsting and lay in 18 bbl
of cement into tubing.
Circ.Hole a :::;: ; ;Circ.Hole jI4
� Provide AOGCC 24 hrs
c4',.4 ,'0,..,:=4, Baker S-3 Packer @ 7,466'KB -®- notice prior.
l •JJ-, 9.)Punch tubing hole above
��1� TOC and circ.in KWF.
� 10.)Cut tubing @ approx.
ii, 3,500'KB.
Cen
XN Nipple @ 7,510'KB • ete
4.5"12.60#L-80 Tubing @ 7,521'KB �II"�
Wueline Entry Guide @ 7,521'KB /e/
Casing 7,816'KB
X , � Gw�
1.47,1(
6-1/8"OH.TD @ 10,867'KB 10-13-2013
!L3 MD
1 WNS • CD1-03
ConocoPhillips Well Attributes Max Angle&MD TD
s Welibore APIIUWI Field Name Well Status Ind(°) MD(ftKB) Act Btm(ftKB)
Alaska.Inc 501032031900 ALPINE INJ 92.20 7,837.99 10,897.0
_ Gonacoti!>IllIps
Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date
•••
Well Congo:-501.03,1NR012 4:89:54 PM SSSV:WRDP Last WO: 43.23 1/5/2000
Schema*-Actual 'Annotation Depth(ftKB) End Date Annotation Last Mod...End Date
Last Tag: Rev Reason:SET NEW INJ VALVE ninam 12/7/2012
Casing Strings
Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd
CONDUCTOR 16 15.062 37.0 114.0 114.0 62.58 H-40 WELDED
x.. Casing Description String O._ String ID...Top(ftKB( Set Depth It Set Depth(TVD)...String Wt...String...String Top Thrd ill _ '` • SURFACE 95/8 8.921 36.8 2,522.6 2,370.0 36.00 J-55 BTC-MOD
HANGER,32 .: ,;t Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TAD)...String Wt...String...String Top Thrd
e�. PRODUCTION 7 6276 34.9 7,8165 6,970.0 26.00 L-80 BTCM
Casing Description String O... String ID...Top(ftKB) Set Depth(f...se Depth(TVD)...String Wt...String...String Top Thrd
OPEN HOLE 61/8 6.125 7,816.5 10,897.0 7,007.1
k‘' l'^., Tubing Strings
Tubing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(ND)...String Wt...String...String Top Thrd
TUBING I 41/2 I 3.958 I 32.3 l 7,522.5 I 6,907.5 I 12.60 L-80 IBTM
Completion Details
Top Depth
(TVD) Top Ind Noml...
':. ' Top(ftKB) (ftKB) (°) Item Description Comment - ID(In)
32.3 32.3 -0.31 HANGER FMC TUBING HANGER 4.500
1,781.1 1,693.7 24.31 NIPPLE CAMCO'DB'NIPPLE 3.812
7,465.6 6,881.0 58.95 PACKER BAKER S-3 PACKER 3.875
7,510.4 6,902.2 64.55 NIPPLE HES'XN'NIPPLE NO GO 3.725
7,521.2 6,906.9 65.79 WLEG WIRELINE ENTRY GUIDE 3.875
Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.)
CONDUCTOR, _
Top Depth
37-114 (TVD) Top Ind
Top(ftKB) (ftKB) (°) Description Comment Run Date ID(in)
1,781 1,693.7 24.31 VALVE CAMCO A-1 INJECTION VALVE(HYS-0236) 2/29/2008 1.250
Notes:General&Safety
VALVE.1,781 )- End Sate Annotation
NIPPLE,1,781 1� 6/21/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0
SURFACE, -I ,
37-2,523
l
PACKER,7,486
-fr.'
t I
NIPPLE,7,5170 I, i
WLEG,7.821
PRODUCTION, A l
35.1816 0 o
OPEN HGLE,
7,817-10897\ o
TD.10(897
I
Doyon 19 CD1-03 Abandonment Procedures:
The proposed scope of work for this sundry application includes:
1. MIRU Doyon 19 on CD1-03
2. Pull BPV and VR plugs. Record tubing, IA and OA pressures.
3. Circulate out freeze protect to kill weight brine and monitor well for pressure.
4. Set BPV and test through inner annulus to 1500psi for 10 minutes. Record test.Set blanking
plug.
5. Nipple down tree.
6. Nipple up BOPE.
a. Test BOPE to 250psi/3500psi (test VBR with 4-1/2"test joint)
b. Notify AOGCC field inspector 24 hours prior to BOPE test.
7. Remove blanking plug and BPV.
8. Pull 4-1/2"tubing(pre-cut at+/-3,500' MD).
9. Test VBR with 5"test joint(or DP size used).
10. Run in with CIBP on DP and set at+/-2,950' MD. it CL8 - lb l°/°s"
11. Run in hole with mechanical casing cutter on drill pipe and cut casing at+/-2,850' MD.
12. Flush 7"x 9-5/8"with KWF.
13. Swab VBR's to 7" casing rams and pressure test. ,
14. Pull 7" casing to surface and lay down same. 3�
15. Swap 7" casing rams to VBR's and pressure test with 3-1/2"test joint. e.2
().t,1( 16. RIH with 3.5"cement stinger ans set cement kick off plu from top of bridge plug to 200'feet Td
L
` within the surface casing.—50 bbl of cement required.
I. 17. P/U directional drilling BHA and RIH.Tag TOC and pressure test surface casing and kick off plug
to 3,000psi/30 minutes. Record test.
18. Drill out 20' new formation and perform LOT.
0 11A)efD
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE: Tuesday,June 18,2013
P.I.Supervisor eel q_7(1 3 SUBJECT: Mechanical Integrity Tests
C CONOCOPHILLIPS ALASKA INC
CD 1-03
FROM: Jeff Turkington COLVILLE RIV UNIT CDI-03
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I.Supry , �
NON-CONFIDENTIAL Comm
Well Name COLVILLE RIV UNIT CDI-03 API Well Number 50-103-20319-00-00 Inspector Name: Jeff Turkington
Permit Number: 199-120-0 Inspection Date: 6/12/2013
Insp Num: mitJAT130614185949
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
D
Well
CDI-03 ,Type Inj N. 6881 IA 460 2485 - 2430 . 2430
T
PTD 1991200 Type Test'SPT(lest psi I 1720 OA G95 720 725 740
1 g 1775 1775 1775 1780
Interval 4YRTST P/F P ' Tubm
Notes: 1.1 bbl diesel to fill
SCANNED FEB 2 0 2014
Tuesday,June 18,2013 Page 1 of 1
•
MEMORANDUM
TO: Jim Regg ~
P.I. Supervisor ~~~ ~ZZ' ~ ~
FROM: Bob Noble
Petroleum Inspector
~
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Monday, June 22, 2009
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
CDI-03
COLVILLE RIV IJNIT CDt-03
Src: Inspector
NON-CONFIDENTIAL
Reviewed By:
P.I. Suprv ~~~
Comm
Well Name: COLVILLE RN iJNIT CD1-03
Insp Num: mitRCN090617202643
Rel Insp Num: API Well Number: 50-103-20319-00-00
Permit Number: 199-120-0 / Inspector Name: Bob Noble
Inspection Date: 6/13/2009
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well CDi-03 Type Inj. G 'j'~ 6881 '~ jt~ 2130 3020 2990 2980
P.T.D 1991200 TypeTest SPT Test psi 3ozo pA ~so ~ao ~ao ~ao
Interval 4YRTST P~' P '~ Tubing 3054 3054 3054 3054
Notes: ~~n.~~` ~'~S~r,l.~ 17Z-t~~s~
; ; ; ;~ r(~~~;4:
~xy~~~ _1 ~ih
..~ lt.+~ Z.. ..
Monday, June 22, 2009 Page 1 of 1
.
.
~
ConocoPhillips
Alaska
/-^\
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
g¡
March 31, 2007
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West ih Avenue, Suite 100
Anchorage, AK 99501
~qq- frO
Dear Mr. Maunder:
Enclosed please find a spreadsheet with a list of wells ITom the Alpine field (ALP). Some of
these wells were found to have a void in the conductor by surface casing annulus. The voids that
were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The
remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered
to prevent water ITom entering the annular space. As per previous agreement with the AOGCC,
this letter and spreadsheet serves as notification that the treatments took place and meets the
requirements of form 10-404, Report of Sundry Operations.
Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions.
Sincerely,
SCANNED APR 0 9 2007
~~C
Jerry Dethlefs
ConocoPhillips Well Integrity Proj Supervisor
Attachment
~
.
.
ConocoPhillips Alaska Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Corrosion
Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/
Well Name PTD# cement pumped cement date inhibitor sealant date
ft bbls ft gal
CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007
II CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007
v CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007
CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007
CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007
CD1-6 200-083 4" na 4" na 2 2/17/2007
CD1-8 204-059 6" na 6" na 8 2/17/2007
CD1-9 200-071 6" na 6" na 3 2/16/2007
CD1-10 200-171 18" na 18" na 8.5 2/16/2007
CD1-12 204-205 4" na 4" na 2 3/8/2007
CD1-14 201-038 4" na 4" na 1 3/8/2007
CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007
CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007
CD1-18 204-206 4" na 4" na 1 3/8/2007
CD1-19 200-040 10" na 10" na 3 3/8/2007
CD1-20 204-240 6" na 6" na 2 3/8/2007
CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007
CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007
CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007
CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007
CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007
CD1-26 199-088 6" na 6" na 3 2/19/2007
CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007
CD1-28 200-199 6" na 6" na 3 2/16/2007
CD1-29 200-215 4" na 4" na 1.8 2/16/2007
CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2/16/2007
CD1-31 200-118 6" na 6" na 3 2/19/2007
CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007
CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007
CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007
CD1-35 199-038 4" na 4" na 1 3/8/2007
CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007
CD1-37 199-067 8" na 8" na 4 2/19/2007
CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007
CD1-39 199-080 4" na 4" na 1 3/8/2007
CD1-40 199-044 4" na 4" na 1.8 2/16/2007
CD1-41 200-017 12" na 12" na 5.6 2/16/2007
CD1-42 199-119 74" 0.8 6" 4/16/2003 2.8 2/16/2007
CD1-43 200-106 8" na 8" na 3.7 2/16/2007
CD1-44 200-055 10" na 10" na 4.7 2/16/2007
CD1-45 199-101 4" na 4" na 2 2/19/2007
CD1-46 204-024 36" na 36" na 16.A ?!16!?OO?
Alpine Field
March 31,2007
ConocoPhillips Alaska, Inc.
Surface Casing by Conductor Annulus Cement Top-Off
Alpine Field, CD-1 CD-2
I
WELLS DEPTH VOLUME TYPE SACKS
BBLS Cement
cD1-1' - 2.25' -¥3 WI 1.8
CD1-2 4' 0.6 WI 3.6
CD1-3 ...... 10,-- ........ '1.4 MI . 8.5
CD1-4 7.33' 1 P 6.0
(iD1-5 4' 0.6 MI 3.6
C'~)-J--~ i0~42' 1.4 Gl 8.5
CD1-16 14.33' 2 WI 12.1
CD1-17 8.75' 1.2 P 7.2
CD1-21 13' 1.8 MI 10.9
CD1-22 1.83' 0.3 P 1.8
CD1-23 i-~-~'n- 2.1 MI 12.7
CD1-24 2' 0.3 P 1.8
' CD1-25 5.66' 0.8 P 4.8
CD1-27 ----¥§~'~§T .... 216 "P 15.7
CD1-28 6.75' 1 P 6.0
CD1-32 8.33' 1.2 P 7.2
CD1-34 41.83' 5.7 P 34.4
---(~'¥-36 ..... 16.75' 2.3 ..... -WI 13.9
CD1-38 3.5' 0.5 P 3.0
CD1-42 5.83' 0.8 MI 4.8
CD2-16 11.66' 1.6 INJ 9.7
CD2-17 18' 2,5 INJ 15.1
.,
CD2-19 11.66' 1.6 P 9.7
C D2-22 13.5' 1.8 INJ 10.9
CD2-25 27.25' 3.7 P 22.3
CD2-26 10.42' 1.4 INJ 8.5
CD2-32 8.5' 1.2 INJ 7.2
CD2-33I' .............. 7Y .................... ~ .... P 6.0
CD2-34 4' 0.6P 3.6
CD2-41 11.83' 1.6 P 9.7
CD2-46 7.42' 1 INJ 6.0
C D2-48 10.33' 1.4 INJ 8,5
CD2-49 9.33' 1.3 INJ 7.8
CD2-50 1.66' 0.25 P 1.5
<
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
April 23, 2003
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
Dear Mr. Maunder:
Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells
was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to
the top of the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves
as notification that the treatments took place.
In the fall of 2002, CD 1-23 was reported to have a "wobbly" tree. The top of cement was measured at 15-
feet below the top of the conductor. Plans were made to stabilize the wellhead by top-filling cement later
in the winter when the ice road to Alpine had been installed. Since that is considerable effort and expense
for pumping a small load of cement, a survey was made of each conductor to see if voids were present. A
list of 34 wells was put together that would need additional cement.
The top-fill operation was started on April 15th and was completed on April 16th, 2003. Dowell-
Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender. The cement was pumped via
high-pressure hose into the conductor. The cement was brought to the top of conductor on each well. The
blender/pump and hose worked down the line, filling the identified wells until the list was completed. The
attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks
used on each conductor.
Please call MJ Loveland or Nina Woods at 907-659-7224, or me at 659-7043 if you have any questions.
Sincerely,
Jerry Dethlefs
ConocoPhillips Problem Well Supervisor
Attachment
Alpine L;ement Iop ~-~11
Subject: Alpine Cement Top Fill
Date: Wed, 23 Apr 2003 17:38:26 -0800
From: "Jerry C Dethlefs" <Jerry. C.Dethlefs@conocophillips.com>
To: Tom Maunder <tom_maunder@admin.state.ak.us>
CC: "n1617" <n1617@conocophillips.com>
Tom: Attached is a letter and spreadsheet with the data mentioned in the
previous email. Thanks for the relief on all the Sundry's! Let me know if
you need additional information.
Jerry Dethlefs
Problem Well Supervisor
ConocoPhillips Alaska(See attached file: AOGCC ALPINE cement top outs
04-16-03.xls)(See attached file: Cement Top Fill AOGCC Letter 04-23-03.doc)
Tom Maunder <tom_maunder@admin.state.ak.us>
04/23/2003 t2:51 PM
To: Jerry C Dethlefs/PPCO@Phillips
cc:
Subject: Re: Sundry's for topping off cement
Hi Jerry,
I agree Jerry that individual 404's aren't necessary. Send a "global
document"
with the information you list. There should also be some sort of
introduction
that describes why you did what you did and how you did it.
Tom
Jerry C Dethlefs wrote:
> Tom: Last week we had a cement crew go down the line at Alpine, top
filling
> the conductors with cement. I believe 34 wells were treated. Chuck Scheve
> and John Crisp were notified but declined to witness when we told them
what
> we were doing. Some time past we had agreed to submit a 10-404 for this
> kind of work. Due to the number of these, is a 10-404 needed on each
well?
> I don't want to commit the time to doing this if it is not necessary;
> 10-404's are time consuming to prepare. Would a list of the jobs suffice,
> or something similar? We have the weft numbers, depth to cement top, and
> sacks used to fill the void. My proposal would not affect future
> submissions of 10-404's for this work. What do you think? Thanks!
> Jerry Dethlefs
(See attached file: tom_maunder.vcf)
1 o~.;A~NE~ ~ ~ 0 2003 4/24/2003 7:55 AM
Alpine Cement Top Fill
Name: AOGCC ALPINE cement top outs 04-16-03. xls
[~AOGCC ALPINE cement top outs 04-16-03.xls Type: EXCEL File (application/msexcel)
Encoding: base64
r-~Cement Top Fill AOGCC Letter 04-23-03.doc
Name: Cement Top Fill AOGCC Letter 04-23-03.d°c
Type: WINWORD File (application/msword)
Encoding: base64
Tom Maunder <tom maunder~admin.state.ak, us>
Sr. Petroleum Engineer
Alaska Oil and Gas Conservation Commission
4/24/2003 7:55 AM
DATA SUBMITTAL COMPLIANCE REPORT
2/$/2002
Permit to Drill No. 1991200 WelIName/No. COLVILLE RIV UNIT CDI-03 Operator PHILLIPS ALASKA INC. APl No.
50-103-20319-00-00
MD 10897 TVD 7007 Completion Date 1/5/2000 Completion Status WAGIN Current Status WAGIN UIC Y
~2
REQUIRED INFORMATION
Mud Log No Samples No Directional Survey No
DATA INFORMATION
Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint)
Well Log Information:
Log/ Interval
Data Digital Digital Log Log Run OH / Dataset
Type Media Format ._Najne~,~._. Scale Media No Start Stop CH Received Number Comments
6 ................................ ;'~ '-iM-p:CDR/GR-MD 2,5 ....... FI-ELD 246-,~ ..... ;(08,56 ...... OH
b~'ADN-MD 25 FIELD 6969
I~ADN-TVD 25 FIELD 6450
·
(L//" IMP[CDR/GR-TVD 25 FIELD 2330
~ SRVY RPT
t~z'r SRVY CALC
7740 OH 2/4/2000
6970 OH 2~4~2000
6978 OH 2~4~2000
O 2/4/2000 '~4~7
OH 1/12~2000
10897 OH 31812000
7728 CH 4/10~2000
2450-10896
SCHLUM 114.-10896.
BH.
BE(C) UIC
0
LI~ SCMT 5 FINAL 100
~/JWL-TME/PRES 5 FINAL 7425 7728 CH 4/10/2000 UIC
Well Cores/Samples Information:
Interval Dataset
Name Start Stop Sent Received Number Comments
ADDITIONAL INFORMATION
Well Cored? Y/~N_~
Daily History Received?
Formation Tops Receuived? ~__~/N
Comments:
DATA SUBMITTAL COMPLIANCE REPORT
2/5/2002
Permit to DriiINo. 1991200 WelIName/No. COLVILLE RIV UNITCD1-03 Operator PHILLIPS ALASKA INC. APl No.
50-103-20319-00-00
MD 10897 TVD 7007 Completion Date 1/5/2000 Completion Status WAGIN Current Status WAGIN UIC Y
:----~_~_~::_:~ .-:: ~ :~_-'-:_~ '-:~_~: ~_-:~' :~_c~:_-:~: :_~_~.]~ ~:-~':-_~:__~_-- ~:_~._-~_-::~- -~-:_-~ ~::~: _c_-~':~:-~-:-:~ :::: ~::~ :::: ~ ~-:: -~ .::-::.~ .... ~:~ _-~ ~-_~ _~._~__~:-~---.:..~ ~::-._~- ~ .: :~ --~.--_ ....~L-_~ - - -~._-~- .....~ ....
Compliance Reviewed By: ~ _ ~ Date: ~---~ ~'~, /,~ ~'~"~,-.
PHILLIPS Alaska, Inc.
Subsidiary of PHILLIPS PETROLEUM COMPANY
Post Office Box 100360
Anchorage, Alaska 99510-0360
P. Mazzolini
Phone (907) 263-4603
Fax: (907) 265-6224
April 24, 2001
RECEIVED
APR
Ms. Wendy Mahan
Natural Resource Manager
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
Re: KuPamk Area Annular Disposal, First Quarter, 2001
Dear Ms. Mahan:
Please find attached the report with the volumes disposed into surface casing by production casing
annuli during the first quarter of 2001, as well as total volumes disposed into annuli for which
disposal authorization expired during the first quarter of 2001.
PleaSe call me at 263-4603 should you have any questions.
Sincerely,
Paul Mazzolini
Drilling Team Leader
PM/skad
CC:
Marty Lemon
Mike Mooney
Paul Mazzolini
Randy Thomas
Chip Alvord
Scott Reynolds
Kuparuk Environmental: Engel / Snodgrass
B. Mordson and M. Cunningham
Sharon Allsup-Drake
Well Files
Annular Disposal durin ; the first quarter of 2001:
h(1) ' h~(2) ' h(3~ Total for Previous New Start End Source Wells
Well Name Volume Volume Volume Quarter Total Total Date Date
CD1-44 8929 100 0 9029 22899 31928 Dec. '00 Jan.'01 ci)1-33, Cm-NQ1, Cra-10, Cm-28
2N-318 12276 100 0 12376 1619 13995 Dec.'00 Jan.'01 2N-314
CD1-43 30552 100 0 30652 385 31037 Jan.'01 Feb.'01 CD1-NQ1, CD1-21
CD1-31 6698 100 0 6798 392 7190 Feb.'01 Mar.'01 CDI-14
1D-42 17187 100 0 17287 15118 32405 Dec.'00 Jan.'01 1D-37, 1D-39
1D-32 23162 100 0 23262 337 23599 Jan.'01 Feb.'01 1D-39
1J-03 13020 100 0 13120 0 13120 Mar.'01 Mar.'01 1J-09~ 1J-14
Zoo - o 5'5"
~.oo - ~oo
Zoo - I oi,
Z,.oO - 01,=, _
Total Volumes into Annuli Cor which Disposal Authorization Expired during the first quarter 2001:
Total Voiume Start End Source Wells
Total h(1) Total h(2) Total h(3) Injected Date Date
Well Name Volume Volume Volume Status of Annulus
1L-28 9837 100 0 9937 Open, Freeze Protected March 2000 April 2000 1L-20A, 1L-26A
CD1-27 32714 100 0 32814 Open, Freeze Protected May 2000 June 2000 CD1-44, CDI-19A,
CD 1-09, CD 1-06
CD1-38 20220 100 0 20320 Open, Freeze Protected March 2000 May 2000 CD 1-44, CD 1-41, CD
19A
CD1-05 286 100 0 386 Open, Freeze Protected Jan. 2000 Jan. 2000 CD1-05
CD1-03 33890 100 0 33990 Open, Freeze Protected Aug. 2000 Sept. 2000 CD1-43, CD1-31, CD1-
30
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Julie Heusser ,~' \~3~' DATE: March 30, 2001
Chairman ~' ~'
/-"~~--~"~UBJECT: Mechanical Integrity Tests
THRU: Tom Maunder Phillips
P.I. Supervisor CD1 Alpine
fA. [~.~-O \ Colville River Unit
FROM: Chuck Scheve Alpine
Petroleum Inspector
NON- CON,,Fi,DENTIAL
I ' . , .. P, acker De~ Pm. test In.itJal 15 Min. 3..0 Min. , ..
'Well! CDI'O1 I Type~nj.I SW IT.V.D. I SSS5 ITUbin~'l 450I ;450I 450! 450 l,n~a,
I ..-r.[~.~ ~"~.~ I~-vm~,,I .' IT~tp~il i721 ! C,,~".n..'l.] ~ '! ~°°°i 5~ I ~000 I "~. i.__"
I Notes:
I' w.,I CDl-O2 'lType~"J.I S I T.9.b."l 6824 Imab~gl 50 ! 5o 'l"so .I '.'.'sO'
I N°t-: ' ' .................
I wel,I CD.~_-o3 l:._T'yminJ, i' '; 'I'J:.V.D.'I'se8'~ I Tubingl 20 I ~'0"1 20''l' 20 l~,ter~,,~l' ~ '
I ~iT:",D:l~::;l~'~20:i[~,pe~tl'' P ' ITestPSil 1720 i Casingl 0 !i'~850 ii !880-1..1850 I' P/F .!
cra-os I Typ~i,;j.l' ~ I .T.V.O. I S~.' l'Tu, bing'l ~'58° I
2550 I 5550 I 28~o
199-128 ITypetasti P. ITastpsil 1671 icasing. I ..7.,5o I ~"so,I 1950 I ]950 I, P/FIB
:~ w~,!
,,P.T.D.
Notes:
"P.T~D.I
Notes:
' W~,l
P.TiDiI
Notes:
i.T'9'""! ~i I T'uU","I ooo, I oooI ooo ,-
200-o83 ITypetestl .p ,ITestpsil 1642 l, aasinel ,.,0 ..J 1,9001 19001 1900 I_P/F lB
CDl'-13-1'TYPeini-! ~ 1T.V.D:I ..6781i TubingI. soo I soo '1 ~oo' I '.'~'oo i~ntewa~l I !
199"052 ITypeteStl P .ITastpsil .1~1 ICasing ! o .I ls5O .I 1850'1 1~5o I P/F I.P I
I
CD1-16 I YYPe Ini-! ~ "i I T.VJbl i" 6~3~
i T'Ub. tng.! 450 I. ~..~o',jl ~5o I '45o I,nte~'all ' I'
~g~o~,.ITypetesti , ..P ITest~",l.
1,683 I c~,,; I o I 1800 1 1800 I. ~S.00 I P~.. I -P
w~,,! CD1-,~9 ITy, pelni.! ',N .'.1 ,T.V.D.: I ss2o ! ~.uU'.ng !' .~.~.~ ! ~.oo. I ~,2-,od 1 220b l lntervall,,' ~
P.T.D.I 200-040 ITypeteStl P I'r.estpsil ~855 I caSin~l 0, J.!.900 I 1.,900 i.1900 I ~/F I P
Notes: Cla.s.s 2 disposal w.ell
i Welll CD1-23 I T..~,e,.~.i . I T.V.D. 1'8785 ITuUngl 2501 2501 250'1 '25o l lr~tervall i
P.T.D.i 19~S,l~pet~ti ,P 'l,T~tPS,I ,1~,9 I',c~!ngl .0 .I ].9°°'i1'~9°° ! .1900'' I' P/F, I --~
Notes: This well failed a previous test
Type INJ. Fluid Codes
F = FRESH WATER INJ.
G = GAS INJ.
S = SALT WATER INJ.
N = NOT hNJECTING
Type Test
M= Annulus Monitoring
P= Standard Pressure Test
R= inlemal Radioactive Tracer Survey
A= Temperature ~aly Survey
D= Differential Temperature Test
h3terv~
!= Initial Test
4= Four Year Cycle
V=- Required by Variance
W= Test during Workover
O= Other (describe in notes)
Test's Details
I traveled to the Phillips Alpine location and witnessed thc initial mechanical i. ~i_njection wells. All
pretest pressures were observed for 1 hour+ while waiting for pumping equipment to arrive and were found to be stable.
A standard annulus pressure test was then performed with alt 9 wells dcmonstrating good mcchanical integrity.
M.I.T.'s pertormecl:::9_
Attachments:
Number ot Failures:
TOtal Time during tests:
cc.._[:
MIT report form
5/12100 L.G.
010330-MIT Alpine-CS
4/4/01
PHILLIPS Alaska, Inc.
Subsidiary of PHILLIPS PETROLEUM COMPANY
Post Office Box 100360
Anchorage, Alaska 99510-0360
P. Mazzolini
Phone (907) 263-4603
Fax: (907) 265-6224
October 13, 2000
Ms. Wendy Mahan
Natural Resource Manager
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501-3192
Re: Kupamk Area Annular Injection, Third Quarter, 2000
Dear Ms. Mahan: "~s~;~ :-: :: ~.
Please find reported below the volumes injected into surface casing"¢~'~6duction"~sing annuli
during the t~rd queer of 2000, as well as tot~ volumes injected into annuli for which injection
authorization expired during the t~rd queer of 2000.
Annular Injection during the third quarter of 2000:
h(1) h(2) h(3) Total for Previous New
Well Name Volume Volume Volume Quarter Total Total
CD1-45 5036 100 0 5136 365 5501
CD1-03 33505 100 0 33605 385 33990-
1D-14 33916 100 0 34016 1487.5 35503.6
CD1-25 24860 100 0 24960 8627 33587
2N-341 13544 100 0 13644 20506 34150
2N-335 25395 100 0 25495 0 25495
2N-347 14666 100 0 14766 340 15106
1D-38 33907 100 0 34007 0 34007
1D-30 30492 100 0 30592 0 30592
2N-318 220 100 0 320 0 320
2N-316 240 100 0 340 0 340
CD1-43 285 100 0 385 0 385
~.q. o%q
'iS'to'5
l.oo- oq°
2'oo - I o [,
Ms. Wendy Mahan
AOGCC
Third Quarter 2000 Annular Injection Report
Page Two
Total Volumes into Annuli for which Injection Authorization Expired during the third quarter 2000:
Total
Total h(1) Total h(2) Total h(3) Volume
Well Name Volume Volume Volume Injected Status of Annulus
CD 1-39 31408 100 0 31508 Open, Freeze Protected
1D-12 32791 100 0 32891 Open, Freeze Protected
CD1-37 32487 100 0 32587 Open, Freeze Protected
CD1-23 33886 100 0 33986 Open, Freeze Protected
CD1-01 5121 100 0 5221 Open, Freeze Protected
Please call me at 263-4603 should you have any questions.
Sincerely,
Paul Mazzolini
Drilling Team Leader
CC;
Marty Lemon
Mike Mooney
Paul Mazzolini
Randy Thomas
Chip Alvord
Scott Reynolds
Kuparuk Environmental: Engel / Snodgrass
B. Morrison and M. Winfree
Sharon Allsup-Drake
Well Files
Re: CD1-03 Sundry Request -
Subject: Re: CD1-03 Sundry Request
Date: Wed, 26 Apr 2000 11:44:15 -0800
From: Blair Wondzell <blair_wondzell~admin. state.ak.us>
Organization: State of Alaska, Dept of Admin, Oil & Gas
To: Michael D Erwin <MERWIN~mail.aai.arco.com>
CC: torn_maunder~admin.state.ak.us, Allen Sanders <ASANDER1 ~mail.aai.arco.com>,
bill_liddell~anadarko.com, Jack T Kralick <N1030@mail.aai.arco.com>,
G Mark Chaney <GCHANEY~mail.aai.arco.com>
Mike,
We are reviewing the 403. It is to the Commissioners for approval. If you don't
receive it by Friday, please call me.
Sincerely, Blair Wondzell
Michael D Erwin wrote:
> Blain and Tom,
> I am forwarding over to your for review and approval a late sundry request for
> pending wel!work on well CDi-03. This is a new injection well which needs an
> coil tubing fill clean out and acid stim to prep it for immediate use when the
> field starts up. The paperwork will be in your office in the am after normal
> courier delivery.
> I regret the short notice request, but your prompt approval would be appreciated
> as the work could begin by the end of this week. Please call me at 240-5817 if
> you have any questions.
> mike
1 of 1 4/26/00 11:45 AM
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of request:
Alter casing _
Change approved program __
Abandon _ Suspend _ Operation Shutdown _
Repair well __ Plugging _ Time extension __
Puli tubing _ Variance _ Perforate _
Reenter suspended well _
Stimulate X
Other _
2. Name of Operator:
ARCO Alaska, Inc.
3. Address:
P.O. Box 100360, Anchorage, Ak, 99510-0360
4. Location of well at surface
236' FNL, 2558' FWL, Sec. 5, T11 N, R5E, UM
At target (7" casing point in Alpine))
168' FNL, 1767' FEL, Sec.5, T11 N, R5E, UM ....
At effective depth
At total depth
2332' FSL, 295' FEL, Sec.5, T11 N, R5E, UM ......
5. Type of Well:
Development _X
Exploratory __
Sfrofogropic __
Service _
per APD
per APD
6. Datum of elevation (DF or KB feet):
RKB 32.4
feet
7. Unit or Property:
Colville River Unit
8. Well number: CD1-03
9. Permit number: 9%120
0. APl number: 50-103-20319-00
1. Field/Pool: Colville River Field
Alpine Oil Pool
12. Present welt condition summary
Total Depth: measured
true vedical
Effective Depth: measured
true vertical
Casing Length
Conductor 77'
Surface 2486'
Production 7782'
10897 feet Plugs (measured) N/A
7007 feet
10897 feet Junk (measured) N/A
7007 feet
Size Cemented
16" 10 cu.yds, Podland Type 3
9.625" 509 sx ASL3, 230 sx Class
G
7" 119 sx Class G
Measured depth True vedicaldepth
114' 114'
2522' 2369'
7816' 6970'
Perforation Depth ;)penhole 7816' - 10879' MD
tubing (size. grade, and measured depth)
ORIGINAL " ' ooo
· ~aska 0ii & Gas Cons. Commission
Anch0r~ge
4-1/2", 32.6 ppf, L-8OIBT-Mod @ 7522'MD
Packers and SSSV (type and measured depth)
4-1/2" x 7" Baker S-3 @ 7466' MD
4-1/2" Camco A-1 SSSV in DB-6 nipple @ 1781' MD
13. Attachments
Description summary of proposal _X Detailed operations program _ BOP sketch _X
14. Estimated date for commencing operation 115. Status of well classification as:
I
Oil _ Gas _
Service WAG Injector
April26. 2000
16. If proposal was verbally approved
Name of approver Date approved
Suspended _
17. I hereby certify that the forgoing is true and correct to the best of my knowledge.
FOR COMMISSION USE ONLY
Date
Conditions of approval: Notify Comission so representitive may witness
Plug integrety _ BOP test ~ Location clearance _
Mechanical integrety test_ Subsequent form required 10-
ORIGINAL SIGNED BY
Robert N. Christenson
Approved by order of the Commissioner
Form 10-4D3 Rev 06/15/88
C o m missjo_%e.el;
.~ oO.~!e6~
,-Returned.
IAppr°val N°'¢OO-il 0
""' ~SUBMITIN TRIPLICATE
Stimulation Procedure
Colville River Field
CD1-37
Stimulation operations are expected to commence on or about April 26, 2000.
This procedure is designed to clean out and stimulate a newly drilled WAG well for injection.
The goal is to remove remnant drill cuttings, filter cake and polymer from the openhole
completion. In the process, an additional formation breakdown test will provide insight into
future performance of the wellbore.
1. RU coil tubing unit. GIH with jet nozzle to cased wellbore TD @ 7800' MD to circulate and
wash the wellbore & coil tubing clean of debris or sand with seawater or brine.
2. Circulate around a caustic pill consisting of approximately 30 bbl. of Arco's Caustic SL,
chased by seawater or brine.
3. GII-I with jet nozzle to open hole TD @ 10,897' MD to circulate and wash the wellbore &
coil tubing clean of debris or sand with seawater or brine.
4. Circulate around a surfactant pill consisting of approximately 10 bbl. of Arco's Caustic SL,
chased by seawater or brine.
5. Lay in +/- 120 bbl. of 8% Formic Acid and 4% Ammonium Chloride Brine in the openhole
interval.
6. POOH and allow the acid to soak for 4-6 hours.
7. GIH & circulate and wash back through openhole with remaining 180 bbls of 8% Formic
acid. Overflush acid away with 500 bbl of Brine or Seawater. POOH.
8. GIH w/packer on coil. Set packer within 100' of the toe of the wellbore and break down the
formation with seawater or brine.
9. Release the packer and POOH.
RECEIVED
'"/: 25 2000
Aia~ka Oil & Gas Cons, Commission
Anchorage
C T Drilling Wellhead Detail
Methanol Injection
tis 7' WLA Quick
onnect ~
"-CT Injector Head
Stuffing Box (Pack-Off), 10,000 psi Working Pressure
--- 7" Riser
Alignment Guide Flange
7-1/16", 5M Ram Type Dual
Gate BOPE
Flanged Fire Resistant
Kelly Hose to Dual HCR
Choke Manifold
Annular BOP (Hydril),7-1/16' ID
5,000 psi working pressure
Cutters or
Combination Cutter/Blinds
Slip / Pipe rams
Manual Valves Drilling spool 7-1/16', 5M
by 7-1/16', 5M
Ram Type Dual Gate BOPE
Manual over Hydraulic ~
7-1/16" ID with
Pipe/Slip Rams
Manual Master Valve
0.458' (5.5")
2" Pump-In
Hanger
Fire resistant Kelly Hose to
Range by Hammer up 1/4 Turn
Valve on DS Hardline to Standpipe
manifold
9-5/8' Annulus
13-3/8" Annulus
/ .... 2 5 2000
0ii & Gas Co~ts, Cornfflissior~
Ancho~cge
cc' w/enclosures
Mr. Kenneth A. B oyd, Director
Alaska Department of Natural Resources
Division of Oil & Gas
3601 C Street, Suite 1380
Anchorage, Alaska 99503-5948
Ms. Teresa Imm, Resource Development Manager
Arctic Slope Regional Corporation
301 Arctic Slope Avenue, Suite 300
Anchorage, Alaska 99518-3035
Mr. Isaac Nukapigak, President
Kuukpik Corporation
PO Box 187
Nuiqsut, Alaska 99789-0187
Mrs. Catherine Lively
Anadarko Petroleum Corporation
PO Box 1330
Houston, Texas 77251-1330
Schlumberger
Schlumberger Technology Corporation, by and through is Geoquest Division
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Sherrie
NO. 121346
Company:
Alaska Oil & Gas Cons Comm
Attn: Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
4/4/00
Field:
Alpine
(Cased Hole)
Color
Well Job # Log Description Date BL Prints Sepia CD
~D1-03 Lt ~ ~ 20127 SCMT 000313 1
CD1-03 20127 JEWELRY LOG 000313 I 1
CD1-05 20128 SCMT 000313 1
.CD1-05 20128 JEWELRY LOG 000313 I 1
CD1-36 20122 SCMT 000311 1
CD1-36 20122 JEWELRY LOG 000311 I 1
CD1-37 20123 SCMT 000311 1
CD1-37 20123 JEWELRY LOG 000311 I 1
CD1-39 20124 SCMT 000311 1
CD1-39 20124 JEWELRY LOG 000311 I 1
CD1-42 20125 SCMT 000312 1
CD1-42 20125 JEWELRY LOG 000312 I 1
CD1-45 20126 SCMT 000312 1
CD1-45 '"' 20126 JEWELRY LOG 000312 I I
Alaska 0il & Gas ¢0,qs. ~0mmissi0n
Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Than~l~.rage
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
March 3, 2000
Mr. Robert Christenson
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Subject: CD1-03 (Permit No. 199-120) Well Completion Report
Dear Mr. Commissioner:
Enclosed is the well completion report for the completion on CD 1-03.
If there are any questions, please call 263-4792.
Sincerely,
,/
D. CHester
Alpine Drilling Team Leader
AAI Drilling
DC/skad
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 F~ Gas E] Suspended F~ Abandoned r~ Service r'~ Injector W&q IN
2. Name of Operator 7. PermitNurn'ber ' t.¢ I
ARCO Alaska, Inc. 199-120
3. Address 8. APl Number
P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20319-00
Colville River Unit
236' FNL, 2558' FWL, Sec. 5, T11N, R5E, UM (ASP: 385986, 5975891)
At Top Producing Interval '~.j%~ ~"~"~-.~.~_, ! ' I 10. Well Number
75' FNL, 1788' FEL, Sec. 5, T11N, R5E, UM (ASP: 386919, 5976038) ; 'r.''-~:_:*: ! CD1-03
At Total Depth ..... '~" .l 11. Field and Pool
2307' FSL, 335' FEL, Sec. 5, T11 N, R5E, UM (ASP: 388336.6, 5973121.5) Colville River Field
5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Alpine Oil Pool
DF 56 feetI ADL 25559 & 25558
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions
December 22, 1999 January 3, 2000 January 5, 2000I 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
10897' MD/7007' TVD 10897' MD/7007' TVD YES r~l No [-1I N/A feetMD 1629'
22. Type Electric or Other Logs Run
GR/Res/Neut/Dens
23. CASING, LINER AND CEMENTING RECORD
SE-I-FING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED
16" 62.5# H-40 Surface 114' 42" 10 cu yds Portland Type 3
9.625" 36# J-55 Surface 2522' 12.25" 5o9 sx AS III L, 230 sx Class G
7" 26# L-80 Surface 7816' 8.5" 119 sx Class G
24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
4.5" 7523' 7466'
OH completion 6.125" OH from 7816' - 10879' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
N/A N/A
27. PRODUCTION TEST
Date First Production Method of Operation (Flowing, gas lift, etc.)
t'~ ....
Waiting on Facility Start-Up
Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO
I
Test Period >
Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr)
24-Hour Rate >
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips.
· ,
,
- ..
. .'.--:~
Form 10-407 Rev. 7-1-80 CONTINU ED ON REVERSE SIDE Submit in duplicate
29.
CD1-03
NAME
Top Alpine
TD
GEOLOGIC MARKERS
MEAS. DEPTH
7648'
10897'
TRUE VERT. DEPTH
6950'
70O7'
30.
FORMATION TESTS
Include interval tested, pressure data, all fluids recovered and gravity.
GOR, and time of each phase.
Annulus left open - freeze protected with diese
31. LIST OF A-I-rACHMENTS
Summary of Daily Operations, Directional Survey
32. I hereby certify that the following is true and correct to the best of my knowledge.
Signed ¢'v,,~,~'~ ~../(/(,/j.¢.¢(/-,,r,,-'l Title Drillinq Team Leader
/oug Chester
Questions? Call Brian Robedson 265-6034
INSTRUCTIONS
Prepared by Sharon AIIsup-Drake
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
Date: 02/09/00
ARCO ALASKA INC.
WELL SUMMARY REPORT
Page: 1
WELL:CD1-03
WELL_ID: 998B12 TYPE:
STATE:ALASKA
COUNTY: NORTH SLOPE WEST
FIELD: COLVILLE RIVER UNIT
SPUD:12/22/99 START COMP:
RIG:DOYON 19
BLOCK:
FINAL:
WI: 0% SECURITY:0
API NUMBER: 50-103-20319-00
12/21/99 (D1) MW: 8.8 VISC: 145 PV/YP: 16/34
TD/TVD: 114/114 (114) DRILLING 12 1/4" HOLE AT APPROX. 600'
SUPV:REYNOLDS/WHITELEY/GOLDBERG
N/U diverter. Hold pre-spud meeting.
APIWL: 15.8
12/22/99 (D2) MW: 9.5 VISC: 180 PV/YP: 22/43 APIWL: 18.0
TD/TVD: 2120/1999 (2006) DRILLING 12 1/4" LOOKING FOR SURFACE TD
SUPV:LUTRICK/GOLDBERG
Hold spill drill. Function test diverter equipment. Drill
12-1/4" surface hole from 114' to 1549'. Circulate and
condition mud for wiper trip. Pump out 6 stands and then
pulled tight. Work pipe free at 975' and run back in hole
without problems. Drill surface hole from 1549' to 2120'
12/23/99 (D3) MW: 9.7 VISC: 65 PV/YP: 21/17 APIWL: 16.0
TD/TVD: 2532/2379 ( 412) TESTING BOPE
SUPV:LUTRICK/GOLDBERG
Drilling 12-1/4" hole from 2120' to 2532' Short trip to
1480'. POOH. PJSM. Run 9-5/8" casing. Pump/push through
tight spot from 940' to 1060' R/U hardlines to new annular
injection well CD1-32. Hardline froze up. Attempt to regain
circulation with warm diesel. R/U cementing head and
circulate and condition mud for cement job. PJSM. Pump
cement. Bumped plug. Floats held.
12/24/99 (D4) MW: 9.6 VISC: 42 PV/YP: 10/24 APIWL: 7.0
TD/TVD: 3475/3264 ( 943) DRILLING 8 1/2" HOLE ~ 3860'
SUPV:LUTRICK~GOLDBERG
N/D flowline, N/U BOP stack and test BOPE to 3500 psi. Test
9-5/8" surface casing to 2500 psi. Test successful. Drill
F/C, shoe joints, F/S and 20' of new hole to 2552'
Circulate and condition mud to ensure 9.5 ppg all the way
around. Perform LOT, 15.8 ppg EMW. Displace hole to new
LSND mud. Drill 8.5" intermediate hole from 2552' to 3475'
12/25/99 (D5 MW: 9.6 VISC: 43 PV/YP: 8/27 APIWL: 6.4
TD/TVD: 5636/5310 (2161) DRILLING 8 1/2" HOLE AT 6012'
SUPV:LUTRICK/GOLDBERG
Drilling 8.5" hole from 3475' to 3542'. Short trip to
2496' Wash last stand to bottom. Drill 8.5" intermediate
hole from 3542' to 4969'. Short trip from 4969' to 3535'
No problems. Drill 8.5" hole from 4969' to 5536' Generator
overheating. Drill 8.5" hole from 5536' to 5636'.
Date: 02/09/00
ARCO ALASKA INC.
WELL SUMMARY REPORT
Page: 2
12/26/99 (D6) MW: 9.6 VISC: 47 PV/YP: 11/25 APIWL: 4.8
TD/TVD: 6969/6514 (1333) RIH WITH BHA #3
SUPV:LUTRICK/GOLDBERG
Drilling 8.5" intermediate hole from 5636' to 6969'
Circulate sweep around. C&C mud for trip out. POOH with
8.5" BHA to 5985'. Some tight spots from 6550' to 6230'
Flush out BOPE with jt of 5"
12/27/99 (D7) MW: 9.6 VISC: 47 PV/YP: 12/24 APIWL: 4.6
TD/TVD: 7568/6925 ( 599) DRILLING 7756'
SUPV:LUTRICK
RIH to 6969' Filled pipe at 4900' Drilling from 6969' to
7568'
12/28/99 (D8) MW: 9.6 VISC: 44 PV/YP: 11/23 APIWL: 4.9
TD/TVD: 7826/6970 (258) CIRC AND CONDITION MUD AT 7816'
SUPV:LUTRICK / REILLY
Drilling from 7568' to 7826'. Circ sweep. Monitor well.
Wiper trip to 6200'. No problems. Circ sweep. Pump slug.
POH. Held prejob safety meeting. RIH w/ 7" casing. CBU. RIH
w/7" casing.
12/29/99 (D9) MW: 9.7 VISC: 44 PV/YP: 8/18 APIWL: 5.5
TD/TVD: 7826/6970 ( 0) DRILL CEMENT AND FLOAT EQUIPMENT
SUPV:LUTRICK / REILLY
RIH w/7" casing to 6000' CBU. Land casing at 7816'. Circ
and condition mud. No losses. PJSM. Pump cement. Bumped
plug to 3500 psi. Check floats, OK. Test BOPE to 300/3500
psi w/annular to 2500 psi. RIH w/ HWDP to 7575'. Wash from
7575' to 7677'
12/30/99 (D10) MW: 9.2 VISC: 43 PV/YP: 9/23 APIWL: 4.8
TD/TVD: 8436/6963 ( 610) DRLG AT 8677'
SUPV:LUTRICK / REILLY
Test casing to 3500 psi. Kick drill. Wash to 7670' Drill
out cement, float equipment and 20' new formation to 7846'
Circ and condition mud to balance wt. Performed FIT,
12.5ppg EMW. Displace to 9.2 Flo-pro mud. Drilling from
7846' to 8436'
12/31/99 (Dll) MW: 9.2 VISC: 46 PV/YP: 10/25 APIWL: 4.0
TD/TVD: 9246/6982 (810) DRILLING AHEAD @ 9536'
SUPV:REYNOLDS / REILLY
Drill from 8436' to 8821'. Circulate sweep. Pump out to
shoe ~ 7816'. Circulate while reciprocating and rotating
pipe. RIH to 8727'. Ream in from 8727' to 8821' Drill from
8821' to 9246'
Date: 02/09/00
ARCO ALASKA INC.
WELL SUMMARY REPORT
Page: 3
01/01/00 (D12) MW: 9.2 VISC: 50 PV/YP: 9/24 APIWL: 4.8
TD/TVD: 9840/6988 (594) CIRCULATING LCM(MIX II FINE) ~ 12 SKS PER HOUR. LOSSE
SUPV:REYNOLDS / REILLY
Drill from 9246' to 9840'. Loss returns. Observe well. Pump
nutplug & MIX II. Partial returns obtained. Pump MIX II LCM
pill. Displace pill out of DP. Shut down to monitor well.
Static, no losses. Pump out to shoe @ 7816' Circulate
while recip & rotating. Monitor well for losses, no losses.
RIH to 9834' with no problems. Circulate and monitor
losses. Partial returns with flow show. Pump MIX II LCM
pill. Drilled 30' of new hole once pill in DP.
01/02/00 (D13) MW: 9.2 VISC: 46 PV/YP: 9/24 APIWL: 5.2
TD/TVD:10364/7000 (524) DRILLING AHEAD ~ 10655' LOSING 0-20 BPH.
SUPV:REYNOLDS / REILLY
Drill from 9840' to 9874'. Noticed increased flow on flow
show while losing mud. Shut down and observe well. Well
flowing. Flow decreased. Well is breathing. Circulate BU
through choke and gas buster, no gas no oil. Closed choke
to observe pressure. Opened well. Drill from 9874' to
9925'. Circulate and monitor losses. Pump MIX II LCM pill.
Drill from 9925' to 10364' Losses averaging 40-60 bph.
01/03/00 (D14) MW: 9.2 VISC: 44 PV/YP: 9/26 APIWL: 5.2
TD/TVD:10897/7007 (533) DISPLACING WELL TO 9.2 PPG BRINE
SUPV:REYNOLDS / GOLDBERG
Continue drilling 6.125" hole. Loss rate at 15-40 bph.
Stringing in LCM while drilling. TD production hole at
10897' Circulate high visc sweep around to clean hole.
Spot LCM pill in openhole. Shut down pumps and monitor
well. Well began to flowback. Flowrate dropped to zero.
Continue to monitor well at zero flowrate. Pump out of hole
to 7" casing shoe. Trip OK. Hole still taking fluid.
Circulate and condition mud at 7" casing shoe. RIH to 9011'
01/04/00 (D15) MW: 9.2 VISC: 26 PV/YP: 1/ 0 APIWL: 0.0
TD/TVD:10897/7007 ( 0) DISPLACING TO INHIBITED BRINE
SUPV:REYNOLDS / GOLDBERG
Continue to circulate hole clean. RIH. Circulate and
condition mud preparing to displace to brine. Displace to
brine. Shut down and monitor well. POOH to 7" casing shoe
at 7816'. Monitor well at 7" shoe. POOH with 6.125" bit and
BHA. PJSM. Run completion jewelry. Continue running 4.5"
tubing.
01/05/00 (D16) MW: 9.6 VISC: 26 PV/YP: 0/ 0 APIWL: 0.0
TD/TVD:10897/7007 ( 0) RIG RELEASED
SUPV:LUTRICK / GOLDBERG
Continue running 4.5" tubing. Install 2 way check valve.
Test to 5000 psi. N/D BOPE. N/U tree and test to 250/5000
psi. OK. Displace well with brine with corrosion inhibitor.
Freeze protect well with diesel. Set packer. Test tubing to
3500 psi OK. Test annulus to 3500 psi OK. Secure well and
rig down. Rig released ~ 1300 hrs. 01/05/2000.
,1;L aC, SURVEY CALCULATION AND FIELD WORKSHEET Job No, 0450-00003 Sidetrack No. Page 1 of 8
i ,; I ~1 ~ ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #19 Field ALPINE FIELD
Well Name & No. PAD CD#1/3 Survey Section Name ~D1___-_3_ ....... ._M...W_._D_ ................................ BHI Rep, _ ..........................................
I~ · ~=:~,,J~ ' WELL DATA
Target TVD (FO Target Coord. N/S Slot Coord. N/S -236.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SSI-J
Target Description Target Coord. E/W' Slot Coord, E/W 2558.00 Magn. Declination 25.930 Calculation Method MINIMUM CURVATURE
Target Direction (DD) Build\Walk\DL per: 10'Oft~ 30mil] lOmJ-'J Vert. Sec. Azim. 151.94 Magn. to Map Corr. 25,930 Map North to: OTHER
SURVEY DATA
Total Coordinate Build Rate Walk Rate
Survey Survey Incl. Hole Course Vertical Build (+) Right (+) Comment
Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL
Type (FO (OD) (DO) (FO (FO (FO (FO (Per tOO FT) Drop (-) Left (-) .......
0.00 0.00 0.00 0.00 0,00 0.00 0,00 TIE IN POINT
22-DEC-99 MWD 114.00 0.00 0.00 114.00 114.00 0.00 0.00 0.00 0.00 0.00 9 1/2" M1C 1.4 DEC AKO
22-DEC-99 MWD 180.00 0.25 240.00 66.00 180.00 0.00 -0.07 -0.12 0.38 0.38 GSS
22-DEC-99 MWD 297.31 1.06 320.30 117.31 297.30 -1.05 0.63 -1.04 0.89 0.69
22- DEC-99 MWD 387.46 3.08 330.20 90.15 387.39 -4.29 3.38 -2.78 2.27 2.24
22-DEC-99 MWD 476.57 5.60 336.19 89.11 476.24 -11.02 9.43 -5.72 2.87 2.83 6.72
22-DEC-99 MWD 566.42 8.60 338.62 89.85 565.39 -22.06 19.70 -9.94 3.35 3.34 2.70
22-DEC-99 MWD 655.24 11.11 339.36 88.82 652.89 -37.15 33.90 -15.38 2.83 2.83 0.83
22-DEC-99 MWD 743.75 12.43 341.42 88.51 739.54 -55.00 50.91 -21.42 1.56 1.49 , 2.33
22-DEC-99 MWD =833.61 15.32 345.43 89.86 826.77 -76.09 71.57 -27.49 3.39 3.22 4.46
22-DEC-99 ~ MWD 923.82 18.13 343.37 90.21 . 913.15 -101.44 96.56 -34.51 3.18 3.11 -2.28
22-DEC-99 MWD 1012.46 21.20 343.77 88.64 996.61 -130.65 125.17 -42.93 3.47 3.46 0.45
22-DEC-99 MWD 1107.27 25.57 342.03 94.81 1083.62 -167.59 161.11 -54.04 4.67 4.61 -1.84
22-DEC-99 MWD 1202.60 25,83 341.11 95.33 1169.52 -208.35 200.33 -67.11 0.50 0.27 -0.97 ,
22-DEC-99 MWD 1297.80 25,51 341,78 95.20 1255.32 -249,02 239.42 -80.24 0.45 -0.34 0,70
22-DEC-99 MWD 1392.82 25.33 339.74 95.02 1341.14 -289.32 277.92 -93.68 0.94 -0.19 -2,15
22- DEC-99 MWD 1488.04 25.25 338,95 95.22 1427.24 -329.66 315.99 -108.02 0.36 -0.08 -0.83
22-DEC-99 MWD 1580,47 24,98 336.38 92.43 1510,93 -368.68 352.27 -122.92 1.22 -0.29 -2.78
22-DEC-99 MWD 1675,61 24.08 336.76 95.14 1597.48 -408.05 388.51 -138.63 0.96 -0.95 0,40
22-DEC-99 MWD 1772.11 24.36 339.30 96.50 1685.49 -447.41 425.22 -153,44 1.12 0.29 2.63
22-DEC-99 MWD 1867,72 24.10 340.03 95.61 1772.68 -486.29 462.01 -167.07 ' 0.41 -0.27 0.76
22-DEC-99 MWD 1962.66 23.87 339.17 94.94 1859.42 -524.54 498.18 -180.52 0,44 -0.24 -0.91
22-DEC-99 MWD 2058.62 24,77 340.91 95.96 1946.87 -563.66 535.32 -194.00 1.20 0.94 1.81
23-DEC-99 MWD 2153.91 24.49 341.83 95.29 2033.49 -602183 572.96 -206.69 0.50 -0.29 0.97
Il{i{ {
"' " SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00003 Sidetrack No. , Page 2 of 8
Company ARCO AlaSKA, INC. Rig Contractor & No. _D_o?n_.pril~_li_n..g__Co_~._-_~i_g:_~.J._~ ............................... Field ALPINE FIELD
Well Name & No. P^D CD#1/3 Survey Section Name CD1-3 MWD BHI Rep.
ww ~ w m;;;q,,m~ WELL DATA
Target TVD (F-r) Target Coord. N/S Slot Coord, N/S -236.00 Grid Correction 0,000 Depths Measured From: RKB ~ MSL[-{ SS0
Target Description Target Coord. E/W' Slot Coord. EAN 2558.00 Magn, Declination 25.930 Calculation Method MINIMUM CURVATURE
!Target Direction (DO) Build\Walk\DL per: l(~0ft[~ 30m[~ 10mi-{ Vert. Sec. Azim. 151.94 Magn. to Map Corr. 25.930 Map North to: OTHER
i
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(+) / W(-) DL Build (+) Right (+) Comment
Type (F'r) (DO) (DD) (F~ (FT) (FT) (F'I~ Per 100 FT) Drop (-) Left (-)
23-DEC-99 MWD 2250.62 24.36 342.03 96.71 2121.54 -642.22 610,97 -219.09 0.16 -0.13 0.21
23- DEC-99 MWD 2344.77 24.20 341.91 94.15 2207.36 -680.34 647.79 -231.08 0.18 -0,17 -0.13
23- DEC-99 MWD 2436.95 23.77 342,98 92.18 2291.58 -717.18 683.51 -242.38 0.66 -0.47 1.16
23-DEC-99 MWD 2471.77 23.87 342.84 34.82 2323.44 -730.99 696.95 -246.51 0.33 0.29 -0.40
24-DEC-99 MWD 2622.00 23.12 341.43 150.23 2461.21 -789.93 753.95 -264.88 0,62 -0.50 -0,94
24-DEC-99 MWD 2718.00 22.81 341.63 96.00 2549.61 -826.86 789.48 -276.74 0.33 -0.32 0,21
24-DEC-99 MWD 2813,00 22.65 341.89 95.00 2637.23 -863.03 824.34 -288.23 0.20 -0.17 0.27
24-DEC-99 MWD 2909.00 22.45 341,60 96,00 2725.89 -899.31 859.30 -299.76 0.24 -0.21 -0,30
.,,
24-DEC-99 MWD 3003,00 19.73 341.89 94.00 2813,58 -932.63 891.42 -310.36 2.90 -2,89 0.31
24-DEC-99 MWD ,3100.00 19,51 341.41 97.00 2904,95 -964.74 922.34 -320.62 0.28 -0,23 -0,49
--
24-DEC-99 ! MWD 3194.00 17.88 340.43 94.00 ' 2993.99 -994.49 950.81 -330.45 1.77 -1.73 -1.04
--
24-DEC-99 MWD 3289,00 16,89 339.06 95.00 3084.65 -1022.61 977,44 -340.27 1.13 -1.04 -1.44
--
24-DEC-99 MWD 3384.00 14,81 340.25 95.00 3176.03 -1048,32 1001.76 -349.31 2.22 -2.19 1.25
25-D EC-99 MWD 3479.00 12.29 340.83 95.00 3268.38 -1070.33 1022.74 -356,73 2.66 -2.65 0.61
25-DEC-99 MWD 3574,00 10.52 343.53 95.00 3361.50 -1088.82 1040.61 -362.51 1.95 -1.86 2.84
_ --
25-DEC-99 MWD 3669.00 8.72 344.12 95.00 3455.16 -1104.35 1055,86 -366,94 1.90 -1.89 0.62
25-DEC-99 MWD 3764.00 7.98 353.76 95.00 3549.16 -1117.52 1069.34 -369.63 1.66 -0.78 10.15
25oDEC-99 MWD 3859.00 7.61 12.21 95.00 3643.29 -1128.44 1082,04 -369.01 2.65 -0.39 19.42
25-DEC-99 MWD 3953.00 7,07 31.96 94.00 3736.54 -1136.08 1093.04 -364.64 2,73 -0.57 21.01
25-DEC-99 MWD 4049,00 7.16 56.61 96.00 3831.82 -1139.59 1101.34 -356.51 3.16 0.09 25.68
25-DEC-99 MWD 4144.00 8.53 81.19 95.00 3925.96 -1137.82 1105.68 -344.60 3.78 1.44 25.87
25-DEC-99 MWD 4239.00 9.65 101.62 95,00 4019,79 -1130.41 1105.16 , -329.84 3,57 1.18 21.51
25-DEC-99 MWD 4335.00 11.84 112.25 96.00 4114.11 -1117.69 1099,81 -312.84 3.07 2.28 11.07
25-DEC-99 MWD 4430.00 14.06 115.81 95.00 4206.69 -1100.87 1091.09 -293,42 2.48 2.34 3.75
r SURVEY CALCULATION AND FIELD WORKSHEET
~ Job No. 0__4..~_0..;.__07.~._0_3- ....... Sidetrack< No. Page 3 of 8
~ Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co.- Rig: #19 Field
Well Name & No. PAD CD#1/3 Survey Section Name CD1-3 MWD BHI Rep.
WELL DATA
Target TVD (F-r) Target Coord. N/S Slot Coord. N/S -236.00 Grid Correction 0.000 D, epths Measured From: RKB ~ MSL~} SS[~
Target Description Target Coord. E/W Slot Coord. E/W 2558,00 Magn. Declination 25,930 Calculation Method MINIMUM CURVATURE
Target Direction (DD) Build\Walk\DL per: l~Oft[~ 30mE] lOmE] Vert, Sec. Azim. 151.94 Magn. to Map Corr, 25.930 Map North to: OTHER
SURVEY DATA
Survey Survey Incl, Hole Course Total Coordinate Build Rate Walk Rate
Date Tool Vertical
Type Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment
(FT) (DD) (DD) (FI') (FT) (F'I') (FT) (Per 100 FT Drop (-) Left (-)
25-DEC-99 MWD 4525.00 15.11 115.82 95.00 4298.62 -1081.54 1080.67 -27i .89 1.11 1.11 0.01
25-DEC-99 MWD 4620,00 17.98 117.24 95.00 4389.68 -1059.48 1068,57 -247.70 3.05 3.02 1.49 i
/'
25-DEC-99 MWD 4715.00 20.65 117.15 95.00 4479.33 -1033,66 1054.21 -219.75 2,81 2,81 -0.09
25-DEC-99 MWD 4811.00 23.94 117.34 96.00 4568,14 -1003.72 1037.54 -187.38 3.43 3.43 0,20
25-DEC-99 MWD 4901.71 26.25 121,64 90.71 4650.29 -971,25 1018,56 -153,95 3.24' 2,55 4,74
25-DEC-99 MWD 5000,00 26.39 121.74 98.29 4738,39 -933.60 995.66 -116.86 0.15 0.14 0.10
25- DEC-99 MWD 5097.00 25.63 121.28 97.00 4825.56 -896.92 973.43 -80.60 0,81 -0.78 -0.47
25-DEC-99 MWD 5192.00 26.84 124.69 95.00 4910,78 -860.18 950,55 -45.40 2.03 1.27 3.59
25- DEC-99 MWD 5288,00 26.45 124.31 96.00 4996.58 -821.97 926,17 -9,92 0.44 -0.41 -0.40
25-DEC-99 MWD 5383,00 25.90 124,50 95,00 5081.84 -784.81 902;49 24.65 0.59 -0.58 0.20
25-DEC-99 "MWD 5478.00 25,56 124.52 95.00 ' 5167.42 -748.20 879.12 58.64 0.36 -0.36 0.02
25-DEC-99 MWD 5573.00 25.34 124.21 95.00 5253.20 -712.02 856.08 92.33 0.27 -0.23 -0.33
26-DEC-99 MWD 5669.00 24.87 123.94 96.00 5340.13 -676.01 833.26 126.07 0.50 -0.49 -0.28 --
26-DEC-99 MWD 5764,00 25.01 125.17 95,00 5426,27 -640.44 810.54 159.06 0,57 0.15 1.29
.,
26-DEC-99 MWD 5859.00 24,54 124.64 95.00 5512.53 -604.98 787,76 191.71 0.55 -0.49 -0,56
26-DEC-99 MWD 5953.00 25.00 125.63 94.00 5597.88 -569.83 765.09 223.91 0.66 0.49 1.05 --
26- D EC-99 MWD 6048.00 24.28 124.99 95.00 5684,23 -534,42 742.19 256.23 0.81 -0.76 -0.67
--
26- DEC-99 MWD 6143,00 26,23 126.43 95.00 5770.15 -498.06 718.52 289,13 2.15 2.05 1.52
--
26-DEC-99 MWD 6238.00 25.90 125.73 95.00 5855.49 -460.50 693.94 322.86 0,47 -0.35 -0.74
26-DEC-99 MWD 6334.00 25.46 126,04 96.00 5942.00 -423.13 669.56 356.57 0,48 -0.46 0.32
26-DEC-99 MWD 6429.00 24.89 125.98 95.00 6027.98 -386.78 645.80 389.26 0.60 -0.60 -0.06
26-DEC-99 MWD 6525.00 26.54 126.55 96.00 6114.47 -349.24 621.15 422.84 1.74 1.72 0.59 '
26-DEC-99 MWD 6620.00 25.96 126.40 95.00 6199.67 -311.31 596.18 456.62 0.61 -0.61 -0.16
26-DEC-99 MWD 6715.00 25.28 126.42 95.00 6285.33 -274.24 571.79 489.68 0.72 -0.72 0.02
~' SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00003 Sidetracf< No. Page 4 of 8
Company ARCO ALASKA, lNG. Rig Contractor & No. Doyen Drilling Co.- Rig: #19 Field ALPINE FIELD
Well Name & No. PAD CD#1/3 Survey Section Name CD1-3 MWD BHI Rep.
i
JfNl"r~l~ WELL DATA
Target TVD (F0 Target Coord. N/S Slot Coord. N/S -236.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL E~ ss~
Target Description Target Coord. E/W' Slot Coord. E/W 2558.00 Magn. Declination 25.930 Calculation Method MINIMUM CURVATURE
Target Direction (oD) Build\Walk\DL per: 100ft~ 3Om[-] 10mJ-] Vert. Sec. Azim. 151.94 Magn. to Map Corr. 25.930 Map North to:
OTHER
ii i
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(+) /W(-) DL Build (+) Right (+) Comment
Type (FO (OD) (DD) (FO (FT) (FT) (FT) (Per 100 F-T) Drop (-) Left (-)
26-DEC-99 MWD 6810,00 26.45 126.93 95.00 6370.81 -236,76 547.04 522.92 1.25 1.23 0,54
26-DEC-99 MWD 6907.00 25.81 125.53 97.00 6457.90 -198.27 521.79 557.37 0.92 -0.66 -1.44
--
27-DEC-99 MWD 6987,00 28.25 126.78 80.00 6529.16 -165.53 500,33 586.71 3.13 3.05 1.56
27-DEC-99 MWD 7016.00 31.77 127.10 29.00 6554.27 -152.38 491.61 598.30 12.15 12,14 1.10
27-DEC-99 MWD 7051,00 35.81 127.43 35,00 6583.35 -134.70 479,82 613.79 11.55 11.54 0.94
27-DEC-99 MWD 7082,00 36.85 126.94 31.00 6608.32 -118.02 468.72 628.42 3,48 3.35 -1.58
27-DEC-99 MWD 7112.00 36,22 127.08 30,00 6632.43 -101.83 457.97 642.68 2.12 -2.10 0.47
27-DEC-99 MWD 7146.00 36.01 127,11 34.00 6659.89 -83.64 445.89 658.67 0,62 -0.62 0.09
27-DEC-99 MWD 7177.00 35.95 127.20 31.00 6684.98 -67,11 434.89 673,18 0,26 -0.19 0.29
27-DEC-99 MWD 7207,00 36.03 127.22 30.00 6709.25 -51.09 424.23 687.22 0,27 0,27 0,07
--
27-DEC-99 i MWD 7241,00 37,87 129.52 34.00 6736.42 -32,36 411.54 703.24 6.77 5.41 6.76
27-DEC-99 MWD 7273.00 41.18 132.28 32.00 6761.11 -13.35 398,19 718.61 11.71 10.34 8,62
27-D LC-99 MWD 7302,00 44.70 134.03 29.00 6782.33 5.35 384.68 733.02 12.81 12,14 6.03
27-DEC-99 MWD 7337.00 48.96 135.68 35.00 6806.27 29.74 366.67 751.10 12.65 12.17 4.71
,.__
27-DEC-99 MWD 7368.00 52.04 136,80 31.00 6825.99 52.77 349.39 767.63 10.32 9,94 3.61
27-DEC-99 MWD 7399.00 55.13 136.72 31.00 6844.39 76.84 331.22 784.72 9.97 9.97 -0.26
27-DEC-99 MWD 7431.00 56.36 136,90 32.00 6862.40 102.38 311.94 802,82 3.87 3.84 0.56
27-DEC-99 MWD 7462.00 58.56 138.48 31.00 6879.08 127.70 292.61 820.41 8.30 7.10 5.10
27-DEC-99 MWD 7494.00 61.99 139.53 32.00 6894,94 154.78 271.64 838,63 11.09 10,72 3.28
27-DEC-99 MWD 7526.00 66,33 139.61 32.00 6908.89 182.91 249.72 857.31 13.56 13.56 0.25
27-DEC-99 MWD 7557,00 69.85 139.87 31.00 6920.45 211,02 227.77 875.89 11,38 11.35 0.84
28-DEC-99 MWD 7589.00 70.82 140,33 32.00 6931.22 240.51 204.66 895.22 3,32 3.03 1.44
28-DEC-99 MWD 7621.00 71.45 139.76 32,00 6941,57 270.14 181.44 914.67 2.59 1.97 -1.78
28-DEC-99 MWD 7652.00 ~-~ ~- 141.29 31.00 6950.76 299.15 158.59 933.48 9.56 8.32 4.94
r,-;~~,~l,~~ SURVEY CALCU EAT ION AND FIELD WORKSHEET Job No. 0450-00003 Sidetrack No. Page 5 of 8 '
.,[11~_,I Company ARCO ALASKA. INC. Rig Contractor & No. Doyon Drilling Co.- Rig: #19 Field ALPINE FIELD
Well Name & No. PAD CD#1/3 Survey Section Name CD1-3 MWD BHI Rep.
WELL DATA
Target TVD (F-r) Target Coord. N/S Slot Coord. N/S -236.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLU SS0i
Target Description Target Coord. E/W' Slot Coord. E/W 2558.00 Magn. Declination 25.930 Calculation Method MINIMUM CURVATURE
Target Direction (DD) Build\Walk\DL per: l(~0ft[~ 30m~] 10m0 Vert. Sec. Azim. 151.94 Magn. to Map Corr. 25.930 Map North to: OTHER
....
SURVEY DATA
Survey Survey Incl. Hole Course Total Coordinate Build Rate Walk Rate
Date Tool Vertical
Type Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment
(FT) (DD) (DD) (FT) (F'D (FT) (FT) (Per lo0 ET) Drop (-) Left (-)
28-DEC-99 MWD 7682.00 77.45 142.04 30.00 6958.15 327.76 135.79 951.51 11.65 11.40 2.50
28-DEC-99 MWD 7716.00 81.78 143.24 34.00 6964.28 360.75 109.21 971.80 13.20 12.74 3.53
28-D EC-99 MWD 7750.00 86.12 144.50 34.00 6967.86 394.22 81.91 991,73 13.29 12.76 3.71
30-DEC-99 MWD 7838.00 92.20 145.73 88.00 6969.15 481.55 9.77 1042.03 7.05 6.91 1.40 4 3/4" M1X 1.2 DEG AKO
30-DEC-99 MWD 7934.00 92.16 153.60 96.00 6965.50 577.33 -72.96 1090.44 8.19 -0.04 8.20
30-DEC-99 MWD 8024.00 90.93 152.19 90.00 6963.07 667.28 -153.05 1131.43 2.08 -1.37 -1.57
30-DEC-99 MWD 8117.00 89.79 153.16 93.00 6962.48 760.26 -235.67 1174.12 1.61 -1.23 1.04
30-DEC-99 MWD 8212.00 90.72 153.40 95.00 6962.06 855.24 -320.52 1216.83 1.01 0.98 0.25 --
30-DEC-99 MWD 8243.00 91.10 154.19 31.00 6961.57 886.22 -348.33 1230.52 2.83 1.23 2.55
--
30-DEC-99 MWD 8274.00 90.27 154.07 31.00 6961.20 917.19 -376.22 1244.04 2.71 -2.68 -0.39
._
--
30-DEC-99 ~ MWD 8303.00 88.84 153.91 29.00 6961.42 946.17 -402.28 1256.76 4.96 -4.93 -0.55
_
30-DEC-99 MWD 8336.00 89.04 153.71 33.00 6962.03 979.15 -431.89 1271.32 0.86 0.61 -0.61
30-DEC-99 MWD 8367.00 89.25 153.63 31.00 6962.50 1010.13 -459.67 1285.07 0.72 0.68 -0.26 --
-- _
30- DEC-99 MWD 8396.00 89.66 154.24 29.00 6962.77 1039.11 -485.72 1297.81 2.53 1.41 2.10
--
30-DEC-99 MWD 8429.00 88.87 153.34 33.00 6963.20 1072.09 -515.32 1312.39 3.63 -2.39 -2.73
31 -DEC-99 MWD 8460.00 87.67 154.41 31.00 6964.13 1103.06 -543.14 1326.03 5.19 -3.87 3.45
--_
31 -DEC-99 MWD 8489.00 88.25 154.20 29.00 6965.16 1132.01 -569.26 1338.59 2.13 2.00 -0.72
--
31 -DEC-99 MWD 8523.00 88.90 153.43 34.00 6966.01 1165.98 -599.76 1353.59 2.96 1.91 -2.26
31-DEC-99 MWD 8555.00 89.28 153.81 32.00 6966.52 1197.97 -628.42 1367.81 1.68 1.19 1.19
31 -DEC-99 MWD 8583.00 89.73 154.40 28.00 6966.76 1225.95 -653.61 1380.04 2.65 1.61 2.11
31 -DEC-99 MWD 8615.00 89.52 153.62 32.00 6966.97 1257.92 -682.37 1394.06 2.52 -0.66 -2.44
31 -DEC-99 MWD 8647.00 89.45 154.43 32.00 6967.26 1289.90 -711.14 1408.07 2.54 -0.22 2.53
31 -DEC-99 MWD 8676.00 89.52 153.02 29.00 6967.52 1318.89 -737.14 1420.91 4.87 0.24 -4.86
31 -DEC-99 MWD 8708.00 89.01 154.23 32.00 6967.93 1350.87 -765.81 1435.13 4.10 -1.59 3.78
SURVEY CALCULATION AND FIELD WORKSHEET Job No. S e rsck No. P ge .....
Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co.- Rig: #19 ...... Field A_~_L._PI_N_E__F.I_E....L.D' ..................................................
Well Name & No. PAD CD#1/3 Survey Section Name CD1-3 MWD BHI Rep,
iJlllli~r~i~ WELL DATA
i Target TVD (FT) Target Coord. N/S Slot Coord. N/S -236.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLF~ ssE]
,
'Target Description Target Coord. E/W Slot Coord, E/W 2558.00 Magn, Declination 25.930 Calculation Method MINIMUM CURVATURE
, ,
Target Direction (DD) Build\Walk\DL per: 100ft[~ 30mE~ lOmE] Vert. Sec. Azim, 151.94 Magn. to Map Corr. 25,930 Map North to: OTHER
SURVEY DATA
__--
--
Sun/ey Survey Incl, Hole Course Vertical Total Coordinate Build Rate Walk Rate
Date Tool Depth Angle Direction Length 'I'VD Section N(4-) /S(-) E(+) /W(-) DL Build (4-) Right (+) Comment
Type (F-r) (DO) (DO) (FT) (F'r) (F'r) (F-r) (Per ~00 FT) Drop (-) Left (-)
31 -DEC-99 MWD 8738.00 89.55 153.82 30.00 6968.31 1380.85 -792.77 1448.26 2.26 1.80 -1.37
31 -DEC-99 MWD 8768.00 89.83 155.01 30.00 6968.47 1410.82 -819.83 1461.22 4.07 0.93 3.97
31 -DEC-99 MWD 8805.00 88.76 154.25 37.00 6968.92 1447,77 -853.26 1477.07 3.55 -2.89 -2,05
31 - DEC-99 MWD 8832.00 87.87 154.44 27.00 6969.72 1474.74 -877.59 1488.76 3.37 -3.30 0.70
31 -DEC-99 MWD 8863.00 86.71 155.18 31.00 6971.18 1505.66 -905,61 1501.93 4.44 -3.74 2.39
-- _
31 -DEC-99 MWD 8895.00 87.02 155.46 32,00 6972,93 1537.56 -934.64 1515.28 1,30 0.97 0.87
31 -DEC-99 MWD 8924.00 87.32 155.53 29.00 6974.36 1566.47 -961.00 1527,29 1.06 1.03 0,24
31 -DEC-99 MWD 8954.00 87.53 155,49 30.00 6975.71 1596.38 -988.27 1539,71 0.71 0.70 -0.13
31 -DEC-99 MWD 8986.00 87,94 155.29 32.00 6976.98 1628,30 -1017.34 1553,03 1.43 1.28 -0.63
31 -DEC-99 MWD 9016,00 88.15 154.56 30.00 6978.00 1658.24 -1044,50 1565,74 2.53 0,70 -2.43
31-DEC-99 MWD 9045.00 88.29 154,86 29.00 ' 6978.90 1687,19 -1070.70 1578.12 1.14 0.48 1.03
31-DEC-99 MWD 9079.00 88.63 154.97 34,00 6979.81 1721,13 -1101.49 1592.53 1.05 1.00 0.32
31 -DEC-99 MWD 9108.00 88.80 155.59 29.00 6980.46 1750.07 -1127.82 1604.65 2.22 0,59 2.14
--__
31 -DEC-99 MWD 9139.00 89.07 155.35 31,00 6981,04 1781.01 -1156.02 1617.52 1.17 0.87 -0.77
31 -DEC-99 MWD 9169.00 89,55 154.84 30.00 6981.40 1810.96 -1183.23 1630.15 2.33 1.60 -1.70
--
--
31 -DEC-99 MWD 9201.00 90.00 155.50 32.00 6981,53 1842,91 -1212.27 1643.59 2.50 1.41 2.06
--,
.__
31 -DEC-99 MWD 9230.00 89,04 153,74 29.00 6981.77 1871.88 -1238.47 1656.02 6.91 -3.31 -6.07
--
01 -JAN-O0 MWD 9262.00 88.39 155.52 32.00 6982.49 1903.83 -1267.37 1669.73 5.92 -2.03 5.56
--
01 -JAN-00 MWD 9293.00 88.90 155.36 31.00 6983.22 1934.77 -1295.56 1682.61 1.72 1,65 -0.52
-- _
01 -JAN-O0 MWD 9322.00 89,18 154.94 29.00 6983.71 1963.72 -1321.87 1694.79 1.74 0.97 -1.45
01 -JAN-00 MWD 9354.00 89,45 155.11 32.00 6984.09 1995.67 -1350.88 1708.30 1.00 0.84 0.53
01 -JAN-00 MWD 9385,00 89.83 154.82 31,00 6984.28 2026.62 -1378.96 1721.42 1.54 1,23 -0.94
__
01 -JAN-00 MWD 9415.00 90.07 155.07 30.00 6984,31 2056.58 -1406.14 1734,13 1.16 0,80 0,83
--
01 -JAN-00 MWD 9446.00 89.79 153.99 31.00 6984.35 2087,55 -1434.13 1747.46 3.60 -0.90 -3.48
;
SURVEY CALCULATIONAND FIELD WORKSHEET Job No..0_4.~-_._0~___03 ..... Sidetrack No. Page 7 of 8
Company A_R___OO____A___~_S_._KA_:..I.N_C__ ..................................... Rig Contractor & No. _D_o__y_o_n.._D_r_i_lJi_n.~..._C_0__F_~[g_.'_~..!..9- Field .A._L_P_I..N__E_..F.,I_E_._L_D
Well Name & No. PAD 0D#1/3 Survey Section Name _C_ D__1....-.3- ......... ,_M_WD. .............................................
i~~/~ .............................................. BHI Rep. _
WELL DATA
Target TVD (FT) Target Coord. N/S Slot Coord. N/S -236.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL L-] ssE]
Target Description Target Coord. E/W' Slot Coord. E/W 2558.00 Magn. Declination 25.930 Calculation Method ,MINIMUM CURVATURE
Target Direction (DD) Build\Walk\DL. per: l~OftE~ 30m[~ 10mD Vert. Sec. Azim. 151.94 Magn. to Map Corr. 25.930 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(+) / W(-) DL Build (-t-) Right (+) Comment
Type (FT) (DD) (DD) (F-r) (FI') (FT) (F'l') (Per ~00 FT Drop (-) Left (-)
01-JAN-00 MWD 9477.00 89.38 154.13 31.00 6984.57 2118.53 -1462.00 1761.02 1.40 -1.32 0.45
01 -JAN-00 MWD 9508.00 89.90 153.33 31.00 6984.77 2149.51 -1489.80 1774.74 3.08 1.68 -2.58
,~_._
01-JAN-00 MWD 9538.00 90.10 153.10 30.00 6984.77 2179.50 -1516.58 1788.26 1.02 0.67 -0.77,
01 -JAN-O0 MWD 9569.00 90.27 154.32 31.00 6984.67 2210.49 -1544.37 1801.99 3.97 0.55 3.94
01 -JAN-O0 MWD 9598.00 88.56 153.99 29.00 6984.96 2239.46 -1570.47 1814.63 6.01 -5.90 -1.14
01 -JAN-00 MWD 9630.00 88.53 154.56 32.00 6985.78 2271.43 -1599.29 1828.51 1.78 -0.09 1.78
01 -JAN-O0 MWD 9660.00 88.90 154.47 30.00 6986.45 2301.39 -1626.36 1841.42 1.27 1.23 -0.30
01 -JAN-00 MWD 9690.00 89.31 153.92 30.00 6986.92 2331.36 -1653.37 1854.47 2.29 1.37 -1.83
01 -JAN-00 MWD 9721.00 89.49 154.57 31.00 6987.24 2362.34 -1681.29 1867.94 2.18 0.58 2.10'
01 -JAN-O0 MWD 9752.00 89.14 154.05 31.00 6987.61 2393.31 -1709.22 1881.38 2.02 -1.13 -1.68
01-JAN-O0 ! MWD 9782.00 87.77 154.22 30.00 . 6988.42 2423.27 -1736.21 1894.46 4.60 -4.57 0.57 --
02-JAN-00 MWD 9844.00 88.52 155.15 62.00 6990.43 ' 2485.17 -1792.22 1920.96 1.93 1.21 1.50
02-JAN-00 MWD 9871.00 88.70 155.08 27.00 6991.08 2512.12 -1816.71 1932.32 0.72 0.67 -0.26
--
02-JAN-00 MWD 9905.00 88.73 154.79 34.00 6991.85 2546.06 -1847.50 1946.72 0.86 0.09 -0.85
,.-._
02-JAN-00 MWD 9936.00 89.28 155.44 31.00 6992.39 2577.01 -1875.62 1959.76 2.75 1.77 2.10
02-JAN-00 MWD 9967.00 89.79 155.14 31.00 6992.64 2607.96 -1903.78 1972.72 1.91 1.65 -0.97
02-JAN-00 MWD 10000.00 88.90 153.57 33.00 6993.01 2640.92 -1933.52 1987.00 5.47 -2.70 -4.76
02-JAN-00 MWD 10030.00 87.94 154.05 30.00 6993.84 2670.90 -1960.43 2000.24 3.58 -3.20 1.60
-- --
02-JAN-O0 MWD 10062.00 88.22 153.15 32.00 6994.91 2702.86 -1989.08 2014.46 2.94 0.87 -2.81
--
02-JAN-00 MWD 10091.00 88.42 154.51 29.00 6995.76 2731.84 -2015.09 2027.24 4.74 0.69 ~,.69
02-JAN-00 MWD 10123.00 88.66 153.89 32.00 6996.58 2763.80 -2043.89 2041.16 2.08 0.75 -1.94
.__
02-JAN-00 MWD 10152.00 88.83 153.52 29.00 6997.21 2792.78 -2069.89 2054.01 1.40 0.59 ,1.28
02-JAN-00 MWD 10183.00 88.90 154.53 31.00 6997.83 2823.75 -2097.75 2067.58 3.27 0.23 3.26
02-JAN-00 MWD 10215.00 89.21 154.30 32.00 6998.36 2855.72 -2126.61 2081.40 1.21 0.97 -0.72
SURVEY CALCULATION AND FIELD WORKSHEET Job No. ......
i Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co.- Rig: #19 Field A_L_.P.!.~E_I~!~E~_?
Well Name & No. PAD CD#1/3 Survey Section Name CD1-3 MWD BHI Rep.
~NITE{~ WELL DATA
Target TVD (F-r) Target Coord. N/S Slot Coord. N/S ~236.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[-'] SS~
,Target Description Target Coord. E/W' Slot Coord. E/W 2558.00 Magn. Declination 25.930 Calculation Method MINIMUM CURVATURE
Target Direction (DD)__ Build\Walk\DL per: l(~0ft[~ 30m~ 10m~] Vert. Sec. Azim. 151.94 Magn. to Map Corr. 25.930 Map North to: OTHER
i
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(+) /W(-) DL Build (+) Right (+) Comment
Type (F-r) (DD) (DD) (FT) (F-'T) (FT) (F-0 (Per ~00 FT) Drop (-) Left (-) ..
02-JAN-00 MWD 10245.00 89.42 153.83 30.00 6998.72 2885.70 -2153.58 2094.52 1.72 0.70 -1.57
.,
·
02-JAN-00 MWD 10278.00 89.76 153.70 33.00 6998,95 2918.68 -2183.18 2109.11 1.10 1.03 -0.39
02-JAN-00 MWD 10308.00 89,49 153.48 30.00 6999.15 2948.67 -2210.05 2122.45 1.16 -0.90 -0.73
02-JAN-00 MWD 10337.00 87,81 153,71 29.00 6999.83 2977.64 -2236.02 2135.34 5,85 -5,79 0.79
03-JAN-O0 MWD 10370,00 88.18 153.26 33.00 7000.99 3010.61 -2265.53 2150.06 1.76 1.12 -1.36
--
03-JAN-00 MWD 10402.00 88.56 153.11 32.00 7001.90 3042.59 -2294.08 2164.49 1,28 1.19 -0,47
03-JAN-00 MWD 10430.00 88.80 153,73 28,00 7002.54 3070.57 -2319.11 2177,02 2.37 0,86 2.21
03-JAN-00 MWD 10462.00 89.04 153.29 32.00 7003.14 3102,56 -2347.75 2191.29 1.57 0,75 -1.38
03-JAN-O0 MWD 10493.00 89.31 153.32 31.00 7003.59 3133.54 -2375,44 2205.22 0.88 0.87 0,10
03-JAN-00 MWD 10520.00 89.52 152.93 27.00 7003.87 3160.54 -2399,52 2217,42 1.64 0.78 -1.44
03-JAN-00 "MWD 10552.00 89.66 153.12 32.00 7004,10 3192.53 -2428,04 2231.94 0.74 0.44 0,59
..
03-JAN-00 MWD 10585.00 89.97 152.36 33.00 7004.20 3225.53 -2457,37 2247.05 2.49 0,94 -2,30
03-JAN-00 MWD 10613.00 90.27 152.18 28.00 7004.14 3253.53 -2482,16 2260,08 1.25 1.07 -0.64
03-JAN-00 MWD 10645.00 89.49 151.90 32.00 7004.21 3285.53 -2510.42 2275.08 2.59 -2.44 -0.88
03-JAN-00 MWD 10675.00 88.87 151.84 30.00 7004.64 3315.52 -2536.88 2289.22 2.08 -2.07 -0.20
03-JAN-00 MWD 10707.00 89.38 151.55 32.00 7005.13 3347.52 -2565.05 2304.40 1.83 1.59 -0.91
-__
03-JAN-00 MWD 10737.00 89.66 152.63 30.00 7005.38 3377.52 -2591.56 2318.44 3.72 0.93 3.60
. __
03-JAN-00 MWD 10768.00 89.86 152.15 31.00 7005.51 3408.52 -2619.03 2332.80 1.68 0.65 -1.55
--
03-JAN-00 MWD 10799.00 89.11 151.48 31.00 7005.79 3439.51 -2646.35 2347.45 3.24 -2.42 -2.16
03-JAN-00 MWD 10839.00 89.28 152.83 40.00 7006.35 3479.51 -2681.71 2366.13 3.40 0.43 3.38
03-JAN-00 MWD 10897.00 89.28 152.83 58.00 7007.08 3537.50 -2733.31 2392.61 0.00 0.00 0.00 Projected Data - NO SURVEY
ANADRILL
SCHLUMBERGER
Survey report
Client ................... : ARCO Alaska, Inc.
Field .................... : Colville River
Well ..................... : CD1-03
AP1 number ............... : 50-103-20319-00
Engineer ................. : St. Amour
Rig: ..................... : Doyon 19 '
STATE: ................... : Alaska
Survey calculation methods
Method for positions ..... : Minimum curvature
Method for DLS ........... : Mason & Taylor
Depth reference ..............
Permanent datum .......... : Mean Sea Level
Depth reference .......... : Driller Pipe Tally
GL above permanent ....... : 19.50 ft
KB above permanent ....... : 56.32 ft
DF above permanent ....... : 56.32 ft
Vertical section origin
Latitude (+N/S-) ......... :
Departure (+E/W-) ........ :
0.00 ft
0.00 ft
Platform reference point
Latitude (+N/S-) ......... : -999.25 ft
Departure (+E/W-) ........ : -999.25 ft
Azimuth from rotary table to target: 151.94 degrees
3-Jan-2000 14:36:19
Page 1 of 8
Spud date .............. [.: 22 Dec. 19999
Last survey date ......... : 03-Jan-00
Total accepted surveys...: 188
MD of first survey ....... : 114.00 ft
MD of last survey ........ : 10897.00 ft
ORIGINAL
Geomagnetic data ........................
Magnetic model ........... : BGGM version 1999
Magnetic date ............ : 21-Dec-1999
Magnetic field strength..: 1144.65 HCNT
Magnetic dec (+E/W-) ..... : 25.93 degrees
Magnetic dip ............. : 80.48 degrees
..... MWD survey Reference Criteria
Reference G .............. : 1002.68 mGal
Reference H .............. : 1144.64 HCNT
Reference Dip ............ : 80.48 degrees
Tolerance of G ........... : (+/-) 2.50 mGal
Tolerance of H ........... : (+/-) 6.00 HCNT
Tolerance of Dip ......... : (+/-) 0.45 degrees
Corrections
Magnetic dec (+E/W-) ..... : 25.93 degrees
Grid convergence (+E/W-).: 0.00 degrees
Total az corr (+E/W-) .... : 25.93 degrees
(Total az corr = magnetic dec - grid cony)
Sag applied {Y/NJ ........ : No degree: 0.00
[(c)2000 Anadrill IDEAL ID6 0C 07]
--
RECEIVED
12 2000
,aa aOil & Gas C, ons.
ANADRILL SCHLUMBERGER Survey Report 3-Jan-2000 14:36:19 Page 2 of 8
Seq Measured Incl Azimuth Course
% depth angle angle length
- (ft) (deg) (deg) (ft)
1 114.00 0.00 0.00
2 180.00 0.25 240.00
3 297.31 1.06 320.30
4 387.46 3.08 330.20
5 476.57 5.60 336.19
0.00
66.00
117.31
90.15
89.11
6 566.42 8.60 338.62 89.85
7 655.24 11.11 339.36 88.82
8 743.75 12.43 341.42 88.51
9 833.61 15.32 345.43 89.86
10 923.82 18.13 343.37 90.21
11 1012.46 21.20 343.77
12 1107.27 25.57 342.03
13 1202.60 25.83 341.11
14 1297.80 25.51 341.78
15 1392.82 25.33 339.74
16 148.8.04 25.25 338.95
17 1580.47 24.98 336.38
18 1675.61 24.08 336.76
19 1772.11 24.36 339.30
20 1867.72 24.10 340.03
21 1962.66 23.87 339.17
22 2058.62 24.77 340.91
23 2153.91 24.49 341.83
24 2250.62 24.36 342.03
25 2344.77 24.20 341.91
88.64
94.81
95.33
95.20
95.02
95.22
92.43
95.14
96.50
95.61
94.94
95.96
95.29
96.71
94.15
TVD
depth
(ft)
114.00
180.00
297.30
387.39
476.24
565.39
652.89
739.54
826.77
913.15
9~6.61
1083.62
1169.52
1255.32
1341.14
1427.24
1510.93
1597.48
1685.49
1772.68
1859.42
1946.87
2033.49
2121.54
2207.36
26 2436.95 23.77 342.98 92.18 2291.58
27 2471.77 23.87 342.84 34.82 2323.44
28 2622.00 23.12 341.43 150.23 2461.21
29 2718.00 22.81 341.63 96.00 2549.60
30 2813.00 22.65 341.89 95.00 2637.23
Vertical Displ Displ Total At DLS Srvy Tool
section +N/S- +E/W- displ Azim (deg/ tool qual
(ft) (ft) (ft) (ft) (deg) 100f) type type
0.00
0.00
-1.05
-4.29
-11.02
-22.06
-37.15
-55.00
-76.09
-101.44
-130.65
-167.59
-208.35
-249.02
-289.32
-329.66
-368.68
-4O8.O5
-447.41
-486.29
-524.54
-563.66
-602.83
-642.22
-680.34
-717.18
-730.99
-789.93
-826.86
-863.03
0
-0
0
3
9
.00
.07
.63
.38
.43
0.00
-0.12
-1.04
-2.78
-5.72
19.70
33.90
50.91
71.57
96.56
-9.94
-15.38
-21.42
-27.49
-34.51
125.17
161.11
200.33
239.42
277.92
-42.93
-54.04
-67.11
-80.24
-93.68
315
352
388
425
462
.99
.27
.51
.22
.01
-108.02
-122.92
-138.63
-153.44
-167.07
498
535
572
610
647
.18
.33
.96
.97
.79
-180.52
-194.00
-206.69
-219.09
-231.08
683
696
753
789
824
.51
.95
.95
.48
.34
-242.38
-246.51
-264.87
-276.74
-288.23
0.00
0.14
1.22
4.37
11.03
22.07
37.22
55.23
76.67
102.54
132.33
169.93
211.27
252.51
293.29
333.94
373.10
412.50
452.05
491.29
529.88
569.39
609.10
649.07
687.77
725.21
739.26
799.13
836.58
873.28
0.00 0.00 TIP
240.00 0.38 GYR
301.42 0.89 MWD
320.59 2.27 MWD
328.77 2.87 MWD
333.23 3.35 MWD
335.60 2.83 MWD
337.18 1.56 MWD
338.99 3.39 MWD
340.33 3.18 MWD
341.07 3.47 MWD
341.46 4.67 MWD
341.48 0.50 MWD
341.47 0.45 MWD
341.37 0.94 MWD
341.13 0.36 MWD
340.76 1.22 MWD
340.36 0.96 MWD
340.16 1.12 MWD
340.12 0.41 MWD
340.08 0.44 MWD
340.08 1.20 MWD
340.16 0.50 MWD
340.27 0.16 MWD
340.37 0.18 MWD
340.47 0.66 MWD
340.52 0.33 MWD
340.64 0.62 MWD
340.68 0.33 MWD
340.73 0.20 MWD
RECEIVED
JAN 12 2000
Alala Oil & Gas Coos. Commimi n
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
ANADRILL SCHLUMBERGER Survey Report '3-Jan-2000 14:36:19 Page 3 of 8
Seq Measured Incl Azimuth Course
% depth angle angle length
- (ft) (deg) (deg) (ft)
31 2909.00 22.45 341.60
32 3003.00 19.73 341.89
33 3100.00 19.51 341.41
34 3194.00 17.88 340.43
35 3289.00 16.89 339.06
36 3384.00 14.81 340.25
37 3479.00 12.29 340.83
38 3574.00 10.52 343.53
39 3669.00 8.72 344.12
40 3764.00 7.98 353.76
TVD Vertical Displ
depth section +N/S-
(ft) (ft) (ft)
96.00 2725.89 -899.31 859.30
94.00 2813.58 -932.63 891.42
97.00 2904.95 -964.74 922.34
94.00 2993.99 -994.49 950.81
95.00 3084.65 -1022.61 977.44
95.00 3176.03 -1048.32 1001.76
95.00 3268.38 -1070.33 1022.74
95.00 3361.50 -1088.82 1040.61
95.00 3455.16 -1104.35 1055.86
95.00 3549.16 -1117.52 1069.34
Displ Total At DLS Srvy Tool
+E/W- displ Azim (deg/ tool qual
(ft) (ft) (deg) i00f) type type
-299
-310
-320
-330
-340
.76 910.09 340.77 0.24
.36 943.91 340.80 2.90
· 62 976.47 340.83 0.28
.45 1006.60 340.84 1.77
· 27 1034.98 340.81 1.13
-349
-356
-362
-366
-369
.31 1060.92 340.78 2.22
.73 1083.17 340.77 2.66
.51 1101.95 340.79 1.95
.94 1117.80 340.84 1.90
.63 1131.42 340.93 1.66
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
41 3859.00 7.61 12.21
42 3953.00 7.07 31.96
43 4049.00 7.16 56.61
44 4144.00 8.53 81.19
45 4239.00 9.65 101.62
95.00 3643.29 -1128.44 1082.04
94.00 3736.54 -1136.08 1093.,04
96.00 3831.82 -1139.59 1101.34
95.00 3925.96 -1137.82 1105.68
95.00 4019.79 -1130.41 1105.16
-369
-364
-356
-344
-329
.01 1143.24 341.17 2.65
.63 1152.25 341.55 2.73
· 51 1157.61 342.06 3.16
.60 ' 1158.14 342.69 3.78
· 83 1153.33 343.38 3.57
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
46 4335.00 11.84 112.25 96.00 4114.11 -1117.69 1099.81
47 4430.00 14.06 115.81 95.00 4206.69 -1100.86 1091.09
48 4525.00 15.11 115.82 95.00 4298.62 -1081.54 1080.67
49 4620.00 17.98 117.24 95.00 4389.68 -1059.48 1068.57
50 4715.00 20.65 117.15 95.00 4479.33 -1033.66 1054.21
-312
-293
-271
-247
-219
· 83 1143.43 344.12 3.07
.42 1129.86 344.95 2.48
· 89 1114.35 345.88 1.11
.70 1096.90 346.95 3.05
· 75 1076.87 348.23 2.81
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
51 4811.00 23.94 117.34
52 4901.71 26.25 121.64
53 5000.00 26.39 121.74
54 5097.00 25.63 121.28
55 5192.00 26.84 124.69
96.00 4568.14 -1003.72 1037.54
90.71 4650.29 -971.25 1018.56
98.29 4738.39 -933.60 995.66
97.00 4825.56 -896.92 973.43
95.00 4910.78 -860.18 950.55
-187
-153
-116
-80
-45
.38 1054.32 349.76 3.43
· 95 1030.12 351.41 3.24
.86 1002.50 353.31 0.15
· 60 976.76 355.27 0.81
· 40 951.64 357.27 2.03
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
56 5288.00 26.45 124.31 96.00 4996.58 -821.97 926.17
57 5383.00 25.90 124.50 95.00 5081.84 -784.81 902.49
58 5478.00 25.56 124.52 95.00 5167.42 -748.20 879.12
59 5573.00 25.34 124.21 95.00 5253.20 -712.02 856.08
60 5669.00 24.87 123.94 96.00 5340.13 -676.01 833.26
-9.92 926.22 359.39 0.44 MWD
24.65 902.83 1.56 0.59 MWD
58.64 881.08 3.82 0.36 MWD
92.33 861.04 6.16 0.27 MWD
126.07 842.74 8.60 0.50 MWD
RECEIVED
6-axis
6-axis
6-axis
6-axis
6-axis
2000
NalaOil a Gas Cons. C mi m
ANADRILL SCHLUMBERGER Survey Report 3-Jan-2000 14:36:19 Page 4 of 8
Seq Measured Incl Azimuth
% depth angle angle
- (ft) (deg) (deg)
Course
length
(ft)
TVD Vertical Displ Displ
depth section +N/S- +E/W-
(ft) (ft) (ft) (ft)
61 5764.00 25.01 125.17 95.00 5426.27 -640.44 810.54 159.06
62 5859.00 24.54 124.64 95.00 5512.53 -604.98 787.76 191.71
63 5953.00 25.00 125.63 94.00 5597.88 -569.83 765.09 223.91
64 6048.00 24.28 124.99 95.00 5684.23 -534.42 742.19 256.23
65 6143.00 26.23 126.43 95.00 5770.15 -498.06 718.52 289.13
Total At DLS Srvy Tool
displ Azim (deg/ tool qual
(ft) (deg) 100f) type type
826.00 11.10 0.57
810.75 13.68 0.55
797.18 16.31 0.66
785.18 19.05 0.81
774.51 21.92 2.15
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
66 6238.00 25.90 125.73 95.00 5855.49 -460.50 693.94 322.86
67 6334.00 25.46 126.04 96.00 5942.01 -423.13 669.56 356.57
68 6429.00 24.89 125.98 95.00 6027.98 -386.78 645.80 389.26
69 6525.00 26.54 126.55 96.00 6114.47 -349.24 621.15 422.84'
70 6620.00 25.96 126.40 95.00 6199.67 -311.31 596.18 456.62
765.37 24.95 0.47
758.58 28.04 0.48
754.04 31.08 0.60
751.41 34.24 1.74
750.95 37.45 0.61
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
71 6715.00 25.28 126.42 95.00 6285.33 -274.24 571.79 489.68
72 6810.00 26.45 126.93 95.00 6370.81 -236.76 547.04 522.92
73 6907.00 25.81 125.53 97.00 6457.90 -198.27 521.79 557.37
74 6987.00 28.25 126,78 80.00 6529.16 -165.53 500.33 586.71
75 7016.00 31.77 127.10 29.00 6554.27 -152'.38 491.61 598.30
752.82 40.58 0.72
756.77 43.71 1.25
763.49 46.89 0.92
771.08 49.54 3.13
774.37 50.59 12.15
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
76 7051.00 35.81 127.43 35.00 6583.35 -134.70 479.82 613.79
77 7082.00 36.85 126.94 31.00 6608.32 -118.02 468.72 628.42
78 7112.00 36.22 127.08 30.00 6632.43 -101.83 457.97 642.68
79 7146.00 36.01 127.11 34.00 6659.89 -83.64 445.89 658.67
80 7177.00 35.95 127.20 31.00 6684.98 -67.11 434.89 673.18
779.08 51.98 11.55
783.97 53.28 3.48
789.16 54.53 2.12
795.40 55.90 0.62
801.44 57.14 0.26
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
81 7207.00 36.03 127.22 30.00 6709.25
82 7241.00 37.87 129.52 34.00 6736.42
83 7273.00 41.18 132.28 32.00 6761.11
84 7302.00 44.70 134.03 29.00 6782.33
85 7337.00 48.96 135.68 35.00 6806.27
-51.09 424.23 687.22
-32.36 411.54 703.24
-13.35 398.19 718.61
5.35 384.68 733.02
29.74 366.67 751.10
807.62 58.31 0.27
814.80 59.66 6.77
821.56 61.01 11.71
827.82 62.31 12.81
835.82 63.98 12.65
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
86 7368.00 52.04 136.80 31.00
87 7399.00 55.13 136.72 31.00
88 7431.00 56.36 136.90 32.00
89 7462.00 58.56 138.48 31.00
90 7494.00 61.99 139.53 32.00
6825.99 52.77 349.39 767.64 843.41 65.53 10.32
6844.39 76.84 331.22 784.72 851.76 67.12 9.97
6862.40 102.38 311.94 802.83 861.30 68.77 3.87
6879.08 127.70 292.61 820.41 871.03 70.37 8.30
6894.94 154.78 271.64 838,64 881.53 72.05 11.09
RECEIVED
[VS~D
MWD
MWD
~D
6-axis
6-axis
6-axis
6-axis
6-axis
Alm Oil & C, ons. C.,ommieaion
·
ANADRILL SCHLUMBERGER Survey Report 3-Jan-2000 14:36:19 Page 5 of 8
Seq Measured Incl Azimuth
# depth angle angle
- (ft) (deg) (deg)
Course
length
(ft)
TVD Vertical Displ
depth section +N/S-
(ft) (ft) (ft)
91 7526.00 66.33 139.61 32.00 6908.89
92 7557.00 69.85 139.87 31.00 6920.45
93 7589.00 70.82 140.33 32.00 6931.22
94 7621.00 71.45 139.76 32.00 6941.57
95 7652.00 74.03 141.29 31.00 6950.77
182.91 249.72 857
211.02 227.77 875
240.51 204.66 895
270.14 181.44 914
299.15 158.59 933
Displ Total At DLS Srvy Tool
+E/W- displ Azim (deg/ tool qual
(ft) (ft) (deg) 100f) type type
· 31 892.94 73.76 13.56
.89 905.02 75.42 11.38
· 22 918.32 77.12 3.32
.67 932.49 78.78 2.59
· 48 946.86 80.36 9.56
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
96 7682.00 77.45 142.04 30.00 6958.15
97 7716.00 81.78 143.24 34.00 6964.28
98 7750.00 86.12 144.50 34.00 6967.86
99 7838.00 92.20 145.73 88.00 6969.15.
100 7934.00 92.16 153.60 96.00 6965.50
327.76 135.79 951
360.76 109.21 971
394.22 81.91 991
481.55 9.77 1042
577.33 -72.96 1090
.51 961.15 81.88 11.65
.80 977.92 83.59 13.20
· 73 995.11 85.28 13.29
· 03 1042.07 89.46 7.05
· 44 1092.88 93.83 8.19
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
101 8024.00 90.93 152.19 90.00 6963.07
102 8117.00 89.79 153.16 93.00 6962.48
103 8212.00 90.72 153.40 95.00 6962.06
104 8243.00 91.10 154.19 31.00 6961.57
105 8274.00 90.27 154.07 31.00 6961.20
667.28 -153.05 1131.43
760.26 -235.67 1174.12
855.24 -320.52 1216.83
886.22 -348.33 1230.52
917.19 -376.22 1244.04
1141.73 97.70 2.08
1197.54 101.35 1.61
1258.34 104.76 1.01
1278.87 105.81 2.83
1299.69 106.83 2.71
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
106 8303.00 88.84 153.91 29.00 6961.42
107 8336.00 89.04 153.71 33.00 6962.03
108 8367.00 89.25 153.63 31.00 6962.50
109 8396.00 89.66 154.24 29.00' 6962.77
110 8429.00 88.87 153.34 33.00 6963.20
946.17 -402.28 1256.76
979.15 -431.89 1271.32
1010.13 -459.67 1285.07
1039.11 -485.72 1297.81
1072.09 -515.32 1312.39
1319.57 107.75 4.96
1342.68 108.76 0.86
1364.81 109.68 0.72
1385.73 110.52 2.53
1409.93 111.44 3.63
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
111 8460.00 87.67 154.41
112 8489.00 88.25 154.20
113 8523.00 88.90 153.43
114 8555.00 89.28 153.81
115 8583.00 89.73 154.40
31.00
29.00
34.00
32.00
28.00
6964.13
6965.16
6966.01
6966.52
6966.76
1103.06 -543.14 1326.03
1132.01 -569.26 1338.60
1165.99 -599.76 1353.59
1197.97 -628.42 1367.81
1225.95 -653.61 1380.04
1432.95 112.27 5.19
1454.61 113.04 2.13
1480.52 113.90 2.96
1505.26 114.68 1.68
1526.99 115.34 2.65
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
116 8615.00 89.52 153.62
117 8647.00 89.45 154.43
118 8676.00 89.52 153.02
119 8708.00 89.01 154.23
120 8738.00 89.55 153.82
32.00
32.00
29.00
32.00
30.00
6966.97
6967.26
6967.52
6967.93
6968.31
1257.92 -682.37 1394.06
1.289.90 -711.14 1408.07
1318.89 -737.14 1420.91
1350.87 -765.81 1435.13
1380.85 -792.77 1448.26
1552.11 116.08 2.52
1577.46 116.80 2.54
1600.74 117.42 4.87
1626.67 118.09 4.10
1651.05 118.70 2.26
RECEIVED
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
ANADRILL SCHLUMBERGER Survey Report 3-Jan-2000 14:36:19 Page 6 of 8 -
Seq Measured Incl Azimuth Course
% depth angle angle length
- (ft) (deg) (deg) (ft)
121 8768.00 89.83 155.01
122 8805.00 88.76 154.25
123 8832.00 87.87 154.44
124 8863.00 86.71 155.18
125 8895.00 87.02 155.46
30.00
37.00
27.00
31.00
32.00
TVD Vertical Displ Displ Total At DLS
depth section +N/S- +E/W- displ Azim (deg/
(ft) (ft) (ft) (ft) (ft) (deg) 100f)
6968.47 1410.82 -819.83 1461.22 1675.50
6968.92 1447.77 -853.26 1477.07 1705.81
6969.72 1474.74 -877.59 1488.76 1728.16
6971.18 1505.66 -905.61 1501.93 1753.83
6972.93 1537.56 -934.64 1515.28 1780.34
Srvy
tool
type
119.30 4.07 MWD
120.01 3.55 MWD
120.52 3.37 MWD
121.09 4.44 MWD
121.67 1.30 MWD
Tool
qual
type
6-axis
6-axis
6-axis
6-axis
6-axis
126 8924.00 87.32 155.53
127 8954.00 87.53 155.49
128 8986.00 87.94 155.29
129 9016.00 88.15 154.56
130 9045.00 88.29 154.86
29.00
30.00
32.00
30.00
29.00
6974.36
6975.71
6976.98
6978.00
6978.90
1566.47 -961.00
1596.38 -988.27
1628.30 -1017.34
1658.24 -1044.50
1687.19 -1070.70
1527.29 1804.47
1539.71 1829.59
1553.03 1856.58
1565.74 1882.15
1578.12 1907.06
122.18 1.06 MWD
122.69 0.71 MWD
123.23 1.43 MWD
123.71 2.53 MWD
124.16 1.14 MWD
6-axis
6-axis
6-axis
6-axis
6-axis
131 9079.00 88.63 154.97
132 9108.00 88.80 155.59
133 9139.00 89.07 155.35
134 9169.00 89.55 154.84
135 9201.00 90.00 155.50
34.00
29.00
31.00
30.00
32.00
6979.81
6980.46
6981.04
6981.40
6981.53
1721.13 -1101.49
1750.08 -1127.82
1781.01 -1156.02
1810.96 -1183.23
1842.91 -1212.27
1592.53 1936.34
1604.65 1961.35
1617.52 1988.15
1630.15 2014.31
1643.59 2042.30
124.67 1.05 MWD
125.10 2.22 MWD
125.55 1.17 MWD
125.97 2.33 MWD
126.41 2.50 MWD
6-axis
6-axis
6-axis
6-axis
6-axis
136 9230.00 89.04 153.74
137 9262.00 88.39 155.52
138 9293.00 88.90 155.36
139 9322.00 89.18 154.94
140 9354.00 89.45 155.11
29.00
32.00
31.00
29.00
32.00
6981.77
6982.49
6983.22
6983.71
6984.09
1871.88 -1238.47
1903.83 -1267.37
1934.77 -1295.56
1963.72 -1321.87
1995.67 -1350.88
1656.02 2067.90
1669.73 2096.24
1682.61 2123.59
1694.79 2149.34
1708.30 2177.88
126.79 6.91 MWD
127.20 5.92 MWD
127.60 1.72 MWD
127.95 1.74 MWD
128.34 1.00 MWD
6-axis
6-axis
6-axis
6-axis
6-axis
141 9385.00 89.83 154.82
142 9415.00 90.07 155.07
143 9446.00 89.79 153.99
144 9477.00 89.38 154.13
145 9508.00 89.90 153.33
31.00
30.00
31.00
31.00
31.00
6984.28
6984.31
6984.35
6984.57
6984.77
2026.62 -1378.96
2056.58 -1406.14
2087.55 -1434.13
2118.53 -1462.00
2149.51 -1489.80
1721.42 2205.64
1734.13 2232.58
1747.46 2260.60
1761.02 2288.81
1774.74 2317.15
128.70 1.54 MWD
129.04 1.16 MWD
129.38 3.60 MWD
129.70 1.40 MWD
130.01 3.08 MWD
6-axis
6-axis
6-axis
6-axis
146 9538.00 90.10 153.10
147 9569.00 90.27 154.32
148 9598.00 88.56 153.99
149 9630.00 88.53 154.56
150 9660.00 88.90 154.47
30.00
31.00
29.00
32.00
30.00
6984.77
6984.67
6984.96
6985.78
6986.45
2179.51 -1516.58
2210.49 -1544.38
2239.47 -1570.47
2271.43 -1599.29
2301.39 -1626.37
1788.26 2344.76 130.30
1801.99 2373.24 130.60
1814.63 2399.84 130.87
1828.51 2429.24 131.17
1841.42 2456.80 131.45
RECEIVED
1.02
3.97
6.01
1.78
1.27
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
A aO, &GasOons.
Am Ke
ANADRILL SCHLUMBERGER Survey Report 3-Jan-2000 14:36:19 Page 7 of 8 ·
Seq Measured Incl Azimuth Course
% depth angle angle length
- (ft) (deg) (deg) (ft)
151 9690.00 89.31 153.92
152 9721.00 89.49 154.57
153 9752.00 89.14 154.05
154 9782.00 87.77 154.22
155 9844.00 88.52 155.15
30.00
31.00
31.00
30.00
62.00
TVD Vertical Displ
depth section +N/S-
(ft) (ft) (ft)
6986.92
6987.24
6987.61
6988.42
6990.43
Displ Total At DLS Srvy
+E/W- displ Azim (deg/ tool
(ft) (ft) (deg) i00f) type
2331.36 -1653.37
2362.34 -1681.29
2393.31 -1709.22
2423.27 -1736.21
2485.17 -1792.22
1854
1867
1881
1894
1920
.47
.94
.38
.46
.96
2484.49 131.72 2.29
2513.16 131.99 2.18
2541.86 132.25 2.02
2569.71 132.50 4.60
2627.19 133.01 1.93
MWD
MWD
MWD
MWD
MWD
Tool
qual
type
6-axis
6-axis
6-axis
6-axis
6-axis
156 9871.00 88.70 155.08
157 9905.00 88.73 154.79
158 9936.00 89.28 155.44
159 9967.00 89.79 155.14
160 10000.00 88.90 153.57
27.00
34.00
31.00
31.00
33.00
6991.08
6991.85
6992.39
6992.64
6993.01
2512.12 -1816.71
2546.06 -1847.50
2577.01 -1875.62
2607.96 -1903.78
2640.93 -1933.52
1932
1946
1959
1972
1987
.32
.72
.76
.72
.00
2652.22 133.23 0.72
2683.83 133.50 0.86
2712.67 133.74 2.75
2741.53 133.98 1.91
2772.49 134.22 5.47
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
161 10030.00 87.94 154.05
162 10062.00 88.22 153.15
163 10091.00 88.42 154.51
164 10123.00 88.66 153.89
165 10152.00 88.83 153.52
30.00
32.00
29.00
32.00
29.00
6993.84
6994.91
6995.76
6996.58
6997.21
2670.90 -1960.43
2702.87 -1989.08
2731.84 -2015.09
2763.80 -2043.90
2792.78 -2069.89
2000
2014
2027
2041
2054
.24
.46
.24
.16
.01
2800.76 134.42 3.58
2830.98 134.64 2.94
2858.38 134.83 4.74
2888.57 135.04 2.08
2916.06 135.22 1.40
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
166 10183.00 88.90 154.53
167 10215.00 89.21 154.30
168 10245.00 89.42 153.83
169 10278.'00 89.76 153.70
170 10308.00 89.49 153.48
31.00
32.00
30.00
33.00
30.00
6997.83
6998.36
6998.72
6998.95
6999.15
2823.75 -2097.75
2855.72 -2126.61
2885.70 -2153.59
2918.68 -2183.19
2948.67 -2210.05
2067
2081
2094
2109
2122
.58
.40
.52
.11
.45
2945.41 135.42 3.27
2975.68 135.62 1.21
3004.15 135.80 1.72
3035.56 135.99 1.10
3064.17 136.16 1.16
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
171 10337.00 87.81 153.71
172 10370.00 88.18 153.26
173 10402.00 88.56 153.11
174 10430.00 88.80 153.73
175 10462.00 89.04 153.29
29.00
33.00
32.00
28.00
32.00
6999.83
7000.99
7001.90
7002.54
7003.14
2977.65 -2236.02
3010.61 -2265.53
3042.59 -2294.08
3070.58 -2319.11
3102.56 -2347.75
2135.34
2150.06
2164.49
2177.02
2191.29
3091.84 136.32 5.85
3123.37 136.50 1.76
3154.02 136.66 1.28
3180.83 136.81 2.37
3211.49 136.97 1.57
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
176 10493.00 89.31 153.32
177 10520.00 89.52 152.93
178 10552.00 89.66 153.12
179 10585.00 89.97 152.36
180 10613.00 90.27 152.18
31.00
27.00
32.00
33.00
28.00
7003.59
7003.87
7004.10
7004.20
7004.14
3133.55 -2375.44 2205.22
3160.54 -2399.52 2217.42
3192.53 -2428.04 2231.94
3225.53 -2457.38 2247.05
3253.53 -2482.16 2260.08
3241.25 137.13 0.88
3267.21 137.26 1.64
3298.02 137.41 0.74
3329.85 137.56 2.49
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
2000
Nm. Oil&Ga Coas.
ANADRILL SCHLUMBERGER Survey Report
3-Jan-2000 14:36:19
Page 8 of 8
Seq Measured Incl Azimuth
% depth angle angle
- (ft) (deg) (deg)
181 10645.00 89.49 151.90
182 10675.00 88 . 87 151.84
183 10707 . 00 89.38 151.55
184 10737.00 89.66 152.63
185 10768 . 00 89.86 152.15
186 10799.00 89.11 151.48
187 10839.00 89.28 152.83
Projected to TD:
188 10897.00 89.28 152.83
Course TVD
length depth
(ft) (ft)
32.00 7004.21
30.00 7004.64
32.00 7005.13
30.00 7005.38
31.00 7005.51
31.00
40.00
58.00
7005.79
7006.35
7007.08
Vertical Disp1 Displ Total At DLS Srvy Tool
section +N/S- +E/W- displ Azim (deg/ tool qual
(ft) (ft) (ft} (ft) (deg) i00f) type type
3285.53 -2510.42
3315.52 -2536.88
3347.52 -2565.05
3377.52 -2591.56
3408.52 -2619.03
2275.08
2289.22
2304.40
2318.44
2332.80
3439.51 -2646.35 2347.45
3479.51 -2681.71 2366.13
3537.50 -2733.31 2392.61
3387.95 137.82 2.59
3417.06 137.94 2.08
3448.15 138.06 1.83
3477.26 138.18 3.72
3507.32 138.31 1.68
3537.47 138.43 3.24
3576.33 138.58 3.40
3632.57 138.80 0.00
MWD
MWD
MWD
MWD
MWD
MWD
MWD
MWD
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
6-axis
[(c)2000 Anadrill IDEAL ID6 0C 07]
RECEIVED
MWD/LWD Log Product Delivery
Customer Arco Alaska, Inc. Dispatched To: AOGCC
Well No CD1-03 Date Dispatche 10-Jan-00
Installation/Rig Doyon 19 Dispatched By: Nathan Rose
LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes
Surveys (Paper) 2
RECi:.IVED
J/-',!,j 12 2000
Received By: ~._~O ~'(_(~~//~~ Please signandreturnto:
Anadrill LWD Division
3940 Arctic Blvd
Anchorage, Alaska 99503
Emaih jleblanc~slb.com
Fax: 907-561-8417
LWD Log Delivery V1.1, Dec '97
Schlumberger
Schlumberger Technology Corporation, by and through is Geoquest Division
3940 Arctic Bird, Suite 300
Anchorage, AK 99503-5711
ATTN: Sherrie
NO. 121145
Company:
Alaska Oil & Gas Cons Comm
Attn: Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
Field: Alpine
Color
Well Job # Log Description Date BL Sepia Prints CD
cD1-03 20014 GR/CDPJIMPULSE "~F-.- d-~ OI ~ ~ 000104 1
CD1-03 20014 MD GR/CDR/IMPULSE 000104 1 1
CD1-03 20014 TVDIGRICDR 000104 1 1
CD1-03 20014 MD ADN 000104 I 1
CD1-03 20014 TVD ADN 000104
, ,
~r'~' 'lVEl~
S,GNE ~;~ DatE: FEB 04 ?000
(~ x ~ask~ Oil & ~ bo~;~.
Anchorage
Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you.
2/2/00
ARCO Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 1215
January 24, 2000
Ms. Wendy Mahan
Natural Resource Manager
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501-3192
Re: Revised Kuparuk Area Annular Injection, Fourth Quarter, 1999
Dear Ms. Mahan:
[CE!VED
Z 8 2000
Anchorage
Please find reported below the volumes injected into surface casing by production casing annuli
during the fourth quarter of 1999, as well as total volumes injected into annuli for which injection
authorization expired during the fourth quarter of 1999.
Annular Injection during the fourth quarter of 1999:
h(1) h(2) h(3) Total for Previous New
Well Name Volume Volume Volume Quarter Total Total
CD1-37 15214 100 0 15314 17273 32587
CD1-39 27391 100 0 27491 4017 31508
1D-12 27089 100 0 27189 5702 32891
CDI-16 28925 100 0 29025 0 29025
CD1-32 7449 100 0 7549 0 7549
CD1-03 285 100 0 385 0 385
CD1-42 287 100 I 0 387 0 387
CD1-40 20 0I 0 20 32649 32669
CD1-45 274 100 0 374 0 374
CD1-36 293 100 0 393 0 393
CD1-35 217 100 0 317 0 317
CD1-23 20 0 0 20 17085 17105
CDI-13 89 100 0 189 0 189
CD1-01 20 0 0 20 5201 5221
,
Total Volumes into Annuli for which Injection Authorization Expired during the fourth quarter
v ;I'otal
Total h(1) Total h(2) Total h(3) Volume
Well Name Volume Volume Volume Injected Status of Annulus
2N-315 25326 I 100 0 25426 Open, Freeze Protected
Open, Freeze Protected
2L-329A 33971 100 0 34071 I
2L-325 20280 100 0 20380 Open, Freeze Protected
2L-313 I 12433 100 0 . 12533 Open, Freeze Protected
Ms. Wendy Mahan
AOGCC
Fourth Quarter 1999 Annular Injection Report
Page Two
Please call me at 263-4603 should you have any questions.
Sincerely,
Paul Mazzolini
Drilling Team Leader
CC:
Mike Zanghi
Paul Mazzolini
Randy Thomas
Kuparuk Environmental: Engel / Snodgrass
Morrison and Winfree
Sharon Allsup-Drake
Well Files
ARCO Alaska, Inc,
Post Office Box 100360
Anchorage, Alaska 99510-0360
Telephone 907 276 12!5
January 11,2000
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Re:
Application for Sundry Approval to Enable Annular Disposal of Drilling Waste on
well: OD1-03
Dear Sirs:
ARCO Alaska, Inc. hereby requests that CD1-03 be permitted for annular pumping of
fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080.
Please find attached form 10-403 and other pertinent information as follows:
,
2.
3.
4.
5.
6.
7.
Form 10-403
Surface Casing Description
Surface Casing Cementing Report
Copy of the Daily Drilling Report covering surface casing cementing.
Casing and Formation Test Integrity Report (LOT at surface casing shoe).
Formation LOT on 9-5/8" x 7" casing annulus.
CD1-03 Well Completion Schematic.
If you have any questions or require further information, please contact Brian Robertson
at 265-6034 or Doug Chester at 263-4792.
Sincerely,
Brian Ro'bertson ~
Senior Drilling En'gineer
CC.
CD1-03 Well File
_Alpine Files
Doug Chester
G racie Stefanescu
ANO-382
Anadarko
ORIGINAL
R CE VED
0il & Gas Cons. C0rr~missi0r,
Anchorage
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
':1': Ty[~-~?'~l-~-~ii .......... -,~:~.~a~--_' ......................................... Suspend ] ............................................................... Operational shutdown _- ........................................................... Re-enter suspended well ] ...........................................................................
Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _
Change approved program _ Pull tubing _ Variance _ Pedorate _ Annular injection - X
2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet)
ARCO Alaska, Inc. Development__X RKB 56' feet
3. Address Exploratory__ 7. Unit or Property name
P. O. Box 100360 Stratigraphic_
iAnchorage, AK 99510-0360 Service__ Colville River Unit
i4. Location of well at surface 8. Well number
i236' FNL, 2558' FWL, Sec.5, T11N, R5E, UM CD1-03
At target (7" casing point in Alpine)) 9. Permit number / approval number
1168' FNL, 1767' FEL, Sec.5, T11 N, RSE, U M .... per APB 199-120
~,At effective depth 10. APl number
50-103-20319-00
iAt total depth 11. Field / Pool
2332' FSL, 295' FEL, Sec.5, T11 N, R5E, UM ...... per APD Colville River Field/Alpine Oil Pool
12. Present well condition summary
Total depbh: measured 10897 feet
true vertical 7007 feet
Effec~ve depth: measured 10897 feet
true vertical 7007 feet
Casing Length Size Cemented Measured Depth True vertical Depth
Conductor 77' 16" 10 cu.yds, Portland Type 3 114 114
Surface 2486' 9.625" 509 sx ASL3, 230 sx Class G 2522' 2369'
Production 7782' 7" 119 sx Class G 7816' 6970'
::CD1-03 is as an open hole injection well. It was suspended after being completed with 4-1/2" tubing. ECEJVED
lit is intended that the 9-5/8" x 7" annulus be used for injection of associated drilling waste as per the previously applied for
annular waste disposal permit application.
ORIGINAL Alaska 0i1 & 6as Cons. C0mmissior~
Anchorage
13. Attachments Description summary of proposal_ Detailed operations program _ BOP sketch __
14. Estimated date for commencing operation 15. Status of well classification as:
February 1, 2000
16. If proposal was verbally approved Oil __ Gas __ Suspended __
Name of approver Date approved Service X
17.1hereby certltyffhat the foregoing is true and correct to the best of my knowledge.i/~,,. [ /l~ /// /~?
Signed "~'l? '" -" ' Title: Drill ng Team Leader Date ~ ~'~
,¢. FOR COMMISSION USE ONLY
Conditions of appr~(~al: Notify Commission so representative may witness IApproval no.
Plug integrity __ BOP Test__ Location clearance --I ,.-~0/¢'~
Mechanical Integrity Test__ Subsequent form required 10- ~,"~,~-r-c.~t~¥ ~ O,~,~'~O, ~ "~.~ ~r',~.%¢_~ ~
ORIGINAL SIGNED' BY
iApproved by order of the Commission Robed: N. Christenson Commissioner Date 1-'/ g ~ ~
Approved Cop~'
Returned
Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE
Casing Detail Well: CD1-03
9 5/8" Surface Casing Date: 12/23/99
ARCO Alaska, Inc.
Subsidiary of Atla~ Subsidiary of Atlantic Richfield Company DEPTH
Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS
Doyon 19 RKB to LDS 36.83
FMC Gen V Hanger 2.40 36.83
Jts 3 to 61 59 Jts !9-5/8" 36# J-55 BTC Csg 2394.36 39.23
Davis Lynch Float Collar 1.55 2433.59
Jts 1 to 2 2 Jts 9-5/8" 36# J-55 BTC Csg 85.74 2435.14
Davis Lynch Float Shoe 1.75' 2520.88
2522.63
TD 12 1/4" Surface Hole' 2532.00
RUN TOTAL 35 BOWSPRING CENTRALIZERS -
I per jt on Jt #1 - #12 (On strop rings of Jt #1 & #3)
#14, 16, 18, 20, 22, 24, 26, 28, 30, 32, 34, 36, 38, 40
42, 44, 46, 48, 50, 52, 54, 56, 58, 60
4 Jts left out #62 -#65
Use ~est-o-Ufe ~000 pipe dope
~e~ar~s: Up Wt - ~ 45
Dn Wt - 135
Block Wt - 70
Supe~isor: D. Lutrick / S. Goldberg
ARCO Alaska, Inc.
Cementing Details
Well Name: CD1-03 Report Date: 12/23/99 Report Number: 3
Rig Name: Doyon 19 AFC No.: 998B12 Field: Alpine
i
Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: I % washout:
9 5/8" 12 1/4" N/A 2522 2433
I
Centralizers State type used, intervals covered and spacing
Comments:
: Ran 35 Bow Spring Centralizers. One per jt on first 12. Every other joint to surface
:
:Mud
Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond):
:comments: 9.7 40 21 50 17
:
: Gels before: Gels after: Total Volume Circulated:
37/74/76 5/20/28
Wash 0 Type: Volume: Weight:
CommentS: Water 40 bbls 8.4 ppg
Bi°zan Wash with Nut PlUg
Marker. Pump at 9 bpm with
rig
Spacer 0 Type: Volume: Weight:
Comments: ARCO Spacer 50 bbls 10.5
pump at 6 bpm
LeadCement 0 -ype: I Mixwtrtemp: No. of Sacks:I Weight: Yie.d:
Comments: AS III Lite 70 509 10.7 ppg 4.4 ft3/sx
pUmp at 7:bpm 'Additives:
: : 30% D053, 0.6% D046, 1.5% D079, 1.5% S001, 50% D124, 9% D044
Tail:Cement 0: Type: I Mixwtrtemp: [ No. ofSacks: I Weight: ] Yield:
comments: GI I I 170 230 15.8 ppg 1.15 ft3/sx
i Pump at 5 bpm
Additives:
0.2% D046, 0.3% D065, 1% S-1 CaCl2
Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. WI. Up:
Comments: 7 bpm 5-7 bpm 145
0.1 bps
Reciprocation length: Reciprocation speed: Str. Wt. Down:
135
Theoretical Displacement: Actual Displacement: Str. Wt. in mud:
1687 stks 1709 stks
Calculated top of cement: CP: Bumped plug: Floats held:
Surface Date:12/23/99 Yes Yes
Time:23:00
Remarks:Good returns throughout job. Estimated 50 bbls good cement circulated to surface.
Cement Company:
Dowell
JRig Contractor:
DOYON
Approved By:
D. Lutrick/S. Goldberg
I EIVED
Daily Drilling Report
ARCO Alaska, Inc.
AFC No. Date Rpt No I Rig Accept - hrs Days Since AcceptJEst: 2.3 / 2.7 Rig Relase - hrs:
998B 12 12/23/99 3I pM12/21/99 05:30:00
Well: CD1-03 Depth (MD/TVD) 2532/2379 Prev Depth MD: 2120 Progress: 412
Contractor: DOYON Daily Cost $ 201794 Cum Cost $ 347689 Est Cost To Date $ 500000
Rig Name: Doyon 19 Last Csg: 9 5/8" @ 2522' Next Csg: 7" @ 7764' Shoe Test: n/a
Operation At 0600: Testing BOPE
Upcoming Operations: P/U 8 1/2" Drilling Assembly, RIH
MUD:DATA DRILLING DATA BIT DATA EH&S DRILLS/BOP DATA
MUD TYPE DEPTH BIT NO. BIT NO. INCIDENT LAST BOP/DIVERT LAST BOP/DRILL
SPUD 2532 I N TST 12/12/99
12/24/99
WEIGHT ROT WT I SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL
9.7ppg 12 1/4" 11/07/99 12/12/99
VISCOSITY PU WT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL
65sqc HTC N SPACE 1 2/22/99
06/21/99
PV/YP SO WT TYPE TYPE TYPE FUEL & WATER
21 / 17 MX1
GELS AVG DRAG SERIAL NO !SERIAL NO VOLUME FUEL USED 4985
5 / 20 / 28 G03DG
APl WL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED - 485
16 2532 11/23/99 BBLS
HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 85
mi/30 min 114 INJECTION USED - BBLS
SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER &
11.5% 2418 CD1-37 PERSONNEL DATA
HOLE VOLUME PUMP PRES ADT/AST ADT/AST SOURCE WELL TEMP °F -21
186bbl 1850 I 2000 I I 19.4/8.61 / CD1-03
MBT PUMP NO WOB 2 WOB 2 RATE (bpm) WIND SPEED 15
25 1121 I 15-30 3.5
~h LINER SZ RPM 1 RPM 1 PRESSURE (psi) 'WIND DIRECTION 90°
9 5.5161 I 80- 90 1100
LGS SPM 1 TFA TFA INJECTION FLUIDS CHILL FACTOR °F -59.47
10.1% 78 176 I I 0.546
Water Base Muds
400
PIT VOL GPM 2 JETS JETS Diesel ARCO PERSONNEL 2
'150 275131911 1011211211811 IIIII 80
Other
160
DAILY MUD SPS 1 BIT COST BIT COST CONTRACTOR 25
$10119 III 11910 0 PERSONNEL
TOTAL MUD SPP 1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 10
$23392 t I I 416 I WTI A I I 640
COMPANY MUD WI- GRADE GRADE TOT FOR WELL (bbl) SERVICE 1
M~ I I I E I 1 I RG I TD I I 32578 PERSONNEL
TOTAL 38
TIME I END HOURS I OPS CODE I HOLE SECT IPHASE OPS I OPERATIONS FROM 0000- 0000
12:00 AM 05:30 AM 5.50 DRIL SURF Making Hole Continue drilling 12 1/4" hole from 2120' to 2532'. TD
Surface Hole.
05:30 AM 06:30 AM 1.00 CIRC SURF WiperTrip Circulate and condition mud for Short Trip
06:30 AM 08:00 AM 1.50 WIPERTRP SURF WiperTrip Short Trip to 1480'. Trip pulled smooth.
08:00 AM 09:00 AM 1.00 CIRC SURF Trip Out Circulate and condition mud for Trip out of hole.
09:00 AM 12:00 PM 3.00 TRIP_OUT SURF Trip Out POOH for casing. K/U and pump out of hole from
1250'-800'. I.JD MWD, Stab, motor and bit.
12:00 PM 12:30 PM 0.50 SAFETY SURF Casing and Hold PJSM on running 9 5/8" surface casing.
'.'. .. Cementing
12:30 PM 05:00 PM 4.50 RUN CSG SURF Casing and PJU floor equipment to run 9 5/8" casing, P/U shoe jts and
~, Cementing Bakerlok. Run 61 jts casing to TD. Pump/Push through
~ _ . tight spot from 940' to 1060',
05:00 PM 07:00 PM 2,00 P.R_B_MlSC . . SURF Casing and R/U hardlines to new Annular Injection well CD1-32,
Cementing Hardline froze up, Attempt to regain circulation with warm
' ' ~ diesel and try to determine where ice plug is located. Clear
lines.
07:00 PM 08:30 PM 1.50 CIRC SURF Casing and PJU cementing head and circulate and condition mud for
Cementing cement job. Cut PV/YP properties to recommended levels.
08:30 PM 09:00 PM 0.$0 SAFETY SURF Casing and Hold PJSM to discuss cement job.
Cementing
Daily Drilling Report: CD1-03 12/23/99 Page 1
09:00 PM 11:00 PM 2.00
11:00 PM 12:00 AM 1.00 NU_ND
24.00
CMT_CSG
SURF
SURF
Casing and
Cementing
Casing and
Cementing
Rig pumped 40 bbls Biozan wash with nut plug marker at 9
bpm. Fill Dowell lines and P/l' lines to 2500 psi. Drop
bottom plug okay. Dowell pumped 50 bbls 10.5 ppg ARCO
Spacer at 6 bpm. Switch to lead slurry. Pump 400 bbls
10.7 ppg ASIII at 7 bpm. Look for Nut Plug at shakers. At
good showingswitch to tail slurry. Pump 46 bbls 15.8 ppg
Class G at 5 bpm. Drop top plug. Chase with 20 bbls water
from Dowell. Switch to rig pumps to displace at 7 bpm.
Circulated approx. 50 bbls good cement to surface.
Bumped plug with 1709 stks. Floats held okay.
I.JD landing it. Flush out stack. Clear rig floor.
Supervisor: LUTRICKJGOLDBERG
IVED
2000
Daily Drilling Report: CD1-03 12/23/99 Page 2
CASING TEST and FORMATION INTEGRITY TEST
Well Name: CD1-03
Date: 12/24/99 Supervisor: Lutrick / Goldberg
Reason(s) for test:
[] Initial Casing Shoe Test
[] Formation Adequancy for Annular Injection
[] Deep Test: Open Hole Adequacy for Higher Mud Weight
:
Casing Size and Description: 9 5/8" 36# J-55 BTC CSG
Casing Setting Depth: 2,522' TMD
2,369' TVD
Mud Weight: 9.5 ppg "
Hole Depth: 2,552' TMD
2,397' TVD
Eength of Open Hole: 30'
EMW = 790 790 psi
+ Mud Weight _ + 9.5 ppg
0.052 x2369 0.052 x 2,369'
EMW = 15.8 ppg
Pump output = .101 BPS Fluid Pumped = 4.0 BBL
BLED BACK =0.8 BBLS
TIME: LINE: :::.
2,800 psi
2,700 psi
2,600 psi
2,500 psi
2,400 psi
2,300 psi
2,200 psi
2,100 psi
2,000 psi
1,000 psi
1.800 psi
1,700 psi
1,600 psi
1,500 psi
1,400 psi
1,300 psi
1,200 psi
1,100 psi
1,000 psi
900 psi
800 psi
700 psi
b00 psi
500 psi
400 psi
300 psi
200 psi
100 psi
0 psi
........................................................I-'~----~--~-~-~-l'--'~l C)Nb MIXIU b IIC;K5:
........................ ' ................~' ....................... ~Z ....... I-ti ~17"2 ~~ ~Z
;~ .... __.~ ___~--'~T---- '"'": ...... LOT SHUT IN TIME
--
~,~ CASING TEST SHUT IN TIME
~ = TIME LINE
- ~ ........ L .... ~ 'r .... .... ~ .....................~ ~---[ .... ~ ..... ~ ~ .... .... ~ ....
0 stk 2 stk 4 stk 6 stk 8 stk 10 slk 12 stk 14 stk 16 stk 18 stk 20 stk 22 stk 24 stk 26 stk 28 stk 30 stk 32 stk 34 stk 36 stk 38 stk 40 stk 42 stk 44 stk 46 stk 48 stk 50 stk
STROKES
LEAK-OFF DATA
MINUTES
FOR
LOT STROKES PRESSURE
.................. I- .............. ~ ............... -I
i Ostks ~ 50 psi
..................
..................
.................. t- .............. ~ ............... -I
.................. L_..~.~!.k_s. ...... ~&°..e~J.__i
~ 8stks 690 psi
.................. I- .............. ~ ...............
: _ [ 10stksi 790psi ~
................. ~--~-~'~-[~'~" f-'~ii~-~'a--!
iiZiZZZiii[ii)Zi :EC[i:EEbiEij
[ 16stks i 640 psi
..................
..................
.................. i--~--~i[;~--i---~-~ij-[,-~FI
.................. ,-T,i'iii'~'-,--i~-ii'i,'a--1
i 26 stks 610 psi
.................. h~_~-~-ii,'~ .....
:::::::::::::::::::::::::::::::::::::::::::::::::
[ 32stks , 600 psi
.................. :--§Z'~ii-;-' :---~,~ii-i,-ii--1
:::::::::::::::::::::::::::::::::::::::::::::::
[ 88stks , 600 psi
CASING TEST DATA
MINUTES
FOR
CSG TEST STROKES PRESSURE
.................. r ....................................
.................. t--Tiiii' ......... §a'-~ir ......
.................. f ....................................
, 2stks 270 psi ,
.................. t'--~'~i[[~' ........ ~'~'i;~[ .....
.................. t--'8';iii'-'~ ..... i8'~'~;[ ..... I
.................. f .............. f ..................... !
[ 8stks I 1,060psi
.................. ~-'i~'[ii%' ..... ~fb--~i ....
................. ~ ....................................
i 16 stks 1,780 psi
................. ~ .................................... !
i 20 stks 2,050 psi
................. ~ .................................... I
~ 22 stks 2,210 psi
................. ~ .............. i ..................... i
I i
i i
................. f .............. f ..................... !
i
................. ~ .............. ~ .....................
I I
................. ~ ...................................
I ~ ! I
.... ~:a"~i~'"-i .............. i .... ~;~'~-6;i ....
.... ~:a-~iR'"-~ .............. ~ .... i~ab--¢~i ....
.................. ~I .............. ; ............... I .................. 10.0mln' ~l .............. 'I ..................... 2,500 psi i
I i ~ .................. I- .............. T .....................
SHUT IN TIME i SHUT IN PRESSURE , 2,495 psi
2.0min [ i 560 psi ~
4.0 min [ j__-.___.. 4550 psi ~
.... §76"r~i7;---: .............. '-- '"'---'--:
i ooup~I i
.................. ~ .............. T ............... I
6.0min : ~ 550psi ~
7.0min = , 550 psi =
.... ~:~)--r~----t .............. t---~-~ii-i,-a-'1
9.0min , i 540 psi i
.................. t- .............. ~ ............... -I
.___l_.O_._o____m_i.n_.__[ .............. i___.5_4__o___p.s, j___i
15.0 min i
.................. I- .............. ? .....................
20.0 min[ i 2,495 psi
25.0min : ~ 2,490 ps~
................. ~- .............. 1 .....................
,- ................ f .............. T .....................
i i i
1 .................. f .............. ! .....................
i i i i
,- ................ f .............. T .....................
i i i i
1 .................. ~ .............. { .....................
................. ~ .............. ~ .....................
i i i i
i i i i
1 .................. ~ .............. t .....................
................. [ .............. . .....................
NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY
CASING TEST and FORMATION INTEGRITY TEST
Well Name: CD1-03 Date: 12/29/99
Supervisor: Donald Lutrick
Reason(s) for test:
[] Initial Casing Shoe Test
[] Formation Adequancy for Annular Injection
[] Deep Test: Open Hole Adequacy for Higher Mud Weight
Casing Size and Description: 9 5/8" 36# J-55 BTC CSG X
Casing Setting Depth: 2,522' TMD
2,369' TVD
7" 26# L-80 BTCM CSG
TOC
Hole Depth: 7,148' TMD
6,660' TVD
Mud Weight: 9.7 ppg
Length of Open Hole: 4,388'
Press
EMW = .052 X TVD + Mud Weight
661 psi
0.052 x 2,369'
EMW = 15.1 ppg
+ 9.7 ppg
Pump output = .020 BPS Fluid Pumped = 6.5 bbl
..... Used cement unit BLED BACK =
700 psi
600 psi
500 psi
u~ 400 psi
~v
LU
12. 300 psi
200 pC
1 O0 psi
0 psi
O.0bbls i.0bbls 2,0bbls 3.0bbls 4.Obbl$ 5.0bbls &0bbls 7.0bbls 8.0bbls 9.0bbls 10.0bbls 11.0bbls 12.0bbls 13.0bbls ]4.0bbls 15.0bbls
BBLS
LEAK-OFF DATA
MINUTES
FOR
LOT BBLS PRESSURE
0.0 bbls i 25 psi
.................... .0. : .5. _b_ _b_ Ls__ j___ !.°__~__P_S. L_
~ 1.0bbls ! 222 psi
1.5 bbls 338 psi
2.0 bbls 444 psi
............... .....
...............
................... ..... ....
.................. ._~:P..~Ls. ..... .s..~.?_?..s.L
................... .4.-..5_.b_.b_Ls. ..... .s__s..s..P..s.L
5.0 bbls 570 psi
................... ~...~_.b..b. Ls. ..... .s_.s.9.?..s.L.
6.0 bbls 550 psi
.................. .6_'..5..b..b_Ls_ ..... .5._s..o_?..s.L.
,
................................ .1 .................
i
i
i
i
................ .(, ............... d .................
, ,
!
J,
!
'
............... ! I
SHUT IN TIME SHUT IN PRESSURE
.__.0...9__.m__Ln. ...................... .5_.5_.0...p.s_L_.
.__.!..o..~j~ ....................... ~.4..~_.,..s_] ....
,._~..o..~j~ ...................... ~.~.9_?..s.] ....
__~.9...m_jp_ ...................... .4. .2. .4. .p. .s_ L .
4.0 min 419 psi
'--g:~%~;; ...................... ~3-~,--~-E-'
6.0 min 404 psi
............... · , ............... ..i .................
,__Z:_O___m.j_n_ ...................... .3..9_9_.p..s_] ....
8.0 min 399 psi
9.0 min 394 psi
............... r ...............................
!
t.. .............. ,.l.. .............. .J- ................
!
!
i- .............. .-i- .............. ..J.. ................
...&.
!
,
!
! !
i.. .............. .i.. .............. ...i. ................
, , !
i i i i
i i i i
NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KE'
Colville River Field
CD1-03 Completion - As Built
16" Conductor @ 114' MD
Camco 4-1/2 .... DB" Nipple (3.812" ID)
at 1781' MD
RKB - GL = 37'
9-5/8" 36 ppf J-55 BTC
Surface Casing
@ 2522' MD / 2369' TVD
cemented to surface
4-1/2" 12.6 ppf L-80 IBT Mod. R2
tubing run with Jet Lube Run'n'Seal
pipe dope
Packer Fluid:
9.6 ppg KCL brine
with diesel to 2150' MD
TOC calculated at 7148' MD
Baker Model S-3 Packer (3.875" ID) at 7466' MD
HES XN (3.725" iD) at 7510' MD
Wireline Entry Guide at 7523' MD
TD at 10897' MD /
7007' TVD
""~ii!~i~i¢ii;;~,,,,,..,~;;~,,~,~;,.,.. ...... ..... 6-1/8 ' Openhole completion interval
7" 26 ppf L-80 BTC Mod
Production Casing @ 7816' MD / 6970' TVD (92 deg)
Updated 01/10/00
Re: Report of Well Control Incident - Doyon 19
Subject: Re: Report of Well Control Incident - Doyon 19
Date: Tue, 04 Jan 2000 09:16:09-0900
From: Blair Wondzell <blair_wondzell~admin.state.ak.us>
Organization: State of Alaska, Dept of Admin, Oil & Gas
To: Brian Robertson <BROBERT4~mail.aai.arco.corn>
Brian,
Thanks, enough on this one.
Blair
Brian Robertson wrote:
Blair,
Yes, the mud system was balanced as far as could be told.
Regards
Brian
Blair Wondzell <blair wondzellSadmin.state.ak, us> on 01/03/2000 11:37:50 AM
--
To: Brian Robertson/AAI/ARCO
cc:
Subject: Re: Report of Well Control Incident - Doyon 19
Brian,
Thanks for the information. After closing-in, was the mud system in balance?
Nothing more is required on your part.
Thanks, Blair
Brian Robertson wrote:
> Blair,
> Please be aware that well CDI-03 was closed in at 01:00 Hrs on Sunday 2
January
> 2000. Reported SICP was 100 psi and SIDPP was 0 psi. The well was closed in
and
> then observed as per AAI Breathing Policy and it was confirmed that there was
> indeed some 'breathing back' of whole mud into the circulating system. The
well
> was circulated through the choke and no hydrocarbons were observed on bottoms
> up. Final SICP and SIDPP were 0 psi. Prior to this incident considerable mud
> losses to the formation were incurred.
> Please contact me on 265-6034 or by return e-mail if you require further
> information.
> Regards
>
> Brian Robertson - Alpine Drilling Engineer
1 ofl 1/4/00 10:06 AM
TON Y KNO W£E$, GO VERNOR
ALAS ~ OIL AND GAS
CONSERVATION COMMISSION
Doug Chester
Drilling Team Leader
ARCO Alaska. h~c.
P O Box 100360
Anchorage, AK 99510-0360
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
Re~
Colville River Unit CD 1-03
ARCO Alaska. Inc.
Permit No: 199-120
Sur. Loc. 236'FNL, 2558'FWL. Sec. 5. T11N, R5E. UM
Btmhole Loc. 2332'FSL. 295'FEL. Sec. 5. T11N. R5E. UM
Dear Mr. Chester:
Enclosed is the approved application for permit to drill the above referenced well.
The permit to drill does not exempt you from obtaining additional permits required bx' law from other
governmental agencies, and does not authorize conducting drilling opcrations until all other required
permitting determinations are made. Annular disposal of drilling wastes will not be approved for this
well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular
disposal of drilling waste will be contingent on obtaining a well cemented surfacc casing confirmed bv a
valid Formation Integrits.' Test (FIT). Cementing records. FIT data. and an3' CQLs must bc submitted to
the Commission on form 10-403 prior to the staff 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 annular disposal on Drill Site CD 1 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 onc ,,'ear.
The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035: and the
mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC
25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the
BOPE test performed before drilling below the surface casing shoe. must be given so that a representative
of the Commission max: witness the tests. Notice max' be given bx' contacting the Commission petroleum
field inspector on the North Slope pager at 659-3607.
Robert N. Chnstenson. P.E.
Chair
BY ORDER OF THF_dlT~. MMISSION
DATED this
day of December, 1999
dlffEnclosures
cc~
Department of Fish & Game? Habitat Section w/o encl.
Department of Enviromnental Conservation w/o encl.
ARCO Alaska, h
Post Office ~3o× 100360
Anchora§e, Alaska 99510-0360
Telephone 907 276 12!5
December 07, 1999
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Re:
Application' for Permit to Drill
CD1-03
Dear Sirs:
ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore injection well from the
Alpine CD1 drilling pad. The intended spud date for this well is December 20, 1999. It is
intended that Doyon Rig 19 be used to drill the well.
CD1-03 will be drilled to penetrate the Alpine sand horizontally. 7" casing will then be
run and cemented in place. A horizontal section will then be drilled and the well
completed as an open hole injector. At the end of the work program, 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 your
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. A proposed drilling program, including a request for approval of annular pumping
operations.
4. A drilling fluids program summary.
5. Proposed completion diagram.
6. Proposed completion diagram with open hole isolation options.
7. Pressure information as required by 20 ACC 25.035 (d)(2).
8. Proposed cementing program and calculations.
9. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b
Information pertinent to this application that is presently on file at the AOGCC is:
1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as
required by 20 ACC 25.035 (a) and (b).
2. A description of the drilling fluids handling system.
If you have any questions or require further information, please contact Brian Robertson
at 265-6034 or Doug Chester at 263-4792.
Sincerely,
Brian Robertson
Senior Drilling Engineer
Attachments
CC:
CD1-03 Well File / Sharon AIIsup Drake
Doug Chester
Mike Erwin
Gracie Stefanescu
Lanston Chin
ATO 1 O54
ANO 382
ANO 384
Anadarko- Houston
Kuukpik Corporation
e-mail ·
Tommy_Thompson @ anadarko.com
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
la. Type of Work Drill X Reddll ~ lb Type of Well Exploratory Stratigraphic Test Development Oil
Re-Entry DeepenI Service X Development Gas Single Zone X Multiple Zone
2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool
ARCO Alaska, Inc. DF 56' feet Colville River Field
3. Address 6. Property Designation /a,~J~? Alpine Oil Pool
P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25559 ,,¢o~.
4. Location of well at surface 7. Unit or property Name ..~ 11. Type Bond (see 20 AAC 25.025)
236' FNL, 2558' FVVL, Sec.5, T11N, R5E, UM Colville River Unit Statewide
At target (=7" casing point ) 8. Well number Number
168' FNL, 1767' FEL, Sec. 5, T11N, R5E, UM CD1-03 #U-630610
At total depth 9. Approximate spud date Amount
2332' FSL, 295' FEL, Sec. 5, T11 N, R5E, UM 12/20/99 $200,000
12. Distance to nearest,2_~'~¢~ 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD)
Property line ,, ....... Alpine CD1- 01 10,913' MD
168' feet ¢~ 19.5' @ 200' Feet 2560 6,998' TVD feet
16. To be completed for deviated'wells 17. Anticipated pres,,~u~e~ 2o AA~ 2~..035(e)(2))
Kickoff depth 300' feet Maximum hole angle 90° Maximum surface ~ 2466~.~,-~s~g At total depth (TVD) 321 5 at psig
7000'
TVD.SS
18. Casing program Setting Depth
size Specifications Top Bottom Quantity of cement
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta~le data)
42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed
12.25" 9.625" 36# J-55 BTC 2523' 37' 37' 2560' 2400' 505 Sx Arcticset III L &
230 Sx Class G
8.5" 7" 26# L-80 BTC-M 7727' 37' 37' 7764' 6981' 117 sx Class G
N/A 4.5" 12.6# L-80 IBT-M 7372' 37' 37' 7409' 6857' Tubing
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured feet Plugs (measured)
true vertical feet
Effective depth: measured feet Junk (measured)
true vertical feet
Casing Length Size Cemented Measured depth True Vertical depth
ConductorStructural :i:'~i !!! {~i: !'~ i'~~¢ ~ ..... i~
Surface
Intermediate
Production
Liner0 RIG INA L
PeRoration depth: measured
20. Attachments Filing fee X Property plat ....... 'BiDP';~ketch DiverterSketch Drilling program X
Ddiling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X
21. I hereby certj~/that the foregoing is true and correct to the best of my knowledge
Signed ~'// C~ Title Drilling Team Leader Date
Commission Use Only
APl number ,,,.~ ~ ~ ~ - Approval date See cover letter for
Permit Number/~ ~ 50- /(-~-~ --~ /
~ "~ Other requirements
Conditions of approval Samples required Yes Mud log required Yes
Hydrogen sulfide measures Yes ~'~o-'~') Directional survey required ("¢~] No
Required working pressure for BOPE~
2M~ 5M 10M 15M
Other:
ORIGINAL .SIGNED BY by order of
.?ved , con n is.io.er th oor, r.i..,on ??
Form 10-401 Rev. 7-24-89 Submit in triplicate
Alpine: CD1-03
.
3.
4.
5.
6.
7.
8.
.
11.
12.
13.
14.
15.
16.
17.
18.
19.
Note:
Procedure
Install diverter. Move on Doyon 19. Function test diverter.
Drill 12 1/4 inch hole to the surface casing point as per the directional plan.
Run and cement 9 5/8 surface casing.
Install and test BOPE to 3500 psi.
Pressure test casing to 2500 psi.
Drill out 20' of new hole. Perform leak off test.
Drill 8-1/2" hole to the intermediate casing point in the Alpine Reservoir.
Run and cement 7 inch casing as per program. Top of cement 500 feet above Alpine reservoir, as per Rule
20 AC 25.030. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure
referenced to the casing shoe. Freeze protect casing annulus and casing.
BOPE test to 3500 psi.
Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5
ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW.
Drill 6 1/8" horizontal section to well TD.
Contingency - set open hole isolation equipment if required (due to unconsolidated formation or wellbore
having moved out of the Alpine reservoir sand).
Displace well to brine and pull out of hole.
Run 4 ~, 12.6 #, L-80 tubing with production packer. Land hanger.
Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP.
Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check.
Circulate in inhibited brine and diesel freeze protection.
Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins.
Set BPV and secure well. Move rig off.
This well will be logged through tubing with a CBL/GR/CCL to determine cement isolation above the top of
the Alpine. This logging will be done after the rig moves off location.
Well Proximity Risks:
Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in
following attachments. CD1-01 will be the closest well to CD1-03 (19.5' at 200' MD). Accounting for survey
tool inaccuracies, the ellipse separation between these wells will be 18.2' at 250' MD.
Drillinq Area Risks:
There are no high-risk events (e.g. over-pressures zones) anticipated.
Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost
circulation. Faulting is predicted, within the Alpine, around the 7" casing point and within the first 500' of the
horizontal section. Conventional LCM treatments have been successful in controlling losses when
encountered in previous CD1 wells.
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.
Annular Pumpinq Or~erations:
Incidental fluids developed from drilling operations on well CD1-03 will be injected into the annulus of a
permitted well.
The CD1~03 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze
protecting with diesel to 2000' TVD. 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 CDt-03 be permitted for annular pumping of fluids occurring as a result of drilling
operations, per regulation 20 AAC 25.080. 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 = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2400') + 1,500 psi
= 2,998 psi
Pore Pressure = 1,086 psi
Therefore Differential = 2998 - 1086 = 1912 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% 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
CD1-03
DRILLING FLUID PROGRAM
SPUD to Intermediate hole to 7" Production Hole
9-5/8"surface casing casing point- 8 ~" Section - 6 1/8"
point- 12 ¼"
Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg
PV 10 - 25 12 -18
YP 20 - 60 15 - 25 35 - 45
Funnel Viscosity 100 - 200
Initial Gels 4 - 8 18 - 22
10 minute gels <18 23 - 27
APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 rain (drilling)
HPHT Fluid Loss at 160 <10 cc/30 min
PH 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5
KCL 6 %
Surface Hole:
A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline
viscosity at + 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain
mud weight < 9.6 ppg by use of solids control system and dilution where necessary.
Intermediate Hole Section:
Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and
maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is
penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good
filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be
important in maintaining wellbore stability.
Production Hole Section:
The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of
6% KCI, with _+ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer
and FIo-Trol starch will be used for viscosity and fluid loss control respectively.
Colville River Field
CD1-03 Completion Plan
16" Conductor @ 114' MD
RKB - GL = 37'
Camco 4-1/2 .... DB" Nipple (3.812" ID)
with Model "Al" Injection Valve (2,125" ID)
at 1700' TVD
9-5/8" 36 ppf J-55 BTC
Surface Casing
@ 2560' MD / 2400' TVD
cemented to surface
4-1/2" 12.6 ppf L-80 IBT Mod. R2
tubing run with Jet Lube Run'n'Seal
pipe dope
Packer Fluid:
9.6 ppg KCL brine
with diesel to 2000' TVD
Tubing tail to include:
4-1/2" Tbg Joints (1)
HES "XN" (3.725" lB)
4-1/2" 10' pup Joint
and WLEG
Note-Baker-lock all components
TOC @ +/-7109' MD
(Minimum of 500' MD above top Alpine)
Baker Model S-3 Packer (3.875'
ID) at +/- 7409' MB - 200' MD
above top Alpine
(Wireline Entry Guide +/- 7464')
TD at10913' MD /
6998' TVD
6-1/80penholecomplet~on~nterv
'~:~ii!~ii~ii~iiiiiiiii!!ii¢!;i;!;~ ........................................................................................................................................................................................................
7" 26 ppf L-80 BTC Mod
Production Casing @ 7764' MD / 6981' TVD (89,7 deg)
Updated 12/06/99
Colville River Field
CD1-03 Completion with Isolation Contingency Options
16" Conductor @ 114' MD
RKB - GL = 37'
Camco 4-1/2 .... DB" Nipple (3.812" ID)
with Model "Al" Injection Valve (2.125" ID)
at 1700' TVD
9-5/8" 36 ppf J-55 BTC
Surface Casing
@ 2560' MD / 2400' TVD
cemented to surface
Packer Fluid:
9.6 ppg KCL brine
with diesel to 2000' TVD
4-1/2" 12.6 ppf L-80 IBT Mod. R2
tubing run with Jet Lube Run'n'Seal
pipe dope
(A) Bonzai ECP Assembly
- Baker ZXP Packer (4.75" ID)
- Baker HMC Liner Hanger
- XO to IBT-Mod
- blank 4-1/2" joints (TBD)
Cementing Valve
- Baker Payzone ECP (mud inflated)
-Landing Collar
- 4-1/2" joint (1- 2) blank
- Guide Shoe
(B) Open Hole Scab Liner
- Baker Payzone ECP (cement inflated)
- 4-1/2" joints (TBD) blank tbg
- Baker Payzone ECP (cement inflated)
- Baker Model XL-10 ECP (anchor)
- Muleshoe / Entry Guide
TOC @ +/-7109' MD
(500' MD above Alpine)
Tubing tail to include:
4-1/2" Tbg Joints (1)
HES "XN" (3.725" lB)
10' pup joint
and WLEG
Note-Baker-lock all components
Baker Model S-3 Packer
(3.875" ID) at +/- 7409' MD
(C) Open Hole Bridge Plug Assembly
- Baker Payzone ECP (cement inflated)
-XO
-Float Collar
- 4-1/2" Float Shoe
.................................... ................. ..................................... ............ ....
TD at 10913' MD /
7" 26 ppf L-80 BTC Mod 6998' TVD
Production Casing @ 7764' MD / 6981' TVD (90 deg)
Updated 12/06/99
CD1-03
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 this well:
Casing Size Csg Setting Fracture Pore pressure ASP Drilling
(in) Depth Gradient (lbs./ (psi) (psi)
MD/TVD(ft) gal)
16 114 / 114 10.9 52 53
9 5/8 2560 / 2400 14.2 1086 1532
7" 7764 / 6981 16.0 3158 2466
N/A 10913 / 6998 16.0 3166 N/A
· NOTE: Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 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 lb./gal
0.052 = Conversion from lb./gal to psi/ft
0.1 = Gas gradient in psi/ft
D = true Vertical depth of casing seat in ft RKB
OR
2) ASP= FPP- (0.1x 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 114 = 53 psi
OR
ASP = FPP - (0.1 x D)
= 1086 - (0.1 x 2400') = 846 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 2400 = 1532 psi
OR
ASP = FPP - (0.1 x D)
= 3158 - (0.1 x 6981') = 2460 psi
3. Drilling below intermediate casing (7")
ASP = FPP - (0.1 x D)
= 3166 - (0.1 x 6998') = 2466 psi
Alpine CD1-03
ANTICIPATED PORE PRESSURE, MUD WEIGHT,
AND FRACTURE GRADIENT
5OO
-500
-1500
-2500
~ -3500
PR
-4500
-5500
-6500
-7500
10
11 12 13 14
EQUIVALENT MUD WEIGHT
15
16
17
AIk,,~e, CD1-03 Well Cementing Requi,,cments
9 5/8" Surface Casing run to 2560 MD / 2400' TVD.
Cement from 2560' MD to 2060' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2060' to
surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess
below the permafrost.
Lead slurry:
(2060'-1629') X 0.3132 ft3/ft X 1.5 (50% excess) = 202.5 ft3 below permafrost
1629' X 0.3132 ft3/ft X 4 (300% excess) = 2040.8 ft3 above permafrost
Total volume = 202.5 + 2040.8 = 2243.3.0 ft3 => 505 Sx @ 4.44 ft3/sk
System:
505 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% D053 thixotropic
additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124
extender and 9% BWOW1 D044 freeze suppressant
Tail slurry:
500' X 0.3132 ft3/ft X 1.5 (5~0% excess) = 234.9 ft3 annular volume
80' X 0.4341 ft3/ft = 34.7 ft° shoe joint volume
Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk
System:
230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator
@ 15.8 PPG yielding 1.17 ft3/sk
7" Intermediate Casing run to 7764' MD / 6981' TVD
Cement from 7764' MD to +/- 7109' MD (minimum 500' MD above top of Alpine formation) with Class G +
adds @ 15.8 PPG. Assume 40% excess annular volume.
Slurry:
(7764' - 7109').,X 0.1268 f[3/ft X 1.4 (40% excess) = 116.3 ft3 annular volume
80' X 0.2148 ft°/ft = 17.2 ft~ shoe joint volume
Total volume = 116.3 + 17.2 = 133.5 ft3 => 117 Sx @ 1.15 ft3/sk
System:
117 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder
and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft3/sk
~ By Weight Of mix Water, all other additives are BWOCement
35O
550
700
1050
1400
1750
2100
2450
2800
5150
$500
3850
4200
I
455O
4900
5250
56OO
595O
6300
6650
7000
7550
1400
I
050
Alaska,
Inc.
Structure : CD#1
Field : Alpine Field
Well : 5
Location : Nodh Slope, Alaska
West Sok
RKB Elevation: 56'
KOP
5.00
6.00
9.00
12.00 DLS: $.00 deg per 100 ft
15.00
18.00
21.00
24.00 EOC #1
[c~.teu ~ i~.e- For: B Robert. son]
Date plotted: 3-Dec-1999 [
Plot Reference Is C01-5 Vemlon jiG. [
Coordinates ore {n feet reference slot ~5. [
True Verb'co, Depth. ore re~ RKB (Ooyon ,19).I
Permafrost
C40
C50 9 5/8 Casing Pt
Begin Angle Drop
24.00
22.50
21.00 DLS: 1.50 deg per 100 ft
19.50
18.00
16.50
15.00
13,50
12.00
10.50 Begin Turn to Tgt
7.00
5.14
4.66 K-$
5.92
8.14
10.75 K-2
15.52 DLS: 3.00 deg per 100 ft
16.36
19.26
22.18
25,12
EOC #2
AVERAGE ANGLE
25 DEC
***THIS SECTION***
AVERAGE ANGLE
26.87 DEG
***THIS SECTION***
151.94 AZIMUTH
3538' (TO TD)
***Plane of Proposal***
Albion-97
TARGET ANGLE
89.69 DEG
i i I
700 350
Albion-g6
CsgPt ~
0 350 700 1050 1400 1750 2100 2450 2800 3150 3500
Vertical Section (feet) ->
Azimuth 151.94 with reference 0,00 N, 0.00 E from slot #3
TD
5850 4200 4550
ICreoted by ~ones For: B Roberlmon[
Dote plotted: $-De¢-1999 I
C~ ore in f~ ~f~en~ slot ~. ]
2100
1800
1500
1200
900
600
300
300
'+- 600
900
1200
1500
1800
2100
24OO
270O
3000
5500
5600
,IC0 Alaska,
Structure : CD#1
Field : Alpine Field
Well: 3
Location : North Slope, Alaska
East (feet) ->
900 600 300 0 300 600 g00 1200 1500 1800 21 O0 2400 2700 3000 3300
I I I I I I I I I I I I I I I I I I I I I I I I I I I I
"~_.,
Angle Drop ~. '~ .,oo ,,~
EOC ~ West Sok
KOP
151.94 Azimuth
3538' (TO TD)
***Plane of Proposal***
TARGET / CASING PT
LOCATION:
168' FNL, 1767' FEL
SEC. 5, T11N. R5E
SURFACE LOCATION:
236' FNL, 2558' FWL
SEC. 5, T11N, RSE
TD LOCATION:
2332' FSL, 295' FEL
SEC. 5, T11N, RSE
TD
i i I I I [ I I i i i i i~ [ i i i i , I i i [ i [ [ [
go0 §00 500 0 300 600 gOO 1200 1500 1800 21 O0 2400 2700 3000 3500
East (feet) ->
2100
1800
1500
1200
9OO
6O0
$00
300
600
900
1200
5600
3300
3000
2700
2400
2100
1800
1500
For; B Roberteon]
Dote plotted: Z-Doc-19gg
Ref ...... I, COf-~ Verelon
C~rdlnaten are in f~t reference
Verticol ~pth8 a~ RKB
ALPC0 Alaska, Inc.
Structure : CD#1
Field : Alpine Field
Well : 5
Location : North Slope, Alaska
Point
KOP
West Sok
FOC
Permafrost
C40
C50
9 5/8 Casing Pt
Begin Angle Drop
C20
Begin Turn to Tgt
K-3
K-2
EOC #2
Albian-97
Albian-96
HRZ
Begin Fnl BId/Trn
K-1
LCU
WEO
Miluveach A
Alpine D
Alpine
Tgt- CsgPt-
TD
EOC
PROFILE
COMMENT
DATA
MD Inc Dir TVD North East V. Sect
300.00 0.00 340.00 300.00 0.00 0.00 0.00
1066.40 22.99 340.00 1046.00 1 42.57 -51.89 - 1 50.22
1153.35 25.00 340.00 1107.14 168.15 -61.20 -177.17
1 628.59 25.00 540.00 1 556.00 564.83 - 152.79 -384.41
2518.21 25.00 340.00 2181.00 638.70 -232.47 -672.98
2555.43 25.00 340.00 2396.00 732.91 -266.76 -772.24
2559.84 25.00 340.00 2400.00 734.66 -267.39 -774.09
2679.84 25.00 340.00 2508.75 782.31 -284.74 -824.30
2964.52 20.73 340.00 2771.00 886.23 -522.56 -933.80
3679.84 10.00 340.00 3459.75 1064.08 -387.29 -1121.19
4033.42 4.92 63.35 5811.00 1099.83 -384.24 -1151.30
4260.19 9.68 104.62 4056.00 1099.58 -557.07 - 11 38.12
4859.53 26.87 123.65 4603.19 1010.90 -194.29 -985.48
6246.94 26.87 123.65 5841.00 663.36 527.72 -431.24
6689.74 26.87 123.65 6236.00 552.45 494.30 -255.02
7087.70 26.87 123.65 6591.00 452.78 644.00 -96.64
7211.47 26.87 123.65 6701.41 421.78 690.57 -47.38
7271.07 53.18 130.42 6753.00 403.72 71 4.22 -20.32
7392.58 46.73 138.92 6846.00 348.52 768.90 54.11
7463.75 54.87 142.27 6890.95 305.89 803.80 1 08.15
7506.45 59.79 143.96 6914.00 277.14 825.35 143.65
7554.20 65.32 145.67 6936.00 242.52 849.75 1 85.68
7565.75 66.42 145.99 6939.91 235.31 854.64 194.55
7608.75 71.65 147.44 6956.00 200.19 877.69 236.18
7763.51 89.69 1 51.94 6981.00 68.85 954.29 388.11
10913.27 89.69 151.94 6998.00 -2710.68 2435.81 3537.83
Deg/ 'p
o. Oo
3.00
3.00
0.00
0.00
0.00
0.00
0.00
1.50
1.50
3.00
3.00
? '~0
0.00
0.00
0.00
12.00
12.00
12.00
12.00
12.00
12.00
12.00
12.00
0.00
ARCO Alaska, Inc.
C~l
3
slot #3
Alpine Field
North Slope, Alaska
SUMMARY
CLEARANCE
by
Baker Hughes INTEQ
REPORT
Your ref : CD1-3 VersionS6
Our ref : prop3747
License :
Date printed : 2-Dec-1999
Date created : 1-Dec-1999
Last revised : 2-Dec-1999
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 34.783,w150 55 31.275
Slot Grid coordinates are N 5975891.018, E 385985.831
Slot local coordinates are 235.15 S 2559.24 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
Object well path
CD1-2 Version#6,,2,CD~l
CD1-6 Version#4,,6,CD~l
CD1-14 Version #3,,14 CD~i
CD1-17 Version #7,,17 CD#1
CD1-18 Version #2,,18 CD#1
CD1-20 Version #3,,20 CD~i
CD1-29 Version#2
CD1-28 VersionS4,
CD1-5 Version#3,
CD1-38/29 Vers #3
CD1-27 VersionS5,
CD1-25 Version#5,
CD1-31 Version#2
CD1-33 Version#4,
CD1-34 Version #4,
,29 CD~i
28 c~1
5,c~1
,38 C~l
27 CD#1
25 C~1
,31 CD#1
33 CD#1
34 CD~i
CD1-41PB1 Version #1,,41PB1,CD~1
CD1-4 Version #5,,4,CD#1
CD1-44 Version#3,,44,CD~l
CD1-43 Version #6,,43,CD~1
CD1-30 Version #4,,30,CD#1
CD1-21 Version #3,,21,CD~1
CD1-9 Version #1,,9,CD#1
?MSS <0-9236'>,,22,CD#1
PGMS <0-10255'>,,WD2,CD~1
PMSS <0-10548'>,,19,CD~1
PMSS <0-10796'>,,24,CD~1
PMSS <0-8168'>,,35,CD~1
Closest approach with 3-D
Last revised Distance
8-Aug-1999
lO-Aug-1999
lO-Aug-1999
lO-Aug-1999
lO-Aug-1999
lO-Aug-1999
11-Aug-1999
lO-Aug-1999
lO-Aug-1999
11-Aug-1999
lO-Aug-1999
31-Aug-1999
11-Aug-1999
11-Aug-1999
11-Aug-1999
26-0ct-1999
8-Aug-1999
12-Aug-1999
11-Aug-1999
11-Aug-1999
lO-Aug-1999
lO-Aug-1999
28-Jun-1999
28-Jun-1999
28-Jun-1999
28-Jun-1999
28-Jun-1999
99
29 8
110 2
140 1
149 7
170 1
259 9
250 1
20 2
-349 7
240 1
220 1
280 1
300 1
310 1
379 8
10 1
410 1
400 4
270 1
180.1
60.1
190.4
765.4
99.6
210.2
320.0
Minimum Distance method
M.D. Diverging from M.D.
200.0 200.0
300.0 300.0
300.0 8600.0
2OO.0 860O.O
344.4 344.4
200.0 200.0
200.0 200.0
200.0 8500.0
300.0 300.0
200.0 10100.0
200.0 10913.3
300.0 10913.3
300.0 300.0
300.0 10700.0
200.0 10700.0
200.0 200.0
300.0 300.0
300.0 300.0
3O0.0 78O0.O
2O0.0 20O.O
200.0 3844.4 ~ e~,,"~l:~ ~J"~.~-J ,.
300.0 300.0--.--L~-
100.0 5720.0~
2220.0 7654.4 ~
188o.o 188o.o~
100.0 9800.0/
100.0 6080.0~
PMSS <0-12055'>,,. ~D~i
PMSS <5946 - 10289'>,,1,CD~1
PMSS <0-7331'>,,1PB1,CD~l
PMSS <0-11300'>,,13,CD~1
PMSS <384 - 14477'>,,23,CD~1
PMSS <562 - 12134'>,,37,CD~1
PMSS <O-10224'>,,39PB1,CD~1
PMSS <9146 - 13289'>,,39,CD~1
PMSS <0-8350'>,,26PB1,CD~1
PMSS <7755-11134'>,,26,CD#1
PMSS <O-9357'>,,16PB1,CD#1
PMSS <8393 - 12600'>,,16,CD~1
PMSS <7950-11950'>,,45,CD~1
PMSS <0-8844'>,,45PB1,CD~l
36 Version #7,,36,CD~1
PMSS <6600 - ???'>,,36,CD~1
PMSS <472 - 1545'>,,36PB1,CD~l
PMSS <763 - 7440'>,,36PBl,CD~l
CD1-32 Version#6,,32,CD~l
PMSS <10016 - 11136'>,,32,CD~1
PMSS <0-11067'>,,32PB1,CD#1
CDi-iO Version #3,,10,CD~1
CD1-42 Version#7,,42,CD~l
28-Jun-1999
27-Jun-1999
18-Jun-1999
15-2u1-1999
18-Aug-1999
26-Aug-1999
16-Sep-1999
22-Sep-1999
4-0ct-1999
1-Nov-1999
25-0ct-1999
25-0ct-1999
16-Nov-1999
30-Nov-1999
29-Nov-1999
1-Dec-1999
24-Nov-1999
29-Nov-1999
22-Nov-1999
23-Nov-1999
19-Nov-1999
lO-Aug-1999
2-Dec-1999
370.1
19.5
19.5
99.8
199.2
340.1
360.1
360.1
230.3
230.3
129.0
129.0
420.0
420.0
2597.0
330.2
330.2
330.2
7500.5
289.8
289.8
70.2
390.1
10,
200.0
200.0
311.1
344.4
0.0
100.0
100.0
100.0
100.0
344.4
344.4
200.0
200.0
6200.0
100.0
100.0
100.0
4688.9
311.1
311.1
200.0
200.0
9000.0
6040.0
6040.0
10900.0
9400.0
10800.0
9000.0
9000.0
10913.3
10913.3
10300.0
10300.0
200.0
200.0
6200.0
100.0
100.0
100.0
4688.9
311.1
311.1
5740.0
200.0
ARCO Alaska, Inc.
Kuparuk Unit Disbursement Account
P.O. Box 102776
Anchorage, AK 99510-2776
PAY
TO THE
ORDER OF:
230099756
73-426
839
0997587
SEPTEMBER 28, 1999
STATE OF ALASKA '
GAS ~.~,..,r'r~'eERVATION COMMI ' : ' :'
ALASKA
OIL
&
, .
3001 PORCUPINEi'DRIV.E
~: .~
':~: ~"~:~ '~ EXACTLY ****** I L~S AND O0 CENTS::¢***********100. O0
The ~irst Nati:ba'at ~:a~k of Chicago-0710
Chicagot::lllin°is
Payable Through Republic Bank
~helbyvilla, Kentucky
TRACE NUMBER: 230099756
,' ;~ 3DOC]c] ? 5F=,' w:OP. :~ c~o h ;3~= ;3.: OC]~ ? 58 ?,'
WELL PERMIT CHECKLIST
FIELD & POOL
ADMINISTRATION
ENGINEERING
DATE
GEOLOGY
APPR DATE _
COMPANY~f~¢--C~
WELL NAME ~_-~,~'/_.~ ~--~)~'-E):~ PROGRAM: exp dev ~" redrll serv ~" wellbore seg ann. disposal para req
INIT CLASS
1. Permit fee attached .......................
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 wellbore 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 3,..%'-r,,.~ .psig.
27. Choke manifold complies w/APl RP-53 (May 84) ........
28. Work will occur without operation shutdown ...........
29. Is presence of U2S gas probable .................
30.
31.
32.
33.
34.
.~N
N
ANNULAR DISPOSAL 35.
APPR DATE
Permit can be issued w/o hydrogen sulfide measures .....
Data presented on potential overpressure zones .......
AREA ~~ UNIT# ~'")~--'C.~ ~'~O ON/OFF SHORE ~,)
)N
N
~N
~N
Seismic analysis of shallow gas zones ............. ,/¢',¢ Y N
Seabed condition survey (if off-shore) ............. ,,~:~ N
Contact name/phone for weekly progress reports [exploratory o'n,~y~_~,. N
With proper cementing records, this plan %~(:::)~\ ~-~q~,'-,~-%&--~--~
(A) will contain waste in a suitable receiving zone; ....... ~ N
(B) will not contaminate freshwater; or cause drilling waste... C~ N ~.¢=~o6s-r ~-pc-o¥cv_-~ ~¢-cu~_.. ~)~¢... oF-¢,,4 ~£ vo~z.., w~z-~- IA.OLC~'7' ),~A,~"/~ ~--o ~/~.
to surface; "i-~5 Lo6~-~- Ir~ro p~o7¢4-c~ t%0¢~o'¢6b p¢~oO~-u.S o~ EJ3/ P~O .
(C) will not impair mechanical integrity of the well used for disposal; ~ N
(D) will not damage producing formation or impair recovery from a (~) N
pool; and
(E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. O N
GE~~,, ENGINEERING: UlC/Annular COMMISSION:
~_~ BEW'"--,, WM ~ IZ[~ DWJ
SE JUN , ~% RNC'
TEIVV..-~_'"'~ ~/'c~ ,-c~% CO ~.o ,~1ol
Comments/Instructions:
c:\msoffice\wordian\diana\checklist (rev. 09~27~99)
