Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout201-104 Imag~"' ~roject Well History' File Cover { ge
XHVZE
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~_O_J _- _J_ O ~'~ Well History File Identifier
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[] Color items: [] Diskettes, No. [] Maps:
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NOTES:
[] Other, No/Type
BY:
BEVERLY ROBIN VINCENT SHERY~WINDY
[] Other items scannable by
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OVERSIZED (Non-Scannable)
[] Logs of various kinds
[] Other
Project Proofing
BY: BEVERLY ROBIN VINCENT SHERYL~ WINDY
--
Scanning Preparation / x 30 = ,~---~4'~
BY:
BEVERLY ROBIN VINCENT SHERYL~WlNDY
Production Scanning
Stage 1 PAGE COUNT FROM SCANNED FILE: .......
PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ,~ YES
BY: BEVERLY(~~INCENT SHERYL MARIA WINDY DATE¢~L'/O"~,'~S/
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RESCANNED BT(; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY
General Notes or Comments about this file:
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Phone:L:'63-46t2
Fax
To'. Mr. Steve Davies From.- Sharon AIIsup-Dmke
Fax.- 9-907-276-7542 Date; Januanj 15, 2002
Phene~ 793-12Z4 ;: Page~; I
R~ 2P pad Iocation~
. CC: .............................
[] urgent [] For Review C] Please Comment I~ Please Reply CI Plmaee Recycle
,Cemme~ts~'
Mr. Davies:
Here is the surface locations for the Meltwater wells as requested. If you have any questions, please
feel free to call me at 263-4612.
Thanks, Sharon
~bl~'l' I~T' 1-10- Z ; U'UUA~I ' UMILL, Ir'~ AI~ lt'qL;~ 'F Z/ z
1'l/8/~q MR] J C:C J J mA~,~ ~'£r~
SURVEYOR'S CER TIFiCA TE
I HEREBY CERTIFY THAT I ,dM PROPERLY REGISTE, R'ED
~ AND LICENSED TO PI:I, dCTICE L,~ND SURVEYING IN THE
1. COORDINATES SHOWN ARE Al ASKA 5~ArE PLANE, STATE OF ALASK,d AND TH,~T THIS PLAT ~EPRESENTS
NAD 27, ZONE 4. A SURVEY DONE BY ME O~ UNDER MY DIRECT
SUPERVISION AND THAT ALL DIMENSIONS AND OTHER
2. MEANALL ELEVAT[ONSsEA LEVEL.$11OWN ARt: BRITISH PETROLI.UM DETAILS ,dRE CO, qRECT AS OF NOVLe'M~ER' I0, 2001.
5. ALL DISTANCFg ARE 1RUF..
4. GEOGRAPHIC COORDINATES SHOWN ARE NAb 2..7, ...4~'.~, !\.,. ............. [~,.,<~t,¢'~ '
5. OR]LL $11E 2P' NORTH IS R('TATED 1."00'1~¢' WEST --F~ -,-~-* '
FROM CRID NON I'H. .. ~ ~ A *~ L,~
6. DA~ OF' %t.JRV[Y. 11/8/~1, FD L~'1-63, Pp. 2D-21. E ~ 49~h ~
/. REFFR[NCE DRAWING CEA-D2PX-6216D4 FOR WELl. ~ ..... ~~--~-~~--~
CONDUCTORS ~15, 41-/, ~2~, 424, 427, 429, 4.34, 438, ~ /~~ *~
~47, & 449. .--~.. ~..,~
Sec. 17, T. BN., R.TE., U.M., AK.
,
we,' ~c. :~ p~p- o.~.
No,. ,y,A.S,P.s 'X' LAT[TUDE LONGITUDE ~.
~ ~s
~__ F.N.L F.W,L,
-
;.
,
~7 s, sss,~7.~'- ~4~,~s.ss z¢' ~' .~.ss2'-- ~s~'"~' ~.es." ~6~
.......
.~2.~_ ~86~,966.26. ~~I~.A~ ~ 7~' ~3" ~9,571" 15~' 26' 0&~22" 9~~ 2~'" 224.~' .216.7'
i "~
~ :
;
427 ' 5,868,~52.7B. 443,~52.~3 7~' ~3' ~9.~34~_ )5~" 2~' 54,7~1" 924' ~..lgg2'
42~ ~'J,~6~,~4~~.8~ 443,91~,~5 7~' ~3' ~9.~" 15~' 26' 55.822" 934~ 19]~r- 224.8'" 21.7,2'
~* ~31..' 5,868,93~.79 443,874, e8 7~' ~' B9.252" 15B' 26' 56.943"'-- 94--5' 1914' 224. B' '217.6~
534_ 5,8~8,921.42 443,815.~2 7~' e3' eg, l16". 158' 26' 58,6~__ 95~ 185~..224. e' 218.2'
.....
....
,~~ , .......
438 5,868,9e5,23 445,737.66 7g" BS' ~8,931" 15g' 27' ee. B66* 975' 1778' 224. g' 218.5'
i~' ' : ' ,~,,~.,
,
.......
447 5,868,e62.91 j 443,562,57 7e- e3' e8,522". 15e' 27' es, geT" le17'. 16e5' ~219,5'
'., 4~ 5,asa. as~.45]~43'542'95 7e' ~5' ea.477" 1~' 27' e~,~66" ~
~~ess,e53.67 44~~2~,2~ ,, ze' eS' ee.42a" -1'5e'~7-~'' eT.e~l" !e26'J
** INDICATES CONDUCTORS AS-BUILT ~IS SURLY, ' .......... ......
,.
.... AREA: 2P M~U~: X~X
PHILLIPS 'ask., Inc.,
~ A Subsidior. y of PI IILL]P5 PFTROLEUU 60UFANY ~ C~DUCTOR
'A~UILT LOCA~S
~621~d2~ l~/~/el CEA-D2PX-6216D25 .~. ~ ~ i
. I , II I _
Individual Well Report
Date 1/15/2002
Start Time [8:10:01 AM
End Time [8:14:31 AM
Category Completion Report
Description
Phone Sharon AIIsup-Drake of Phillips about apparent discrepancy in surface location for
KRU 2P-417 well between surface location recorded on the permit to drill application and
the location reported on the Completion Report..
Notes
Sharon: Their surveyors, Lounsbury, noticed a "shift" in the Isurface locations of the wells
on the KRU 2P-Pad. She will fax me the revised locations and will find out the cause of this
"shift" in locations from Lounsbury.
9:10AM: received fax containing well locations from Sharon.
Follow-Up Tasks
Phone Sharon AIIsup-Drake. Find out what caused the "shift" in the surface locations for
the KRU 2P-Pad.
Primary File Path
Primary File Name
Secondary File Path
Secondary File Name
Tuesday, JanUary 15, 2002
Page I of 1
AI,ASKA 01L AND GAS
CONSERVA~ION COMMISSION
TONY KNOWLES, GOVERNOR
333 W. 7TM AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
James Trantham
Drilling Engineering Supervisor
Phillips Alaska, Inc.
PO Box 100360
Anchorage AK 99510
Re:
Kuprauk River Unit 2P-447
Phillips Alaska, Inc.
Permit No: 201-104
Sur Loc: 1017' FNL, 1606' FWL, SEC. 17, T8N, R7N, UM
Btmhole Loc. 1513' FSL, 1191, FWL, SEC. 18, T8N, R7E, UM
Dear Mr. Trantham:
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 by law from
other governmental agencies, and does not authorize conducting drilling operations 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 surface casing confirmed by a
valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be
submitted to the Commission for approval on form 10-403 prior to the start of disposal
operations.
Please note that any disposal of fluids generated from this drilling operation which are pumped
down the surface/production casing annulus of a well approved for annular disposal on Kuprauk
River Unit 2P Pad must comply with the requirements and limitations of 20 AAC 25.080.
Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater
than 35,000 barrels through the annular space of a single well or to use that well for disposal
purposes for a Period longer than one year.
Permit No: 201-104
Page 2 of 2
Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035.
Sufficient notice (approximately 24 hours) must be given to allow a representative of the
Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given
by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607.
Sincerely,
Julie M. Heusser
Commissioner
BY ORDER OF THE COMMISSION
DATED this ~ r~ day of June, 2001
jjc/Enclosures
CC'
Department ofFish & Game, Habitat Section w/o encl.
Department of Environmental ConserVation w/o encl.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILl.
20 AAC 25.005
la. Type of work: Drill ~ Redrill La I lb. Type of well. Exploratory [_J StratigraphicTest [~ Development Oil
Re-entry r"] Deepen [~I Service E] Development Gas [~ Single Zone E~/,~ Multiple Zone
2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool
Phillips Alaska, Inc. RKB = 102 feet AMSL Kuparuk River Field
3. Address 6. Property~Designation ~,~ '7'~.~//z~./~ Meltwater Oil Pool
P.O.
Box 100360 Anchorage, AK 99510-0360 ADL 3,.JLgeS'8 ALK 4998
4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25.0251)
1017' FNL, 1606' FWL, Sec. 17, T8N, R7E, UM Kuparuk River Unit Statewide
At top of productive interval 8. Well number Number
1661' FSL, 1478' FWL, Sec. 18, T8N, R7E, UM 2P-447 #59-52-180
At total depth 9. Approximate spud date Amount
1513' FSL, 1191' FWL, Sec. 18, T8N, R7E, UM June 12, 2001 $200,000
12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'rVD)
1191' @ TD feetI 2P-438 179' @ 313' feet 2560 8355' MD / 5325' TVD
16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2))
Kickoff depth: 300 MD Maximum hole angle 57.1 Maximum surface 1791 psig At total depth (TVD) 2353 psig
18. Casing program Settln~l Depth
size Specifications Top Bottom Quantity of Cement
Hole Casing Weight Grade couplin~l Length MD TVD MD TVD (include stac, le data)
42" 16" 62.5# H-40 Weld 90' 30' 30' 120' 120' 9 cu yds High Early
9.875" 7.625" 29.7# L-80 BTCM 3036' 30' 30' 3066' 2454' 240 sx AS Lite & 210 sx LiteCRETE
6.75" 5.5"x 15.5# L-80 BTCM 7712' 30' 30' 7742' 4992' 230 sx Class G
6.75" 3.5" 9.3# L-80 IBT 63' 7742' 4992' 8355' 5325' see above
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total Depth: measured feet Plugs (measured)
tree vertical feet
Effective Depth: measured feet Junk (measured)
tree vertical feet
Casing Length Size Cemented Measured depth True Vertical depth
Conductor
Surface
0
Pedoration depth: measured r,:/i,,~ ¥ ~:i:~ f'''~
......
tree vertical
20. Attachments Filing fee ~] Property Plat F'] BOP Sketch r-] Dive,er Sketch ~ Drilling program r~
Drilling fluid program r~ Time vs depth plot r'lRefraction analysis D Seabed report r"l 20 AAC 25.050 requirements r~]
21. i hereby (~rtihj that the. foregoing..._..____is true and correct to the best of my knowledg~ Ouestions?CallPatReill~.265-60/i
Signed~,.~ Jal~~ I .~C~ ¢"~.(_ c't.~ Title: DrillingEngineeringSupervi$or Date
Pre~areW bv Sharon AIIsu~)-Drak~
Commission Use Onl)
Number ~IAP'number .ZO C~C~ I Appr°va'date~/~"k/Isee°°ver'etter
Permit.~._.~/--/~') 50- /~-"~"- .~"7~- Ifor other requirements
Conditions of approval / Samples required [~ Yes [~ No Mud log required I ['~ Yes ~ No
Hydrogen sulfidemeasures [--] Yes r'~ No Directional surveyrequired ~ Yes E] No
.equ redwo i.gpressurefor OPE 1--12 r-I 5M: I--! 0M:I--I I--I
Other:
Approved b.¥ Commissioner the commission Date ,
Form 10-401 Rev. 12/1/85 ·
j U j L ubmit in r,p,ioate
Ap~," ,tion for Permit to Drill, Well 2P-447
Saved: 30-May-01
Permit It - Meltwater 2P- 447
App//cat/on for Perm/t to Dr///Document
MaxWell
MOxicniz;
'~ell
Table of Contents
lm
m
Well Name ..,,..?............ 3
............................................................................. ~;,~, ................
Requirements of 20 AAC 25.005 (f) ..............................................................
Location Summary ................................................................................................... 3
Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 3
Requirements of 20 AAC 25.050(b) ........................................................................................................ 3
3. Blowout Prevention Equipment Information ......................................................... 4
Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 4
4. Drilling Hazards Information ................................................................................... 4
Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 4
5. Procedure for Conducting Formation Integrity Tests ........................................... 4
Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4
6. Casing and Cementing Program ............................................................................. 4
Requirements of 20 AA C 25. 005(c) (6) ................................................................................................... 4
7. Diverter System Information ................................................................................... 5
Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 5
8. Drilling Fluid Program ............................................................................................. 5
Requirements of 20 AAC 25. 005(c)(8) ................................................................................................... 5
9. Abnormally Pressured Formation Information ...................................................... 6
Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 6
10. Seismic Analysis ...................................................................................................... 6
Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 6
11. Seabed Condition Analysis ..................................................................................... 6
Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6
12. Evidence of Bonding ................................................................................................ 6
Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6
2P-447 PERMIT IT 5-22-01.doc
Page 1 of 7
ORiGiNAl
Ap,~" ' ~tion for Permit to Drill, Well 2P-447
Saved: 30-May-01
13. Proposed Drilling Program ...................................................................................... 6
Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6
14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 7
Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7
15. Attachments ............................................................................................................. 7
Attachment I AOGCC Form 10-401 (Front of permit package) ............................................................ 7
Attachment 2 Directional Plan ................................................................................................................ 7
Attachment 3 Drilling Hazards Summary ............................................................................................... 7
Attachment 4 Well Schematic ................................................................................................................ 7
Attachment 5 Cement Details ................................................................................................................ 7
2P-447 PERMIT IT 5-22-01.doc
~,, ! Page 2 of 7
(,1 J'i A
Ap~'" -~tion for Permit to Drill, Well 2P-447
Saved: 30-May-O1
.
m
Well Name
Requirements of 20 AAC 25.005 (f)
Each ~ve// must be identified by a unique name designated by the operator and a unique API number assigned by the commission
under 20 AAC 25.0dO(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API
number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the
cornrni~'ion.
The well for which this Application is submiL-ted will be designated as 2P-447.
Location Summary
Requirements of 20 AAC 25.005(c)(2)
An application for a Permit to Dr///must be accompanied by each of the fo/lowing item.% except for an item a/ready on file with the
con7mis~ion and identified in the application:
(2) a p/at identifyir[q the prope~y and ~he proper~Y owners and showing
(A)the coordinates of the proposed location of the wee at the sud~ce, at the top of each objective fbrmat/on, and at total depth,
ref~re/7c~,d to governmental se~ion Iines~
(B) t/Te coordinates of the proposed/oc~tion of the wee at the sud~ce, ref~,renced to the state plane coordinate system fbr this
state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration;
(C) the proposed depth of the well at E~e top of e~ch objective tDrmat/on and at total depth7
Location at Surface J
NG$ Coordinates
North/ngs: 5868862.8 East/ngs: 443562
1017' FNL~
1606' FWL~ Sec 17~ T8N~ R7E, UM
RKB E/evat/on: 254.0 ft AMSL
Pad E/evat/on: 224.0 ft AMSL
Location at Top of
Productive ~[nterval
(Bermuda Formation)
1661' FSL, 1478' FWL, Sec 18, T8N, R7E, UM
NGS Coordinates
Northings: 5866349.74
East/ngs: 438704
Measured Depth (RKB feet):
True Vertical Depth ($$ feet):
True Vertical Depth (RKB feet):
7841 '
4792'
5046'
Location at Total Depth I
NGS Coordinates
North/ngs: 5866155 East/ngs: 438319
1513' FSL, 1191' FWL, Sec 18, T8N, R7E, UM
J Measured Depth (RKB feet): 8355'
True Vertical Depth (SS feet): 5070'
True Vertical Depth (RKB feet): 5324'
and
(D) other information required by 20 AAC 25~ 05'0(b)7
Requirements of 20 AAC 25. 050(b)
Ifa well is ~o be intentionally deviatec~ E)e application for a Permit to Drill (Form 10-401) must
(1) include a p/at; drawn ~o a suitable sca/e, showing ~he path of E~e proposed we//bore,/ndudirtq ail adjacent we//bores witl)ifl 20(}
feet of any po/%1on of the proposed welt
Please see A~achment 2: Directional Plan
and
(2) for all wells within 200 f~.~et of the proposed we//bore
(A) list the names of the opera, tots of those we/L% to E~e extent that those names are known of discoverable in pubt/c r~rd~
and show that each named operator t~as been ~mi. zhed a copy of the application by certified mai//or
(B) stat~ tt~at the applicant is the only affected owner.
The Applicant is the only affected owner.
2P-447 PERMIT IT 5-22-01.doc
O R t G I NAt
AT' ~tion for Permit to Drill, Well 2P-447
Saved: 30-May-01
.
w
.
m
Blowout Prevention Equipment Information
Requirements of 20 AAC 25. 005(c)(3)
An application for a Permit to DH// must be accompanied by each of the fo#owing items, except for an iten7 a/ready on file ~vith the
commission and identified in the application:
(3) a di~qran7 and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25. 035, 20 AAC 25, 036, or 20
AAC 25. 037, as applicable;
Please refer to Doyon Rig 141 BOP Schematic currently on file with the Commission.
Drilling Hazards Information
Requirements of 20 AAC 25.005 (c)(4)
An application for a Permit to Di#I must be accompanied by eacl~ of the fo/lowing items, except for an item a/ready on file w/th the
con?miss/on and identified in the application:
(4) intbrmation on drilling hazards, including
(A) the maX#hUm downhole pressure that may be encountered, cr/~'eria used to determine it, and maximurr~ potent/a/surface
pressure based on a methane gradient;'
The expected reservoir pressures in the Bermuda sands in the 2P pad area vary from 0.44 to 0.46 psi/ft,
or 8.5 to 8.9 ppg EMW (equivalent mud weight). These are pressures obtained from drilling and testing
operations on the nearby exploration wells, Meltwater North #1 and IVleltwater North #2/2A.
The maximum potential surface pressure (HPSP) based on the the above maximum pressure gradient, a
methane gradient (0.11) and the vertical depth of the expected base of the Bermuda formation is:
MPSP =(5186 ft)(0.46- 0.11 psi/ft)
=1815 psi
Assuming a leak off of 15.9 ppg (0.$3 psi/ft) based on open hole LOT results from offset Meltwater
exploration wells, formation breakdown at the surface casing shoe (2454' TVD) can be expected to
occur at 2037 psi. Therefore, the MPSP may be based on the maximum pressure gradient as calculated
above.
(B) data on potential gas zones;
No potential gas zones have been identified along the planned well path.
and
(C) dat'~ c¥)nceming potential causes of hole problems s'uc?~ as' abnom~ally geo-pres~z~red strata, lost circulation zone.~; and z~x~es'
that have a propensfty for diffbrential sticking;
Please see Attachment 3: Drilling Hazards Summary.
Procedure for Conducting Formation Integrity Tests
Requirements of 20 AAC 25.005 (c)(5)
An application for a Permit t'o Dr#1 must be accompanied by each of the fo/iow#Lq item.s; except fix'an i~em a/ready on file with the
commL~-ion and identified in the application:
(52 a des~:Tiption of the procedure for ct~nduc~ing fo/znation 2~tegri~y tests; as required under 20 AAC 25~030(0;
A formation integrity test will be performed after drilling out below surface in accordance with the Phillips
Alaska LOT / FIT procedure, currently on file with the Commission.
Casing and Cementing Program
Requirements of 20 AAC 25. 005(c)(6)
An application for a Pea'mit to Di#/ must be accompanied by ead~ of' the fo/lowing item.s except/bt an item a/ready on file with the
commLcsion and identified in the application:
(b~ a complete proposed casing and cementi/tg pfogr~/n as re~ired by 20 AAC 25:0.?0, and a de.~cription of any slotted line5 pre..
perforated line5 or screen to be installed;
2P-447 PERMIT IT 5-22-01.doc
Page 4 of 7
ORIGINAL Printed:SO-May-01
Apse" at/on for Permit to Drill, Well 2P-447
Saved: 30-May-01
Casing and Cementing Program
Hole Top Btm
Csg/Tbg Size Weight Length MD/TVD MD/TVD
OD (in) (in) (lb/fi) Grade Connection (ft) (fi) (fi) Cement Program
30 x 16 42 62.5 H-40 Welded 80 30 / 30 110 / 110 9 cy High
Insulated Early
7-5/8 9-7/8 29.7 L-80 BTC, AB 3036 30 / 30 3066 / 2454 240 sx 10.7
Modified ppg AS3 Lead,
210 sx 12.0
ppg LiteCrete
Tail
Planned Top of
Cement:
Surface
5 1/2 6-3/4 15.5 L-80 BTC, AB 7711 30 / 30 7741 / 4991 230 sx 15.8
Modified ppg Class 'G'
3-1/2 6-3/4 9.3 L-80 EUE, 8rd 614 7741 / 4991 8355 / 5324 Planned Top of
Mod Cement:
7242' MD
1
Diverter System Information
Requirements of 20 AAC 25. 005(c)(7)
An application for a Permit to Dr/II must be acct'~mpanied by each of the/b/lowing items; except for an item m/ready on file with the
c~mmi~on and identified b~ the application:
(7) a di~Fram and desc~ipgion of fl~e dive~er sysTem as required by 20 AAC 2%A?~; unfes~ this requirement/3' waived by the
comm/~sfon under 2~
Please refer Doyon Rig 141 Diverter Schematic currently on file with the Commission.
al
Drilling Fluid Program
Requirements of 20 AAC 25. 005(c)(8)
An al~plication for a Permit to Dr///must be accompanied by each of the ?o/Iow/f Lq/tem.$ except ?or an item a/ready on file with the
comm/.cs'ion and identified in the apl.~/icat/on:
(8) a ¢illi~ flu/d program, inc/uding a diagram and description of the C¢//irLq flu/d s'ystem, as requ//'ed by 20AAC25:033;
Water based drilling fluid systems will be utilized to drill this well from spud to TD. These systems will be
built and maintained to the following specifications:
Spud to g-5/8" Dr/Il Out to Top Bermuda
Surface Casing Top Bermuda To Well TD
Initial Value Final Value Initial Value Final Value Initial Value Final Value
Density (ppg) 9.6 9.8 9.4 9.8 9.8 9.8
Funnel Viscosity 80 100 50 65 50 65
(seconds)
Yield Point 35 45 10 25 20 30
(cP)
Plastic Viscostiy 13 21 6 14 6 14
(IbnO0 sf)
10 second Gel 10 15 2 6 4 7
Strength (lb~lO0 sf)
10 minute Gel 15 40 4 8 4 8
Strength (lb~lO0 sf)
pH 9.5-10 9.5-10 9.0-9.5 9.0-9.5 7.5-8.5 7.5-8.5
APl Filtrate(cc) <15 <15 <6 <6 8-10 8-10
2P-447 PERMIT IT 5-22-01.doc
ORIGINAL
t A~~ at/on for Permit to Drill, Well 2P-447
Saved: 30-May-01
1
10.
11.
12.
13.
Please refer to Doyon Rig 141 Fluid System Components currently on file with the Commission.
Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005 (c)(9)
An appl/~ation for a Permit to Dr///must be accompanied by each of tile follo~ving items, except for an item a/ready 0/7 file w/th the
commission and identified in the application:
(9) for an exploratory or stratigraphic test we/I, a tabu/at/on setting out the depths of predicted abnorn?ally geo-pressured strata as
required by 20 A.4C 25~033(0;
Not applicable: Application is not for an exploratory of stratigraphic test well.
Seismic Analysis
Requirements of 20 AAC 25.005 (c)(10)
An application for a Permit to DH// must be accompanied by e~.~d~ of' the fo/lowing items, except fbr an item a/ready on file w/th the
con~mL~sion and identified in tile application:
(1 O) for' an explorator? or s/rat/graphic test well~ a seLs'mic refi'~ction or reflection analysis as required by 20 AAC 2.5: 061(a);
Not applicable: Application is not for an exploratory of stratigraphic test well.
Seabed Condition Analysis
Requirements of 20 AAC 25.005 (c)(11)
An application for a Pern'Ht to D/ill must be ac'companied by each of' the fbi/owing items; e. xcept fbr an item a/ready on hie w/th the
commission and identified in the application:
(11) tbra well ddlled f~'om an off:~hore plat?orm~ mobile bottom..fbunded structure, .jack..up rig, or floating drilling vessel, an analysis
of seabed conditions as required by 20 AAC 25.061(b)7
Not applicable: Application is not for an offshore well.
Evidence of Bonding
Requirements of 20 AAC 25.005 (c)(12)
An application for a Permit t'o Dr///must be accon'~panied by each of the lb/lowing items; except for afl item a/ready on file wit/'/the
commission and identified/fl tile application:
(12) evidence showing that the requirements of'20 AAC 25.025/'Bonding}have been met;
Evidence of bonding for Phillips Alaska, Tnc. is on file with the Commission.
Proposed Drilling Program
Requirements of 20 AAC 25. 005 (c)(13)
An applicatk)n for a Permit to D/lit must be accompanied by each of the followizLq it~,m.~5 except ?or an item a/ready on file with the
commissiof7 and identified in the appli~.~tion:
The proposed drilling program is listed below. Please refer as well to Attachment 4: Well
Schematic:
1. Excavate cellar, install cellar box, set and cement 16" x 30" insulated conductor to +/- 110' RKB.
Weld landing ring on conductor.
2. Move in / rig up Doyon 141. Install diverter & function test same.
3. Spud and directionally drill .~" hole to~)-5/8" surface casing point (+/- 3,066 MD') according to
directional plan. Run MWD / LWD logging tools in drill string for directional monitoring and formation
data gathering.
4. Run and cement~-5/8" zJJ::M~ L-80 BTCM casing to surface using ArcticSet 3 lead slurry and
LiteCrete tail to assure cement returns to the surface. Adequate tail cement will be pumped to
ensure cement reaches the surface. Displace cement with mud.
5. Nipple down diverter and install wellhead. Nipple up BOPE and test to 5000 psi. Record results.
6. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes. Record results.
2P-447 PERMIT IT 5-22-01.doc
Page 6 of 7
ORiGiNA£
'i"' A~'r' ation for Permit to Drill, Well 2P-447
Saved: 30-May-01
7. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not
to exceed 16.0 ppg~MW.
~'~,~., . .
8. Directionally drill 8,~2 ho~e to well total depth (+/- 835.5' I~ID) according to directional plan. Run
MWD / LWD logging tools in drill string for directional monitoring and formation data gathering.
Circulate and condition hole. POOH.
9. Run open hole e-line or drill ~)ipe conveyed logs as needed.
10. Run " ~-% -~- ~"'~
and cement 7 26.0# L-80 BTCM x ~-1/2 ~2,,r6# L-80 BTCM tapered production casing string with
Baker casing seal receptacle crossover (CSR). Place CSR +/- 100' above the planned top perforation.
11. Run and land ~-1/2" tubing. Displace well to completion brine.
12. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV.
Install test plug. Pressure test production tree. Pull test plug. Secure well.
13. Freeze protect well. Set BPV. Release rig and turn well over to production.
14. Clean location and RDMO in preparation for coiled tubing cleanout and perforating.
Cement bond log will be run prior to perforating.
14,
15.
Discussion of Mud and Cuttings Disposal and Annular Disposal
Requirements of 20 AAC 25. 005 (c)(14)
,4n app/ication for a Pem#t' ('o Dr#1 mustc be accompanied by each o? the fo#owing item,.~; except' for an i[[~f17 a/ready on/)Ye with the
commi_~sion and identified in the applicatio/):
(Z 4) a genera/de,s'criptior~ of how the operator p/an.s' t'o dispose of drilling mud and cut~ifLqs and a ,~tat'en?er~t of whether the
operator intends to request authorization under 20 AAC 25; 080 for an anz'~ular disposal operation in the well.;
Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 2P
pad or hauled to a Class TI disposal well. All cuttings to be disposed of will be either disposed of down
the annulus or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for
disposal down an approved disposal well.
At the end of drilling operations, a request will be submitted for this well to be permitted for annular
pumping of fluids occurring as a result of future drilling operations on 2P pad.
Attachments
Attachment I AOGCC Form 10-401 (Front of permit package)
Attachment 2 Directional Plan
Attachment 3 Drilling Hazards Summary
Attachment 4 Well Schematic
Attachment 5 Cement Details
2P-447 PERMIT IT 5-22-01.doc
Page 7 of 7
ORIGINAL
Printed:30-May-01
0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0
I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O:
~ o c,,] ¼ ¼ ¼ o d c5 o o d o o o o
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ORIGtiVAL
~,~o~o~ ~ ~.oo, For: P Reilly
Do~e ¢ottea: 29-Uoy-2001
Plot Reference
Coor~n~t~ or~ ~n fcct r=f~rcnc~ slot ~447,
Veal;col Depths ere reterence RKB (~yon 1~1).
Phillips Alaska, Inc.
Structure : Drill Site 2P Well : 447
Field : Meifwofer Locofion : North Slope, Alosko
400
800
1200
"~ 1600
2000
-I--
¢'h 2400
2800
3200,
3600
4000
4400
48OO
5200
5600
RKB Elevation: 254'
KOP
2.00
4.00
6.00
8.00
DLS: 2.00 deg per 100 ft
Begin BId/Trn
12.8,5
1,5.76
18.70 DLS: 3.00 deg per 100 ft
21.65
24.62
27.59
,50.57 Bose Permafrost
33.55
39.5~
45.49 Bose West Sok
51.47
EOC
7 5/8 Casing Pt
C80
242.22 AZIMUTH
5578' (TO TARGET)
***Plane of Proposal***
C50
TANGENT ANGLE
57.13 DEG
C40
C37
0 400 800 1200
Casing crossover
T3 (Top Bermuda)
Target-T~, MidBermuda , ~
T2 (Base Bermuda)
C3 %~o_p A~lbign)
L, oslng
i i i ~ i i i ~ i i i i i i i i i i i i i i i i
1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000
Verticol Section (feet) ->
Azimuth 242.22 with reference 0.00 N, 0.00 E from slot #447
Soufh (fee'i') ->
c~ I I I I I I ~ I [ I I I I I I I I I I I I I [ I I I I ~
ORIGINAL
c~o~ ~)~ ~;~, For: P Reilly
Dine plottc~: 29-~oy-2001
,Tr~e reft;col Dep~h~ ore reference RKB (D~on 14~).:
tN I'EQ
...........................................................
,Phillips Alaska, Inc.
::
Structure : Drill Site 2P Well : 447
Field : Meltwater Location : North Slope, Alaska
510
300
320
330
34O
* 1900
TRUE NORTH
350 0 10
210
2O
5O
1300
1100
900 ... , '
·
30
290
7 o
280
270
700
+
8O
9O
260
250
100
2100
110
240
120
230
220
210
200 160
190 1 80 1 70
,, 140
',
150 '
,,
.~, 1900
.,
.,
Normal Plane Travelling Cylinder - Feet ¢,~
All depths shown are Measured depths on Reference Well
130
ORIGINAL
oo
.4--.
I
,...o
oD
u~
i I I i
South (feet) ->
§ 8 o° 8
' 8
8
., oo
8
0 ~
0 \
\
0 \
\
\
8
o
I I I I
° ~ *
~o
%
cN
~q
cq
~r~
0
i I I I i
8 o° o°
(.I. eej.) Ul.l. nos ->
8
8 v
ORI Ci i NAL
i
South (feet)
0
0
\
\
\
\
\
\(N
0
\
\
\
\
\
\\ 0
\
\
\
\
,
o
o
-o
o
6-4
i i i i
o
(~e@t) q,nog ->
ORIGINAL
(D o
(.I. eeJ.) Lt+nos ->
fl)
o 6)
~ v
ORIGINAL
Phillips Alaska, Inc.
Drill Site 2P
447
slot #447
Meltwater
North Slope, Alaska
PROPOSAL LISTING
by
Baker ~{ughes INTEQ
Your ref : 2P-447 Version#3
Our ref : prop4476
License :
Date printed : 29-May-2001
Date created : 22-Feb-2001
Last revised : 25-May-2001
Field is centred on 441964.235,5869891.466,999.00000,N
Structure is centred on 441964.235,5869891.466,999.00000,N
Slot location is nT0 3 8.521,w150 27 5.911
Slot Grid coordinates are N 5868862.800, E 443562.270
Slot local coordinates are 1016.56 S 1605.98 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
ORIGINAL
Phillips Alaska, Inc.
Drill Site 2P,447
Meltwater,North Slope, Alaska
Measured Inclin. Azimuth True Vert R E C T A N G U L A R
Depth Degrees Degrees Depth C 0 0 R D I N A T E S
0.00 0.00 0.00 0.00 0.00N 0.00E
100.00 0.00 225.00 100.00 0.00N 0.00E
200.00 0.00 225.00 200.00 0.00N 0.00E
300.00 0.00 225.00 300.00 0.00N 0.00E
400.00 2.00 225.00 399.98 1.23S 1.23W
500.00 4.00 225.00 499.84 4.93 S 4.93 W
600.00 6.00 225.00 599.45 11.10S 11.10W
700.00 8.00 225.00 698.70 19.71S 19.71W
800.00 10.00 225.00 797.47 30.78S 30.78W
900.00 12.85 229.69 895.48 44.11S 45.40W
1000.00 15.76 232.69 992.36 59.55 S 64.69 W
1100.00 18.70 234.77 1087.87 77.03 S 88.59 W
1200.00 21.65 236.30 1181.72 96.52 S 117.04W
1300.00 24.62 237.47 1273.67 117.97S 149.96W
1400.00 27.59 238.41 1363.46 141.30S 187.25W
1500.00 30.57 239.18 1450.85 166.46S 228.82W
1503.67 30.67 239.21 1454.00 167.42S 230.43W
1600.00 33.55 239.82 1535.59 193.38S 274.55W
1700.00 36.53 240.37 1617.46 221.99S 324.32W
1800.00 39.51 240.85 1696.23 252.20S 377.99W
1900.00 42.50 241.27 1771.68 283.94S 435.41W
2000.00 45.49 241.65 1843.61 317.12S 496.43W
2014.88 45.94 241.70 1854.00 322.17S 505.81W
2100.00 48.48 241.99 1911.82 351.64S 560.88W
2200.00 51.47 242.30 1976.12 387.41S 628.57W
2300.00 54.46 242.58 2036.34 424.34S 699.34 W
2389.08 57.13 242.82 2086.42 458.13S 764.80 W
2500.00 57.13 242.82 2146.62 500.68S 847.67 W
3000.00 57.13 242.82 2418.00 692.52S 1221.23W
3066.32 57.13 242.82 2454.00 717.97S 1270.78W
3176.87 57.13 242.82 2514.00 760.38 S 1353.38W
3500.00 57.13 242.82 2689.38 884.36 S 1594.80W
4000.00 57.13 242.82 2960.77 1076.20S 1968.36W
4098.08 57.13 242.82 3014.00 1113.83S 2041.64W
4500.00 57.13 242.82 3232.15 1268.04S 2341.92W
4761.35 57.13 .242.82 3374.00 1368.32S 2537.18W
5000.00 57.13 242.82 3503.53 1459.88S 2715.49W
5111.41 57.13 242.82 3564.00 1502.63S 2798.72W
5500.00 57.13 242.82 3774.91 1651.72S 3089.05W
6000.00 57.13 242.82 4046.30 1843.56S 3462.61W
6500.00 57.13 242.82 4317.68 2035.40S 3836.17W
7000.00 57.13 242.82 4589.06 2227.24S 4209.74W
7500.00 57.13 242.82 4860.44 2419.08S 4583.30W
7741.87 57.13 242.82 4991.72 2511.88S 4764.01W
7841.87 57.13 242.82 5046.00 2550.25S 4838.72W
7970.82 57.13 242.82 5115.99 2599.72S 4935.06W
7970.84 57.13 242.82 5116.00 2599.73S 4935.08W
8000.00 57.13 242.82 5131.83 2610.92S 4956.86W
8099.81 57.13 242.82 5186.00 2649.21S 5031.43W
8155.08 57.13 242.82 5216.00 2670.42S 5072.73W
PROPOSAL LISTING Page
Your ref : 2P-447 Version#3
Last revised : 25-May-2001
Dogleg Vert
Deg/100ft Sect
0.00 0.00
0.00 0.00
0.00 0.00
0.00 0.00 K0P
2.00 1.67
2.00 6.67
2.00 14.99
2.00 26.63
2.00 41.57 Begin Bld/Trn
3.00 60.73
3.00 84.99
3.00 114.29
3.00 148.54
3.00 187.65
3.00 231.53
3.00 280.03
3.00 281.90 Base Permafrost
3.00 333.04
3.00 390.41
3.00 451.97
3.00 517.57
3.00 587.02
3.00 597.67 Base West Sak
3.00 660.12
3.00 736.69
3.00 816.51
3.00 890.18E0C
0.00 983.33
0.00 1403.25
0.00 1458.95 7 5/8" Casing Pt
0.00 1551.79C80
0.00 1823.17
0.00 2243.09
0.00 2325.46 C50
0.00 2663.01
0.00 2882.50C40
0.00 3082.93
0.00 3176.49C37
0.00 3502.85
0.00 3922.77
0.00 4342.69
0.00 4762.60
0.00 5182.52
0.00 5385.66 Casing crossover
0.00 5469.64 T3 (Top Bermuda)
0.00 5577.94 Target-T3 MidBermuda
0.00 5577.96 MW(A) Rvsd 24 May 01
0.00 5602.44
0.00 5686.27 T2 (Base Bermuda)
0.00 5732.69 C35(Top Albian)
Ail data is in feet unless otherwise stated.
Coordinates from slot #447 and TVD from RKB (Doyon 141) (254.00 Ft above mean sea level).
Bottom hole distance is 5900.66 on azimuth 242.25 degrees from wellhead.
Total Dogleg for wellpath is 57.67 degrees.
Vertical section is from wellhead on azimuth 242.22 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
ORIGINAL
Phillips Alaska, Inc.
Drill Site 2P,447
Meltwater,North Slope, Alaska
Measured Inclin. Azimuth True Vert R E C T A N G U L A R
Depth Degrees Degrees Depth C 00 R D I N A T E S
8355.08 57.13 242.82 5324.55 2747.15 S 5222.15 W
PROPOSAL LISTING Page 2
Your ref : 2P-447 Version#3
Last revised : 25-May-2001
Dogleg Vert
Deg/100ft Sect
0.00 5900.65 TD - Casing Pt
Ail data is in feet unless otherwise stated.
Coordinates from slot #447 and TVD from RKB (Doyon 141) (254.00 Ft above mean sea level).
Bottom hole distance is 5900.66 on azimuth 242.25 degrees from wellhead.
Total Dogleg for wellpath is 57.67 degrees.
Vertical section is from wellhead on azimuth 242.22 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
ORIGINAL
Phillips Alaska, Inc.
Drill Site 2P,447
Meltwater,North Slope, Alaska
MD TVD Rectangular Coords.
PROPOSAL LISTING Page 3
Your ref : 2P-447 Version#3
Last revised : 25-May-2001
Comments in wellpath
Comment
300.00 300.00 0
800.00 797.47 30
1503.67 1454.00 167
2014.88 1854.00 322
2389.08 2086.42 458
3066.32 2454.00 717
3176.87 2514.00 760
4098.08 3014.00 1113
4761.35 3374.00 1368
5111.41 3564.00 1502
7741.87 4991.72 2511
7841.87 5046.00 2550
7970.82 5115.99 2599
7970.84 5116.00 2599
8099.81 5186.00 2649
8155.08 5216.00 2670
8355.08 5324.55 2747
.00 N
.78 S
.42 S
.17 S
.13 S
.97 S
.38 S
83 S
32 S
63 S
88 S
25 S
72 S
73 S
21 S
42 S
15 S
0.00 E
30.78 W
230.43 W
505.81 W
764.80 W
1270.78 W
1353.38 W
2041.64 W
2537.18 W
2798.72 W
4764 01 W
4838 72 W
4935 06 W
4935 08 W
5031 43 W
5072 73 W
5222 15 W
KOP
Begin Bld/Trn
Base Permafrost
Base West Sak
EOC
7 5/8" Casing Pt
C80
C50
C40
C37
Casing crossover
T3 (Top Bermuda)
Target-T3 MidBermuda
MW(A) Rvsd 24 May 01
T2 (Base Bermuda)
C35(Top Albian)
TD - Casing Pt
Casing positions in string 'A'
==============================
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing
0.00 0.00 0.00N 0.00E 3066.32 2454.00 717.97S 1270.78W 7 5/8" Casing
0.00 0.00 0.00N 0.00E 8355.08 5324.55 2747.15S 5222.15W 3 1/2" Casing
Targets associated with this wellpath
=====================================
Target name Geographic Location T.V.D. Rectangular Coordinates Revised
MW(A) Rvsd 24 May 01 438608.000,5866301.000,999.00 5116.00 2599.73S 4935.08W 22-Feb-2001
ORIGINAL
Phillips Alaska, Inc.
Drill Site 2P
447
slot 9447
Meltwater
North Slope, Alaska
PROPOSAL LISTING
INCLUDING POSITION UNCERTAINTIES
Baker Hughes INTEQ
Your ref : 2P-447 Version$3
Our ref : prop4476
License :
Date printed : 29-May-2001
Date created : 22-Feb-2001
Last revised : 25-May-2001
Field is centred on 441964.235,5869891.466,999.00000,N
Structure is centred on 441964.235,5869891.466,999.00000,N
Slot location is n70 3 8.521,w150 27 5.911
Slot Grid coordinates are N 5868862.800, E 443562.270
Slot local coordinates are 1016.56 S 1605.98 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
ORIGINAL
Phillips Alaska, Inc.
Drill Site 2P0447
Meltwater,North Slope, Alaska
PROPOSAL LISTING Page 1
Your ref : 2P-447 Version#3
Last revised : 25-May-2001
Measured Inclin. Azimuth True Vert R E C T A N G U L A R Vert Ellipse Semi Axes Minor
Depth Degrees Degrees Depth C 00 R D I N A T E S Sect Major Minor Vert. Azi.
0.00 0.00 0.00 0.00
100.00 0.00 225.00 100.00
200.00 0.00 225.00 200.00
300.00 0.00 225.00 300.00
400.00 2.00 225.00 399.98
500.00 4.00 225.00 499.84
600.00 6.00 225.00 599.45
700.00 8.00 225.00 698.70
800.00 10.00 225.00 797.47
900.00 12.85 229.69 895.48
1000.00 15.76 232.69 992.36
1100.00 18.70 234.77 1087.87
1200.00 21.65 236.30 1181.72
0.00 N
0.00 N
0.00 N
0.00 N
1.23 S
0.00E 0.00 0.00 0.00 0.00 N/A
0.00E 0.00 0.26 0.26 0.15 N/A
0.00E 0.00 0.52 0.52 0.30 N/A
0.00E 0.00 0.78 0.78 0.45 N/A
1.23W 1.67 1.05 1.05 0.60 N/A
4.93 S
11.10 S
19.71 S
30.78 S
44.11 S
4.93 W 6.67 1.36 1.31 0.75 45.00
11.10 W 14.99 1.73 1.58 0.90 45.00
19.71W 26.63 2.21 1.86 1.05 45.00
30.78W 41.57 2.80 2.16 1.21 45.00
45.40W 60.73 3.58 2.47 1.37 46.46
59.55S 64.69 W 84.99 4.57 2.81 1.53 48.24
77.03S 88.59 W 114.29 5.82 3.17 1.71 49.97
96.52S 117.04W 148.54 7.34 3.56 1.90 51.53
1300.00 24.62 237.47 1273.67 117.97 S 149.96 W 187.65 9.16 3.98 2.12 52.90
1400.00 27.59 238.41 1363.46 141.30 S 187.25 W 231.53 11.32 4.43 2.36 54.09
1500.00 30.57 239.18 1450.85 166.46 S 228.82 W 280.03 13.83 4.90 2.64 55.12
1503.67 30.67 239.21 1454.00 167.42S 230.43W 281.90 13.94 4.92 2.65 55.16
1600.00 33.55 239.82 1535.59 193.38S 274.55W 333.04 16.72 5.40 2.95 56.02
1700.00 36.53 240.37 1617.46 221.99S 324.32W 390.41 19.99 5.91 3.31 56.80
1800.00 39.51 240.85 1696.23 252.20S 377.99W 451.97 23.67 6.44 3.73 57.49
1900.00 42.50 241.27 1771.68 283.94S 435.41W 517.57 27.76 6.98 4.19 58.10
2000.00 45.49 241.65 1843.61 317.12S 496.43W 587.02 32.27 7.52 4.71 58.63
2014.88 45.94 241.70 1854.00 322.17S 505.81W 597.67 33.01 7.60 4.80 58.70
2100.00 48.48 241.99 1911.82 351.64S 560.88W 660.12 37.20 8.06 5.29 59.11
2200.00 51.47 242.30 1976.12 387.41S 628.57W 736.69 42.54 8.59 5.92 59.54
2300.00 54.46 242.58 2036.34 424.34S 699.34 W 816.51 48.28 9.12 6.61 59.92
2389.08 57.13 242.82 2086.42 458.13S 764.80 W 890.18 53.71 9.57 7.27 60.23
2500.00 57.13 242.82 2146.62 500.68S 847.67 W 983.33 60.50 10.14 8.10 60.54
3000.00 57.13 242.82 2418.00 692.52S 1221.23W 1403.25 91.31 12.69 11.89 61.34
3066.32 57.13 242.82 2454.00 717.97S 1270.78W 1458.95 95.41 13.03 12.40 61.39
3176.87 57.13 242.82 2514.00 760.38 S 1353.38 W 1551.79 102.26 13.59 13.24 61.47
3500.00 57.13 242.82 2689.38 884.36 S 1594.80W 1823.17 122.25 15.24 15.72 61.72
4000.00 57.13 242.82 2960.77 1076.20S 1968.36W 2243.09 153.26 17.80 19.57 61.95
4098.08 57.13 242.82 3014.00 1113.83S 2041.64W 2325.46 159.34 18.30 20.33 61.98
4500.00 57.13 242.82 3232.15 1268.04S 2341.92W 2663.01 184.28 20.36 23.43 62.10
4761.35 57.13 242.82 3374.00 1368.32S 2537.18W 2882.50 200.51 21.69 25.44 62.15
5000.00 57.13 242.82 3503.53 1459.88S 2715.49W 3082.93 215.33 22.92 27.29 62.20
5111.41 57.13 242.82 3564.00 1502.63S 2798.72W 3176.49 222.25 23.49 28.15 62.22
5500.00 57.13 242.82 3774.91 1651.72S 3089.05W 3502.85 246.38 25.48 31.15 62.28
6000.00 57.13 242.82 4046.30 1843.56S 3462.61W 3922.77 277.44 28.04 35.02 62.34
6500.00 57.13 242.82 4317.68 2035.40S 3836.17W 4342.69 308.51 30.60 38.89 62.39
7000.00 57.13 242.82 4589.06 2227.24S 4209.74W 4762.60 339.58 33.17 42.75 62.43
7500.00 57.13 242.82 4860.44 2419.08S 4583.30W 5182.52 370.65 35.73 46.62 62.46
7741.87 57.13 242.82 4991.72 2511.88S 4764.01W 5385.66 385.68 36.97 48.50 62.48
7841.87 57.13 242.82 5046.00 2550.25S 4838.72W 5469.64 391.89 37.49 49.27 62.48
7970.82 57.13 242.82 5115.99 2599.72 S 4935.06 W 5577.94 399.91 38.15 50.27 62.49
7970.84 57.13 242.82 5116.00 2599.73S 4935.08W 5577.96 399.91 38.15 50.27 62.49
8000.00 57.13 242.82 5131.83 2610.92S 4956.86W 5602.44 401.72 38.30 50.49 62.49
8099.81 57.13 242.82 5186.00 2649.21S 5031.43W 5686.27 407.92 38.81 51.27 62.50
8155.08 57.13 242.82 5216.00 2670.42S 5072.73W 5732.69 411.36 39.09 51.69 62.50
Ail data is in feet unless otherwise stated.
Coordinates from slot #447 and TVD from RKB (Doyon 141) (254.00 Ft above mean sea level).
Bottom hole distance is 5900.66 on azimuth 242.25 degrees from wellhead.
Vertical section is from wellhead on azimuth 242.22 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
ORIGINAL
Phillips Alaska, Inc.
Drill Site 2P,447
Meltwater,North Slope, Alaska
PROPOSAL LISTING Page 2
Your ref : 2P-447 Version#3
Last revised : 25-May-2001
Measured Inclin. Azimuth True Vert R E C T A N G U L A R Vert Ellipse Semi Axes Minor
Depth Degrees Degrees Depth C 0 0 R D I N A T E S Sect Major Minor Vert. Azi.
8355.08 57.13 242.82 5324.55 2747.15 S 5222.15 W 5900.65 423.79 40.12 53.24 62.51
POSITION UNCERTAINTY SD-HMARY
==============================
Depth Position Uncertainty
From To Survey Tool Error Model Major Minor Vert.
0 8355 ARCO (H.A) Mag) User specified 423.79 40.12 53.24
1. Ellipse dimensions are half axis.
2. Casing dimensions are not included.
3. Ellipses are calculated on 2.58 standard deviations.
4. Uncertainty calculations start at drill depth zero.
5. Surface position uncertainty is not included.
6. Where two surveys are tied together the errors of one are considered
to have a systematic relationship to the corresponding errors of the other.
7. Detailed description of the INTEQ error models can be found
in the Ec*Trak manual.
Ail data is in feet unless otherwise stated.
Coordinates from slot #447 and TVD from RKB (Doyon 141) (254.00 Ft above mean sea level).
Bottom hole distance is 5900.66 on azimuth 242.25 degrees from wellhead.
Vertical section is from wellhead on azimuth 242.22 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
ORIGINAL
Phillips Alaska, Inc.
Drill Site 2P,447
Meltwater,North Slope, Alaska
PROPOSAL LISTING Page 3
Your ref : 2P-447 Version#3
Last revised : 25-May-2001
Co~ents in wellpath
MD TVD Rectangular Coord$. Comment
300.00 300.00 0.00 N 0.00 E KOP
800.00 797.47 30.78 S 30.78 W Begin Bld/Trn
1503.67 1454.00 167.42 S 230.43 W Base Permafrost
2014.88 1854.00 322.17 S 505.81 W Base West Sak
2389.08 2086.42 458.13 S 764.80 W EOC
3066.32 2454.00 717.97 S 1270.78W 7 5/8' Casing Pt
3176.87 2514.00 760.38 S 1353.38W C80
4098.08 3014.00 1113.83S 2041.64W C50
4761.35 5374.00 1368.32S 2537.18W C40
5111.41 3564.00 1502.63S 2798.72W C37
7741.87 4991.72 2511.88S 4764.01W Casing crossover
7841.87 5046.00 2550.25S 4838.72W T3 (Top Bermuda)
7970.82 5115.99 2599.72S 4935.06W Target-T3 MidBermuda
7970.84 5116.00 2599.73S 4935.08W MW(A) Rvsd 24 May 01
8099.81 5186.00 2649.21S 5031.43W T2 (Base Bermuda)
8155.08 5216.00 2670.42S 5072.73W C35(Top Albian)
8355.08 5324.55 2747.15S 5222.15W TD - Casing Pt
Casing positions in string 'A'
==============================
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coord$. Casing
0.00 0.00 0.00N 0.00E 3066.32 2454.00 717.97S 1270.78W 7 5/8" Casing
0.00 0.00 0.00N 0.00E 8355.08 5324.55 2747.15S 5222.15W 3 1/2" Casing
Targets associated with this wellpath
Target name Geographic Location T.V.D. Rectangular Coordinates Revised
MW(A) Rvsd 24 May 01 438608.000,5866301.000,999.00 5116.00 2599.73S 4935.08W 22-Feb-2001
ORIGINAL
Phillips Alaska, Inc.
Drill Site 2P
447
slot #447
Meltwater
North Slope, Alaska
PROPOSAL LISTING
by
Baker Hughes INTEQ
Your ref : 2P-447 Version#3
Our ref : proD4476
License :
Date printed : 29-May-2001
Date created : 22~Feb-2001
Last revised : 25-May-2001
Field is centred on 441964.235,5869891.466,999.00000,N
Structure is centred on 441964.235,5869891.466,999.00000,N
Slot location is n70 3 8.521,w150 27 5.911
Slot Grid coordinates are N 5868862.800, E 443562.270
Slot local coordinates are 1016.56 S 1605.98 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
ORIGINAL
Phillips Alaska, Inc.
Drill Site 2P,447
Meltwater,North Slope, Alaska
Measured Inclin Azimuth True Vert
Depth Degrees Degrees
0.00 0.00 0.00
100.00 0.00 225.00
200.00 0.00 225.00
300.00 0.00 225.00
400.00 2.00 225.00
500.00 4.00 225.00
600.00 6.00 225.00
700.00 8.00 225.00
800.00 10.00 225.00
900.00 12.85 229.69
1000.00 15.76 232.69
1100.00 18.70 234.77
1200.00 21.65 236.30
1300.00 24.62 237.47
1400.00 27.59 238.41
1500.00 30.57 239.18
1503.67 30.67 239.21
1600.00 33.55 239.82
1700.00 36.53 240.37
1800.00 39.51 240.85
1900.00 42.50 241.27
2000.00 45.49 241.65
2014.88 45.94 241.70
2100.00 48.48 241.99
2200.00 51.47 242.30
2300.00 54.46 242.58
2389.08 57.13 242.82
2500.00 57.13 242.82
3000.00 57.13 242.82
3066.32 57.13 242.82
3176.87 57.13 242.82
3500.00 57.13 242.82
4000.00 57.13 242.82
4098.08 57.13 242.82
4500.00 57.13 242.82
4761.35 57.13 242.82
5000.00 57.13 242.82
5111.41 57.13 242.82
5500.00 57.13 242.82
6000.00 57.13 242.82
6500.00 57.13 242.82
7000.00 57.13 242.82
7500.00 57.13 242.82
7741.87 57.13 242.82
7841.87 57.13 242.82
7970.82 57.13 242.82
7970.84 57.13 242.82
8000.00 57.13 242.82
8099.81 57.13 242.82
8155.08 57.13 242.82
8355.08 57.13 242.82
PROPOSAL LISTING Page 1
Your ref : 2P-447 Version#3
Last revised : 25-May-2001
RECTANGULAR GRID C O 0 R D S GE
Depth C 0 0 R D I N A T E S Easting Northing C 0
0.00 0.00N 0.00E 443562.27 5868862.80 n70
100.00 0.00N 0.00E 443562.27 5868862.80 n70
200.00 0.00N 0.00E 443562.27 5868862.80 n70
300.00 0.00N 0.00E 443562.27 5868862.80 nT0
399.98 1.23S 1.23W 443561.03 5868861.58 n70
499.84 4.93S 4.93W 443557.30 5868857.90 nT0
599.45 11.10S ll.10W 443551.09 5868851.79 n70
698.70 19.71S 19.TiW 443542.41 5868843.24 nT0
797.47 30.78S 30.78W 443531.26 5868832.26 nT0
895.48 44.11S 45.40W 443516.54 5868819.04 n70
992.36 59.55S 64.69W 443497.13 5868803.75 n70
1087.87 77.03S 88.59W 443473.10 5868786.45 n70
1181.72 96.52S 117.04W 443444.51 5868767.18 n70
1273.67 117.97S 149.96W 443411.43 5868745.99 n70
1363.46 141.30S 187.25W 443373.96 5868722.95 n70
1450.85 166.46S 228.82W 443332.21 5868698.10 n70
1454.00 167.42S 230.43W 443330.60 5868697.16 n70
1535.59 193.38S 274.55W 443286.28 5868671.53 n70
1617.46 221.99S 324.32W 443236.30 5868643.31 n70
1696.23 252.20S 377.99W 443182.40 5868613.51 n70
1771.68 283.94S 435.41W 443124.75 5868582.21 n70
1843.61 317.12S 496.43W 443063.48 5868549.50 n70
1854.00 322.17S 505.81W 443054.07 5868544.52 nT0
1911.82 351.64S 560.88W 442998.78 5868515.48 n70
1976.12 387.41S 628.57W 442930.82 5868480.22 n70
2036.34 424.34S 699.34W 442859.79 5868443.84 n70
2086.42 458.13S 764.80W 442794.07 5868410.56 n70
2146.62 500.68S 847.67W 442710.89 5868368.64 n70
2418.00 692.52S 1221.23W 442335.91 5868179.67 n70
2454.00 717.97S 1270.78W 442286.17 5868154.60 n70
2514.00 760.38S 1353.38W 442203.27 5868112.82 n70
2689.38 884.36S 1594.80W 441960.93 5867990.70 n70
2960.77 1076.20S 1968.36W 441585.96 5867801.73 n70
3014.00 1113.83S 2041.64W 441512.40 5867764.66 n70
3232.15 1268.04S 2341.92W 441210.98 5867612.76 n70
3374.00 1368.32S 2537.18W 441014.98 5867513.99 n70
3503.53 1459.88S 2715.49W 440836.00 5867423.79 n70
3564.00 1502.63S 2798.72W 440752.45 5867381.69 n70
3774.91 1651.72S 3089.05W 440461.02 5867234.82 nT0
4046.30 1843.56S 3462.61W 440086.04 5867045.86 n70
4317.68 2035.40S 3836.17W 439711.07 5866856.89 n70
4589.06 2227.24S 4209.74W 439336.09 5866667.92 n70
4860.44 2419.08S 4583.30W 438961.11 5866478.95 n70
4991.72 2511.88S 4764.01W 438779.72 5866387.54 n70
5046.00 2550.25S 4838.72W 438704.72 5866349.74 n70
5115.99 2599.72S 4935.06W 438608.02 5866301.01 n70
5116.00 2599.73S 4935.08W 438608.00 5866301.00 n70
5131.83 2610.92S 4956.86W 438586.13 5866289.98 n70
5186.00 2649.21S 5031.43W 438511.28 5866252.26 n70
5216.00 2670.42S 5072.73W 438469.83 5866231.37 n70
5324.55 2747.15S 5222.15W 438319.84 5866155.78 n70
OGRAPHIC
ORDINATES
3 08.52 w150 27 05.91
3 08.52 w150 27 05.91
3 08.52 w150 27 05.91
3 08.52 w150 27 05.91
3 08.51 wlS0 27 05.95
3 08.47 w150 27 06.05
3 08.41 w150 27 06.23
3 08.33 w150 27 06.48
3 08.22 w150 27 06.80
3 08.09 w150 27 07.22
3 07.94 w150 27 07.77
3 07.76 w150 27 08.46
3 07.57 w150 27 09.28
3 07.36 w150 27 10.23
3 07.13 w150 27 11.31
3 06.88 w150 27 12.50
3 06.87 w150 27 12.55
3 06.62 w150 27 13.82
3 06.34 w150 27 15.25
3 06.04 w150 27 16.80
3 05.73 w150 27 18.45
3 05.40 w150 27 20.21
3 05.35 w150 27 20.48
3 05.06 w150 27 22.07
3 04.71 w150 27 24.02
3 04.35 w150 27 26.06
3 04.02 w150 27 27.94
3 03.60 w150 27 30.33
3 01.71 w150 27 41.09
3 01.46 w150 27 42.52
3 01.04 w150 27 44.90
2 59.82 w150 27 51.85
2 57.94 w150 28 02.61
2 57.57 w150 28 04.72
2 56.05 w150 28 13.37
2 55.06 w150 28 18.99
2 54.16 w150 28 24.13
2 53.74 w150 28 26.52
2 52.28 w150 28 34.88
2 50.39 wlS0 28 45.64
2 48.50 w150 28 56.40
2 46.61 w150 29 07.15
2 44.72 w150 29 17.91
2 43.81 wlS0 29 23.11
2 43.43 wlS0 29 25.26
2 42.95 w150 29 28.04
2 42.95 w150 29 28.04
2 42.84 w150 29 28.66
2 42.46 w150 29 30.81
2 42.25 w150 29 32.00
2 41.50 w150 29 36.30
Ail data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot ~447 and TVD from RKB (Doyon 141) (254.00 Ft above mean sea level).
Bottom hole distance is 5900.66 on azimuth 242.25 degrees from wellhead.
Total Dogleg for wellpath is 57.67 degrees.
Vertical section is from wellhead on azimuth 242.22 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented byBaker Hughes INTEQ
ORIGINAL
Phillips Alaska, Inc.
Drill Site 2P,447
Meltwater,North Slope, Alaska
MD TVD Rectangular Coords.
PROPOSAL LISTING Page 2
Your ref : 2P-447 Version#3
Last revised : 25-May-2001
Cormuents in wellpath
Comment
300.00 300.00 0
800.00 797.47 30
1503.67 1454.00 167
2014.88 1854.00 322
2389.08 2086.42 458
3066.32 2454.00 717
3176.87 2514.00 760
4098.08 3014.00 1113
4761.35 3374.00 1368
5111.41 3564.00 1502
7741.87 4991.72 2511
7841.87 5046.00 2550
7970.82 5115.99 2599
7970.84 5116.00 2599
8099.81 5186.00 2649
8155.08 5216.00 2670
8355.08 5324.55 2747
.00N 0.00E KOP
.78S 30.78W Begin Bld/Trn
42S 230.43W Base Permafrost
17S 505.81W Base West Sak
13S 764.80W EOC
97S 1270.78W 7 5/8" Casing Pt
38S 1353.38W C80
83S 2041.64W C50
32S 2537.18W C40
63S 2798.72W C37
88S 4764.01W Casing crossover
25S 4838.72W T3 (Top Bermuda)
725 4935.06W Target-T3 MidBermuda
73S 4935.08W MW(A) Rvsd 24 May 01
215 5031.43W T2 (Base Bermuda)
42S 5072.73W C35(Top Albian)
1SS 5222.15W TD - Casing Pt
Casing positions in string 'A'
==============================
Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing
0.00 0.00 0.00N 0.00E 3066.32 2454.00 717.97S 1270.78W 7 5/8" Casing
0.00 0.00 0.00N 0.00E 8355.08 5324.55 2747.15S 5222.15W 3 1/2" Casing
Targets associated with this wellpath
=====================================
Target name Geographic Location T.V.D. Rectangular Coordinates Revised
MW(A) Rvsd 24 May 01 438608.000,5866301.000,999.00 5116.00 2599.73S 4935.08W 22-Feb-2001
ORIGINAL
Phillips Alaska, Inc.
Drill Site 2P
447
slot #447
Meltwater
North Slope, Alaska
SUMMARY CLEARANCE REPORT
by
Baker Hughes INTEQ
Your ref : 2P-447 Version#3
Our ref : prop4476
License :
Date printed : 29-May-2001
Date created : 22-Feb-2001
Last revised : 25-May-2001
Field is centred on 441964.235,5869891.466,999.00000,N
Structure is centred on 441964.235,5869891.466,999.00000,N
Slot location is n70 3 8.521,w150 27 5.911
Slot Grid coordinates are N 5868862.800, E 443562.270
Slot local coordinates are 1016.56 S 1605.98 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
Object wellpath
MWD <0 - 6008'>,,417,Drill Site 2P
MWD <0-9224'>,,438,Drill Site 2P
PMSS <0-6122'>,,MWN#1,Meltwater North #l
PM$S <2212-7349'>,,MWN#2A, Meltwater North #2
PMSS <0-8935'>,,MWSouthl,Meltwater South #1
Closest approach with 3-D Minimum Distance method
Last revised Distance M.D. Diverging from M.D.
25-May-2001 599.9 0.0 0.0
29-May-2001 179.4 312.5 312.5
26-Feb-2001 5920.9 4620.0 4620.0
26-Feb-2001 4103.1 1977.8 1977.8
6-Mar-2001 44879.9 8355.1 8355.1
ORIGINAL
SVY~t
T~e-ln
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
50
Pad 2P. Well ,~t44.7 Version #3
:I~'TEQ ': ·" ' ' "''
' ~)0.00
. ~)0.00
· 680.00
JO00.O0
'JlOO.oO
1200.00
1300,00
1400.00
1500.00
ueg . .deg.' ~t . S,~)Saa · ~t'.
· 0.00'' 0.00 ' 0:00: -264.00"~562.2~
0.00 226,00
0.00 ·. 225,00:
0.00 ' 225.00
2.00
4.00 225,00
6.00 : 225.00
8.00 , 225.00
10.00m
12.85: 2~,89
15.76· 232..69
18.702'34.77.
21.65 . 236.30
24.62 237,47
27.59 238.41
30.57 239.i8
443562.27 5888862,80
443562.27 5868862.80
443562.27 556~80'
443561.03 58~8861.58
443557.30 5868857,901
443551.09 5868~1;7~
443542.41 5868843.24
443531.26 5838832.2~
443516.54 98688`1g'.04
443497.13 '5888803,75
443473.10 686878~4~5
443444.51 5868767.18
443411.43 5868745.99.
443373.96 586872.2.95
.
443332.21 5868698.t0.
.1503.67
1600.00
1700.00
2000.00
2014.88
2100.00
2200.00'
2300.00
2500.00'
3O00.00
3066.32
3176.87,
4098.08
t500.00
4761.35
50O0.00
5111.41
6000.00
6500.00
7000.00
7500.00
7741.87,
7841.87
797o.82
7970,84.'
8000.00
8099.81
8155.08
8355.08
30.67239.21'
33.55239.82
36.53240,37.
39.51240,85
42.50241,27
45.49241.85
45.94241.70
48.48241.99.
51.47. 242.30
54.46242.58
57.13'. 242.82
57.13242.82'
57.13242.82
57.13242.82
57.13242.82
57.13242.82
57.13242.82
57.13242.82
57.13242.82
57.13242.82
57.13242.82
57.13242.82
57.13242-32:
57.13242.82
57.13·242.82
57.13 242.82
57.13 242.82
57.13 242.82
57.13 242.82'
57.13 242.8~
57.13 242.82,
57.13 242.82
57.13 242.82
57.13 242.82
57.13 242.82
100.00 . -154.00 · ..
200.00 : ,-54.00
300.00 ' .,.45;00 · .
399.98145.98
499.84245;54'
599.45345:45
698.70· 444.70
797.47543;47'
895.48641.45.
992.36' 738,38
1087.87 833.87'
1181.72 327.72'
1273.67 1019.67
1363.46 1109.45
1450.85 ', 1198.85
1454.001200.00 443330.60 5868697.16
1535.591281.59 443286.28 5868671~53
1617.461363,46 443236.30 5868643,31'
1696.231442.23:443182.40 5868613,53
1771.68 . 1517..68'. 443124.75 ~58582..21.
1843.61,. 1589;61, 443063.48 5868549.50
1854.001800.08i 443054.07 5868544.52
1911.821657.82, 442998.78 5868515.45
1976.12. 1722J12=: 442930.82 5868480.22
2036.341782.34' 442859.79 5868443.84
2086.42:· .1832i42. 442794.07 .686841Q.5~
2146.62· 1892.62 442710.89 5868368.64
2418.00 2164.00 442335.91 5868179.67
2454.00· 2200.(X) 442286.17 5868154.60
2514.00 2260.00 442203.27 5868112.82
2689.38 2458.38 441960.93 5867990.70
2960.77 ' 2706,77' 441585.96 5867801.73.
3014.00 2760.00 441512.40 5867764.68.
3232.15 2978,15 441210.98 5867612.76
3374.00 ' 3120,00.441014.98 6867513,99
3503.53 . 3249.53. 440836.00 5867423,79.
3564.00 . 3810,00 440752.45 5867381.69'
3774.91 .~ 351t0.91'. 440461.02 58672~4.82.
4046.30 3792.30' 440086.04 5867045.86
4317.684063.68' 439711.07 5866856.89'
4589.064335.06:439336.09 5868667.92.
4860.444606,44 438961.11 5865479~05
4991.72" 4737.72:438779.72 6868387.54'
5046.004792.00 438704.72 5866349.74
5115.994861;991 438608.02 5866301.0i
5116.004862.00' 438608.00 5866301.00
5131.834877~83. 438586.13 5866289.98
5186.00. 4tL32~00 438511.28 5866252.26
5216.004962.00' 438469.83 5866231.37
5324.555070.55. 438319.84 5868155.78
0.00: :'. 0.00
0.00 0.00
0.00' . 0.00
0.00 '"' 0.08
-1.23 ~1,23
-4.93 -4.93
-11.10. -11i10
-19.71.-19.71
-30.78' -:30.78'
-44.11 .::.: .-4.5,40
-59.55 ''-64.69
-77.03. -88.5:9
-96.52-117.04
-117.97 ". -149,96
-141.30 .o187,25.
-166.46 '-226.22
-167.42: -230.43
- 193.38 -274.55
-221.99 -:,.324,32
-252.201 -377;99
-283.94
-317.12 -496.43
-322.17, .505.81
-351.64 -560.68
-387.41 -628-57
-424.34.. :-699,34
-458.13 .: ~.764,.8Q.
-500.68' -84.7:67
-692.52*1221,23
-717.97-1270.78
-760.38.1353.38
-884.36-1594.80
- 1076.20' -1 358.36
-1113.83 -2()4,1.54
-1268.04 -2341,92
-1368.32' -2537.18'
-1459.88 -2715.49
-1502.63 -2798,72
-1651.72 · -3089.08.
-1843.56. -3462.01
-2035.40 -3836.17,
-2227.24·' .-4209.74'
-2419.08 .4583.30'
-2511.88 ..4764.0'1
-2550.25' -4836.72;
-2599.72. -4935.08
-2599.73 -4935,08
-2610.92 -4956.86'
-2649.21 , -5031.43
-2670.42 -5072.73
-2747.15 -5222.15
0.00 .... :' 0.00
0.00 ". ' ' 0,00
0.00' "0.00
0.00 .:, 0.00
2.00 1
2.00 : 6.67
2.00 26.63:
2.00 41.57
3.00 m
3.001'''
3.00 ~:.: !:14.29
3.00: '148.54i
3.00,. 280.031
3.00 m m
3.00 ,': 333,04i
3.00 :, 390.41
3.00 '.'451.97i
3.00 , 5t7.57i
3.00:
3.00
3.00
3.00
3.00
3.00 .
0.00
0.00 ,
0.00 '
0.00 '
0.00
0.00:
0.00 ·
0.00 '
0.00
0.00 ' 3082.931
0.00 3176.49~
0.00
.: = 3602.85!
0.00.. 3822.77{
0.00 ~k~42.6ei
o.oo · .'. 4762..8oi
0.00 5385.68i
0'00 m mm 5468,54j
0.00 .5577.94i
0.00 ' 5577.081
0.00 5602.44i
0.00 . 6886.,?.7i
0.00 5732.691
0.00 5900,65i
..
587.02i
· , 680.12~
736.69i
· 816,5'1i
' 962.381
1403.25)
1458.95i
1551.791
1623.171
2325.46'
2663.01
2862.50i
2P-447 Drilling Hazards Summary
(to be posted in Rig Floor Doghouse Prior to Spud)
(See Well Plan for further discussion of these risks)
12-1/4" Hole / 9-5/8" Casinq Interval
Event Risk Level Mitigation Strategy
Conductor Broach Low Monitor cellar continuously during interval.
Well Collision Low Careful well planning and surveying,
adherence to anti-collision policy
Gravel and sand Low Elevated mud viscosity from spud; Hi dens
sloughing sweeps; contingent 13-3/8" casing string.
Shaker/Trough Cuttings Low Controlled ROP
System Overflow
Permafrost Hydrates Low Controlled drilling, reduced pump rates,
higher mud weights, lower viscosities, and
lecithin additions as needed
Shoe Fracture/Lost Low Reduced pump rates, and lightweight tail
Returns during cement cement
job
8-1/2" Hole/7"x 4-1/2" Casing Interval
Event [ Risk Level I Mitigation Strategy
Lost Circulation in' Low Good drilling practices. LCM as needed.
Bermuda interval Possible PBL sub on coring assembly
High ECD and Low Pumping and rotating out on all trips to
swabbing if higher MW reduce swab and barite sag potential.
is required
Hole stability during e- Moderate Emphasis on maintaining mud properties.
line runs Clean out runs as needed. Good drilling
practices
2P-447 Drilling Hazards Summary. doc
prepared by Pat Reilly
05/29/01
Meltwater 2P-447
Proposed Completion Schematic
Slimhole Base Case - 3-1/2" Completion String
PHIL-IPS Alas
A Subsidiary of PHILLIPS PETROLEUM
16" 62.6#
@ +/- 120' MD
Depths are
based on
Doyon 141
RKB
Surface csg.
7-5/8" 29.7# L-80 BTCM
+/- 3066' MD / 2454' TVD
Intermediate csg.
5-1/2" 15.5# L-80 BTCM
run CSR to surface
+/- 7741' MD / 4992' TVD
Future Perforations
Production csg
3-1/2" 9.3# L-80 EUE8RD
TD to CSR
+/- 8355' MD / 5324' TVD
3-1/2" FMC Gen 5 Tubing Hanger, 3-1/2" L-80 EUE8RD pin down
3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required
3-1/2" 9.3# L-80 EUE8RD Tubing to Surface
3-1/2" Camco 'DS' nipple w/2.875" No-Go Profile. 3-1/2" x 6' L-80 handling
pups installed above and below, EUESRD set at +/- 500' MD
3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple
3-1/2" x 1" Camco 'KBUG-2-9' Mandrels w/DV's and RK latch's (Max. OD 4.725",
ID 2.90"), IBT box x box, 3-1/2" x 6'L-80 EUE8RD box x IBT pin handling pup
installed above, 3-1/2" x 6' L-80 IBT pin x EUE8RD pin handling pup installed
below. Spaced out w/3-1/2" 9.3# L-80 EUE8RD tubing as follows:
GLM # TVD-RKB MD-RKB
GLM Numbers and Spacing To Be Determined
3-1/2" x 1" Camco 'KBUG-2-9' mandrel w/DCK-3 shear valve and latch (Max.
OD 4.725", ID 2.90"), IBT box x box, pinned for 3000 psi shear (casing to tubing
differential), 3-1/2" x 6' L-80 EUE8RD box x IBT pin handling pup installed above,
3-1/2" x 6' L-80 IBT pin x EUE8RD pin handling pup installed below
1 jt 3-1/2" 9.3# L-80 EUE8RD tubing
3-1/2" Baker 'CMU' sliding sleeve w/2.813" Camco No-Go profile, EUE8RD
box x pin. 3-1/2" x 6' L-80 EUE8RD handling pups installed above and below
Spaceout pup, 3-1/2" x 15', 9.3# L-80 EUE8RD
3-1/2" Camco 'D' nipple w/2.75" No-Go profile. 3-1/2" x 6' L-80 EUE8RD
handling pups installed above and below
1 jt 3-1/2" 9.3# L-80 EUE8RD tubing
3-1/2" Baker 80-40 GBH-22 casing seal assembly w/15' stroke, 3-1/2" L-80
EUESRD box up, 3-1/2" x 6' L-80 EUE8RD handling pup installed on top
Baker Casing Seal Receptacle, 80-40, 5-1/2"BTCM x 3-1/2" EUE8RD
Baker 5" OD x 4" ID 17' Seal Bore Extension
CSR set at +/- 100' above top perforation
PJR, 12/27/00
Schlumberger
Rig: Doyon 141
Location: Kuparuk (Meltwater)
Client: Phillips Alaska, Inc.
Revision Date: 5/29/01
Prepared by: Kevin Tanner
Location: Anchorage, AK
Phone: (907) 265-6205
Mobile: (907) 230-6628
email: ktanner@slb.com
< TOCat Surface
R'evious Csg.
< 16", 62.6~ casing
at 120 ft. rVD
< Base of Permafrost
at 1,504 ft. IVD
< Top of Tail at
1,524 ft. IVD
< 7 5/8", 29.7# casing
in 9 7/8" OH
TD at 3,066 ft.
(2,454 ft. TVD)
Preliminary Job Design based on limited input data. For estimate purposes only.
Volume Calculations and Cement Systems
(Volumes are based on 250% excess in the permafrost and 45% excess below the
permafrost. Top of tail slurry is designed to be 20' below base of permafrost.)
Lead Slurry (minimum pump time 166 min.)
ASLite @ 10.7 pp~j, Class G + 50%D124, 9%D44, 0.4%D46, 30%D53, 1.5%S1,
1.5%D79 - 4.44 ft°/sk
0.9513 ft3/ft x (120') x 1.00 (no excess) =
0.2148 ft3/ft x (1504'- 120') x 3.50 (250% excess) =
0.2148 ft3/ft x (1524' - 1504') x 1.45 (45% excess) =
114.2 ft3 + 1040.5 ft3+ 6.2 ft3 =
1046.7 ft3/4.44 ft3/sk =
Round up to 240 sks
114.2 ft3
1040.5 ft3
6.2 ft3
1046.7 ft3
235.7 sks
Have 170 sks of additional Lead on location for Top Out stage, if necessary.
Tail Slurry (minimum pump time 134 min.)
LiteCRETE @ 12.0 ppg - 2.40 ft3/sk
0.2148 ft3/ft x (3066'- 1524') x 1.45 (45% excess) =
0.2578 ft3/ft x 80' (Shoe Joint) = :
480.3 ft3 + 20.6 ft3 =
500.9 ft3/2.40 ft3/sk =
Round up to 210 sks
480.3 ft3
20.6 ft3
500.9 ft3
208.7 sks
BHST = 58°F, Estimated BHCT = 74°F.
(BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost)
PUMP SCHEDULE
Stage Pump Rate Volume Stage Stage Time Cumulative Time
(bpm) (bbl), , (min) (min), ,
CW 100 6 40 6.7 6.7
Drop Bottom Plug 3.0 9.7
MudPUSH XL 6 30 5.0 14.7
Lead Slurry 6 190 31.7 46.4
Tail Slurry 6 90 15.0 61.4
Drop Top Plug 3.0 64.4
Displacement 6 117 19.5 83.9
Bump Plug 3 20 6.7 90.6
MUD REMOVAL
Recommended Mud Properties: 9.8 ppg, Pv = 15-20, Ty = 15-20. As thin and light as
possible to aid in mud removal during cementing.
Spacer Properties: 10.5 ppg MudPUSH* XL, Pv = 17-20, Ty = 20-25
Centralizers: Recommend I per joint across zones of interest for proper cement
placement.
'Mark of SchIumber§er
ORIGINAL
Schlumberger
Rig: Doyon 141
Location: Kuparuk (Meltwater)
Client: Phillips Alaska, Inc.
Revision Date: 5/29/01
Prepared by: Kevin Tanner
Location: Anchorage, AK
Phone: (907) 265-6205
Mobile: (907) 230-6628
email: ktanner@slb.com
Previous Csg.
< 7 5/8", 29.7# casing
at 3,066 ft. IVD
< 5 1/2", 15.5~ casing
in 6 3/4" OH
< Top of Tail at
7,242 ft. rvD
< X-over at 7,742 ft. IVD
< Top of Bermuda Fm
at 7,842 ft. IVD
< 31/2", 9.3~ casing
in 6 3/4" OH
'rD at 8,355 ft. rvD
(5,325 ft. TVD)
Preliminary Job Design based on limited input data. For estimate purposes only.
Volume Calculations and Cement Systems
(Volumes are based on 75% excess. Top of tail slurry is designed to be 500' above
casing X-over.
Tail Slurry (minimum thickening time 136 min.)
GasBLOK w/Class G + D53, D600, D135, D800, D047, D065, per lab testing
@ 15.8 ppg, 1.2 ft3/sk
0.0835 ft3/ft x 500' x 1.75 (75% excess) =
0.1817 ft3/ft x (8355'- 7742') x 1.75 (75% excess) =
0.0488 ft3/ft x 80' (Shoe Joint) =
73.1 ft3 + 194.9 ft3 + 3.9 ft3 =
271.9 ft3/1.2 ft3/sk =
Round up to 230 sks
73.1 ft3
194.9 ft3
3.9 ft3
271.9 ft3
226.6 sks
BHST = 133°F, Estimated BHCT = 122°F.
(BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost)
PUMP SCHEDULE
Stage Pump Rate Volume Stage Stage Time Cumulative Time
(bpm) (bbl), , (min) (min), ,
CW100 6 40 6.7 6.7
Drop Bottom Plug 3.0 9.7
MudPUSH XL 6 30 5.0 14.7
Tail Slurry; 6 49 8.2 22.9
Drop Top Plugi 3.0 25.9
Displacement 6 169 28.2 54.1
Bump Plugl 3 20 6.7 60.8
MUD REMOVAL
Recommended Mud Properties: 9.8 ppg, Pv =15-20, Ty=15-20. As thin and light as
possible to aid in mud removal during cementing.
Spacer Properties: 12.0 ppg MudPUSH* XL, Pv = 19-22, Ty = 22-29
Centralizers: Recommend 1 per joint across zones of interest for proper cement
placement.
'Mark of SchIumber§er
PHILLIP,., Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
Phillips Alaska, Inc.
Post Office Box 100360
Anchorage, Alaska 99510
May 29,2001
Ms. Camille Taylor, Commissioner
Alaska Oil and Gas Conservation Commission
333 West 7'h Avenue, Suite 100
Anchorage, AK 99501
(907) 279-1433
Re: Application for Permit to Drill:
KRU 2P-447
Surface Location:
Target Location:
Bottom Hole Location:
1017' FNL, 1606' FWL, Sec. 17, T8N, R7E
1661' FSL, 1478' FWL, Sec. 18, T8N, R7E
1513' FSL, 1191' FWL, Sec. 18, T8N, R7E
Dear Ms Commissioner:
Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well KRU 2P-447.
The well will be drilled and completed using Doyen 141. Please utilize documents on file for this rig.
Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an
approved and existing annulus on Drillsite 2P, or hauled to an approved Prudhoe Bay or GKA disposal
well.
The following people are the designated contacts for reporting responsibilities to the Commission:
A) Completion Report Sharon AIIsup-Drake, Drilling Technologist
(20 AAC 25.070) 263-4612
B) Geologic Data and Logs
(20 AAC 25.071)
Steve Moothart, Geologist
265-6965
If you have any questions or require further information, please contact Pat Reilly at (907) 265-6048 or
James Trantham at (907) 265-6434.
Sinlerely' ~-
James lrantham
Drilling Engineering Supervisor
ORIGINAL
American Express®
Cash Advance Draft
136
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PaY TO THE ...... "/¥-/~ ; '~: t" L-!,'~_~f ' ....... '~..'
orD~,o, ........... ;- /:.'_. ...... '!?,;~, d $ /~"'"" ~"'"':'
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:. ' ........ / .,'.': ,; .......................................... DOLLARS
Issued by Integrated Payment System, Inc.
Englewood, Colorado
Payable at Norwest Bank of Grand Junction - Downtown, N~.
Grand Junction, Colorado
PERIOD ENDING
,: l,O ~? ~,OO t, OO,: 5 5
NOT VALID FOR AMOUNT OVER $1000
'/ SHARON. AI~LSUP~DRAKE
"/ , ' '"' ~l
,... ...::...1.:,,'~. ..-,. :...,.,.,/',.~,
..,'.~ ,-.,.". ,. :':"' .... :.~"'~'.-.:'::"'Z~::".:.~: ',;;.._.,~
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TI,~NSMITAL LETTER CHECK LIKI
CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO
BE INCLUDED IN TRANSMITTAL LETTER
WELL NAME
CHECK 1 CHECK WHAT APPLIES
STANDARD LETTER
DEVELOPMENT
DEVELOPMENT
REDRILL
EXPLORATION
INJECTION WELL
INJECTION WELL
REDRILL
ADD-ONS (OPTIONS)
MULTI LATERAL
(If api number last two (2)
digits are between 60-69)
PILOT HOLE (PI-I)
ANNULAR DISPOSAL
( ¥~)NO
ANNULAR DISPOSAL
( ) YES
ANNULAR DISPOSAL
THIS WELL
DISPOSAL INTO OTHER
ANNULUS
"CLUE"
The permit is for a new wellbore segment of existing well
, Permit No, APl No. ~.
Production should continue to be reported as a function of
the original API number stated above.
In accordance with 20 AAC 25.005(0, all records, data and
logs acquired for the pilot hole must be clearly
differentiated in both name (name on permit plus PI-I)
and API number (50 -70/80) from
records, data and logs acquired for well (name on permit).
Annular disposal has not been requested...
Annular Disposal of drilling wastes will not be approved...
Annular Disposal of drilling wastes will not be approved...
(t/~) YES +
SPACING EXCEPTION
Please note that an disposal of fluids generated...
Enclosed is the approved application for permit to drill the
above referenced well. The permit is approved subject to
full compliance with 20 AAC 25.055. Approval to perforate
and produce is contingent upon issuance of a conservation
order approving a spacing exception.
(Company Name) will assume the liability of any protest to
the spacing exception that may occur.
Templates are located m drive\jody\templates
WELL PERMIT CHECKLIST_ , COMPANY WELL NAME 2-/ - ZS/' PROGRAM: exp
ADMINISTRATION
devv/ redrll serv
wellbore seg ann. disposal para req
1.
2.
3.
4.
5.
UNIT# ///~ ~'~ ON/OFF SHORE ~..~
Permit fee attached.
Lease number appro~ri~t~.~' ~ ?'.~'.~i'~. ,~' ~ ~'~ / ~~ ....
N
Unique well name and number .................. ~~ ~ ~ff /~g-~~',-& ~~ ~7~ff'~t~
Well lo,ted in a defined pool .................. ~
Well lo,ted proper distance from ddlling unit bounda~ .... '{~)~)N
.
7.
8.
9.
10.
11.
DATE , 12.
5--5i-o I 13.
Well located proper distance from other wells ..........
Sufficient acreage available in ddlling unit ............
If deviated, is wellbore plat included ...............
Operator only affected party ...................
Operator has appropriate bond in force .............
Permit can be issued without conservation order ........
Permit can be issued without administrative approval ......
Can permit be approved before 15-day wait. '
ENGINEERING
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...
DATE
22. Adequate wellbore separation proposed .............
23. If diverter required, does it meet regulations ..........
24. Drilling fluid program schematic & equip list adequate .....
25. BOPEs, d° they meet regulation ................
26. BOPE press rating appropriate; test to ~_~ psig.
27. Choke manifold complies w/APl RP-53 (May 84) ........
28. Work will occur without operation shutdown ...........
29. Is presence of H2S gas probable .................
GEOLOGY
DATE
30. Permit can be issued w/o hydrogen sulfide measures ..... ('"~)N
31. Data presented on potential overpressure zones .......
32. Seismic analysis of shallow gas zones.. ~ . . . ....... ,//~,,-~ N
33. Seabed condition survey (if off-shore) ............. ~ ~f' Y N
34. Contact name/phone for weekly progress reports [explo~ only] Y N
ANNULAR DISPOSAL35. With proper cementing records, this plan
(A) will contain waste in a suitable receiving zone; ....... Y N
APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N
to surface;
(C) will not impair mechanical integrity of the well'used for disposal; Y N
(D) will not damage producing formation or impair recovery from a Y N
pool; and
(E) will not circumvent 20 AAc 25.252 or 20 AAC 25.412. Y N
GEOLOGY: ENGINEERING: UIC/Annular COMMISSION'
Comments/Instructions:
0
Z
0
c:\msoffice\wordian\diana\checklist (rev. 11/01//00)
