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203-099
• • ~_. _~~ _-~. MICROFILMED 03/01/2008 DO NOT PLACE ~~` T' ~~: r ~,. ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc . . ~ IF' ~¡:;-::¡ ,...... , ."" r ! ~ IA d: ru UÚì11 œ (ñ'n ',- H' H!! o FRANK H. MURKOWSKI, GOVERNOR AI1ASIiA OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 December 14, 2005 Jim Weeks Winstar Petroleum LLC 311 C Street Suite 500 Anchorage, AK 99503 Re: Oliktok Point State #1 PTD 203-099 - -t' ,-,\,.',,11\1:,,: ~...J( . ~~," '~" . . \.~,'-U --'\~ '';'' "'(.....' ~~ . Dear Mr. Weeks: We have review the file for the referenced well, which contains a field inspection report and recommendation for final location clearance. The field inspection report shows the location to be in compliance with (20 MC 25.170 Onshore Location Clearance) and, therefore, the Alaska Oil and Gas Conservation Commission ("Commission") requires no further work on the subject well. Please note, however, that Winstar Petroleum LLC will remain liable if any problems were to occur in the future with this well. Accordingly, final location clearance is hereby approved for the above listed well. If you have any questions or need further information, please contact Jim Regg (907) 793-1236. cc: Randy Thomas cc: Steve McMains cc: Well File q ~ ''''-~ DATA SUBMITTAL COMPLIANCE REPORT 8/1/2005 Permit to Drill 2030990 Well Name/No. OLlKTOK POINT STATE 1 Operator CONOCOPHILLlPS ALASKA INC _Stlu.l }.. ~ J~ .{ 6~.3 J API No. 50-029-23160-00-00 MD 11 037 ~-- ND 6964./' Completion Date 7/9/2003 Completion Status P&A Current Status P&A UIC N ------------ ----- -- -- --- REQUIRED INFORMATION Mud Log No ¡'\J2t {\~I.L\r'¿ Samples No Directional surv~___~: ..:: DATA INFORMATION Types Electric or Other Logs Run: Text to lengthy see 10-407 Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Logl Electr Data Digital Dataset Type Med/Frmt Number Name I i :11,·ED C Asc 12022 LIS Verification L¡ -- I ! IIšt) C Pdf 12022 Directional Survey I ¡-ED C Pdf 12022 I nd uction/Resistivity ¡ED C Pdf 12022 I nd uction/Resistivity ~ì ! ¡ ÆD C Pdf 12022 Neutron i i ! i·- Il ED C Pdf 12022 Neutron Fr \ ED C Pdf 12022 Density ~~. i ¡ED C Pdf 12022 Density Name Interval Start Stop Log Log Run Interval OHI Scale Media No Start Stop CH Received Comments 6470 11040 Open CWLS LOG, ( MWD = RWD = Recorded while drilling). 0 11037 Open 25 Final 129 11037 Open RWD = Recorded while drilling. ORD, CCN, DIRECTIONAL - MD 25 Final 129 11037 Open RWD = Recorded while drilling. ORD, CCN, DIRECTIONAL - ND 25 Final 129 11037 Open RWD = Recorded while drilling. ORD, CCN, DIRECTIONAL - MD 25 Final 129 11037 Open RWD = Recorded while drilling. ORD, CCN, DIRECTIONAL - ND 25 Final 129 11037 Open RWD = Recorded while drilling. ORD, CCN, DIRECTIONAL - MD 25 Final 129 11037 Open RWD = Recorded while drilling. ORD, CCN, DIRECTIONAL - TVD -------------- -- Sample Set Sent Received Number Comments Well Cores/Samples Information: DATA SUBMITTAL COMPLIANCE REPORT 8/1/2005 Permit to Drill 2030990 Operator CONOCOPHILLlPS ALASKA INC Well Name/No. OLlKTOK POINT STATE 1 MD 11037 Current Status P&A ND 6964 Completion Date 7/9/2003 Completion Status P&A ADDITIONAL INFORMATION Well Cored? y íÐ Chips Received? -- Y 1 N - Daily History Received? WN '1JJ/ N Formation Tops Analysis ~ Received? Comments: Compliance Reviewed By: I \ \ ~ \ Date: API No. 50-029-23160-00-00 UIC N --~- -- - --- ------- n;~---:--u~ --- ---- ') 01 -1-~: ----,-:.- -- ,,'- I At\)~ .> .J: ~, Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocóPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 August 7, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for Winstar Oliktok Point State #1 (APD # 203-099) Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits its Well Completion Report for the work it performed in drilling its Winstar Oliktok Point State #1 well from KRU 3R Pad in the Kuparuk River Field on the North Slope. The well proved to be non-productive and has been plugged and abandoned. The abandonment was witnessed and approved by AOGCC inspectors. Please find attached the following information for you r review: 1) Form 10-407 Well Completion or Re-completion Report and Log 2) Updated wellbore schematic 3) Well Operations Summary 4) CD containing the wellbore directional survey and the gamma ray, resistivity and neutron-density logs recorded while drilling. 5) Documentation photos of the cutting off, marking and burial of the abandoned wellbore at the surface. If you have any questions or require additional information, please contact me at 265- 6830 or Bill Penrose at 258-3446. Sincerely, '~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling AUG 1. 1 2003 gl ORIGINAL I STATE OF ALASKA , ALASKA L.L. AND GAS CONSERVATIO~ ~OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG OIL: GAS: 2. Name of Operator ..1!'1 N~T N1 N:Tn-olCUM, Llv'" 3. Address 3111 C STREET, SUITE 500, ANCHORAGE, ALASKA 99503 4. Location of well at surface 1693' FNL, 2342' FWL, Sec 9, T13N, R9E, UM At Top Producing Interval N/A At T,9)~~~YJ~ ~FSL, 1774' FEL, Sec 33, T14N, R9E, SUM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 38.8' DF (AMSL) ADL 388584 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 6/26/03 7/6103 7/10103 17. Total Depth (MD+TVn! 18. Plug Back Depth (MD+TVD) 19. Directional Survey ( 11 ,037'MD/6,964;TVD'} Surface Yes: X No: 22. TYpe t:.lectric or Other Logs Run MWD Directional in 12-1/4" hole section, MWD DirectionaI/PWD/GR/ResistlDensity-Neutron in 8-1/2" hole section 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM 33' 112'MD 33' 1 ~D (,.~ 1. Status of Well SUSPENDED: ABANDONED: X SERVICE: ~O~ ¡;4,'jJ,f.J ,4 4s;c. ~. In ./ H'~ Classification of Service Well 7. Permit Number 203-099 8. API Number 50- 029-23160-00 9. Unit or Lease Name Oliktok Point State 10. Well Number No.1 11. Field and Pool Kuparuk River Oil Pool 15. Water Depth, if offshore NIA 20. Depth where SSSV set N/A CASING SIZE 16' HOLE SIZE WI. PER FT. 62.58 Ibltt 40 Ibltt GRADE H-40 L-80 24" 12-1/4" 9-5/8" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 25. SIZE N/A 16. No. of Completions None 21. Thickness of Permafrost 1960' CEMENTING RECORD AMOUNT PULLED 250 sx Arcticset Cut off 3' below tundra 826 sx Arcticset Lite + Cut off 3' below tundra 459 sx LiteCrete TUBING RECORD DEPTH SET (MD) PACKER SET (MD) No perforations in this well 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) N/A PRODUCTION FOR TEST PERIOD => Flow Tubing Casing Pressure CALCULATED Press. 24-HOUR RATE => 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. r-<tc.o",,~~ cc~ Q b ocr (À. '\ ~ . ~~~ ô-L~¡;?I. µ-~ ~~ ,(~ 27. Date First Production Date of Test NIA Hours Tested OIL-BBL GAS-MCF OIL-BBL GAS-MCF No cores taken in this well. Form 10-407 Rev. 7-1-80 ---"--""-'-~":''':"'''~ .\ CO,,\~r;1 [::T\(',N 'I, \d t- 1_, ,.P , ~ \1-1~~- \ \ -~~\ \~-'tI....!,~,\,...~,...... . ADS 1 ·Al lÐWf CONTINUE@Rttf tJ A ~ IRIIII6BfL c.,(Í W A TER-BBL CHOKE SIZE GAS-OIL RATIO W A TER-BBL OIL GRAVITY-API (corr) AUG 1 1 2003 Submit in duplicate 29. NAME Base Permafrost Top West Sak Base West Sak Top HRZ Base HRZ Top Kuparuk A1 Sand Base Kuparuk ) ) 30. GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Interval not logged Interval not logged Interval not logged 10329 10486 10910 10981 6402 6527 6862 6920 31. LIST OF ATTACHMENTS Wellbore schematic, Summary of Rig Drilling Operations, P&A Photos, Logs, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~ Form 10-407 \ ~Title 81ì(03 Drillinq Team Leader Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other space 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 productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". la":;) I " ~l~ " 'M;. (~ \ ~",1",'¡;' , f"\ ~ r4 f·~· ~~~ i I'~ï t\~ '\~ki ~ ., ,J ,) ) Winstar Petroleum, LLC Oliktok Point State #1 Well Operations Summary 0000 hrs to 2400 hrs, 6/25/03 MW: 8.8 ppg Vis: 200 sec Accept rig at 1900 hrs, 6/25/03. N/U diverter, fill pits and mix spud mud. Load pipe shed, hold pre-spud safety meeting. 0000 hrs to 2400 hrs, 6/26/03 MW: 9.0 ppg Vis: 143 sec Function test diverter, M/U BRA and clean ice out of conductor. Spud well at 1200 hrs. Directionally drill 12-1/4" hole from 110' to 1,000'MD. 0000 hrs to 2400 hrs, 6/27/03 MW: 9.4 ppg Vis: 123 sec Directionally drill 12-1/4" hole from 1,000' to 2,720'MD. Lost 400 psi pressure. POR and found washout in UBRO sub. Replace sub, check bit and Rill. Directionally drill 12-1/4" hole from 2,720' to 2,746'MD. 0000 hrs t02400 hrs, 6/28/03 MW: 9.4 ppg Vis: 133 sec Directionally drill 12-1/4" hole from2,746' to 5,000'MD. 0000 hrs to 2400 hrs, 6/29/03 MW: 9.5 ppg Vis: 146 sec Directionally drill 12-1/4" hole from 5,000' to 6,335'MD. 0000 hrs to 2400 hrs, 6/30103 MW: 9.6 ppg Vis: 78 sec Directionally drill 12-1/4" hole from 6,335' to 6,519'MD (9-5/8" casing point). Short trip to RWDP (bit at 1,078'), then trip back to bottom with no problems. Circulate hole clean, POR, LID BRA and prepare to run 9-5/8" casIng. 0000 hrs to 2400 hrs, 7/1/03 MW: 9.6 ppg Vis: 46 sec Run 134 joints of9-5/8", 40#, L-80, BTC casing to 6,512'MD, 4,215'TVD. Circ and cond mud for cementing. Cement casing wi 826 sx Arcticset Lite lead followed by 459 sx Litecrete tail. Displace with 9.6 ppg mud using rig pumps. Shut down at calculated volume half way through shoe track - did not bump plug. Check floats - OK. CIP at 1850 hrs. N/D diverter and start N/U BOPE. 0000 hrs to 2400 hrs, 7/2/03 MW: 9.6 ppg Vis: 64 sec N/U and test BOPE. M/U 8-1/2" BRA and Rill. P/U add'15" DP, cut & slip drilling line. Tag up wi bit at 6,396'. Circulate csg clean, attempt to test csg 3 times wlo success. ) ) 0000 hrs to 2400 hrs, 7/3/02 MW: 9.5 ppg Vis: 85 sec POR and SIB BRA. PIU retrievable test pIa and Rill. Test port collar at 957' - OK. Rlli, test casing shoe -leaked below test pIa, OK above test pIa. Test csg to 2,500 psi and POR. LID pIa, PIU BRA, Rill. Drill out shoe track and 20' of new formation. Perform LOT to 15.8 ppg. Directionally dri1l8-l/2" hole from 6,539' to 6,560'MD. 0000 hrs to 2400 hrs, 7/4/03 MW: 9.65 ppg Vis: 85 sec Directionally dri1l8-l/2" hole from 6,560' to 8,875'MD. 0000 hrs to 2400 hrs, 7/5/03 MW: 10.05 ppg Vis: 76 sec Directionally dri1l8-l/2" hole from 8,875' to 9,922'MD. Make short trip to 9- 5/8" shoe. Raise MW to 10.0 ppg. Directionally dri1l8-l/2" hole from 9,922' to 10,158'MD. 0000 hrs to 2400 hrs, 7/6/03 MW: 10.8 ppg Vis: 53 sec Directionally dri1l8-l/2" hole from 10,158' to 11,037'MD, TD. CBU and noted increase in chlorides and slight flow from well. Gradually raise MW from 10.0 ppg to 10.8 ppg while monitoring well. 0000 hrs to 2400 hrs, 7/7/03 MW: 11.9 ppg Vis: 59 sec Raise MW from 10.8 ppg to 11.7 ppg while monitoring well. Well static. Wipe hole 10 stands to 10,110'MD. Didn't take proper fill. Rlli, raise MW to 11.9 ppg and monitor well - well static. POR, LID BRA. 0000 hrs to 2400 hrs, 7/8/03 MW: 11.9 ppg Vis: 60 sec Install 2-7/8" rams. PIU and RIR wi cement stinger. Set balanced cement plug #1 11,037' - 10,700'. PIU and pump around to clear DP. POR to 6,938' and spot high vis pill 6,938' - 6,350'. POR to 6,540' and set balanced cement plug #2 6,650' - 6,350'. PIU and pump around to clear DP. POR, LID DP. 0000 hrs to 2400 hrs, 7/9/03 MW: 11.8 ppg Vis: 57 sec WOC Plug #2. Rlli and tag cmt at 6,425'. Plug top too low. Pump add' I 6 bbls cmt on top of Plug #2. Est TOC at 6,350'. PIU and pump around to clear DP. POR, LID DP. LID DP from derrick. Rlli to 2,103' and displace well above that point wi 9.7 ppg CaCI brine for freeze protection. POR. Insert 9- 5/8" rubber top cementing plug in casing and push to 270'. Place cement from 270' to ground level. 0000 hrs to 0300 hrs, 7/10103 MW: 11.8 ppg Vis: 57 sec RDMO Doyon 141. Rig released at 0300 hrs, 7/10103 7/15/01 Area around well excavated and all well casings cut off 3 feet below original tundra level. 18" diameter plate welded across top of casing with State- required information bead welded to it. Well with marker plate buried with gravel up to current pad surface elevation. 16.. X 30" insulated conductor @ 110' TAM 9-5/8" Port Collar Std Grade BTC Threads (@ 941' MD) Surface csg. @ 6512' MD 9-5/8" 40# L-80 BTC ) Oliktok Point State # 1 Final P & A Schematic All csg cut off 3' below tundra level i~~~;:~'!;¡:~t~';~~~}~·t~~~~~::~~:;~~t~~;2~~·~; i~\(' '~:1¥ . ,1,:1·· '1"~' ....1"'.-· -I) ";"I~ ......,\,. ,-,,-\~ ~~.. <-f'¡· . '11 "';- '~~:"~" '~".::. !'.·¿:.:::,aeMð.~;.,-.::.;..,':,?~~::,,,;'" .~:.::::. ',' ,.~.¡, :.~...-, ,'¡' ,.-·...~;~'1.~. ;'.:' ".,.~~.., :I'~' f. '..;'~..~~ ,~::.f·~ ";:":.;':1':' ~.): ,:.'. '~'~"'·'~,"~)"'~'>'7·~.3~:·~·2·~:)~ '~~r) .." "~~~.,- ""~, '" .:.t.. I, :...... .' .",.:,~, , ,~. ".I"~ "_.., :. .~~'~~.. .~··L.. :I:~~ .1\>;:-..;,,.., ~).-;~.:~'T .:I'~t·J~:~.r~ ", . Itr..' .., . ææ'~ ~ -,- :~., ,.- .. lÆ ),'..---" ",,\.. ··t 1~'''i-~ ,¡. ~ .~. ~~"'"'' ~". ;...;.. ~ ~,,,,"'''::i'~. .'; .J.~I~:.I 1.'7 ~~..,": ~~r~ .:, or '~"i .'.;"....~ 5,;:\~ .".,~ ,...., ." ¡"'....'" . '~"',: "'~'. \ '1/' ,.;," _,~~;~~~;;~{.~;:!:t~~~~~7;r~i~~:·~T:~~,~; ~1· '~:"~} ~ .L ..f1~~.L o. I.. "i~ ..,,~ir;,'... ~ ht .~~".,.., ... "l~ :~;.,:.~~~.._.I . + ..~ .'- ,.... . :.1 ..," .'1.';. ~.,;",",~~ .;.' <.~ ~.;,y ¡ ~fl ~~n~ E .:;:-.. }.·2 .~:.:. I,i)~':~ -' ~:.~. ~._._._._._._.~_._.__.-I:,: .~.~). .. ,,~ ~.. '0 .~.i '.'.mJ¡: 12.1 ppg ~;!~¡;~: ... ~ ~1..._" ...~...~ mud ~':':I':;,! ..'~ "'c~ ~t '\.. ..;....~.:~ ~~;::.~~ :,.":~~ " '. .' . ......., 'J" .... ~I~' "1-' r'¡·~.('· ...,..~.. t..J- ...1. "'1'.,J,..t"~.,..f" . ..... ,~.:'.::;:' ,:...~..:~.-:....-?:' ~::::.:~.:~,;...~:o:;:~.:::;.; '...<~,;- -,..... - .... '. ':'~'. ;'.'.;'. ..... '~~..... ..... . \. J ~ ., '.:: ,'. .,: ' .'. ":.-; .. '.~', -. ,:., .,~ '....J. .' '>,~.; "..'¡ '\~"'¡;"-":;-':11," ·""_'·~':_-'·o, :. . '~;'''',.' ;>;,~.~"\,., enl ,-~."";~:.':~ ~.r'~~~ \:..' ". .,::."..~~~ "..- ,- "0 . \.~... . ..~," :'. . ~:~~ 1!~,_'; ... ~..... ,...11,_.",., '41"~""'" . '," ~ "',} ,,'ß. ..-...':' ..... """r";!; ,-.... .'~~';,.,., '..~, ,:~",- ~...:: ;', '. t: ';. ::"', '0, ..:;" :'_" .'~ ~.. '~"'\ ~~."- .- . ".--, 0,; ,..~".\. /i i~;~~~1¡\I;f~¡~1~ -.:; 12.1 ppg Mud iflllii TO @ 11 ,037'MD, 6964'TVD ) ~~~ßM TOC Plug #3: Surface Bottom of Plug #3: 270' MO Base of permafrost: 1960' MD, Brine @ 2103' TOC Plug #2: 6350' MO Bottom of Plug #2: 6725' MO TOC plug #1: 10,700' MO Top Kuparuk "A" Sand: 10'900' MD Bottom Plug #1: 11,037' MD, TO Bill Penrose 7/29/03 ) ') Bill Penrose From: Sent: To: Subject: NSK Fld Drlg Supv [n1335@conocophillips.com] Wednesday, July 16, 2003 7:14 AM Scott L Lowry; Bill Penrose OPS#1 P&A Complete ~ ~ ~ ~ OPS #1 3'below tundra OPS#lP&A OPS#lBackfiII071503. leveI.JP... Complete071503.JPG JPG 2003. Witnessed by AOGCC PI, Jeff Jones. OPS# 1 Marker071503. JPG OPS#l P&A Completed on July 15th, (See attached file: OPS #1 3 'below tundra level.JPG) (See attached file: OPS#lP&A Complete071503.JPG) (See attached file: OPS#lBackfill071503.JPG) (See attached file: OPS#lMarker071503.JPG) Bobby Morrison/Nick Scales Drilling Field Supervisor 659-7726 pgr 243 Email¡ n1335@conocophillips.com 1 Page 1 of 1 file://C:\WlNDOWS\Temporary Inten1et Files\OLK6001 \OPS#lMarker071503.JPG 7/28/03 7/28/03 file://C:\WINDOWS\Temporary Internet Files\OLK6001 \OPS #1 3'below tundra level.JPG Page 1 Qf 1 :\ ,,~ I ¡+~t;2~::¡~.j?3~;,iJ+:~,:~)~,;" 'c,,"fi,'""" :." "+~¡ ,:J .. . ,~¡!~.::~ .".". '"'I~1: I":'r.;::+..~:~:LlJ,' LfJ··,( 1..1 .t11 ,.",'''.-h",\,·;.¡¡·!)',~;·.:::,J.''''~I''VI .'~"r ,I ""1,1/ ",~,',,~::~lii,~"'f'i:v;\¡, fW .. ·'4'~~~):~, it "!".' ':', ',:':.,.; ··...11',.. il',,-,'" '''j<''': 'l :;.'./1 ':~":':¡":;hi::,:y':' "'":;"",,,.' "~, ··':'Ie--,;·I,' .' 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'r J~''':::'iIL:!!.:-t\:',,:"...\,'''~'~'~~..:::ç.~~~:-,..~. .l"'?<·,r....:~S·...;¡. '-', ~...,...;~.)..q........I:..~,"_.~~t.~:'ft;.~ ~ ..~.:~ r .... ..,....... 10" .."")r-. .' . ...~..... 01...... _..... rC· _,.......r:q:u.p-~,;J-_- ,.... . R.... _./': ,:~~ -r~ .... ~Ii..'" '. _ ..-,;'r,;¡ iii '..... ~ t'. I'..... rr.:-,,~~I.., :¡,"~:. . ~ .." "i"....... ..." , -;:r:,. ~,..,.;:..,..f"t,,1,.::~~-""~" .,.; ¡A·,·f,;.... ~. ·':r..;...~...ßr..·'II:.....r."~·...._,_.~.... ~~~~*,..,:.::..._~~i.~}~;)~~¡~~~_.~. -¿~.,~'. ....::.- ,<,.':;..~t,.~" ::'I....L' "'~,;~..~":""T~~r1~.~~......'i: ~._.JI ßT;.~.'~'t""':;. ;~.~,. _..... '.'" '..' ,..1 '1'\-" ..... ·...'r.-...-... ..~...........::~....qo~~..,."".I::""¡ ~,,.1'i ~"!cN~!:.t:'.,..~ c'o.~,,.....~. )o.~t· -;:-'\ril' ..¢'...._~ .,' ~f'.:""...' ~I.:~~...r\ "'~~1" ~"1~~ .~~::........,..~~~.. ~.'"~~~~~:...,.it:~..:..~~~..:-.~~~~~~ ~ p~ ~,II , ~...:- ~..'I. r.,,..r-,,,·~. ._'.~/_ .~I:;"-"'" . ....:..~ ".,... '"., ,~~ ·~~?~~~?,r{~ :.:!""=;';'::;' .~~< :,,~"'!:'. ~~~;1·,,".::_~.., ...,.... W"';~~~~'1I:-'~~-'-S:""'~J""':'~'~r ~~~~..~.,..;~:~~~'i...\.~:,')1 T"". ~.r- ~ ]1'-~;' ,,'...r:... -,..~._'-:~.......a ~·J~~·rI '..{ ... _JO" "r.i~' '~ ,I ~JI..&...9_·"IY...,',:~~.i~.t~;J....' ,,« J"",. . . ~"'~ .~~~~. ~::i~~~"')"~j~.:,.~~·;p-.1~;'\<·~ ':h~1:¡.;". r. -Mj ;~.r~~, , _ ~:''fí..;.~~..t:''S-:!;i~IC.I:.....~: ~r~~M-~_~.-:-_.~~~~ '\~""Ð. . -:-..:_ ~~~ file://C:\WINDOWS\Telnporary Internet Files\OLK6001 \OPS#lBackfill071503.JPG 7/28/03 ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission THRU: FROM: TO: Randy Ruedrich Commissioner t(Í i~t\ù ) Jim Regg . ¥-Ill i\ P.I. Supervisor / Jeff Jones Petroleum Inspector Section: 9 Township: 13N Lease No.: ADL 388584 Drilling Rig: NIA Operator Rep.: Nick Scales (Conoco-Phillips) CasinQlTubinQ Data: Conductor: 16" x 30" ins. O.D. Shoe@ 110' MD Surface: 95/8" O.D. Shoe@ 6512 MD' Intermediate: O.D. Shoe@ Production: 0.0. Shoe@ Liner: 0.0. Shoe@ Tubing: O.D. Shoe@ Type PluQ (bottom up) #3 to Surface #2 Balanced #1 Open Hole Type PluQ Open Hole Perforation Annulus Casing Stub Surface DATE: SUBJECT: NON- CONFIDENTIAL July 15, 2003 Plug & Abandonement Oliktok Point State #1 Winstar Petroleum LLC Kuparuk River Field KRU 203-099 Range: 9E Rig Elevation: 38.8' DF Meridian: Umiat Total Depth: 11,037' MD/6964' TVD CasinQ Removal: Casing Cut@ 8' MD Feet Casing Cut@ 8' MD Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Founded on Bottom of Cement 200' MD 6,650' MD 11,037' MD PluQQinQ Data: Top of Cement Depth Verified? Surface Yes 6,350' MD No 10,700 MD No Balanced Balanced Bottom Founded on: Bottom Bridge plug Balanced Retainer Verified? Drillpipe tag Wireline tag C.T. Tag No Mud Weight above plug Steel Cap 12.1 PPG 12.1 PPG Pressure Test Applied July 15, 2003: I traveled to Conoco-Phillips Alaska Inc.'s 3R Pad in the Kuparuk River Field to witness the suface abandonment of the Oliktok Point State #1 well. Nick Scales (Conoco-Phillips Alaska Inc.)was the representative for the abandonment work. The intermediate plug depth (#2) placed in the well was witnessed by AOGCC Inspector John Spaulding. On my arrival, the well had been excavated and the casing strings cut to a depth of 3 +1- feet below the 60" thick production pad grade. I requested that the casing be excavated c//· and cut off at 3' below original grade (tundra) and was accomodated. Cement was visible to surface in the top of the casing strings and a steel cap I marker plate displaying the required well information was seal welded to the top of the 30" conductor casing. The excavation was then backfilled and slightly mounded with gravel and should settle to the required condition. A P&A wellbore Schematic provided by Mr. Scales and location photos are attached for reference. Summary: I witnessed the surface abandonment of the Oliktok Point State #1 well in the Kuparuk River Field, KRU. f£. Randy Thomas (Conoco-Phillips Inc.) Distribution: Bill Penrose (Winstar Petroleum LLC) orig - Well File c - Operator c - DNR/DOG c - Database c - Rpt File c - Inspector Rev.:5/28/00 by L.R.G. Attachments: Well bore P&A Schematic (1) Location photos (3) P-A KRU Oliktok Point State #1 7-15-03 JJ1.xls 7/21/2003 Bill Penrose 6/07/03 Bottom Plug #1: 11,037' MD Top Kuparuk "A" Sand: 10'900' MD TOC plug #1: 10,700' MD Bottom of Plug #2: 6650' MD TOC Plug #2: 6350' MD Base of permafrost: 1960' MD Bottom of Plug #3: 200' MD TOC Plug #3: Surface ~.IIRATRDL.EI(M . ' I - -, , TD @ 11 ,037'MD, 6964'TVD :~~I~\;t~if·~·~~;j;~~~~:~:~ :. 'I'" r.. 11 .pJ!J9; 'II" r.' '1' -' J~:~1~~~~J~~1:~~~, ( 12.1 ppg Mud W£ '¡.:", .~ ~,~ ....!? :i.. ..;1:..:.,': t·'·L·..! '~:'7.'S;"~~L"" "~ ~~....:.: ~~. ··,\::'~;,·.r:.-.o:t·'·~··...· '\:"'~"'~-;"~' '.\:~ ~,., .:I~"N'" 'L, - .",.. -L ~.. .~ ~ ~',',I ;,,'.":'.- """ 'ç!) ;. ".,.,':.' ~ "!I.'~""'~ ~ :~. :.....;.. :. ::-.:~ .'! ~ ~:. :..;:~.. :~~. ":..~ ~ i ~.'. ;....; ~ I· ~ ::1· ':'f~', ~·";.~'C"-·..'·· . tl~L. ~!.:,.;1,·'··~·,.:~!·1 ~:> :.~:.> ~-:'~"'~.f;·r~m~~ . ::.....~ ;';';'~~':":~ I-··';~:,d~ '.,~.~r,'·:l"': }.~.::.+.'~ . ;~. . ,~.{;!. ~;.~:J I ~."'..o..~J"I.o.. .' 1..1...··~ll..!I.. . \~. .''2t~ ~ .'::': ~"l.l·:t.t';i:~,,:t-~_~.~>::·.'f.¡.::/ï:\~I·~J ...J ~ ~.~ '''f~.....':-~ ~~', ';/.'-i.·~i~ ,. ~~~~ ~~'''''.,,:~'>¡.~''f...,...¿ :,..~.~...~..:. ~'i.,,"t...,.~ :)~~. ';".~ I' ~" .,~ ~',\,~,-:" ~. ..-., r ¿"1'~'¡¿' "--~>--.".~~ ~'ø.'I/>..,. '~~" . :,..;~... "~""··:':!.'-::?-:'~I~'~'·· ..3$: ..11~" . ., - '.. . '; :'.' 1'.',' ..~ '~I.~ ~'.' , . ~,,~ "... ,'''' '"J'. '·".~"'o(.'7 ~:,,·~.r :~"i':~' .:~': ". ....... ........,I.'~. "., '::!~.·;I· ., , . - .. . . ,. --I}t~,~~ [it ~~n~ I¡~ :~;...I I;:··Y'·' .' .,::. ~.._._._._._._._._._._._.~'.'" '.' ..',j.' ~.~ ~' ~O' ~~:~tt 12.1 ppg J~~~~: ';.~.....;I mud 1"1.!··~ ,.. .\ t ~ I:?: .'q \~~r)~I.:;.·..¡.; ".>.~.-;":.'...-. ;. ',.' ¡t.-.:..·lt~,.:, ;'';; \) ,I~ ,.~:,.,y."':I:.'-:I;,..,:'5..'L '1:' ~-r ·,:.;-:tI::·!', '.:;'~ ~:I'::\'~'; "~:¡~}'\' .;.\i~·~:.~;~:~';V"'~~ :·1::::;·:, <.;.:.~ ~ (,~i'j"'li¡;~'~C"~J:..-:...:£rf··jf.~ I}-'--:r.lr~~ ;.....:~. '~':o/~';;;'<"'_:'~"'~' ~m~.., ":'~:'';';~.''>¡';~~:L.~ .1.1·- ~··''\':·· :··~··'''·~\'···t 'j.....~ '''''~I~'J...·J". : 1.1':"~~"."..J .....,~···~f~; ·:~';':-:·.\d'· ;'.~ ',·.f··~I'''' "- .....~'~...,.~,.'''''. ,..,.....' ....,..,...,~ t'ED"'·· .¿,.~. l 'l.~' ....:.,.."1( ''!t-...Iõ ." '1 ,~",~....','-c. " ",'.." ';" '\.:-~"·'·í..·;'f'1 ,\Æ,;:" .".,.~.,.,.,..·....·1..,.~ '. _~. ~.:.. ~~~')~~~~f=. ,,1 ~~~~;I!.~~·.:~~.~;~.;;;~· ..).~~ .:: ~'1:\ f~:f."1'""1I ,I.,~~!~~l~f:¡;~ ~~iJ~~~Jl~~; Proposed P & A Oliktok Point State # 1 Surface csg. 9-5/8" 40# L-80 BTC ( 6512' MD) TAM 9-5/8" Port Collar Std Grade BTC Threads ( @ 941' MD) 16" X 30" insulated conductor @ 110' O~ï{:to·( ?t State #~ "?~:J 203-099" , / - Drilled from KRU 3R pad - Cut 3 ft below tundra - Backfilled and mounded Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ~ ConocoPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 July 8, 2003 Ms. Sarah Palin, Chair Alaska Oil and Gas Conservation Commission 333 West 7ili Ave., Suite 100 Anchorage, Alaska 99501 RE: Sundry Notice for Permanent Plugging and Abandonment; Winstar Oliktok Point State #1 Dear Ms. Palin, ConocoPhillips Alaska, Inc. hereby requests approval of the attached program for permanent abandonment of the recently drilled Winstar Oliktok Point State #1 well. We have already commenced setting the bottom plug per a verbal approval received from the AOGCC's Mr. Winton Aubert. Pertinent information attached to this application includes the following: 1) Form 10-403 Application for Sundry Approval. 2) Plug and Abandonment Procedure 3) Cement plug formulations and volume calculations. 4) Proposed P&A wellbore schematic. If you have any questions or require additional information, please contact me at 265-6830 or Bill Penrose at 258-3446. Sincerely, CONOCOPHILLIPS ALASKA, INC. " <4 \ ~ Randy Thomas GKA Drilling Team Leader R' :)EI(f~E [¡' \', . ""'" 11 . 11 \. 1,-' C") '= ~",¿7 'I' 1¡"'~" tl :'I!':I.~ :~I '. ii\,:t.~I" J~..:.' ~ JUL 0 B 2003 J~I21s~m Oil &! enclosures cc: Mr. Jim Weeks - Winstar Petroleum, LLC ORIGINAL vJ6.A- 1/ ! I z.oo·~ Ð~ 7/ c:f'/3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 13. Attachments . [ X] Description of Sumary Proposal ,/'1 14. Estimated dßit§ f¢ commencing operation J .JfY 7;t?H03 /f 16. If propo~L$š verbally approved Winton .l\ubert July 6, 2003 Name of approver Date Approved Contact Engineer Name/Number: Bill Penrose 907-258-3446 17. Signed ~ t ~ Randy Thomas Title Kuparuk Drilling Team Leader Commission Use Only Notify Commission so representative may witness , Plug integrity X BOP Test Location Clearance X Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commission ~ ~~.. Commissioner Form 10-403 Rev. 06/15/88 ).. ORtGtNA- 1. Type of Request: [X] Abandon [ ] Alter Casing [ ] Change Approved Program [ ] Suspend [ ] Repair Well [ ] Operation Shutdown 2. Name of Operator WINSTAR PETROLEUM, LLC 3. Address 3111 C ST., SUITE 500, ANCHORAGE, ALASKA 99503 4. Location of well at surface 1693' FNL, 2342' FWL, Sec. 9, T13N, R9E, UM At top of productive interval 649' FSL, 1800' FEL, Sec. 33, T14N, R9E, UM At effective depth 839' FSL, 1757' FEL, Sec. 33, T14N, R9E, UM At total depth 839' FSL, 1757' FEL, Sec. 33, T14N, R9E, UM 12. Present well condition summary Total depth: measured true vertical measu red true vertical 11,037 feet 6,964 feet 11,037 feet 6,964 feet Effective depth: Casing Length Size Structural Conductor Surface Intermediate Production Liner 71' 6,473' 16" 9-5/8" Perforation depth: measured N/A True vertical NIA Tubing (size, grade and measured depth) NIA Packers and SSSV (type and measured depth) NIA Conditions of Approval: RBDMs 8Ft JUl O!.} 2003 [ ] Plugging [ ] Time Extension [ ] Perforate [ ] Pull Tubing [ ] Variance [ ] Other [ ] Re- Enter Suspended Well [] Stimulate 5. Type of well: 6. Datum Elevation (OF or KB) [ X] Development 38.8' OF (AMSL) [ ] Exploratory [ ] Stratigraphic 7. Unit or Property Name [ ] Service Oliktok Point State 8. Well Number NO.1 -9. Permit Number / 203-099 10. API Number /' 50-029-23160-00 11. Field and Pool Kuparuk River Oil Pool Plugs (measured) None Junk (measured) None Cemented MD TVD Grouted to Surface 826 sx Arcticset + 459 sx LiteCrete 110' 6,512' 110' 4,219' JUL 0 8 Z003 ~gi!" [ ] Detailed Operations Program [ ] BOP Sketch 15. Status of well classification as: [X] Oil [ ] Gas [ ] Suspended Service Prepared By Name/Number: Bill Penrose 907-258-3446 1('8(ð? Date ¡Approval NO.~ 'tOl Date Z7/ Ø/a3 Su ~ In ;¿;p~cate Oliktok Point State #1 Plug and Abandonment Procedure 1. Contact AOGCC inspector to witness job. / 2. PU a minimum of 500' of cement stinger w/ slotted flow diverting joint on bottom. 3. RIH with stinger and 5" DP to TD. 4. Circulate and condition mud to obtain consistent mud weight in and out. PluQ # 1 (PluQ Across Kuparuk Interval) 5. Spot balanced cement plug from TD at 11,037' to 10,700' to cover the Kuparuk sand ,,/ interval. (see cement calculations) Reciprocate pipe until cement reaches the end of the plug-back string. Spot plug at 8-10 BPM. 6. Pull stinger and DP out of plug no faster than 1 stand per 2 minutes. Pull out of hole to +/- 10,600' MD and pump 25 bbls at maximum rate to clear the drill pipe. /" 7. POOH to 6950' MD and spot a weighted (1 ppg over mud weight) high viscosity pill from 6950' to 6650' MD. PluQ # 2 (CasinQ Shoe Plug) 8. POOH to 6650' MD and circulate and condition mud to spot plug across the 9-5/8" surface casing shoe. Reduce the YP to 15-20. Balance mud weight in and out. 9. Spot balanced cement plug from 6350' MD to 6650' (see cement calculations). Reciprocate pipe until cement reaches the end of the plug-back string. Spot plug at 8- 10 BPM. 10. Pull stinger and DP out of plug to 6200' MD no faster than 1 stand per 3 minutes while pulling out of cement. 11. Circulate up spacers and contaminated mud/cement the long way at maximum rate. ,,/ 12. POOH to 2000' (approximate base of permafrost) and displace well above this depth / with 9.7 ppg NaCI brine viscosified with Flovis to a YP of 15-20. Plug # 3 (Surface PluQ) 13. POOH to 200' and spot balanced cement plug from 200' MD to surface (see cement calculations). Reciprocate pipe until cement reaches the end of the plug-back string. /' Spot plug at 8-10 BPM. 14. Pull stinger out of plug to surface no faster than 1 stand per 3 minutes while pulling out of cement. Flush cement stinger and BOP stack. 15. N/D BOPE, RID Doyon 141 and release rig. 16. Cut starting head off of casing and weld a flat 18" diameter (minimum), ~" thick (minimum) marker plate across the top of both of the casing strings with the following information bead-welded onto it: ConocoPhillips Alaska, Inc. prD No. 203-099 Oliktok pt. State #1 API No. 50-029-23160-00 j' 17. Remove cellar and backfill with gravel around the abandoned well to slightly above the level of the pad to allow for gravel settlement without allowing water to pond. Oliktok Point State #1 P&A Cement Requirements Cement Plug #1 (Plug Across Kuparuk): 10 bbls CW 100 ahead of cement 32 bbls (155 sacks) Class G + additives @ 15.8 ppg (35% excess cement - batch mix cement) 1.5 bbls CW100 behind cement to balance plug (verify volume of CW100 to balance) Displace wI mud (cut displacement 2.5 bbls short of calculated balance point) Calcu lations: (11,037' - 10,700') x (0.3941 cuft/ft) x (1.35) 179.3 cuft I 1.16 cuft/sk = 179.3 cu ft = 155 sacks /' Cement Plug #2 (Casing Shoe Plug): 15 bbls CW 100 ahead of cement 29 bbls (160 sacks) Class G + additives @ 17.0 ppg (35% excess cement - batch mix cement) 3.5 bbls CW100 behind cement to balance plug (verify volume of CW100 to balance) Displace wI mud (cut displacement 2.5 bbls short of calculated balance point) Calculations: (6650' - 6350') x (0.3941 cufUft) x (1.35) = 159.6 cu ft 159.6 cuft I 1.0 cufUsk = 160 sacks ./ Cement Plug #3 (Surface Plug): 10 bbls CW 100 ahead of cement 17 bbls (91 sacks) Arcticset I @ 15.7 ppg (mix on the fly - cannot batch mix) Displace wI mud Calculations: (200') x (0.42573 cufUft) = 91 cu ft 91 cuft/ 1.0 cufUsk = 91 sacks (round up to 100 sx) /' 16" X 30" insulated conductor @ 110' TAM 9-5/8" Port Collar Std Grade BTC Threads (@ 941' MD) Surface csg. 9-5/8" 40# L-80 BTC (6512' MD) Oliktok Point State # 1 Proposed P & A 11.9 ppg Mud ( \ TD @ 11 ,037'MD, 6964'TVD TOC Plug #3: Surface / Bottom of Plug #3: 200' MD Base of permafrost: 1960' MD TOC Plug #2: 6350' MD /' Bottom of Plug #2: 6650' MD TOC plug #1: 10,700' MD /'. Top Kuparuk "A" Sand: 10'900' MD Bottom Plug #1: 11,037' MD Bill Penrose 6/07/03 , I, ?~ r--: ¡n\ ,r \ J I ! ! L_, \ ( \ ~ ! r l U! ¡ ¡ _.,,' l~" {r\ \ r1 1M ([ù 1i 17 ,lA\ 'LJ\ ¡ - i!I\.\' \ {lJ\ I r--u\ ì \ i r\ \\ ~ , , ,\ \ j~, \ L.} ~u \~~L!Û_U L:. ¡-"-;::.:' ¡ , ! L~ \ L~ L.__~, AI~ASIiA. OIL AND GAS CONSERVAnONCO~SSION Randy Thomas Kuparuk Drilling Team Leader Winstar Petroleum, LLC 3111 C Street, Suite 500 Anchorage AK 99503 FRANK H. MURKOWSKI, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (S07) 279-1433 FAX (907) 276-7542 Re: Oliktok Point State #1 Winstar Petroleum, LLC Permit No: 203-099 Surface Location: 1693' FNL, 2342' FWL, Sec. 9, T13N, R9E, UM Bottomhole Location: 839' FSL, 1757' FEL, Sec. 33, T14N, R9E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, 2 ~¿ ;/. /} , c~~/ ...-,,() '^-~ Sarah Palin Chair BY ORDER 9f THE COMMISSION DATED thisY- day of June, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section 7" { STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMM"JSION PERMIT TO DRILL 20 AAC 25.005 [ ] Service [ ] Development Gas [X] Single Zone [ ] Exploratory [ ] Stratigraphic Test [X] Development Oil 5. Datum Elevation (DF or KB) 10. Field and Pool 38.8' OF (AMSL) 6. Property Designation ADL 388584 / 7. Unit or Property Name Oliktok Point State 8. Well Number NO.1 9. Approximate spud date Amount 7/15/03 $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 1,240 / 11,144'MD,7,047'TVD 17. Anticipated pressure ,( {see 20 MC 25.035 (e) (2)} Maximum surface 2,260 psig, At total depth (TVD) Setting Depth Top Bottom MD TVD MD TVD 33' 33' 110' 110' 33' 33' 6,500' 4,172' 33' 33' 11,144' 7,047' k(~ 1a. Type of work [X] Drill [] Redrill11b. Type of well [ ] Re-Entry [ ] Deepen 2. Name of Operator WINSTAR PETROLEUM, LLC. 3. Address 3111 C ST., SUITE 500, ANCHORAGE, ALASKA lS7'Û::3 - 4. Location of well at surface 1693' FNL, 2342' FWL, Sec. 9, T13N, R9E, UM At top of productive interval 649' FSL, 1800' FEL, Sec. 33, T14N, R9E, UM At total depth 839' FSL, 1757' FEL, Sec. 33, T14N, R9E, UM 12. Distance to nearest prope~ line tfL..A 113. Distance to nearest well 649'.,a.t::::fð"'vr1'~At 384': 164' from 3R-26 16. To be completed for dëviated wells ~ Kick Off Depth 300' MD Maximum Hole Angle 58 deg 18. Casing Program Size Specifications Casing Weight Grade Coupling 16" 9-5/8" [ ] Multiple Zone ~ . ki.'fdA-4-' ~~" ð~' I ¡f.! Â> 11. Type Bond (See 20 MC 25,025) Statewide Number #59-52-180 ' , 3,700 psig 12-1/4" 8-1/2" 40# 26# L-80 L-80 BTC BTCM Length 80' 6,467' 11,111' Quantity of Cement (include stage data) Grouted to surface Lead: 810 sx Arcticset, Tail: 440 sx LiteCRETE 260 sx Class G Hole 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Plugs (measured) Junk (measured) Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner RECE\\/E.D) JUN 0 2 2003 . & G Com;;. Comm\SS\OO I\\aska 0\' as Anchorage Perforation depth: measured true vertical 20. Attachments [ X] Filing Fee [X] Property Plat [ ] BOP Sketch [ ] Diverter Sketch [ X] Drilling Program [ X] Drilling Fluid Program [X] Time vs Depth Plot [] Refraction Analysis [ ] Seabed Report [ ] 20AAC25.050 Req. Name/Num r: ill Penrose (907)258~3446 Prepared By Name/Number: Bill Penrose (907)258-3446 re oi s tr~J:?~, correct to the best of my knowledge 0'-19::; ~ö:> ~?2~ /f!, 1~Þ14( s ~. , Title Kuparuk Drilling Team Leader Date Commission Use Only IAP~ðm~eÓ2..9_¿~ /6D -OD Samples Required: [ ] Yes M No Hydrogen Sulfide Measures: [ ] Yes '.(X\fNo Required Working Pressure for BOPE: [] 2M, [] 3M, [] 5M, Oth'=;: ::'SOG ~ìJ" f'..\""-":,", \3.~? ~." * Approved By /.:{/:X}..Þ---._~~. Commissioner Form 10-401 Rev. 12-01-85 ~ o '~'l ..;¡ 1/ Permit Number ¿:Jô 2-D?> '"C>7 7 Conditions of Approval: AP~~. ~I ~~ I See cover letter ((:) V:) for other requirements a Log Required [ ] Yes ÞcrNo Directional Survey Req'd þ<J Yes [ ] No [ ] 10M, [] 15M by order of the commission Date /^ /q 0~ Su~~n ~4'¡le .Î ~ Au. Oliktok Point State #1 Proposed Drilling Program 1. MIRU Doyon 141. 2. Install diverter system. 3. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run LWD logging equipment with OR tool only. 4. Run and cement 9-5/8" 40#, L-80 BTC casing string to surface. Employ lightweight permafrost cement lead slurry and LiteCRETE tail slurry. Pump adequate excess to ensure cement reaches the surface. If cement does not circulate to surface, utilize port collar installed in casing to pump a second cement stage. Install and test BOPE to 5000 psi. Test casing to 2500 psi. . 5. Drill out cement and 20' of new hole. Perform LOT. 6. Drill 8-1/2" hole to contingent top-set casing point according to directional plan. Run L WD logging equipment with GR and resistivity. Perform second LOT to evaluate long string option. POOH and PIU neutron density tool, drill well to total depth according to directional plan, and run 7" 26# L-80 BTCM casing to surface and cement. Note: If significant hydrocarbon zones are present above the Kuparuk C sand, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). 7. Run 3-112" 9.3#, L-80 EVE 8rd-Mod completion assembly wi permanent packer and PBR. Set packer, shear out ofPBR, PIU tubing hanger, and land tubing. Pressure test tubing to 3500 psi. Pressure test 3 ~" x 7" annulus to 3500 psi. Burst shear valve for freeze protect. 8. Set TWC and ND BOPE. Install and pressure test production tree. 9. Freeze protect. Secure well. Rig down and move out. Note: If the deep LOT indicates insufficient formation integrity to continue drilling, 7" 26# L-80 BTCM casing will be run and cemented above the Kup,aruk C sand. 6 1/8" hole will be drilled to total depth according to the directional plan and a 3 ~"9:3# L-80 SLHT liner will be ran and cemented across the productive interval. CRi ¡J L 16" X 30" ~ insulated I conductor @ +/- ,125' I ~ I ~ TAM 9-5/S" Port Collar Std Grade BTC Threads ( +1- 1000' MDfTVD) Surface csg. 9-5/S" 40# L-SO BTC (6500' MD/ 41S5' TVD ) A Sand Perfs (To be determined after logging) Production csg 7" 26 # L-80 STCM (+/-11,147 MD) Oliktok Point State # 1 Proposed Completion Schematic Single Completion Wins tar Petroleum, LLC I II I II I I ~ I - I _ I I I I ) I L ) ) ) I I Valve #5: 3-1/2" X 1-1/2" 'MMG' GLM w/DCR Dump Kill Valve ( 3000 psi casing to tubing shear). ) 6' L-SO handling pups installed on top and bottom of mandrel. 1 Joint 3-1/2", L-SO, 9.3# EUE Srd Mod Tubing D.:,:Õ:.~ ~~~~ ~~~e~~~~~~s~~~~ã~I~~~eS~D2h~~~;i~~;~~S ~~~g~fJ~~~~~.UESRD 1 Joint 3-1/2", L-SO, 9.3# EUE Srd Mod Tubing 6' Handling pup Joint 3-1/2", L-SO, 9.3# EUE Srd Mod Tubing I~ 1 c. T I Baker '80-40' PBR ~ 8 E3 sl Baker 7" x 3-1/2" 'SA B-3' Permanent Packer set +1- 100' MD above top planned perf. i~¡m~~~~~~ ¡;''''''''''f' ",''''''I'''',\\j~j>'~ I~~~~~~~ Minimum I D through the paCk.er 3.00" I _ 3-1/2" Camco "D" Nipple with 2.75" ID No-Go profile 6' Handling pup Joint 3-1/2", L-SO, 9.3# EUE Srd Mod Tubing I - - I Baker 3-1/2" WL Re-entry GUide wI shear out sub. ~ I Tubing tail 50' above top planned perforation. .~ t: ~~~ I ~ I ,.,_.... ··"'1·.·'··'·- .-.,.,,~ ~ ~.¡¡.,.:':;,~~.. '~...:.¡<j;..;(.~ ~~·~~¡~h:~.. ··i~~~'f;~:~.;~ "..,.,../,.,. ..,,,.,,\\, ,~~,&;....>~- ~:~~/'::~"~~ "~:',':~~:.~~~~':': >.' '2", ttJ:,~'~~~ . l 3-1/2" FMC Gen V tubing hanger, 3-1/2" L-SO EUESRD pin down. Special Drift 2.91" 3-1/2" tbg Retrievable SSSV @ +/- 2500' GLM Placement Placement TBD Valves #1-4: 3-1/2" X 1" KBUG TD @ 11,147 MD /7053'TVD (~ ,""" /.,),1 ~ .'~ ~ A~ Bill Penrose 4/03 0.00 - -1000.00 - -2000.00 - -3000.00 - -4000.00 - -5000.00 - - ~ cc ~ -6000.00- .c: ë. CI> C -7000.00 - -8000.00 - -9000.00 - ) ) Oliktok pt. State #1 MI ~U Doyon 141 0(11112-114" hole / <un and cmt 9-5/8" c:sg, N/U BOP[, COnduct LO I ¡ Kun ard ComJlete -10000.00 - cmtr" csg Well -11000.00 - j J -12000.00 2 3 14 6 8 9 10 11 12 13 4 5 7 Day O :"""'" , /~ ~ ~ ,. AI ~,~,,< 1\ ,~. ~ .'~ "~ .III~ .,' t a H lA ~ ~ Ij }4. -) ConocoPhillips Alaska, Inc. Drilling Fluid Program, Pressure Calculations, and Drilling Area Risks Oliktok Point State #1 Drillin2 Fluid Properties: Density Funnel Vis YP PV 10 Second Gel 10 Minute Gel pH API Filtrate % Solids 12-1/4" Hole Section Surface to Base Permafrost (45' to 1,9851MD) 8.5 - 9.4 150 - 200 30 - 60 8 - 22 1 0 - 30 25 - 55 8-9 8 - 15 5-8 Drillin2 Fluid System: 12-1/4" Hole Section Base Permafrost to Csg pt. (1,985' - 6,500'MD) <9.4 65 - 150 20 - 40 15 - 30 1 0 - 25 20 - 40 8-9 <8 5 - 11 8-1/2" Hole Section Surface Csg pt to TD ~'-11,147'.)., ~9.0 - 10.5 ~" 40 - 55 5 - 26 6 - 25 3-7 6 - 14 9 - 10 <6 4 - 12 Specifications of the drilling fluid system for Doyon Rig 141 are on file with the Commission. BOP System and Diverter: Specifications for the blowout prevention equipment, including diverter, for Doyon Rig 141 are on file with the Commission. Maximum Anticipated Surface Pressure: The maximum anticipated surface pressure (MASP) for this well will be the lesser of the fonnation pore pressure (less a full gas column to the surface) at TD or the fonnation fracture pressure at the last casing shoe (less a full gas column to the surface). Based on offset well data, the highest fonnation pressure expected in the final hole section is 3,700 psi at the well's TD of 7,053' TVD (or 0.52~si/ft). Documented fracture gradient data for this area indicates that the fracture gradienttt 4,185 'TVD (the 9-5/8" surface casing shoe) is a minimum of 0.650 psi/ft (12.5 ppg). Complete evacuation of the wellbore, except for a 0.11 psi/ft gas gradient, is assumed. \¡ \0 ~\ E\-\.W J2'fr!l ') ) ConocoPhillips Alaska, Inc. Drilling Fluid Program, Pressure Calculations, and Drilling Area Risks Oliktok Point State #1 Drillioe Fluid Properties: Density Funnel Vis YP PV 10 Second Gel 10 Minute Gel pH API Filtrate % Solids 12-1/4" Hole Section Surface to Base Permafrost (45' to 1,985'MD) 8.5 - 9.4 150 - 200 30 - 60 8 - 22 10 - 30 25 - 55 8-9 8 - 15 5-8 12-1/4" Hole Section Base Permafrost to Csg pt. (1,985' - 6,500'MD) <9.4 65 - 150 20 - 40 1 5 - 30 10 - 25 20 - 40 8-9 <8 5 11SJ ,,:>ùVL~~~ ~ ( Š If iii Drillioe Fluid System: Specifications of the drilling Commission. BOP System and Diverter: 8-1/2" ole Section Surf e Csg pt to TO (6 00'-11,147'MD) 8.8 - 10 40 - 55 5 - 26 6 - 25 3-7 6 - 14 9 - 10 <6 4 - 12 or Doyon Rig 141 are on file with the Specifications for the blowo prevention equipment, including diverter, for Doyon Rig mISSIon. Maximum Aotici ted Surface Pressure: The maximum ticipated surface pressure (MASP) for this well will be the lesser of the formation po pressure (less a full gas column to the surface) at TD or the formation fracture pr sure at the last casing shoe (less a full gas column to the surface). Based on offset we data, the highest formation pressure expected in the final hole section is 3,700 psi at tewell's TD of 7,053' TVD (or 0.525 psi/ft). Documented fracture gradient data for t s area indicates that the fracture gradient at 4,185 'TVD (the 9-5/8" surface casing s e) is a minimum of 0.650 psi/ft (12.5 ppg). Complete evacuation of the wellbore, xcept for a 0.11 psi/ft gas gradient, is assumed. O R,: {:~ :' I .11, L 'I' L ~J ,I~ ':<:.) , ' ., ~ ,t ~ ,,,' . "' r ,I. ,,' ) ') 8-1/2" hole section MASP (pore pressure) MASP (fm breakdown) = (7,053 ft)(0.525 - 0.11) = 2,927 psi (4,185 ft)(0.650 - 0.11) = 2,260 psi Therefore, MASP in the 8-1/2" open hole section is 2,260 psi and the 5,000psi BOPE system to be used will be adequate. Well Proximity Risk: The nearest wellbore to that of the Oliktok Point State #1 is KRU 3R-26. OPS #1 will pass 164' from 3R-26 at a depth of384'MD. Drillioe Area Risks: See attached Drilling Hazard Summary. Disposal of Muds and Cuttines: Surficial gravels drilled up in the shallow part of the well will be processed through the drilling rig's rock washer and retained on location in cuttings bins. They will then be tested and beneficially re-used as road/pad fill material within the Kuparuk River Unit. The remainder of the drill cuttings will be processed in the rig's ball mill, blended with waste mud and injected down designated Class II disposal well 3R-ll. 0.. /..~. ß'~ .~'\ ., t1 L ~!'·,'.:I "., I : f' I.. .. ,.' J í~' ., ~ ¡I ,j l~:~, . , ,'ofj,'1:~,"j _~ .1' ' ,Ii .,) ) ) OLIKTOK POINT STATE #1 DRILLING HAZARDS SUMMARY 12-1/4" Hole / 9-5/8" Casin2 Interval EVENT Broach of Conductor RISK LEVEL Low . Gas Hydrates Low Gravel/Sand Sloughing to 500' Moderate Hole Swabbing/Tight Hole on Trips Possible thaw bulb/water flow Moderate Low Lost Circulation Low 8-1/2" Hole / 7" Casio2 Interval Event Shale stability in HRZ, K -1, and Miluveach High ECD and swabbing with higher MW's required Risk Level Low Moderate Barite Sag Low Differential Sticking Moderate Abnonnal Reservoir Pressure Moderate Lost Circulation Moderate Miti2ation Strate2Y Monitor cellar continuously during interval. If observed - control drill, reduce pump rates, reduce drilling fluid temperatures, additions of Leci thin. Increase mud weight/viscosity, High viscosity sweeps. Monitor fill on connections Circulate hole clean prior to trip. Proper hole fill (use of trip sheets), pumping out of hole as needed. Watch return viscosity for signs of thinning. Increased mud weight/viscosity as needed. Prevent by keeping hole clean. If losses occur - reduce pump rates and mud rheology, use LCM Miti2ation Strate2V Control with higher MW and proper drilling practices. Condition mud prior to trips. Monitor ECD' s with PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Good drilling practices as documented in well plan. Periodic wiper trips. Do not leave pipe static for extended period of time Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Use PWD to monitor hole cleaning. Reduced pump rates, mud rheology, LCM. Use GKA LC decision tree. OR· ;;.. ,~ ~ , " '1,\" J ~ :' ';', J .7. ;.~ " _ . . ItA .~ ~ ...,! Y .~ .I/.:,. Oliktok Point State #1 Casin2 Properties and Desi2n Casing Perfonnance Properties Internal Collapse Tensile Strength Size Weight Yield Resistance Joint Body TVD MD Design Safety Factor* (in.) (lb/ft) Grade Cnxn œru fuill (1.000 lbs) (ft RKB) (ft RKB) T B C a 9-5/8 40 L-80 BTC 5,750 3,090 979 916 4,185 6,500 4.10 1.96 1.95 ::;r:, 7 26 L-80 BTCM 7,240 5,410 667 604 7,053 11,147 2.45 2.47 1.87 - ~~-...s -- * Tensile design safety factors are calculated using pipe weight less buoyancy. Burst design safety factor for 7" casing is calculated using Maximum Anticipated Surface Pressure. Collapse design safety factors are calculated assuming complete evacuation of the casing. /~:~ f--- Casing Setting Depth Rationale 9-5/8" 6,500' RKB, MD Surface casing to provide an anchor for BOP equipment and sufficient fracture gradient until the reservoir is reached. Production casing to provide hole stability and pressure containment for production operations. 7" 11,147' RKB, MD Rig: Doyon 141 Location: Wildcat Client: Winstar Revision Date: 4/10/2003 Prepared by: Mike Ma rtin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com < TOC at Surface Previous Csg. ~ < 16",62.6# casing at 120' MD < Base of Permafrost at 1,98S' MD (1,770' TVD) < Top of Tail at 4,29S' MD < Top of West Sak at 4,79S' MD < 9 S/8", 40.0# casing in 12 1/4" OH TD at 6,600' MD (4,280' TVD) Mark of Schlumberger ) , ..: . ··eemCADE.··....p>t~lirr1ihøryJÓb·..ØØsign ·9qI8"eQf(ø(jß . IcblUI~øpl8P Prellmnary Job Design based on li'nited input data. FOr estimate purpoæs only. Volume Calculations and Cement Systems Volumes are based on 300% excess in the permafrost and 40% excess below the permafrost. The top of the tail slurry is designed to be 500' above the West Sak formation. Lead Slurry Minimum pump time: 270 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.28 ft3/sk 0.7632 ft3/ft x (120') x 1.00 (no excess) = 0.3132 ft31ft x (1985' -120') x 4.00 (300% excess) = 0.3132 ft31ft x (4295' - 1985') x 1.40 (40% excess) = 91.6 ft3 + 2336.5 ft3 + 1012.9 ft3 = 3441 ft3 I 4.28 ft3/sk = Round up to 810 sks 91.6 ft3 2336.5 ft3 1012.9 ft3 3441 ft3 804 sks Have 280 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 180 min. (pump time plus 90 min.) LiteCRETE @ 12.0 ppg - 2.40 ft3/sk 0.3132 ft31ft x (6600' - 4295') x 1.40 (40% excess) = 0.4257 ft31ft x 80' (Shoe Joint) = 1010.7 ft3 + 34.1 ft3 = 1044.8 ft31 2.4 ft3/sk = Round up to 440 sks 1010.7 ft3 34.1 ft3 1044.8 ft3 435.3 sks BHST = 95°F, Estimated BHCT = 88°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 7 50 7.1 7.1 Drop Bottom Plug 3.0 10.1 MudPUSH XL 7 50 7.1 17.2 Lead Slurry 7 617 88.1 105.3 Tail Slurry 7 188 26.9 132.2 Drop Top Plug 3.0 135.2 Displacement 9 474 52.7 187.9 Slow Rate 3 20 6.7 194.6 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.2 ppg MudPUSH* XL, Pv ? 17-21, Ty ? 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. Rig: Doyon 141 Location: Wildcat Client: Winstar Revision Date: 4/10/2003 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Previous Csg. k < 95/8",40.0# casing at 6,600' MD I' ;~ [. F ~ ¡ I' I..'j' ~ p < Top of Tail at 9,900' MD < 7", 26.0# casing in 8 1/2" OH TD at 11,147' MD (7,053' TVD) ) ) W. .... .in.>st,..8>. ...r> ..0. >...I..·.~..> . .p.. .t..>." .8. .,.t.,.8,.. .t8. #. ..1.. . . IchlUlblPD8P OèmCADEt..~rèl iminary~ob...·Design .'. . 7" Prc>ducti()nC~siJ1g Prelimnary Job Design basad on linited input data. fur estimate purpoæs only. Volume Calculations and Cement Systems Volumes are based on 75% excess. Tail slurry is designed for 800' MD above target - (1247' MD annular length). Tail Slurry Minimum thickening time: 180 min. (Pump time plus 90 min.) 15.8 ppg Class G + 2.0 gps D600G + 0.02% B155 + 0.3% D65 + 0.2 gps D47 + 1/4# per Sack D29 - 1.16 ft3/sk 0.1268ft31ft x 1247' x 1.75 (75% excess) = 0.2148 ft31ft x 80' (Shoe Joint) = 276.7 ft3 + 17.2 ft3 = 293.9 ft3/1.16 ft3/sk = Round up to 260 sks 276.7 ft3 17.2 ft3 293.9 ft3 253.4 sks BHST = 167°F, Estimated BHCT = 128°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 6 30 5.0 5.0 Drop Bottom Plug 6.0 11.0 MudPUSH XL 6 40 6.7 17.7 Tail Slurry 6 54 9.0 26.7 Drop Top Plug 10.0 36.7 Displacement 6 403 67.2 103.9 Slow Rate 3 20 6.7 110.6 MUD REMOVAL Recommended Mud Properties: 10.6 ppg, Pv < 15, Ty < 15. 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. ¢ -+- ~ Xf'RMR UGHT POLE- ¢ Å @ @ @ Å @ Å @ @ Å 1 22 261415251713192J2 UGHT POLE -¢ ~ I I I I I Å @ @ 5 6 7 8 9 1) 1112 C-OB y-- I I ~~ O~t.I-~-L_-"L-_ ,.----J---. ! 00° PlUNG <H.Y-¡ 0 D D I ~ 0 ----r ESO MOO --to - lEST SEPERATOR (f) L-01 RESERVE PIT W LAUNCHER MOO ~ ] E-04 W.~ METH TANK, PlUNG ONLY ~ I ~ ~ PIGGING PROD H\t~ - -~, ~IT ~J T-~": ..:.~ -,-~- y ~-c-._ ~--:::, {::'-,~ ~- ~__~-J - -~-:&."--,,-,.:.:&. -~~'}. ~-=-'~ ->--( OLIKTOK ROAD r .. " APPROVAl: DATE: DRAWING NO. REV. CUST DATE REVlSlOOS BYCHK~~ ~/ ~ '\ '\ ~ LEGEND / @ EXISTING PRODUCER Å EXISTING IN.£CTOR I ABANDONED CONDUCTOR SCALE: 1" = 150' -- ,/ '" '- Drill Site 3R Plot Plan CADD NO. SHEET: REV: ') ') ConocoPhillips Alaska, Inc. -..""'" ConocoPhillips Craatod by bmichaol For: B Penrose Dot. plotted: 9-May-2DD3 Plot Reference lIS Qliktok Pi st 1 Ver3. Coordinates are In foot I'CIforoncD Dial Is. True Vortlcol Depth. or. rofor.no. RKB (Doyon *141). ... ...- ..... INTEQ 1000 - 1500 - 2000 - ..--... 2500 - - a> a> - 3000 - ........... ...r:: - a.. a> 3500 - 0 0 4000 - Ü - I.... a> > 4500 - a> :::J I.... 5000 - l- I V 5500 - 6000 - 6500 - 7000 - 7500 - 8000 - Structure : Pad 3R Well: 9 ~ ~"'¡i'\1' Field : Kuparuk RIver UnIt LocatIon: North Slope, Alaska o - A RKB Elevation: 38.80' 500 - 49.67 JLS: 4.00 deg per 100 ft 53.27 57.5\OC #2 Top West Sak 8.19 AZIMUTH 7244' (TO TARGET) TARGET ANGLE 37.79 DEG OLS: 3.00 deg per 100 ft Oliktok Shllw(T1 )-EOC T/ HRZ B/ HRZ - T/ Kup Oliktok Main(T2) Top A1 B/ Kuparuk ~~9 TO - Casing pt. 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 Vertical Section (feet) -> Azimuth 8.19 with reference 0.00 N, 0.00 E from slot #9 0("'.'·, c I' * I \in ;; '~~'I ,": ,~ , '¡ :' ·"!'~1 "i '. ~'.l~ I~t Creatod by bmichaol For: B Penrose Oato ploUod: 9-May-200J Plot Reference is Oliktok pt st 1 Ver3. Coordinates are in fo"t reference slot *9. True VertIcal Depths are reference RKB (Doyon *141). uIf}- IIUGIB INTEQ BOOO - 7500 - 7000 - 6500 - 6000 - 5500 - 5000 - ^ I 4500 - ~ - Q) Q) 4000 - - '--/ ...c: - L 3500 - 0 Z 3000 - 2500 - 2000 - 1500 - 1000 - ) ConocoPhillips Alaska, Inc. Structure : Pad 3R Well : 9 Field: Kuparuk River Unit Location: North Slope, Alaska 500 ~ /~ ~ o - TD LOCATION: 840' FSL, 1737' FEL SEC. 33, T14, R9E T2 TARGET LOCATION: 651' FSL, 1781' FEL SEC. 33, T14N, R9E 1d TD - Casing pt. f:o,;¡ B/ Kuparuk '<>: Top A1 C'J Oliktok Main(T2) :¡ B/ HRZ - T/ Kup .... T/ HRZ Oliktok Shllw(T1 )-EOC cin Drop/Turn ì r N < ~ ~ I SURFACE LOCATION: I 1693' FNL. 2342' FWL SEC. 9, T13N, R9E ) ...../ ConocoPhillips ~~ ;.,I';'·:',:::',·!,?'i: 8.19 AZIMUTH 7244' (TO TARGET) ***Plane of Proposal*** <f TRUE T1 TARGET LOCATION 198' FSL, 1885' FEL SEC. 33, T14N, R9E 500 1000 1500 2000 2500 3000 3500 East (feet) -> 0' ~..,~' .",,, ,~ '1' I _J' jl'~X ~ :,', ,I ~ \1·,:J7 M ~',~ \',.; :, ,~ - ConocoPhillips Alaska, Inc. ...... ConocoPhillips Created by bmichael For: B Penrose Structure : Pad 3R Well: 9 "'~M. Dote plolted: 9-t.lay-2D03 Plot Reference i. Dliktok pt St 1 Ver3_ Field : Kuparuk River Unit Location : North Slope, Alaska Coordinates are in feel reference slot 19. True Vertical Oeptl1' ore reference RKB (Ooyon 1141). .-a .... INTEQ ==== PROF~LE COMMENT DATA == == - ----- Point ----- MD Inc Dir TVD No rt h East V. Sect Deg/100 KOP 300.00 0.00 45.00 300.00 0.00 0.00 0.00 0.00 CJ EOC 1722.15 44.78 45.00 1595.38 342.55 342.55 387.87 3.50 -:¡?-~.- Begin Build/Turn 1863.02 44.78 45.00 1695.37 412.71 412.71 467.32 0.00 f. B/ Permafrost 1960.24 45.46 39.59 1764.00 463.64 459.02 524.33 4.00 ~.- ~ 'C .' EOC #2 2739.25 58.40 3.12 2253.44 1022.66 658.99 1106.14 4.00 :'~.-:.>~ Top West Sak 4772.70 58.40 3.12 3319.00 2751.99 753.38 2831 .27 0.00 f~ Base West Sak 6413.87 58.40 3.12 4179.00 4147.71 829.56 4223.60 0.00 9 5/8 Casing pt. 6500.00 58.40 3.12 4224.13 4220.96 833.55 4296.67 0.00 Begin Drop/Turn 9342.24 58.40 3.12 5713.51 6638.13 965.48 6707.96 0.00 Oliktok Shllw(T1 )-EO ~ --..- 10068.75 37.79 12.83 6196.79 7170.50 1032.58 7244.4 7 3.00 T/ HRZ 10291.72 37.79 12.83 6373.00 7303.71 1062.91 7380.64 0.00 B/ HRZ - T/ Kup 10695.36 37.79 12.83 6692.00 7544.84 1117.83 7627.14 0.00 Oliktok Main(T2) 10826.68 37.79 12.83 6795.79 7623.30 1135.70 7707.34 0.00 Top A 1 10864.91 37.79 12.83 6826.00 7646.14 1140.90 7730.69 0.00 B/ Kuparuk 10929.44 37.79 12.83 6877.00 7684.69 1149.69 7770.09 0.00 TO - Casinq pt. 111 44.29 37.79 12.83 7046.80 7813.04 1178.92 7901.30 0.00 L ",-~ ;" .. ( :, ~ i: ~ ~." } O· R'·~ ~,,"l·1 4 Reference North is True North Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Slot location is n70 29 51.666,w149 49 52.156 Slot Grid coordinates are N 6031670.680, E 520647.180 Slot local coordinates are 1691.45 S 2346.27 E Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 30 8.305,w149 51 1.222 Your ref : Oliktok pt St 1 Ver3 Our ref : prop5444 License Date printed : 12-May-2003 Date created : ll-Apr-2003 Last revised : 8-May-2003 by Baker Hughes INTEQ PRO P 0 S ALL I S TIN G 9 slot #9 Kuparuk River Unit North Slope, Alaska ConocoPhillips Alaska, Inc. Pad 3R "II ; ') .'~. '.. . ! ! ~,.'. I!Ok~. ~) ~ j !.¡ All data is in feet unless otherwise stated. Coordinates from slot #9 and TVD from RKB (Doyon #141) (38.80 Ft above mean sea level). Bottom hole distance is 7901.48 on azimuth 8.58 degrees from wellhead. Total Dogleg for wellpath is 101.63 degrees. Vertical section is from wellhead on azimuth 8.19 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ 5993.43 6417.61 6707.96 Begin Drop/Turn 6756.54 6838.55 4223.60 Base West Sak 4296.67 9 5/8" Casing Pt. 4720.86 5145.05 5569.24 2599.92 2831.27 Top West Sak 3024.11 3448.30 3872.49 1072.97 1106.14 EOC #2 1327.36 1751.55 2175.73 682.19 754.50 830.11 908.64 989.73 467.32 Begin Build/Turn 488.50 524.33 B/ Permafrost 548.86 613.53 200.75 244.65 292.55 344.28 387.87 EOC 46.51 68.25 94.64 125.61 161. 02 5.59 8.10 16.82 23.71 29.53 0.00 0.00 0.00 0.00 KOP 1. 40 Vert Sect PROPOSAL LISTING Page 1 Your ref : Oliktok pt St 1 Ver3 Last revised: 8-May-2003 ì! , 0.00 0.00 0.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 4.00 4.00 0.00 0.00 0.00 4.00 4.00 4.00 4.00 4.00 0.00 4.00 4.00 4.00 4.00 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 3.50 2.00 2.50 2.50 2.50 3.50 0.00 0.00 0.00 0.00 2.00 Dogleg Deg/100ft 926.39 E 949.60 E 965.48 E 968.38 E 974.43 E 829.56 E 833.55 E 856.76 E 879.97 E 903.18 E 740.72 E 753.38 E 763.93 E 787.14 E 810.34 E 656.74 E 658.99 E 671.09 E 694.30 E 717.51 E 554.18 E 585.38 E 611.35 E 631. 97 E 647.12 E 412.71 E 430.83 E 459.02 E 476.71 E 517.90 E 177.29 E 216.06 E 258.36 E 304.05 E 342.55 E 41. 08 E 60.27 E 83.58 E 110.93 E 142.20 E 4.93 E 7.15 E 14.85 E 20.94 E 26.08 E 0.00 E 0.00 E 0.00 E 0.00 E 1.23 E 5921.85 N 6347.07 N 6638.13 N 6686.79 N 6768.77 N 4147.71 N 4220.96 N 4646.18 N 5071.40 N 5496.63 N 2520.08 N 2751.99 N 2945.30 N 3370.52 N 3795.74 N 989.47 N 1022.66 N 1244.41 N 1669.63 N 2094.85 N 609.42 N 677.98 N 750.63 N 827.01 N 906.75 N 412.71 N 431. 50 N 463.64 N 485.88 N 545.28 N 177.29 N 216.06 N 258.36 N 304.05 N 342.55 N 41. 08 N 60.27 N 83.58 N 110.93 N 142.20 N 4.93 N 7.15 N 14.85 N 20.94 N 26.08N 0.00 N 0.00 N 0.00 N 0.00 N 1.23 N R E eTA N G U L A R COO R DIN ATE S 5272.16 5534.17 5713.51 5744.49 5801. 41 4179.00 4224.13 4486.14 4748.15 5010.16 3176.10 3319.00 3438.11 3700.12 3962.13 2232.62 2253.44 2390.08 2652.09 2914.10 1928.44 1994.18 2057.78 2118.91 2177.28 1695.37 1721.57 1764.00 1791.80 1860.87 1297.77 1381. 38 1461.49 1537.79 1595.38 838.47 934.70 1029.09 1121.29 1210.96 499.84 539.71 639.11 698.49 740.76 0.00 100.00 200.00 300.00 399.98 3.12 3.12 3.12 3.70 4.75 3.12 3.12 3.12 3.12 3.12 3.12 3.12 3.12 3.12 3.12 4.65 3.12 3.12 3.12 3.12 26.96 22.04 17.36 12.90 8.67 45.00 42.93 39.59 37.42 32.09 45.00 45.00 45.00 45.00 45.00 45.00 45.00 45.00 45.00 45.00 45.00 45.00 45.00 45.00 45.00 0.00 45.00 45.00 45.00 45.00 58.40 58.40 58.40 56.73 53.86 8500.00 9000.00 9342.24 9400.00 9500.00 58.40 58.40 58.40 58.40 58.40 6413.87 6500.00 7000.00 7500.00 8000.00 58.40 58.40 58.40 58.40 58.40 4500.00 4772.70 5000.00 5500.00 6000.00 57.51 58.40 58.40 58.40 58.40 2700.00 2739.25 3000.00 3500.00 4000.00 48.16 49.67 51. 38 53.27 55.32 2200.00 2300.00 2400.00 2500.00 2600.00 44.78 45.01 45.46 45.81 46.86 1863.02 1900.00 1960.24 2000.00 2100.00 31. 50 35.00 38.51 42.01 44.78 1342.89 1442.89 1542.89 1642.89 1722.15 14.00 17.50 21. 00 24.50 28.00 842.89 942.89 1042.89 1142.89 1242.89 4.00 5.00 7.50 9.00 10.50 500.00 540.00 640.00 700.00 742.89 0.00 0.00 0.00 0.00 2.00 0.00 100.00 200.00 300.00 400.00 Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth ) ConocoPhillips Alaska, Inc. Pad 3R,9 Kuparuk River Unit, North Slope, Alaska , }~: , "i \1 t" ~ ! ~ r~"-' () . All data is in feet unless otherwise stated. Coordinates from slot #9 and TVD from RKB (Doyon #141) (38.80 Ft above mean sea level) . Bottom hole distance is 7901.48 on azimuth 8.58 degrees from wellhead. Total Dogleg for wellpath is 101.63 degrees. Vertical section is from wellhead on azimuth 8.19 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 2 Pad 3R,9 Your ref : Oliktok pt St 1 Ver3 Kuparuk River Unit,North Slope, Alaska Last revised : 8-May-2003 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/l00ft Sect 9600.00 51. 00 5.88 5862.38 6847.68 N 981. 76 E 3.00 6917.70 9700.00 48.15 7.11 5927.22 6923.31 N 990.36 E 3.00 6993.78 9800.00 45.31 8.45 5995.76 6995.44 N 1000.20 E 3.00 7066.58 9900.00 42.49 9.93 6067.80 7063.89 N 1011.25 E 3.00 7135.90 10000.00 39.69 11. 58 6143.16 7128.45 N 1023.49 E 3.00 7201. 55 10068.75 37.79 12.83 6196.79 71 70.50 N 1032.58 E 3.00 7244.47 Oliktok Shllw(T1)-EOC 10068.77 37.79 12.83 6196.80 7170.51 N 1032.58 E 3.00 7244.48 Oliktok Shallow Tl l1-Apr-03 10100.00 37.79 12.83 6221.48 7189.17 N 1036.83 E 0.00 7263.55 10200.00 37.79 12.83 6300.51 7248.91 N 1050.44 E 0.00 7324.62 10291.72 37.79 12.83 6373.00 7303.71 N 1062.92 E 0.00 7380.64 T/ HRZ 10300.00 37.79 12.83 6379.54 7308.65 N 1064.04 E 0.00 7385.69 10400.00 37.79 12.83 6458.58 7368.39 N 1077.65 E 0.00 7446.76 10500.00 37.79 12.83 6537.61 7428.14 N 1091. 25 E 0.00 7507.83 10600.00 37.79 12.83 6616.64 7487.88 N 1104.86 E 0.00 7568.90 10695.36 37.79 12.83 6692.00 7544.84 N 1117.84 E 0.00 7627.14 B/ HRZ - T/ Kup 10700.00 37.79 12.83 6695.67 7547.62 N 1118.47 E 0.00 7629.97 10800.00 37.79 12.83 6774.70 7607.36 N 1132.07 E 0.00 7691. 04 10826.68 37.79 12.83 6795.79 7623.30 N 1135.70 E 0.00 7707.34 Oliktok Main(T2) 10826.70 37.79 12.83 6795.80 7623.31 N 1135.71 E 0.00 7707.35 Oliktok Main T2 ll-Apr-03 10864.91 37.79 12.83 6826.00 7646.14 N 1140.90 E 0.00 7730.69 Top Al 10929.44 37.79 12.83 6877.00 7684.69 N 1149.69 E 0.00 7770.09 B/ Kuparuk 11000.00 37.79 12.83 6932.76 7726.84N 1159.29 E 0.00 7813 .18 11144.29 37.79 12.83 7046.80 7813.04N 1178.92 E 0.00 7901.30 TD - Casing Pt. ) ') \ ' A i ! L l"~ .- '\ ' ...' ¡' í .\,...~ '; ~i .~ ~:>,,¡ 1032.58E 11-Apr-2003 1135.71E 11-Apr-2003 71 7 0 . 51N 7623.31N Oliktok Shallow T1 1 521662.000,6038843.000,0.0000 6196.80 Oliktok Main T2 11-A 521764.000,6039296.000,0.0000 6795.80 ----------------------------------------------------------------------------------------------------------- Revised Rectangular Coordinates T.V.D. Geographic Location Target name ------------------------------------- ------------------------------------- Targets associated with this wellpath 833.55E 9 5/8" Csg 1178.92E 7" Liner 4220.96N 7813.04N O.OOE 6500.00 4224.13 O.OOE 11144.30 7046.80 O.OON O.OON 0.00 0.00 0.00 0.00 ----------------------------------------------------------------------------------------------------------- 300.00 300.00 0.00 N 0.00 E KOP 1722.15 1595.38 342.55 N 342.55 E EOC 1863.02 1695.37 412.71 N 412.71 E Begin Build/Turn 1960.24 1764.00 463.64 N 459.02 E B/ Permafrost 2739.25 2253.44 1022.66 N 658.99 E EOC #2 4772.70 3319.00 2751.99 N 753.38 E Top West Sak 6413.87 4179.00 4147.71 N 829.56 E Base West Sak 6500.00 4224.13 4220.96 N 833.55 E 9 5/8" Casing Pt. 9342.24 5713.51 6638.13 N 965.48 E Begin Drop/Turn 10068.75 6196.79 71 70.50 N 1032.58 E Oliktok Shllw(T1)-EOC 10068.77 6196.80 71 70.51 N 1032.58 E Oliktok Shallow T1 11-Apr-03 10291.72 6373.00 7303.71 N 1062.92 E T/ HRZ 10695.36 6692.00 7544.84 N 1117.84 E B/ HRZ - T/ Kup 10826.68 6795.79 7623.30 N 1135.70 E Oliktok Main(T2) 10826.70 6795.80 7623.31 N 1135.71 E Oliktok Main T2 11-Apr-03 __ 10864.91 6826.00 7646.14 N 1140.90 E Top A1 10929.44 6877.00 7684.69 N 1149.69 E B/ Kuparuk 11144.29 7046.80 7813.04 N 1178.92 E TD - Casing Pt. Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- Comment Rectangular Coords. TVD MD -------------------- -------------------- Comments in wellpath PROPOSAL LISTING Page 3 Your ref : Oliktok pt St 1 Ver3 Last revised: 8-May-2003 ConocoPhillips Alaska, Inc. Pad 3R,9 Kuparuk River Unit,North Slope, Alaska ) ) ) ) 1 -. :'1'Ø'O':90 0.00 :"!~':"),1'45::Ø'O 2 ":,:;:;~otn~ó' 0.00 I'!':I~ !':~4'5~'C:k)'1 'ii:':: .' I.;,.,,! t~.' :'~t: ,~~ ' " " '.~",: I,: :1")\'1"" ::::'::1\ :'.. 3 ',i~I~8iHP 0.00 ::~,:': ,.ir~!ífR¡9,9¡ 4 ,:"p~qqtQP 2.00 '::,/,,::~ê;q,g: 5 'I ·.'·,;S0Ö::ÞØ 4.00',:,::\·,,:"~5:dO 6:"1;5~q:;'Ø'Ô' 5.00 ':i¡';,::':,~~;!~þ 7,:a~Ô'I:'ôQ: 7.50 'i,.,,'I,'!,:IW. ',,00 8 ;,·,,",1.,1', '·'·"0' 9.001.,:.!',':i,'·'''''I,,;Q:: 9 10.50' Q; 10 14.00 11 17.50 12 21.00 13 24.50 : 14 28.00 I, 15 31.50¡: 16 35.00 17 38.51 18 I 42.01 19 44.78 20 44.78 21 45.01 22 45.46' 23 45.81 24" 46.86 25 ¡~:'I 48.16, 26 1,,1. 49.67 ¡, , 27 "~'" ;,":'"..,.1.....1' _.',.'.~Þ."\': 51.38 ;,,'~;'!,'Ii ..'~."$AI 1,1,"' .'·',:i ""','",,,~II 281':~P,;. 0 53.27'>",:lr'I'~:li~I?:;~ql 29 ,'~~99:;'9,9 55.32:, 'i",:¡!",,~'·ß:7 30~Z~,Pi~q. 57.51"1 'I "~il~~'1 3127~Q 25 58.40 '1',II::;'h'III,;'ª:1'i 32 ;,',"3ôôd:b·" 58.40 ::rrl:'\':'(;-:3~1~1,2'1 33 ~·'.(:!iI~$~ê~:9~; 58.401"11' 34 -',.409° ,mo 58 40 : (,'''iif:f'ilJ;:::f'"i'' "~I . 35 ')II;,~3m~\9pl 58.40 ¡iil¡'::; 36 I'.' 'i':417,\7:ØI,;7.Q' 5840 t' 1'1.[' .11, .'i.IT"".,_,.:..D,""";,"I./',.'."".'. . :':i),¡(,;::¡':'f',."'III,i:,,"'''.1 37 ." ,5,(;\,Q.0.g,n 58.40 "}":':,:,/':"ß~~'~ " .', "'..!! ~ I"'."";.~ ,II 1.;t:¡.·1 è.. '!'"II\I,jl'IIII,I,~'::::I .'ï;! 38'ooØO 00, 58.40 ".'.. :":i',,::'\;;',:,~;;~~.. I~.:': ',' ':6-.·.1.·.:0.'.'.10,:::0"'.'.·,'.·.·,0.,'.',0·. ,- I' , 39 58.40 ":':"",,:,~;~,f 40 . 640,q.09 58.40 1(::::¡I\~;}2, 41 6~ 1'~t87' 58.40 ',, ,1:",,< 1'30,1'21 42 -i'à5då'6ö 58.40 "';:"Jll;":;'~:~:'~2' 43;,fQ~~~gQ 58.40 !11\;(,;ii\t:~;I~:?,: 44 :,,;.7êRRP9 58.40 1{':;i;';:i;;\i~~...",,?c:1 45 ·00' 58.40 !:i.;i~,::t;(~ì~·'.i'g:: 46 :I:.:,'.,.':":'.'~.,.,:::II.:.'..~ .,',., ,.','.,. ."0-.::,;1·.:. 58.40 :~r~I,\11}~1!;~~~~;~:I· 47 '~"" 58.40 ::F?,!::í;~'¡3:12 48 ':934Ž'24-' 58.40 "-';\'':\:i,:~~~l?' 49 "94ÔÔ\OÒ 56.73. .. ',;3/7Þ, 50 95ÔO':OÒ 53.86 :~.7p 51 96QO.QO 51.00?;88 52 9~0.0;00 48.15 ,:7;11 53 9800.00 45_318.45 54 99qO..Ç>0 42.49):93 55 1 QO:Op:ÖO 39.69', '11;58 561Ð0~~.ip 37.79 ";\,~112,83 57 'jHðãif77 37.79, ., ". ",1.,~2,;8.'·,3 '1' ·'O';'¡¡I~',·O"'"'·· ;;';"'00'·"''' ,; . ," "',r). . 58 "1>. v. 37.791"-':·1~;o3 59 1å2'OÕ':Ob. 37.79 ," ,<'::,1':2:ä~ 60 i1P~Q~t:.7ì· 37.79" '~'2;8'31 61 10áøö~öò 37.79 .)2:83 62 . tÓ~Qg:~Q 37. 79;\·,~~;aá 63 1'()sO,O.,QO 37.79 ~·2.'~3 6410eOp.00 37.79 ; - . ,12.83 65 10695:36 37.79 I ,~,1:2~~~ 66 101bö.oo 37.79 . ..' .12:~~3 67 '1080&ÓO 37.79 ,!'{';:'11~~~~ 68 :;:1~~I~~~l 37.79 ' . 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"1 n~:'f~,'i.':. 521706.58 ~ '§.~~."'~._, ~, ....,., 4J.' P. .97 6537.61 ·:.:'~~ß.,;~1' 521720.03. ~~~1qO,7.4 6616.64.()5l~7.~4 521733.49. 603~160;51 6692.00..: ;,,~:~~ª,.~d 5217 46.32~9~:~)l:50 6695.67 :~Ei9§i~7 521746.95~R~~~9·2~ 6774.70~\':~J§,~¡~ 521760.41 ":~9~.?~Q.04 6795.79,",X~Jæ.;~~ 521764.00 ,_§~~~~&.9_~ 6795.80 :"",_¡:(:~~_,p.l.:9.0. ,.. 521764.00. .~Q.,f.,,~~.~·~O 6826.00 :"~ 67~7.?0 521769.14-§:Qª~ª!ª.~4 o ", '\.:~1d ~'I ~\;:i/'.:··.', '1._;\., :»'~:':I :,j ,llìtf¡~~*g~Y~i,~~:;~~~~1~!IJ:!!~~;~~;: 0.0011'111!,.'900 0.00':' ·...0.00' 0.00"'. I·',;,,:,o¡þo" 0.00 :, ',.', O:<!iO" 0.00 O,op 0.00 '0,00 1.23 '{?3 2.00, 1.40 4.93' ..... '4}~3 2.00. ....... 5.69 7.15,,' 1',11',7:'16 2.50 :. '1',;·'1"·8.:1<:) 14 85 :1' " .'. . 1'~·'R5 2 50 '. ' ;'.1: .j'~, 8? : . 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'1,1, I ',' , ,1'1" : I, ,~ ,I., i I: ,II" " ," 1'1"11. ,Ii 258.36 . ··~"~'28,36 3.50"':~r"(.:"129,~:55 304.051 . . 3.501,",,11' ,'I", "'~~1?8'¡ \,. ~I"'i 342.55 3.50 ~"~:] 412.71 0.00 :.f"'i 431.50 4.00 0 "1"".1,' 463.64 4.00 :~~,(::i.31 485.88 4.00 :1:.I'::i!I' 545.281".' 4.001,:\':1":'::,'1' 'I 609.42 !' , 4.00 ¡ III '1::""'1 2.19 I 677 98 ,,':. 4 00 L.I,'.'.,·:II.',[I',..., ,.,. .11"., .1::1, '15.'0 II"'" 1'1,1, ;~ ¡,:III""'Y~ I 750:63 I:"~ ',161Ih:jI3<5 4:00il~:"I:'1~13d}1d 827.01'::r¡.,~3"jl'ri7" 4.00' ",:908;~;4 906.75",!¡,.,16~7':1112· 4.00 '·",'·'·~8~:'73 989.47 1:1 ',"1'6561!'~4'; 4. 00 ',Iii,': "1'Þ!t21!97 1'1"'1 ,I,., .'-,,":::11,'1 ,1EJ.·d::, " 1022.66" '~II 4.00""·'I,,~,10Q.~4 1244.411"'1;1 '9' 0.00 ;'r!"'::':/,'.I:.,!,.,H"'I"'36 1 1669.6311,111 ",,'ll 0.00 ,', ·,,'1'1., r·· , 2094.85 0.00:'",,, ., , .:'1 \) II '::~II.':" ' ": ;!rl ,i" -",.. ~":. '.,1,1,/,,1' " :, 2520.081\',.;"".. ' 0.00 '".;i,":(~,'.,·?~,~,?!~21 2751.99 "I'I:'I"i:7,.5~¡38 0.00 .'. '12å$~,~'27 ".,......,..,'..'.,..",'..',.,',11:,,:...".'.·1.1.".1'1'.'.';".'"...,1.1'.'."", ',,1'.""'1·1,1,,1,.,.., J..;..I:'.'..I...'..,.,."'I;.."III.¡ ".1 2945.30':', ,I' rf3:9$ 0.00 ¡i':' ::"~O~4:11' 3370.52 !, '...'.. .,1...,'.,.: 1::'ZI:í,."..'.'1:.";:II~."4! 0.00 Ill;, :.,::.~:'.~ß44. .' .~: '1. O. I, ':,':,'.,.'!')II~,' ',~; ,"' - I" ~ ,I"" I,:',: :~':",Lr-,':I~"'"VL~ 3795.74',·,",...,'.,.".':",,8. .11.,:O~, 3~.·. . 0.00 ,.1....1.",""11',.·'....'.3. 8. 7.2;:49.. .,!, " 'I"I,'¡"",',IIII'. 'I'I"I"" 1",1"', 1'·"2,,',1'" "', 4135.92::'/.liI,:~~ê"i~'" 0.00: ·'·'i."141,,~(~4, 4147.71 :i::;;:,:,~~~.56 0.00,':ð~~~;60 4220.96:i:r}"~~~~'~15,' 0.00 .'I,::::llil:,~~~,6ß( 4646.181:i:i\~8~,¡~~ 0.00 ...',:,..,47.fÞ..~6 5071.40 1"¡;'r~Z~:~7 0.00 ',":\,p,1~~:95 5496.63 ii'':IAI,ªp~;J8 0.00 i,!':!":,:p!?~9~?4i 5921.85~" ¡,i~~6i39 0.00 :-",'.'~:599~~43 6347.071:-'I>-·\:9¡~i60· 0.00'-":';: ,'6'41"7.61 6638.13 : .,:,,~~5\48 0.00 - 6707.96 6686.79 '9Øß.38 3.00 675ß.94 6768.77. .974.43 3.00.. ·6&313'95 6847.68" 'i'~8'1;76 3.00 69,1f70 6923.3199q,36 3.00 6$93;78 6995.441990.20 3.00 7066.58 7063.89 1011.25 3.00 7135.90 7128.45 1023.49 3.00 7201.55 7170.50 ,1Ö~~:_98 3.00 r?44,47 7170.51 1Ö32:~ 3.00 ..7~~,48 7189.17 1<).3~.ª3 0.00.7263.55 7248.91 1q~9.¥ 0.00 7ª2~.~~ 7303.711t;1~,~iI¡l2 0.00 7:AAg·6,4 7308.65' '1 Q~.0.4 0.00 73~!5~69 7368.39 ,'!JÒ7,:r.6!5 0.00 ..., ]446.76 7428.14 '. '1qá1:;~5 0.00·'j~:i:ä3 7487.88. 1'1q4;.86 0.00 75a~.90 7544.84 HJl.~ 0.00 7627;14 7547.62 1118:47 0.00 7629.97 7607.36, 1t~~.Ó7 0.00 , (~~j,;Q4 7623.30 .113!5:70 0.00 77Ò7.~ 7623.31 1}~;71 0.00 770I35 7646.14 ':::ë.1i4þ;,9º 0.00 1!ªg,:~~ ,'",\, '; , J 71 72 73 ) 6877.00,1: ,ij$3â'20 521777 836Ò3~8§ir.4~ 7684.69' "'11,,1"~9.69 6932. 76: ,,:~~~:~:9,Ø 521787:32',::&Q;~~'~~'~:~ål 7726.84 .:"1'1~Q:2Q 7046.80 '.7º9ê,ºº 521806.74 /êº~~~ª5;ª'? 7813.04':11:7~:!~? O r..;~1 , ~ ,,'. (I.'.) ~ .. H'i / . l, ¡ì ~~~,¡ ,1 , ; \ :¡ , ~ ) 0.00' '·'·'~k~O;'9~ 0.00'7&'1:3.Jª O. 00:"<Z~q'~,,.3(l Company: Field: Reference Site: Reference 'Well: Ref~rence .W:eJlpªt~: ) ) Baker Hughes Incorporated Anticollision Report ConocoPhillips Alaska,lnc. KuparukRiver Unit Pad 3R 9 Oliktók pt Sf.1 Vers#3 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD + Stations Interval: 100.00 ft Depth Range: 0.00 to 11144.30 ft Maximum Radius: 10000.00 ft Survey Program for Definitive Wellpath Date: 4/17/2003 Validated: No Planned From To Survey ft ft 0.00 11144.30 Planned: Oliktok pt St 1 Vers# Casing Points MD ft 6400.00 11144.30 TVD Diametèr Hole Size 'N lime ft in in 4171.74 9.625 12.250 95/8" 7046.80 7.000 8.500 7" Summary <-.......... - Site Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Pad 3R Date:4/t7/2003 Time: 10:36:43 Page: CO·Qrdinate(NE) Reference: Vertl':a] (TVD) Reference: Well: 9, True North Wellhead(38.8') 38.8 Reference: Error Model: Scan Method: Error Surface: Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Version: 0 Toolcode Tool Name MWD+SAG MWD + Sag correction - Offset 'Yellpath ...';._~.-:-~.~".~ Well , WeUpa~h.·., 10 10 11 12 14 15 17 18 19 20 21 22 25 26 26 Olik Pt#2A Olik Pt#2A 3R-10 V4 3R-10A VO 3R-11 VO 3R-12 VO 3R-14 VO 3R-15 VO 3R-17 VO 3R-18 VO 3R-19 VO 3R-20 VO 3R-21 VO 3R-22 VO 3R-25 VO 3R-26 VO 3R-26A VO Olik Pt 2A VO Olik St Pt#2 VO Reference ' Offset qr"CtrNo.Go Allowable ,·.M'D' 'MD Distance Area Devia.tion Warning ft ft ft ft ft 486.24 500.00 26.81 10.00 16.81 Pass: Major Risk 486.24 500.00 26.81 10.00 16.81 Pass: Major Risk 386.11 400.00 49.50 7.66 41.85 Pass: Major Risk 484.50 500.00 75.41 9.04 66.36 Pass: Major Risk 384.34 400.00 191.29 7.22 184.07 Pass: Major Risk 384.06 400.00 215.68 7.21 208.47 Pass: Major Risk 383.34 400.00 266.68 7.20 259.48 Pass: Major Risk 383.02 400.00 292.26 7.19 285.07 Pass: Major Risk 382.74 400.00 316.53 7.19 309.34 Pass: Major Risk 382.49 400.00 342.25 7.18 335.07 Pass: Major Risk 286.78 300.00 365.99 5.43 360.56 Pass: Major Risk 381.87 400.00 390.66 7.17 383.49 Pass: Major Risk 383.68 400.00 242.09 7.20 234.89 Pass: Major Risk 383.52 400.00 164.20 7.91 156.30 Pass: Major Risk 383.52 400.00 164.20 7.91 156.30 Pass: Major Risk 2369.71 5100.00 2605.91 116.74 2523.86 Pass: Major Risk 2100.00 4400.00 2613.78 96.83 2546.82 Pass: Major Risk OR "q /),r \ i i i ,~ ~ .~ , ;,¡ J t~,., -360 ^ ill' '1 600 I -320 Z 0 :¡. ;11500 ::r -280 "......., -+. CD CD - 240 - .......,., '* '1400 -200 -160 -120 . '11 00 - 80 - 40 ~ 0 - 40 - 80 ) ConocoPhillips Alaska, Inc. Creat.d by bm!chao¡ For: B Penrose oat. plottod: 9-Moy-2003 Pial Rof.",n"" I. Oliktak PI 51 1 Vor3_ Coordlnat.. % in fo.t ,"I.","eo 0101 *9. True Vertlca Dept". or8 reference RKB (Doyon #141). iii. ... Structure: Pod 3R Well: 9 Field : Kuparuk River Unit Location North Slope. Alaska INl'I!:Q 40 I o , 40 I 120 I East (feet) - > 200 24-0 280 320 I I I I 360 I 400 80 I 160 '* '1700 ORl ~ i~ f .I~, II !.I \ ,'II ) ,~~ ':~~') ~ ~~ , ~';; ;{ ,~ '\ ) ConocæhilliDS ...¿,..',.:'.......',i.;¡:........i.~,.I:,I,~I(f!~'€IIN ~ ':'-\ t' ~",II';' 44-0 , 480 600 680 e- 520 I 560 I I I I I I I - 64-0 I I ,: 1900 - 600 I I I I I I I I ¡ 1600 -560 -520 I I - 4-80 - 4-40 - 4-00 ) ) t creato~ by bmlahaol For: B Penrose Dat. ploUod: g-l.4ay-200J Plot Roforonco la Oliktok PI 51 1 VerJ. Coordlnatoa are In foot rohlrana. alot 19. True V.rtlcol OÐptha or. ref.ronco RKB (Doyon "1.1). structure: Pad 3R Well: 9 .."..,... ConocoPhilliDS ~!R#MW ConocoPhillips Alaska, Inc. field : Kuparuk River Unit Location North Slope. Alaska ..I: I NU;Q East (feet) -> 3000 2500 2000 1500 1000 500 o 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 - 9500 - 9000 - 8500 - 8000 .PJ7000 I I ~ 6500 - 7500 ~ 6000 - 7000 - 6500 ~ 5500 - 6000 ^ ~ 5000 - 5500 I Z 0 , - 5000 -+ :J .;. 4500 ..-..- -+. - 4500 CD CI> -+ "-'" - 4000 .;. 4000 - 3500 10A - 3000 ,1.5' - 2500 5500 - 2000 - 1500 - 1000 - 500 I, (,j , l ) Creotod by bmlchool For: B Penrose Doto ploUod: 9-Mcy-2003 Plct Roforenco 10 Ollktok pt 5t 1 Vor3. Coordinatoa are in feet referenco .,Iot 19. True Vortlcol Ooptho or. reference RKB (Doyon '141). Bi. .... structure: Pad 3R Well: 9 ......./ ConocoPhillips ~ ConocoPhillips Alaska, Inc. Field : Kuparuk River Unit Location: North Slope, Alaska I NU;Q 330 TRUE NORTH <:?- c:::J 350 0 1 0 210 20 340 30 240 310 50 320 40 300 60 290 70 280 80 270 90 260 100 250 11 0 120 230 130 220 140 150 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ¡{"St)':' ì:1.~·,i' ,'.',,' 'I. ~;.. "" "r .1 I '~:," , ,111 ~~ <'¡ ~ ) Baker Hughes Incorporated Error Ellipse Survey Report ) Company: ConocoPhiUips Alaska,lnc. Field: Kuparuk River Unit Site: Pad3R Well: 9 Wellpath: Oliktok pt 5t t Vers#3 Field: Kuparuk River Unit North Slope, Alaska USA Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Date:4/17/20P3 Time: 10:50:18 Page: Co;ordinate(NE) Reference: WeU:9. True North Vertical (I'VD) .Reference: WeUhead(38.8') 38.8 Section(VS)Referen~e: Well· (0.00N,O,00E,8.58Azi) ~urvey Calculation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: Pad 3R Site Position: Northing: 6033356.18 ft Latitude: 70 30 8.305 N From: Map Easting: 518296.98 ft Longitude: 149 51 1.222 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.14 deg Well: 9 Slot Name: Well Position: +N/-S -1691.45 ft Northing: 6031670.68 ft Latitude: 70 29 51.666 N +E/-W 2346.27 ft Easting : 520647.18 ft Longitude: 149 49 52.156 W Position Uncertainty: 0.00 ft Wellpath: Oliktok pt St 1 Vers#3 Drilled From: Surface Tie-on Depth: 0.00 ft Current Datum: Wellhead(38.8') Height 38.80 ft Above System Datum: Mean Sea Level Magnetic Data: 4/17/2003 Declination: 25.37 deg Field Strength: 57498 nT Mag Dip Angle: 80.83 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 8.58 Survey Program for Definitive Wellpath Date: 4/17/2003 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 0.00 11144.30 Planned: Oliktok pt St 1 Vers# MWD+SAG MWD + Sag correction Position uncertainty and bias at survey station All uncertainties at 2.6 standard deviation Highside-----> Lateral-------> Vertical------> Magn. Semi-major Semi-minor MD Incl Azim TVD Unc. Bias Unc. Bias Unc. Bias of Bias Unc. Unc. Azimuth Tool ft deg deg ft ft ft ft ft ft ft ft ft ft deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE LINE 100.00 0.00 0.00 100.00 0.09 0.00 0.09 0.00 2.96 0.00 0.00 0.09 0.09 0.00 MWD+SAG 200.00 0.00 0.00 200.00 0.38 0.00 0.38 0.00 2.96 0.00 0.00 0.38 0.38 0.00 MWD+SAG 300.00 0.00 0.00 300.00 0.67 0.00 0.67 0.00 2.97 0.01 0.01 0.67 0.67 0.00 MWD+SAG 400.00 2.00 45.00 399.98 0.92 0.00 0.92 0.00 2.97 0.02 0.02 0.92 0.92 135.00 MWD+SAG 500.00 4.00 45.00 499.84 1.17 0.00 1.18 0.00 2.97 0.03 0.03 1.19 1.17 82.86 MWD+SAG 600.00 6.50 45.00 599.41 1.43 0.00 1.52 0.00 2.97 0.04 0.04 1.52 1.45 55.36 MWD+SAG 700.00 9.00 45.00 698.49 1.70 0.00 1.98 0.01 2.96 0.06 0.06 1.98 1.75 49.80 MWD+SAG 800.00 12.50 45.00 796.72 1.97 -0.01 2.61 0.01 2.95 0.08 0.08 2.61 2.06 47.86 MWD+SAG 900.00 16.00 45.00 893.63 2.24 -0.01 3.46 0.02 2.93 0.10 0.10 3.46 2.38 46.92 MWD+SAG 1000.00 19.50 45.00 988.85 2.51 -0.02 4.54 0.04 2.90 0.12 0.13 4.54 2.70 46.40 MWD+SAG 1100.00 23.00 45.00 1082.04 2.78 -0.03 5.85 0.07 2.87 0.14 0.16 5.85 3.03 46.08 MWD+SAG 1200.00 26.50 45.00 1172.83 3.05 -0.04 7.39 0.10 2.84 0.17 0.20 7.39 3.36 45.87 MWD+SAG 1300.00 30.00 45.00 1260.91 3.32 -0.05 9.15 0.15 2.82 0.20 0.25 9.15 3.68 45.73 MWD+SAG 1400.00 33.50 45.00 1345.93 3.58 -0.06 11.12 0.20 2.80 0.22 0.31 11.12 4.00 45.62 MWD+SAG 1500.00 37.00 45.00 1427.57 3.84 -0.08 13.29 0.26 2.81 0.25 0.38 13.29 4.31 45.54 MWD+SAG 1600.00 40.50 45.00 1505.55 4.10 -0.09 15.67 0.34 2.83 0.28 0.45 15.67 4.62 45.48 MWD+SAG 1700.00 44.00 45.00 1579.55 4.36 -0.11 18.23 0.43 2.89 0.30 0.54 18.23 4.92 45.43 MWD+SAG 1722.15 44.78 45.00 1595.38 4.41 -0.12 18.82 0.45 2.87 0.31 0.56 18.82 5.01 45.42 MWD+SAG 1800.00 44.78 45.00 1650.64 4.70 -0.12 20.92 0.52 3.00 0.33 0.64 20.92 5.19 45.39 MWD+SAG 1863.02 44.78 45.00 1695.37 4.93 -0.12 22.62 0.58 3.13 0.35 0.70 22.62 5.34 45.36 MWD+SAG 1900.00 45.01 42.93 1721.57 5.08 -0.13 23.4 7 0.62 3.18 0.36 0.74 23.49 5.41 45.32 MWD+SAG O· ry~" I ~~~. ',j I" ..', ' , ,'~ .,,(ìf .~ 1 t:" .¡1 l' ) Baker Hughes Incorporated Error Ellipse Survey Report Company: CohocoPhillips Ala~ka, Inc. ,pate: .. .4/17/2003 i... Time: 10:50:18 Page: 2 Field: ~uparukRi~er Unit C9-o~dinat~(NE)Refe"~,nce: Well: 9, True North Site: pad3R Ver~cal(Tyq)R~fel"ence: Wellhead(38.8') 38.8 Well: 9 $ectiQn(YS)~eference: Well (0.OON,O.OOE,8.58Azi) Wellpath: OliktokPt St1 Vers#3 .SurveyCalculatiol1 Met~od: Minimum Curvature Db: Oracle Position uncertainty and bias at sUrvey station All uncertainties at 2.6 standard deviation Higbside-----> Lateral-----~-> Vertical------> Magn. Semi-major Semi-minor MD bel Azim TVD Unc. Bias Unc. Bias Unc. Bias of Bias Une. Une. Azimuth Tool ft deg deg ft ft ft ft ft ft ft ft ft ft deg 2000.00 45.81 37.42 1791.80 5.68 -0.18 25.36 0.71 3.29 0.39 0.82 25.56 5.55 44.87 MWD+SAG 2100.00 46.86 32.09 1860.87 6.63 -0.24 27.16 0.77 3.43 0.42 0.88 27.73 5.70 44.02 MWD+SAG 2200.00 48.16 26.96 1928.44 7.76 -0.30 28.88 0.80 3.58 0.45 0.92 29.97 5.90 42.82 MWD+SAG 2300.00 49.67 22.04 1994.18 8.94 -0.35 30.53 0.80 3.77 0.48 0.93 32.28 6.14 41.34 MWD+SAG 2400.00 51.38 17.36 2057.78 10.09 -0.40 32.14 0.77 3.97 0.51 0.92 34.64 6.45 39.65 MWD+SAG 2500.00 53.27 12.90 2118.91 11.13 -0.45 33.75 0.70 4.20 0.54 0.88 37.06 6.82 37.76 MWD+SAG 2600.00 55.32 8.67 2177.28 12.03 -0.48 35.36 0.60 4.46 0.56 0.83 39.54 7.26 35.74 MWD+SAG 2700.00 57.51 4.65 2232.62 12.76 -0.52 37.02 0.47 4.73 0.59 0.76 42.09 7.78 33.59 MWD+SAG 2739.25 58.40 3.12 2253.44 12.99 -0.53 37.69 0.41 4.84 0.60 0.73 43.11 8.01 32.73 MWD+SAG 2800.00 58.40 3.12 2285.28 13.11 -0.53 39.55 0.31 5.03 0.62 0.69 44.72 8.26 31.46 MWD+SAG 2900.00 58.40 3.12 2337.68 13.33 -0.53 42.62 0.16 5.34 0.64 0.66 47.44 8.52 29.62 MWD+SAG 3000.00 58.40 3.12 2390.08 13.56 -0.53 45.73 0.00 5.67 0.67 0.67 50.23 8.80 27.96 MWD+SAG 3100.00 58.40 3.12 2442.48 13.80 -0.53 48.87 -0.16 6.00 0.70 0.73 53.08 9.09 26.46 MWD+SAG 3200.00 58.40 3.12 2494.88 14.05 -0.53 52.03 -0.32 6.33 0.73 0.81 55.98 9.38 25.11 MWD+SAG 3300.00 58.40 3.12 2547.29 14.30 -0.53 55.21 -0.48 6.67 0.75 0.92 58.93 9.67 23.88 MWD+SAG 3400.00 58.40 3.12 2599.69 14.57 -0.53 58.41 -0.63 7.01 0.78 1.04 61.91 9.96 22.76 MWD+SAG 3500.00 58.40 3.12 2652.09 14.84 -0.53 61.62 -0.79 7.35 0.82 1.18 64.93 10.24 21.75 MWD+SAG 3600.00 58.40 3.12 2704.49 15.12 -0.53 64.84 -0.95 7.69 0.85 1.33 67.98 10.52 20.83 MWD+SAG 3700.00 58.40 3.12 2756.89 15.41 -0.53 68.08 -1.11 8.04 0.88 1.48 71.06 10.79 19.98 MWD+SAG 3800.00 58.40 3.12 2809.29 15.70 -0.53 71.32 -1.27 8.39 0.91 1.63 74.16 11.06 19.21 MWD+SAG 3900.00 58.40 3.12 2861.70 16.00 -0.53 74.57 -1.43 8.74 0.95 1.79 77.27 11.32 18.50 MWD+SAG 4000.00 58.40 3.12 2914.10 16.31 -0.53 77.83 -1.58 9.09 0.98 1.95 80.41 11.57 17.84 MWD+SAG 4100.00 58.40 3.12 2966.50 16.62 -0.53 81.09 -1.74 9.44 1.02 2.12 83.56 11.83 17.24 MWD+SAG 4200.00 58.40 3.12 3018.90 16.94 -0.53 84.36 -1.90 9.80 1.05 2.28 86.73 12.07 16.68 MWD+SAG 4300.00 58.40 3.12 3071.30 17.26 -0.53 87.63 -2.06 10.15 1.09 2.45 89.90 12.31 16.16 MWD+SAG 4400.00 58.40 3.12 3123.70 17.58 -0.53 90.91 -2.22 10.51 1.13 2.62 93.09 12.55 15.67 MWD+SAG 4500.00 58.40 3.12 3176.10 17.91 -0.53 94.19 -2.37 10.86 1.16 2.79 96.29 12.79 15.22 MWD+SAG 4600.00 58.40 3.12 3228.51 18.25 -0.53 97.47 -2.53 11.22 1.20 2.96 99.50 13.02 14.80 MWD+SAG 4700.00 58.40 3.12 3280.91 18.59 -0.53 100.76 -2.69 11.58 1.24 3.13 102.71 13.25 14.40 MWD+SAG 4800.00 58.40 3.12 3333.31 18.93 -0.53 104.05 -2.85 11.94 1.28 3.30 105.94 13.48 14.04 MWD+SAG 4900.00 58.40 3.12 3385.71 19.27 -0.53 107.34 -3.01 12.30 1.32 3.48 109.16 13.71 13.69 MWD+SAG 5000.00 58.40 3.12 3438.11 19.62 -0.53 110.64 -3.17 12.66 1.37 3.65 112.40 13.93 13.36 MWD+SAG 5100.00 58.40 3.12 3490.51 19.98 -0.53 113.94 -3.32 13.02 1.41 3.83 115.64 14.16 13.05 MWD+SAG 5200.00 58.40 3.12 3542.92 20.33 -0.53 117.23 -3.48 13.38 1.45 4.01 118.89 14.38 12.76 MWD+SAG 5300.00 58.40 3.12 3595.32 20.69 -0.53 120.53 -3.64 13.74 1.50 4.18 122.14 14.60 12.49 MWD+SAG 5400.00 58.40 3.12 3647.72 21.05 -0.53 123.84 -3.80 14.10 1.54 4.36 125.39 14.82 12.23 MWD+SAG 5500.00 58.40 3.12 3700.12 21.41 -0.53 127.14 -3.96 14.46 1.59 4.54 128.65 15.04 11.98 MWD+SAG 5600.00 58.40 3.12 3752.52 21.78 -0.53 1 30.45 -4.11 14.82 1.63 4.72 131.92 15.26 11.75 MWD+SAG 5700.00 58.40 3.12 3804.92 22.15 -0.53 133.75 -4.27 15.18 1.68 4.90 135.18 15.4 7 11.53 MWD+SAG 5800.00 58.40 3.12 3857.33 22.52 -0.53 137.06 -4.43 15.54 1.73 5.08 138.45 15.69 11.32 MWD+SAG 5900.00 58.40 3.12 3909.73 22.89 -0.53 140.37 -4.59 15.91 1.77 5.27 141.73 15.91 11.12 MWD+SAG 6000.00 58.40 3.12 3962.13 23.26 -0.53 143.68 -4.75 16.27 1.82 5.45 145.00 16.12 10.92 MWD+SAG 6100.00 58.40 3.12 4014.53 23.64 -0.53 146.99 -4.90 16.63 1.87 5.63 148.28 16.34 10.74 MWD+SAG 6200.00 58.40 3.12 4066.93 24.02 -0.53 150.30 -5.06 17.00 1.92 5.82 151.56 16.55 10.57 MWD+SAG 6300.00 58.40 3.12 4119.33 24.40 -0.53 153.61 -5.22 17.36 1.98 6.00 154.84 16.76 10.40 MWD+SAG 6400.00 58.40 3.12 4171.74 24.78 -0.53 156.92 -5.38 17.72 2.03 6.19 158.13 16.98 10.24 MWD+SAG 6500.00 58.40 3.12 4224.14 25.16 -0.53 160.24 -5.54 18.09 2.08 6.37 161.41 17.19 10.09 MWD+SAG 6600.00 58.40 3.12 4276.54 25.54 -0.53 163.55 -5.70 18.45 2.13 6.56 164.70 17.41 9.94 MWD+SAG 6700.00 58.40 3.12 4328.94 25.93 -0.53 166.87 -5.85 18.81 2.19 6.75 167.99 17.62 9.80 MWD+SAG 6800.00 58.40 3.12 4381.34 26.32 -0.53 170.18 -6.01 19.18 2.24 6.94 171.28 17.83 9.66 MWD+SAG 6900.00 58.40 3.12 4433.74 26.71 -0.53 173.50 -6.17 19.54 2.30 7.13 174.58 18.05 9.53 MWD+SAG 7000.00 58.40 3.12 4486.14 27.10 -0.53 176.81 -6.33 19.91 2.36 7.32 177.87 18.26 9.41 MWD+SAG 7100.00 58.40 3.12 4538.55 27.49 -0.53 180.13 -6.49 20.27 2.41 7.51 181.17 18.47 9.29 MWD+SAG ~ -C'" ," ,,- . l·! 'I ~.':_'" , . h '! ) Baker Hughes Incorporated Error Ellipse Survey Report Company: ConocoPhillips Alaska, Inc. Date: '. 4117/~P03 Time: 10:50:18 Page: 3 Field: KuparUk River Unit Co-oI:'dinate(:NE),Referenee: WeU:9,True North Site: Pad3R Verticál çrVD)Ite~erence: W~lIh~.ad(38.8') 3S.8 Well: 9 Seetio~ (V~)J~eferencc:: .. . Well (0.00N,O.00E,8.58Azi) Wellpatb: Oliktok PLStt Vers#3 ~µr~FyÇal~ulatiol) Methód: Minimum Curvature Db: Oracle Position u~eertainty !tndðias~t$u~ve;ystation.. Laterål~--~--~ Vertieal---~~> l\fagn. Semi-major Semi-minor All ~ncertain~ies'at 2.6,. standard ,deviation Hi~hside-;;~-> MD Incl Azbn TVD Unc; Bias Uric. '.,' Bias Une. Bia.s óf.BiasUne. Vne. Azimuth Tool ft d~g d~g ft ft ft ft ft ft ft ft ft ft deg 7200.00 58.40 3.12 4590.95 27.88 -0.53 183.45 -6.64 20.64 2.47 7.70 184.46 18.69 9.17 MWD+SAG 7300.00 58.40 3.12 4643.35 28.27 -0.53 186.77 -6.80 21.00 2.53 7.89 187.76 18.90 9.06 MWD+SAG 7400.00 58.40 3.12 4695.75 28.67 -0.53 190.09 -6.96 21.37 2.59 8.09 191.06 19.12 8.95 MWD+SAG 7500.00 58.40 3.12 4748.15 29.06 -0.53 193.40 -7.12 21.73 2.65 8.28 194.36 19.33 8.84 MWD+SAG 7600.00 58.40 3.12 4800.55 29.46 -0.53 196.72 -7.28 22.10 2.71 8.48 197.66 19.54 8.74 MWD+SAG 7700.00 58.40 3.12 4852.96 29.85 -0.53 200.04 -7.44 22.46 2.77 8.67 200.97 19.76 8.65 MWD+SAG 7800.00 58.40 3.12 4905.36 30.25 -0.53 203.36 -7.59 22.83 2.83 8.87 204.27 19.97 8.55 MWD+SAG 7900.00 58.40 3.12 4957.76 30.65 -0.53 206.68 -7.75 23.19 2.90 9.07 207.57 20.18 8.46 MWD+SAG 8000.00 58.40 3.12 5010.16 31.05 -0.53 210.00 -7.91 23.56 2.96 9.26 210.88 20.40 8.37 MWD+SAG 8100.00 58.40 3.12 5062.56 31.45 -0.53 213.32 -8.07 23.92 3.03 9.46 214.19 20.61 8.29 MWD+SAG 8200.00 58.40 3.12 5114.96 31.85 -0.53 216.65 -8.23 24.29 3.09 9.66 217.49 20.83 8.21 MWD+SAG 8300.00 58.40 3.12 5167.37 32.25 -0.53 219.97 -8.38 24.65 3.16 9.86 220.80 21.04 8.13 MWD+SAG 8400.00 58.40 3.12 5219.77 32.66 -0.53 223.29 -8.54 25.02 3.22 10.07 224.11 21.26 8.05 MWD+SAG 8500.00 58.40 3.12 5272.17 33.06 -0.53 226.61 -8.70 25.38 3.29 10.27 227.42 21.47 7.97 MWD+SAG 8600.00 58.40 3.12 5324.57 33.46 -0.53 229.93 -8.86 25.75 3.36 10.47 230.73 21.69 7.90 MWD+SAG 8700.00 58.40 3.12 5376.97 33.87 -0.53 233.26 -9.02 26.12 3.43 10.67 234.04 21.90 7.83 MWD+SAG 8800.00 58.40 3.12 5429.37 34.27 -0.53 236.58 -9.18 26.48 3.50 10.88 237.35 22.12 7.76 MWD+SAG 8900.00 58.40 3.12 5481.77 34.68 -0.53 239.90 -9.33 26.85 3.57 11.08 240.66 22.33 7.69 MWD+SAG 9000.00 58.40 3.12 5534.18 35.09 -0.53 243.22 -9.49 27.21 3.64 11.29 243.97 22.55 7.63 MWD+SAG 9100.00 58.40 3.12 5586.58 35.49 -0.53 246.55 -9.65 27.58 3.71 11.50 247.28 22.76 7.56 MWD+SAG 9200.00 58.40 3.12 5638.98 35.90 -0.53 249.87 -9.81 27.95 3.79 11.71 250.60 22.98 7.50 MWD+SAG 9300.00 58.40 3.12 5691.38 36.31 -0.53 253.20 -9.97 28.31 3.86 11.91 253.91 23.20 7.44 MWD+SAG 9342.25 58.40 3.12 5713.52 36.48 -0.53 254.60 -10.03 28.47 3.89 12.00 255.31 23.29 7.42 MWD+SAG 9400.00 56.74 3.70 5744.49 36.50 -0.39 256.22 -10.18 28.59 3.93 12.12 256.75 23.36 7.39 MWD+SAG 9500.00 53.86 4.75 5801.42 36.25 -0.17 258.15 -10.41 28.67 4.02 12.32 258.42 23.39 7.37 MWD+SAG 9600.00 51.00 5.88 5862.38 35.97 0.03 259.95 -10.64 28.74 4.11 12.51 260.04 23.42 7.36 MWD+SAG 9700.00 48.15 7.11 5927.22 35.80 0.21 261.59 -10.86 28.80 4.22 12.68 261.60 23.45 7.35 MWD+SAG 9800.00 45.31 8.45 5995.76 35.94 0.36 263.04 -11.06 28.86 4.33 12.85 263.09 23.47 7.35 MWD+SAG 9900.00 42.49 9.93 6067.81 36.71 0.47 264.25 -11 .27 28.91 4.46 13.01 264.52 23.50 7.36 MWD+SAG 10000.00 39.70 11.58 6143.17 38.48 0.54 265.15 -11.46 28.96 4.60 13.15 265.86 23.52 7.38 MWD+SAG 10068.76 37.79 12.83 6196.80 40.51 0.56 265.55 -11.59 28.99 4.70 13.24 266.74 23.54 7.40 MWD+SAG 10100.00 37.79 12.83 6221.49 40.56 0.56 266.11 -11.61 29.03 4.74 13.28 267.29 23.59 7.41 MWD+SAG 10200.00 37.79 12.83 6300.52 40.88 0.56 268.41 -11.66 29.26 4.90 13.42 269.58 23.87 7.46 MWD+SAG 10300.00 37.79 12.83 6379.55 41.19 0.56 270.71 -11.70 29.49 5.05 13.55 271.87 24.15 7.50 MWD+SAG 10400.00 37.79 12.83 6458.58 41.51 0.56 273.01 -11.75 29.71 5.20 13.69 274.17 24.43 7.55 MWD+SAG 10500.00 37.79 12.83 6537.61 41.83 0.56 275.31 -11.80 29.94 5.36 13.84 276.46 24.71 7.59 MWD+SAG 10600.00 37.79 12.83 6616.64 42.15 0.56 277.62 -11.84 30.16 5.51 13.98 278.75 24.99 7.63 MWD+SAG 10700.00 37.79 12.83 6695.67 42.47 0.56 279.92 -11.89 30.39 5.67 14.13 281.05 25.27 7.68 MWD+SAG 10800.00 37.79 12.83 6774.70 42.79 0.56 282.22 -11.94 30.62 5.83 14.28 283.34 25.56 7.72 MWD+SAG 10900.00 37.79 12.83 6853.73 43.11 0.56 284.53 -11.98 30.84 6.00 14.43 285.64 25.84 7.76 MWD+SAG 11000.00 37.79 12.83 6932.76 43.43 0.56 286.83 -12.03 31.07 6.16 14.59 287.93 26.12 7.80 MWD+SAG 11100.00 37.79 12.83 7011.79 43.76 0.56 289.14 -12.08 31.30 6.33 14.74 290.23 26.41 7.84 MWD+SAG 11144.30 37.79 12.83 7046.80 43.90 0.56 290.16 -12.10 31 .40 6.40 14.81 291.25 26.53 7.86 MWD+SAG ./1 [: I~A"\ ; J~ ( nI .::. ,-"I"~ " '...... ~,. '''I' '.' ' . .wi' ') STATE OF ALASKA ALASKA. OIL AND GAS CONSERVATION COMMISSION DESIONA 11 ON Of OPERATOR. 20 AAC 25.020 .. I Na11\R and. A.ðd;l:'t!:1!1tt ot Owne t ~ W/11..5' tift. r ~ irole t./f)'J LI...CL p 0, ßrOx J3t.y Pe /e.. r 5' j, ~ r!J.J #k' 9 "R'i(~ "i.U .NQtfee J.S ~¢.:r~bf g:i.~l'l O!-' ~ d4ll;"i~àt:1ëm" 'àt OoX)(:!l'.,tor!šhi.p !or. t)jo'/!';¡ ~~1i "And. 'gòl~ .. pl"OJ)t):rt.y d.e-.er .1..t-ed. I&ol.o., ~ S "7/} T E L..E.IJ 51?" #.7) L 3 r~ 5?1:1 L6g'~ deec;::riø-tion of J)t'o'D$rt.y: ........, - .._ - _._ 0.. \__,. T /.lJ4/ It(q £; tll7J ;/J..? ;1l~; d /~h ) ~ . 5~¡ :;8') fräfro._c.-fed, Q,IL Ti'de.. c¿nJ .:>uJme'Y~J kds ¿;fb~~ ! See.....a~ !',.drac.feira..l/ ~./~~ "J S'ttJ.hf""'Jc!'~.JQ.n¿5 ¿#o dC'r~.s P~ope~ty ~lat At~~~4 ~ .. ·'1[7···· - .... \ ¡III' _ \/ .......,.., \" . -... ~'.t'\.,..,tl"f..... ... _. I J. Ham. .rod A~d¡~$S ot Oe~i9~~ted O~.ra~or: GO/lCC!.,O PA///J,P5 ,A-Âa..sk~, 700 C- 51"",-. l!?~-+ /l11f!.ADrILJ e ¡1,,1-)( 9?~--oJ ~L /1/ (!... , - .. . .~. £tfcçt~ve ga~c of de5iqna(icn: ,.- --...... -... \. JI.~O~¡¡t4.nC<l! of. ð~~.t::at()~tbi~...-f~~ u.. ~bC't~..- d~;~'~Tb~~ prOlpex'ty ...ltb. ä.,Ù-'··~~t~~&nt rC$pon.$~biUtits Ar\(S oOllga·~1.DÕ)" i:'.! htti:"tllby .çbO'Þollc d.\)". S.igned I fA- . :ot~ ~... tP!':L":f(!,~ . .. __..._ _"...__ . . 'h.ti.,~u"hll) \ . . -..' _.- . -~ '. '-. , . . ,. Tht~'~er re~1 ~,r~~:-1~~ t~At 1~~ t9~~1~~B~ i~ t~q ~Rd ~~~~~~~. , $1g-ned ~ ~~d _ ..n._- T)at~ '-I-/~~O-:{. ~K¡.. (~l t~)__..;r..ç:tl~~-,~.r+~~: u __ htLt;priat~~) ~"\~~~~~~__--_"'U..IU ~ . ·~pp~o~.~ D4c~ Cow~¡¡IJÐ.r 1\~j)J:'òvad. '. - -. - . . --. "-~"._"'. _. -'41"a1 ~ ___. I)...t:.e _.... . cœr.~~~.LlÞWr ~PP2:Q""ed . ~- ¡II' - . Y··. -...,. i '~uum~r J ¡ tl!~U~ r.~:s t~~':. ~~.~:ðtur.e_:lr: ~~Su. o~a. ANt) GAS CON~:~'¡~~ON _:O~~IS$IO~ plDrm 1et-.." ....., 01.~.': ~ ....-..-.'''. ",t D...tl": I ....j ~ :S~bm¡' 'in dll~lko\.t' ro 3~l1d ,.~ 2~d Of~ ",/'"'''' p ~, ~ I ~00\1 Ii\" j j ,/ .->'11 ~'~¿~J..~¿3& ~:1t tQQl/~lJ1Q ~""():An f='n Rr ...1014 eeo:yy EO 80 r;;ew ) ") EXHIBIT A r'O, , .. "'-'f"-~,- _ 'M"-' 28 Tr~86- \ 84 _ _ .... ...._ ~ _ 1M....;....... .--. ...- 1280· Ac. 33 L.,., TRACT 86-184 T. 14 N., R. 9 E., Umiat Meridian. Alaska, Sectìcn 28, Protracted, AI[ tide and ~ubmerged lands., 640.00 acres; Sec1io~ 33, Protracted~ All tide âr1d submerged léJ.i,ds, 640.00 aems; This tract contains 1,280.00 acres more or less. o I ¡ '1,,;,., ,'f L E·d e£O:Yl E:O 80 hew APD Revision: Oliktok Point State #1 ) ') Subject: APD Revision: Oliktok Point State #1 Date: Thu, 5 Jun 2003 14:20:29 -0800 From: Bill Penrose <bill@fairweather.com> To: "Tom Maunder (E-mail)..<tom_maunder@admin.state.ak.us> CC: "Tom Brockway (E-mail)..<Thomas.A.Brockway@conocophillips.com> «ASP, Risks,etc. .doc» Tom, Per our discussion earlier, please find attached a revised Anticipated Surface Pressure section of the subject APD. The mud weight range in the last hole section as specified in the mud properties chart has been increased to 9.0 - 10.5 ppg to better match the calculation in the MASP section that indicates a potential 1 0.1 ppg gradient at TO. Please replace the originally submitted section with this one, Regards, Bill '""""""""''''''''''''N''''''''.''.''''''< "'."''''''.W'"''''''''''"<"''.'"'.'"''''''''''''<·''''<***<_'<*''"<W'<'''''<''''''<''<""*.'__*~"""""""''''''''''''<"''''"'''''""""",,,,,,,,,,,,""<,,,,,w.".,,,,"",.' """""''''<'''''''''"''''''''<''"'''.''1 Name: ASP, Risks,etc..doc ,,' DASP, Risks,etc..doc Type: WINWORD File (apPlication/mSWOrd)... · ! . Encoding: base64 :'k"'" \-~.. " ",' Ii ',':i ".. ',;';-', .,.." " :c," ""10'."" "·'Ii,XI¡i,¡".;ii.-"--'·, -;''''''' """~,"'''' ,Ai.-'''''''.''''i.';,..:,~' "".".' "'i"i "'." .,. ',","':" ....." '" "!...'....."....",",,,¡.'-"""'-'",,'M'", ,- ':i""'" ." v'.·· -,' "'N ," ii'¡'¡;''' .. , 'in "', 1 of 1 6/5/2003 2:36 PM H2S Questions ) ) Subject: H2S Questions Date: Thu, 5 Jun 2003 10:47:56 -0800 From: Bill Penrose <bill@fairweather.com> To: "Tom Maunder (E-mail)..<tom_maunder@admin.state.ak.us> CC: "Tom Brockway (E-mail)..<Thomas.A.Brockway@conocophillips.com> , "Steve Davies (E-mail)..<steve_davies@admin.state.ak.us> Tom, Steve Davies called yesterday with several questions pertaining to the Oliktok Point State #1 APD. I could answer most of the questions right there on the phone or via the cementing sheets that I had sent you the previous day. However, I promised I would look into the topic of H2S mitigation and respond with an email today. This well will penetrate the Kuparuk Sands in ~ fault block that has not previously been penetrated. Since some of the offset wells produce some H2S, the question of whether or not we will be encountering H2S in the subject well was raised. Also asked was if and where an H2S sequestering agent for the mud would be available. The target fault block will contain either Kuparuk crude or in situ water. Either way, the block is fault-isolated and the reservoir fluids (oil or water) will be the same as those found originally in the Kuparuk Field. Kuparuk's original reservoir fluids did not contain H2S. The H2S now seen in the producers offsetting the subject well results from the action of sulfate reducing bacteria in injected waterflood water. The target fault block, being isolated, will not contain this H2S-tainted water. That being said, the rig to be used, Doyon 141, will have operating H2S detection and alarm instrumentation while this well is being drilled. Also, a supply of an H2S sequestering agent, Safe-Scav HS, will be maintained on site. This scavenger comes in liquid form, is based on an organic chemical in place of the typical zinc- or iron-base compound and remains stable after reacting with H2S. If you have additional questions or need any clarifications, please let me know. Regards, Bill 1 of 1 6/5/2003 1 :35 PM Oliktok Pt. State #1 Cement Plans ) ) Subject: Oliktok Pt. State #1 Cement Plans Date: Tue, 3 Jun 2003 15:54:15 -0800 From: Bill Penrose <bill@fairweather.com> To: "Tom Maunder (E-mail)..<tom_maunder@admin.state.ak.us> «Oliktok 1 - 958 Surf Cement Summary, V1.pdf» «Oliktok 1 - 70 Prod Cement Summary, V1.pdf» Tom, I think these sheets are what you called about. Sorry they didn't make it into the APD. Would you like to incorporate them into your copy? If so, let me know and I'll put them in mine and CPAI's, too. Regards, Bill o Oliktok 1 - 958 Surf Cement Summary, V1 Name: Oliktok 1 - 958 Surf Cement Summary, V1 Type: Acrobat (application/pdf) Encoding: base64 . . .... ......_.....,..........,,;.,.....-....;......~. .I." ..~...~.........-:.,....._;.... Name: Oliktok 1 - 70 Prod Cement Summary, V1.pdf DOliktok 1 - 70 Prod Cement Summary, V1.pdf Type: Acrobat (application/pdf) Encoding: base64 \. .'~.... .', .. '.. ',", '·'f,."-'....-·· ,'II, ......·...··.....··...·..··""1"'''''',''''"", 1 of 1 6/5/2003 2:48 PM ) '} Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ConocriP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 May 29, 2003 Commissioner Palen State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 RECE\VED JUN 0 2 2003 Comm\ss\on 0·\ & Gas Cons. Maska , ').nchorage RE: Application for Permit to Drill: Winstar Oliktok Point State #1 Dear Ms. Palen, ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development production well, the Oliktok Point State #1, from KRU 3R Pad. The anticipated spud date of Oliktok Point State #1 is approximately July 15, 2003. Attached is a copy of form 10-411, Designation of Operator from Winstar that designates ConocoPhillips Alaska, Inc. as the operator of record for Wins tar' s Lease ADL 388584. A separate application for Designation of Operator has been filed concurrently with this Permit to Drill. As operator, ConocoPhillips will be drilling this well into this lease which is within the Kuparuk River Unit. The well will be drilled from the existing KRU 3R-9 conductor. A 12-1/4" hole will be directionally drilled to the base of the West Sak Formation where 9-5/8" surface casing will be set and cemented. An 8-1/2" hole will then be direction ally drilled to penetrate the Kuparuk sands and 7" production casing will be set and cemented after which a 3-1/2" gas lift completion will be installed. Please find attached information as required by 20 AAC 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 AAC 25.005 (a). 2) Fee of $100.00 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the well's proposed surface and bottomhole locations per 20 AAC 25.050 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. ORIGINAL ) ') 5) Diagrams and descriptions of the diverter and BOP equipment to be used as required by 20 AAC 25.035 (a)(1) and (b) were previously submitted to the AOGCC and are on file. 6) A complete proposed casing program is attached as per 20 AAC 25.030. 7) The drilling fluid program, in addition to the requirements of 20 AAC 25.033 are attached. 8) A copy of the proposed drilling program is attached. 9) ConocoPhillips does not anticipate the presence of H2S in the formation to be encountered in this well. However, H2S monitoring equipment will be functioning on the rig at all times during drilling and completion operations. 10) Since this well is a development well, no mud logging will be performed. 11) A Summary of Drilling Hazards is attached. 12) The following are the designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Bill Penrose, Senior Drilling Engineer 258-3446 2) Geologic Data and Logs (20 AAC 25.071) Doug Hastings, Senior Geologist 272-1232 If you have any questions or require additional information, please contact me at 265-6830 or Bill Penrose at 258-3446. Sincerely, CONOCOPHILLIPS ALAS~t\~ INC. ".';">//~" ""/,.""/~"". ,/",,""".,,/'/ ,~ ,,/ .. ,'" .~/ { ,/, ¡;. ,-" l'r-,Z:? ' . / /'" I ,(. . /? "",'td/'~,,,,.¿...., / . / ." k./' /,/. /. < ~ L{ //~';::2'~ ~ 'Y17 /11<:,,,,,,,.5 Randy Thomas V' GKA Drilling Team Leader enclosures cc: Mr. Jim Weeks, Winstar Petroleum, LLC O~<iGlf'JAL .. -. . . - - - . - . . - . .- - - . Oliktok ····Petroleum ,LLC 1629W 11 thÄvß Anchorage, AK 99503 .. ..-. ---. '.. . -- . . - -. -- .-. 89.-~3I1i52 - .:/'104__ -' PAY TO THE ORDER OF ;,." ~. MEMO I: . 2 5 20 0 ~ 3 I. I: 7. 0 0 28 £1 0 £11. /I- O. 0 I. --' RECEIVED JUN 0 2 2003 Alaska Oil i>_ G·· as C'on'" C '. Of :s. omnUSSI{Jn Anchorage ') ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMtTT AL LETTER WELL NAME D!¡Iv/- fl· 2. /" PTD# ;2{) 3 -un CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) paOT (PH) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to· be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(t), all· records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number· (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates 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. (Companv Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT ,CHECKLISr Company CONOCOPHILUPS ALASKA INC Well Name: KUPARUK RIV UNIT OUK PT ST 1 Program _PEV Well bore seg PTD#: 2030990 Field & Pool KUPARUK RIVER, KUPARUK RV OIL - 490100 Initial ClasslType DEV 11-01L GeoArea 890 Unit 51170 On/Off Shore -º~ Annular Disposal Administration 1 Permit fee attached _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ _ .. _ _ .. .. . . .. ., _ .. _ _ .. _ .. .. _ . _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . . . . . . . . . . . . . . . . _ _ . _. . _ _ . _ _ _ . _ _ . . . . . . _ . _ . _ _ _ . _ . _ . . . _ . 2 .Lease_number _apprOPJiate. _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes. . . _ _ . _ _ . . . . . . . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ . .. . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ .. .. . . _ _ _ . . . . . . . _ . 3 _U.nique well_ rtame _aod oumb_er . _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ .. _ . _ _ _ . _ _ _ _ _ . _ Yes . _ _ . . _ . _ . _ . .. . _ . _ . _ _ . _ _ . _ _ _ _ _ . _ _ _ _ _ . _ . _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ . . . . . . . _ . . _ . . . . . . 4 _WeIUQcatedin_a_d_efined.pool_.. _. _ _. _ _ _ _ _ _. _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _. Yes_... _ _ _ ..WelJisJo_catedwithjn.theKup_aruJ<_RiverOilPQol,~odisgQ'£ernedbyCO.4328.... _ _ _......... _ _.. _. 5 _Well JQCÇlteçl pr9per .di.stançeJrom. driJling unit.b_ound~r:y_ _ . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ Yes. _ _ _ _ . . Per Rute_3. CO .4328, pr:oPQsec;l well i~)fn.oreJbqn_5_00' Jr91Jl_prQPer:ty-ltne._ _ _ _ _ _ . _ . . . . _ _ _ . . . _ _ . . . _ _ 6 _Well JQC;;Ited pr9per _distanceJrom. QtbeJ wells_ _ _ . _ _ _ . _ . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _. _ Yes _ . _ . . . . ~earest pe.netration tn Kup<:Iruk ßiver QiI Pool .Is. ,",:3,,0.00' _away. _ _ . _ _ . _ _ _ _ _ _ . _ . _ . . _ __ _ . _ _ . . _ . . _ 7 _S_ufficient.acreage_ayailable in.driUiog unjt _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ . _ _ _ _ _ _ Yes _ _ . . _ . . . _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . _ . . _ _ . _ . . . . . _ . . . . . _ . _ . . _ _ _ . . . . . . . . . . . . . . . . _ . . 8 Jf.deviated, .Is. weJI bQre platincJuded _ _ _ . _ .. _ _ . . . _ . _ _ _ _ _ _ . . . . . _ . . . . _ . . . . _ .Yes _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . _ . . . . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . . . . _ . . . . . . . _ _ _ _ _ . _ . _ . . . _ _ _ . _ 9 _Qper:ator only- <:Iftected P<:Irty _ . . _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ . . . . _ _ . . . _ _ _ _ _ . _ _ _ _ _ Yes _ _ _ _ _ _ _ . . _ _ .. . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ . . _ . _ . _ . . _ _ _ _ _ . _ _ . . _ . . . _ _ . . _ . . . . . . 10 .Qper:ator b<:ls.appropriate. Qond in JQrce . _ . . _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ . . . _ . . . . . . . _ . Yes. . . . . . . . . . . . . . . . . . _ . _ . _ . . _ . . . . . . . . . . . . _ . _ _ . _ _ . . _ _ . _ _ . . . . . . . . _ . . . . _ . _ . . . . . . . 11 Permit c_ao be issued wjtbQut co_nservaJion order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _, _ _ _ . . _ Yes _ .. _ . . _ _ _ _ .. _ _ _ _ _ _ _ _ __ _ _ _ _ . _ . _ . . . _ _ . . _ _ _ _ _ _ _ _ _ _ _ . _ _ . . . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 12 Permit c.ao be [ssu_ed wjtbQut ad_ministr:ative.appr9vaJ _ _ _ _ . . _ _ _ _ _ _ . . _ . . _ . . _ . _ _ . Yes. . _ _ _ . _ _ _ _ _ _ _ _ _ _ . . _ . . _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . . _ . _ . . . . _ . _ _, _ _ _ _ _ _ . . . . _ _ . _ _ _ _ _ Br"'-n),.'. 6/3/2003 13 .C.aopermjt_beaPRrQvedbefore.15-day_wait... _........... _............... Yes.. -. -. - - - - -. -.. -.................. - - -.. - - - -. - - - - -..... - -.. - - -. - - - - - - -. - - - - -. 14 _WellJQcated wiJhin are<:l and_strata autþorized by..l(ljec.tioo Order # (Put.lO# in_C9IJlme(ltsUFor. NA _ _ _ _ _ _ _ _ _ _ _ _, _ _ _ _ _ _ . . _ . _ . _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ . . . _ _ . _ . . .. _ . _ _ . _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ 15 .AJlwells_witþin.1l4..rlJite.are.a_ofreyiewide(ltified (For:~ervjce_welJ only). _ _ _ _ _ _ _ _ . . . _ _ _ NA _ . ._ . . . . . . . . _ . . . _ _ . _ _ _ _ . _ _ _ . _ . _ . . . _ . . . . . . _ . _ _ _ _ _ _ _ _ _ _ _ _ . . . . . _ . . _ . . . _ _ . _ _ . . _ 16 Pre-produ.cedinjector; duraUo_n_ofpre-produetionless.than_3morÜhs.(For_seryLcewelt Qnly) _ _ NA _. _ _ _ _ _. _. _... _... _. _ _ _ _ _.. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _.. _ _. _.. _.. _.. _ _ _ _ _ _ _ _ _ _ _ _ _. _. _._ 17 .A.GMP_ F:inding _of ÇQn_si,Steoc.y_h~s beenj~suedJorJbis pr91ect . . . _ . . _ . . _ _ . . . _ _ _ _ . Yes _ _ . _ . _ . Oevel9pmenJ well drilled_ from. existirm K,upar_uls Pad 3R.. . . . ,. . . . . . . . _ _ _ _ _ _ . _ . _ _ _ _ . _ _ _ . _ _ _ . _ 18 .C.oodu.ctor strin..g.prQvided . _ _ . _ _ _ . . _ _ _ _ . . . . . _ . . . _ _ . _ _ _ _ _ _ _ _ _ _ . . . . _ _ Yes _ . . _ . _ _ . . . . . . . . . . . . . . . _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ ,_ . . _ _ . . . .. _ _ . _ . . _ _ . _ . _ . . . _ . . _ _ _ . 19 .SJJrJace _CÇl~ing_PJQtect~ <:III_known. USQWs _ _ . . _ _ _ . . .. . _ . _ _ . . _ _ _ _ _ . . . . _ . _ _ . NA _ _ _ _ _ _ _ All. <:IqJJifeJS ex.elJlpted 4Q CfR j 47_. 1..02 _(b)(3) _ _ _ _ _ _ _ _ . . . . . . . . _ . _ _ _ _ _ _ _ _ _ . _ _ _ . . _ _ . . _ _ _ _ 20 _CMT.v9ta_dequ.ateJo CircJJI~te.on_cond_uctor..& SUJf..CSg . . . . . . . . . . . . . _ . . . . . . . _ . . Yes. . . . . _ _ _ _ _ _ _ _ _ . _ .. . . . . _ _ . _ _ . _ _ . _ _ _ _ _ _ . _ _ _ _ . . . . _ . . . . . . . . . . _ . _ _ . _ . _ _ . . _ _ _ . _ . .. 21 .CMT. v9t qdequ_ateJo tie-LnJQng _striog to_s!.Jlf ~g_ .. _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ .. _ _ _ _ _ _ _ _ _ .. .. _ .. .. .. .. .. .. .. .. .. .. .. .. _ .. .. .. _ _ .. .. _ _ _ _ _ _ _ _ _ 22 .CMT. will Goyer _all koow_n _pro.duGtiYe bQri?Qrts _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . . _ Yes _ _ _ _ _ _ .. . _ _ . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . _ _ . _ _ _ . _ . . _ . . _ _ _ _ . _ _ _ . _ _ _ . . _ _ . . . . . .. . . . . . . . . . 23 .C.asi(lg desi-9ns adeç ua.te for C,.T~ 13_&_ p_ermafr9St. . _ _ . . .. . _ _ . _ _ _ _ . _ _ _ . _ . . . _ Yes.. _ _ .. _ . _ _ . . . _ . . . . . _ . _ _ . .. . _ _ . .. _ _ . _ . . . . _ . . . . . . . .. . . _ _ _ . .. _ . _ _ . . . _ . . . . . . . . . _ 24 Adequate..tan.kage.or re..serye pit. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . _ Rig equipped wiJh steeJ pits. N9Jeserve pit plçlOned._ Waste to.Clas_sJl.well._ . . . _ . . . .. _ _ .. . _ . . . . _ _ _ _ _ 25 Jf..a_re-drill~ Þas_a. 1..0:-4:03 fQr abandonment bee(l apprQvec;J _ . _ _ . _ _ _ _ _ . _ _ _ _ _ . _ _ .. _ _ NA .. _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ .. . _ . _ . _ _ _ _ _ _ . . . . . . . . _ . . . _ _ _ . _ _ . _ _ ._ _ _ . . . . _ . . . . _ . _ 26 _AdequatewellboreseparatjoJl_proposed_. _ _ _ _. _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _. _ _. _.. _ _ Yes. _ _ _.. _Pro~imLtY-<:Inalysisperf9rme_d, G!ose apprQache'sJd.entjfied.. Gyrospo,Ssible._ _... _ _ _ _...... _.. _.. 27 Jf.djver:ter reqJJired. dQes jt .meet reguJa.tions. _ . _ . . . . . . . _ _ . . _ _ . _ . _ _ _ _ . . . . . . . Yes. _ _ . . . _ _ _ _ _ _ _ _ _ . _ _ . . _ . _ . _ _ . . _ . . _ _ _ _ _ . _ _ _ _ _ _ _ . . _ . _ _ . _ . . . . . . . . _ _ _ _ . . . 28 _DrilJi(lg fJujd.RrQgr<:lm sehematic_&_ eqJJipJist.adequate. . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ . _ . .Yes _ _ _ _ _ _ _tiighe.st pO'ssible atll? .10.1 EMW. _PIQnned MW_ raoge..to 1Q.5 ppg, _ _ . _ . . _ . . . _ _ _ . _ _ _ . _ _ _ _ . 29 .BOPEs..d9 .they meet reguJé1,tion . . _ . _ _ . _ _ . _ . . _ . . . . . _ . . . _ _ . _ . _ _ _ _ _ . _ . . .Yes. . . . . . _ . . _ . _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ . _ . . . _ . . . . _ . . _ . . . _ _ . _ _ _ . _ _ _ . _ _ . _ . . . . _ _ . _ _ . . 30 _BOPE_pr~ssra.tiogappropriate;.testt.o-<pu.tpsigiJl.comments).............. _..... .Yes...... .MASPcaJeu!ate.d.at2927,_althQu-9bth_e_shQe_WQuld.li!<elybreak_d_owo..3~OOpsi.appropriate.50_00!ikely,. __ 31 _C_hoke_manifolc;J cQrTJpJies_ w/AI?I.RP-53 (May 84). . _ _ _ . .. . _ . _ . . _ . . _ _ . _ _ . . . _ . . . .Yes. . _ _ _ _ _ _ _ . . _ . . . . _ _ _ _ _ _ _ . _ _ _ _ . _ _ . . . . _ ._ . . . _ _ . . _ _ _ _ _ . _ _ . . . . . . . . _ _ 32 WQrk will OCCJJr without.operation _sbutdown _ _ _ _ . _ . _ _ _ .. _ _ . _ _ _ _ . _ _ _ _ _ _ . . . _ _ _ .Yes. . _ _ _ _ _ . _ . _ _ . . _ . . _ . . _ _ _ _ _ _ _ _ _ _ . _ _ _ . _ _ . _ _ . . _ _ . . . . . _ _ _ _ _ _ _ _ . _ 33 J~ pre~e!lçe_ Qf H2S gQs_ Rrob_aþle _ _ . _ . . _ . . _ _ _ _ . . _ . _ . . .. . .. _ _ _ . _ . _ _ . _ . _ _ . No. . _ . _ . _ _ _ _ . . _ .. _ _ _ _ _ _ . _ . _ _ _ . _ _ . _ _ _ _ . . . . . . _ . _ . . _ _ _ _ _ . _ _ _ _ . . _ 34 Meçba_nlCÇII.coodjti.on o{ W~II$ within AQR yerifiect (for_s_ervice welJ QnJy-) _ . _ _ _ _ _ .. _ _ _ . _ NA _ _ _ _ . _ _ _ _ _ . . _ _ . . . . _ _ . . _ _ _ _ . _ _ _ . _ _ . . _ _ _ _ _ _ . _ _ _ _ . _ _ _ . _ _ _ _ . . _ . . _ . _ _ _ _ _ _ _ _ Appr Date Engineering Appr Date TFrv 6/5/2003 ~~ W~' Geology Appr SFD Date 6/3/2003 Geologic Commissioner: ff)rj£ D D 35 Pe(lT)itc.aobei_ssuedw!o.hydr_ogen.s_utfidemeas .lres. .. _ _ _ _. _ _ _.. _ _ Y~s. _ _ _ _ _ _Welltargets_aJau_lt.bloçkthathasnotÞeen_PJoduced_.tl2Sr:nonitpringßqUip._willbeJunctiona!at_aUtimes_. _ 36 D.ata_preseoted Qn pote_nti<:ll overpres_sure .zones _ _ _ . _ . . . _ . _ _ . _ . _ _ _ _ . _ _ _ _ . . _ . Yes _ _ . Expected. Kupa(Ul< re.seryQiq~res.sure Js_1.0.1_ppg _EMW .. _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ 37 _Sei$lJllC_analysJs. Qf shaJlow g<:ls.zpoes_ _ _ _ _ . _ . _ _ _ . _ _ _ . _ _ _ _ . _ NA .. _ . _ _ . _ . . . _ . _ . _ _ _ _ _ _ _ _ . . _ _ . . _ _ _ . _ 38 _Seabed _condjtioo survey.(if Qff-shore) _ _ _ _ _ _ . _ _ . _ . . _ . _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ . . _ NA . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . . _ _ _ _ _ _ . _ _ _ _ . _ _ _ . _ _ . _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ .. _ _ _ _ _ 39 _ CQnta_ct namelpnoneJorweekly progress_reports [exploratory _onlYl _ _ _ _ _ _ _ _ _ . _ . . _ _ . NA . _ _ _ _ _ _ _ . _ . _ _ _ .. _ _ _ _ . . _ _ _ . _ _ . _ _ _ _ _ . . _ . _ . _ . . . . _ . _ - - . . - - - - - - - - - - - - Date: ó~DÎI6J Engineering Commissioner: Public Commissioner ~ate ~~ Date
