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Home My WebLink About202-039 TityroF &\ �j�,s� THE STATE Alaska Oil and Gas i� 7 of Conservation Commission O._'n___- � ALAs A '.��•�,#__-=_ 333 West Seventh Avenue legPt GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF Main. 907.279 1433 ALASY'� Fax 907 276.7542 scow JUN U 5 zn15 www aogcc alaska gov Aras Worthington Well Intervention Engineer O BP Exploration (Alaska), Inc. `� 0017P.O. Box 196612 �C Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU P-18L1 Sundry Number: 315-324 Dear Mr. Worthington: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair kot- DATED this Z day of June, 2015 Encl. STATE OF ALASKA RECEIVED ALAS ,-.. OIL AND GAS CONSERVATION COMM,oSION �+ APPLICATION FOR SUNDRY APPROVAL MAY 2 2015 20 AAC 25.280 Q it G Z/S 1 Type of Request: .AOG C ❑Abandon ❑Plug for Redrill 0 Perforate New PooL ®Repair Well 0 Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate ❑P I Tubing ❑Time Extension PIA 1[vo 6iv,✓,✓1 c r wCll l oc. ❑Operations Shutdown 0 Re-Enter Suspended Well 0 StimulateAlter Casing ®Otherlogy ' r SC 1<a4- 2 Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑Stratigraphic 202-039 • 3 Address: ® Development 0 Service 6 API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-22097-60-00 7. If perforating: 8 Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU P-18L1 • Will planned perforations require a Spacing Exception? 0 Yes No 9. Property Designatior 10 Field/Pool(s): ADL 028288&028289 ' Prudhoe Bay/Prudhoe Bay ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft) Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured): Junk(measured) 12345'• 9013' • 10526' 8584' 10526' None Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 40'- 120' 40'- 120' Surface 2651' 10-3/4" 40'-2691' 40'-2691' 5210 2480 Intermediate 10790' 7-5/8" 38'- 10828' _ 38'-8785' 8180 5120 Production Liner 392' 5-1/2" 10559'- 10951' 8605'-8875' 7740 6280 Solid/Slotted Liner 1812' 3-3/16"x 2-7/8" 10533'- 12345' 8588'-9013' Perforation Depth MD(ft). Perforation Depth TVD(ft): Tubing Size. Tubing Grade: Tubing MD(ft): Slotted Liner: 10635'- 12310' Slotted Liner: 8654'-9009' 4-1/2", 12.6# L-80 10564' Packers and SSSV Type: 7-5/8"x 4-1/2"TIW HBBP Packer Packers and SSSV 10468'/8548' MD(ft)and TVD(ft): 12. Attachments: 13.Well Class after proposed work: ®Description Summary of Proposal ❑ BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development 0 Service 14. Estimated Date for 15. Well Status after proposed work Commencing Operation June 7,2015 • 0 Oil ❑WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: ❑WAG ❑SPLUG ❑Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Aras Worthington,564-4102 Printed Name. Aras Worthington Title: Well Intervention Engineer Email: Aras Worthington@bp.com Signature ,'`� ��,?/ Phone: 907-564-4102 Date: Commission Use Only Conditions of approval: Notify Commission so that a representative may witness ? 3 2_1.4Sundry Number: ❑ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ❑Location Clearance Other Spacing Exception Required? 0 Yes 13/No Subsequent Form Required. `C — 4-o 1 APPROVED BY Approved By: P�Aj`7-v -- COMMISSIONER THE COMMISSION Date: G- Z- /5-- Form 10-403 Revised 0/2012 a d for 12 months from the date of approval Submit In Duplicate efii€ijaNi .5109//5VTL DMSJ - JUN - 3 2015,4 e2s ,iS6 4724,, it To: Ken Bulloch / Scott Bundy; AK, D&C Special Projects Tyler Norene / Len Seymour; AK, D&C Well Services Team Lead Date: 05-21-2015 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: P-18 WeIlLock Conductor Treatment Obiective This program is for treating surface casing response to pressure by external repair with WeIlLock. The well fails an MIT-OA. WellLock is a Newtonian resin that sets with temperature as an inert, hard, plastic-like material. The viscosity has been tested at 60 cP. The objective is to place the WeIlLock between the conductor and surface casing to mitigate the leak. Approximately one week before treatment, put under evaluation and POP to warm well and aid in treatment/curing of resin. Well Detail Current Status: Not Operable — PAL Previous Test: 07-08-2007 MIT-OA Fail Integrity Issues: Surface casing leak Well Operation Detail Fluid Density: WeIlLock: 9.1-9.3 ppg (keep WeIlLock at or above 85°F) Musol A: 7.5 ppg Diesel: 6.8 ppg Temperature: Maintain 75°-80° F throughout the entire job, leave heater trunks in well during cure period (one week) Relevant History: > 06/14/07: Unable to ID leak point > 07/08/07: MIT-OA Failed w/ N2 1 of 3 Procedure 1 D Thoroughly clean the conductor by surface casing annulus to remove any deleterious material. This include steam washing the annulus and cleaning with detergent. 2 D Run open bleed on OA during the entire job. 3 D ***Pump WeIlLock into conductor by casing annulus. 4 D Allow WellLock to cure for one week. 5 D MIT-OA to 1200 psi with diesel *** Collect approximately one cup sample of WeIlLock in disposable container. Place sample in representative condition and monitor viscosity throughout job. Leave sample during seven day cure period and record temperature and observable viscosity of sample. 2of3 — TREE= - 4-1/16'CMV WELLHEAD= FMC P-18 S. ,Y NOTES: WELL ANGLE>70°@ 11225'*** ACTUATOR- OTIS 5-1/2"CHROME LNR***MAX DOGLEG(P-1811): KB.13EV 91.85' I L-11I 42.3*@ 11092'*** BF.BEV= 55.82' ,I KOP= 3600' 20"CONDUCTOR, --I ? / 2077' —14-1/2'0115 SSSV NP,ID=3.813" 410 I Max Angle= )9 @ 11452' # _ Datum MD= 10973' D= " Datum TVD 8800 SS GAS LFT MASS ST MD TVD DEV TY1 VLV LATCH FORT DATE 10-3/4"CSG,45.5#,L-80,D=9.950" 2690' 6 3016 3016 0 KBMG-M DMY BK 0 05/09/13 1 5 5443 5190 46 KBMG-M DMY BK 0 05/09/13 L 4 7835 6801 49 KBM3-M DMY BK 0 05/09/13 3 9317 7796 49 KBMG-M DMY BK 0 02/20/02 2 9934 8203 49 KBMG-M DMY BK 0 02/20/02 1 10433 8526 52 KBMG-M DMY BK 0 07/27/10 Minimum ID = 2.377" @ 11108' 3-3/16" X 2-7/8" LNR X-OVER 10460• -4-1/2"SWS NP,O=3.813" ll 1 10465' H RIGHT HAND RELEASE LATCH,D=4.00" .Z X 10467' -17-5/8"X 4-1/2"11W HBBP PKR,D=4.00" ' ' 10524' H4-1/2"SWS NP,13=3.813" F' 10526` H4-1/2"WRP(07/26/10) r.... - 10533' --13.75*BKR DEPLOY SLV,D=3.000" 10539' -13-1/2"X 3-3/16"XO,D=2.786' 4-1/2"18G,12.6#,L-80,.0152 bpf,D=3.958'H 10557' \I "----------- 10544' H4-112"OTIS XN NP,MILD TO 3.80'D TOP OF TNN TEBACK SLEEVE H 10559' I s' ""-------1 10557' - TOP OF 11W SEAL ASSI3K3LY BEHIND 10563' -J5-1/2"71W SEAL ASSY W/O SEALS CT LNR I I 10571' -i 7-5/8'X 5-1/2"TIW HY DRO LNR HGR 7-5/8"CSG,29.7#,NT-95HS,D=8.875' H 10828' 1 Ilk I I 5-1/2"MLLOUT WINDOW (P-18 L1) 10951'-10961' TOP OF BKR FLOWTI-ROUGH W-IPSTOCK -1 10950' RA PP TAG --I 10959' 4] 5-1/2"BKR RP PKR W/STANDING VLV -1 11050' 417 R RFORATION SUMMARY N� REF LOG: ATLAS Bi-CA 11/14/90MI►�1 11108' -H3-3/16'X 2-7/8'XO,D=2.377" ANGLE AT TOP PERF: N/A I Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ P-18 I \ \\ 3-3/8* 6 10910-10920 0 02/14/02 " ‘ 33/8" 4 11068 11100 0 01/07/91I \ 3-3/8" 4 11126-11144 0 01/07/91 3-3/8" 4 11154-11170 0 01/07/91 \ ` 3-3/8* 4 11180-11191 0 01/07/91 P-1811 I N. N.�N. 3-3/16" SLID 10635-10666 SLOT 03/06/02 N, N. 2-7/8' SLID 11536-11885 SLOT 03/06/02 ,y'.y. PSTD --1 12310' 2-7/8" SLID 11962-12310 SLOT 03106/02 .10.. \ . 4001 5-1/2"LNR,17#,13-CR,.0232 bpf,ID=4.892" -{ 11520' 2-7/8'LNR 6.16#,L-80 SR, 12345' .0058 bpf,D=2.441' DATE REV BY COMMENTS DATE REV BY COMMENT'S PRUDFDE BAY UNIT 11/19/90 INITIAL COMPLETION 07/28/10 MBMRuMCEPLOY SLV DEPTH CORRECTION WELL: P-18 t L1 03/06/02 CTD SIDETRACK (P-18L1) 05/16/13 DJS/PJC GLV C/O(05/09/13) PB2MT No: 1901450/2020390 01/20/06 KSB/TLH GLV C/O 05/21/15 PJC WRP DEPTH CORRECTION(M)) AR No: 50-029-22097-00(60) 05/22/08 SWC/SV SET FX PLUG(05/14/08) 05/22/15 PJC REFORMAT LNR/CSG/TBG SEC 31,T11 N,R13E 2348'FSL&2076'RAC 07/28/10 GJF/PJC GLV C/O(07/27/10) 07/28/10 MBMVPMU RLL PX/SET WRP(07/26/10) BP Exploration(Alaska) Irr '~e Project Well History File Cov tPage XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ O~- fJ:::£j Well History File Identifier Organizing 1,lnn .~ RESCAN (. Color items: 1:1 Grayscale items: 0 Two-Slued DI~TAL DATA },6' Diskettes, No. 0 Other, Norrype 0 Poor Quality Originals: 0 Other: NOTES: BY: BEVERLY ROBIN VINCENT SI-II::R(~INDY Project Proofing BY. BEVERLY ROBIN VINCENT SHERVG>WIND'f Scanning Preparation I x 30 = . -:jD BY. BEVERLl ROBIN VINCENT SHER''l.01ARI.yWlt'JD( (Rescan Needed OVERSIZED (Scannable) 0 Maps: Other items scannable by large scanner 0 OVERSIZED (Non-Scannable) 0 Logs of various kinds ,0 Other DATE:4 /:;/ ùtS! ~1tf DATE:q ~4twfsl , + 7: '" TOTAL PAGES?> 7 DATE:4 .qDtfs, V~1 ~ V1tP Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: 37 / PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: f Y YES - NO BEVERL'{ ROB'" V'"CE''' SHERneW'"D''' OATE8: il!tt/s, 111 p Stage 2 IF NO IN STAGE 1 PAGE(S) DISCREPANCIES WERE FOUND: - YES - NO B": B (: BEVERl ý ROBIN VINCENT SHER'fl Mr~RIA WIND'( (SCAIIPIIPIG IS COMPLETE AT THIS POIIIT urJlEss SPECIAL ATTEtlTlorJ IS REQUIRED or AP ItlDIVlDUAl PAGE BASIS Dl'E TO QlIAUTV, GRAYSCALE OR COLOR IMAGES) ReScanned /l1>I!1\'I,I'"." l'''I''{'./'''';,11.,I/,','I/','I} '.' ""'1/1,' .""IP'I",""rl) RESCArJNED Bi': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Noles or Comments about this file: DATE' 151 II II DATE' ISI Quality Checked Iii 111':1 12/10/0¿Ra~JNOTScannt:!d lApd . .-._,<~,. . ~,,'1! '> ff1¥,.:;/ \f;1J.M "1 <-\:;~',:''fPè WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 13, 2006 RE: MWD Formation Evaluation Logs: M-38A_PBl, N-OIA, P-18 Ll, S-18A, W-16A_PBl, W-32A PBl. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 ';i. M-38A_PBl: U ..l.c.. got- \3'd- (4'--/10 Digital Log Images: 50-029-22519-01,70 1 CD Rom SCANNI:D FEB 0 1 2007 N-OIA: 'dt:f-.l-( 13 $l/4LII/ Digital Log Images: 50-029-20079-01 1 CD Rom P-18 Ll: dO~ - 03'1 'P'-IL/L/Ó'f) Digital Log Images: 50-029-22097 -60 1 CD Rom S-18A: c?Od-/(P3 #/¿./L//d. Digital Log Images: 50-029-21156-01 1 CD Rom W-16A_PBl: :;;)0"3-/00 'IX 1'-/409 Digital Log Images: 50-029-22045-01, 70 1 CD Rom W-32A_PBl: dOC) -do'1 tt IL./LfI3 Digital Log Images: 50-029-21790-01, 70 1 CD Rom 1- e e WELL LOG TRANSMITTAL dO!l~ODq To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 13Lpl.o I RE: MWD Fonnation Evaluation Logs P-18 L1, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 P-18 Ll: LAS Data & Digital Log Images: 50-029-22097 -60 1 CD Rom t ~ a-Iwlo(p e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfitm _ Marker.doc l.~ ,,1 ¿,') " t.. r.o " ! J ¡',~1" '^~ .~) '..J '"1 DATA SUBMITTAL COMPLIANCE REPORT 4/2/2004 Permit to Drill 2020390 Well Name/No. PRUDHOE BAY UNIT P-18L 1 Operator BP EXPLORATION (ALASKA) INC ,-.. , ,." ('11V.. ,.~1.IQ ~ . >1'" u v API No. 50-029-22097-60-00 MD TVD 9013 ~ Completion Date 3/6/2002 ,.----- Completion Status 1-01L 12345 ' ------ - ------.- --------- -_.- --- -- REQUIRED INFORMATION Mud Log No Samples No --- ---------- ----- --- - --- - - - - - - - --- - ----- -------- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~. D Lis . -Lr1466 LIS Verification --- ---- --- Log Log Run Scale Media No 1 Rpt Lis 'ED C Lis vED C Lis LIS Verification l-11740 LIS Verification '11740 See Notes 1,2,3 1,2,3 ~''ÉD C LIS LtÚ 40 See Notes 1.2,3 ----- --- ------- ----.---- ---- --- ---- Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y /rfij Daily History Received? Chips Received? - Y / N Formatiùn Tops Analysis Received? ~ - - - - - -- - ----- ---- --- -- - --------- --- ------- --------- - ------- --- .--- - --- - - - - Comments: . - --_-: - ---=----:--_..:.:..:.:...~ =---~- ~--~-r--- -- Compliance Reviewed By: -- - --- - -- - - - -- 'jJ~) ----- -- - ---- ----- ------- ----- Current Status 1-01L UIC N - - -- --- - Directional Survey Yes t..--'---- ---- ---- -- --- -- - --- -- --- - -- - ---- (data taken from Logs Portion of Master Well Data Maint) Interval OH / Start Stop CH Received Comments ------- ----- - -- - --- - -- ---- ------------------- 10947 12301 Case 1/9/2003 10947 12301 Case 1/9/2003 10891 12347 Open 8790 8966 Open ROP, NGP, DGR, EWR TVD .emf . .pdf with emf viewer 109ì5 12345 Open ROP, NGP, DGR, EWR MD .emf, .pdf with emf viewer --------- ------------- -- -------- Sample Set Number Comments tJJN T., (t1JN -------- - --- -------- --------- -------------------- ------------ ---------- ----- -;--- /t'Jr )~J '-L - Date: ,ÞC ~d-- - (~ :5 c¡ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 9950 I ~1ay 09, 2003 RE: MWD FOn11ation Evaluation Logs: P-18 L 1, AK-MW-22040 P-18 LI: Digital Log Images 50-029-22097-60 I CD Rom , ) 1 ~O PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun DriHing Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: {¡;ï ( I 0103 Signed £~v-- ,¡), &"lD ¡,.- RECEI\/ED MAY 13 2003 ÞJaska O¡; & Gas Cons. Gomm~n Anchomge ¿;;°d-õ39 114te{, WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th A venue, Suite 100 Anchorage, Alaska January 07, 2003 RE: MWD Formation EvaJuation Logs P-18 L 1, AK-MW-22040 1 LDWG fonnatted Disc with verification listing. API#: 50-029-22097-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Spefl)'-Sun DriUing Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage. Alaska 995 ] 8 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Sign~ /~~-J RECEIVED JAN 0 9 2003 AI-a Oii & Gas Cons. CommiSlion .Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well !HI Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 202-039 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22097-60 4. Location of well at surface r'";~'7$1 9. Unit or Lease Name 2348' NSL, 2076' EWL, SEC. 31, T11N, R13E, UM I. I ,( ;¡"~~j1tf -~\ '\ Prudhoe Bay Unit At top of productive interval t . 'j/ 1202' SNL, 466' EWL, SEC. 05, T10N, R13E. UM " ---3. (.,__L_~ ~ ~,I;~ "i.(\ Ik." 1~ 10. Well Number At total depth " ::. r~4 P-18L 1 22891 SNL, 987' EWL, SEC. 05, T10N, R13E, UM '/i/) -- - . ",~ ,'- ' 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 91.851 ADL 028289 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp.. or Aband. 3-2-2002 3-4-2002 3-6-2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12345 9013 FT 12345 9013 FT !HI Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES 23. CASING SIZE 20" 10-3/4" 7-5/8" 5-1/2" 3-3/16" x 2-718' Classification of Service Well 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2077' MD 1900' (Approx.) WT. PER FT. Condo 45# 29.7# 17# 6.2 x 6.16# GRADE CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 110' 30" To Surface Surface 2690' 13-1/2" 2891 cu ft Permafrost Surface 10828' 9-7/8" 1588 cu ft Class 'GI 10559' 10951' 6-3/4" 191 cu ft Class IGI 105331 123451 3-3/4" Uncemented Solid & Slotted Liner AMOUNT PULLED L-80 NT95HS NT80-S L-80 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) MD TVD 3-3/8" Gun Diameter, 6 spf MD TVD 10910' - 10920' 8845' - 8852' 26. SIZE 4-1/2", 12.6#. L-80 TUBING RECORD DEPTH SET (MD) 1563' PACKER SET (MD) 104661 25. 3-3/16" X 2-7/8" Slotted Liner 10635' - 10666' 8654' - 8674' 11536' - 11887' 9007' - 8960' 11962' - 12310' 8968' - 9009' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11050' Set Baker PIP packer w/ Standing Valve 10951' Top of Window off of Whipstock 2000' Freeze Protected with 30 Bbls MeOH. 27. Date First Production March 19. 2002 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO 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 cor11t:~t:IVl::LJ OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) No core samples were taken. APR 9 2002 Alaska Oil & Gas ConI. Commission Andmge Form 10-407 Rev. 07-01-80 ''''''''.1 ~......., ~ .....", '\ I ,~ j R B n .~ ~ B F l ,. PC> 5 y,_,.,Submit In Duplicate A \\ I ,j,Ji.I:... ,'t:: J 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Sag River 109021 88391 Eileen Sandstone 110391 89381 Sadlerochit 11058' 89511 Sadlerochit 117521 89611 Sadlerochit 119701 89691 RECEIVED APR 9 2002 AlalkaOil&GasCoDl. Commission Anchorage 31 . List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble /fQ~ ~ Title Technical Assistant P-18L 1 202-039 Well Number Permit No. I Approval No. Date Öt{ --Oß. 0 ~ Prepared By Name'Number: Sondra Stewman, 564-4750 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection. water injection, steam injection, air injection, salt water disposal. water supply for injection, observation. injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16. and in item 24 show the producing intervals for 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing. Gas Lift. Rod Pump, Hydraulic Pump. Submersible. Water Injection. Gas Injection. Shut-In. Other-explain. ITEM 28: If no cores taken. indicate 'none'. Form 10-407 Rev. 07-01-80 ,..F-""., "'--°1, . i .~', , '. 1 ,~ ij !' Well: Field: API: Permit: P-18L 1 Prudhoe Bay Unit 50-029-22097 -60 202-039 Rig Accept: 02/28/02 Rig Spud: 03/02/02 Rig Release: 03/06/02 Drilling Rig: Nordic #1 PRE-RIG WORK 12/20/01 DRIFT W/ DUMMY WHPSTK TO 10,375' WLMD -- RUN 3.675 BROACH TO 11,050' WLMD -- RUN 3.725 BROACH TO XN NIPPLE @ 10,520' WLMD -- RUN PDS CALIPER SURVEY FROM 11,127' WLMD TO SURFACE @ 50 - 60 FPM. PAD OPERATOR PUT WELL BACK ON PRODUCTION. 01/27/02 MASTER AND WING VALVE PASSED PT, SWAB VALVE PASSED PT, MITOA ABORTED (HAS BEEN DOWN- SQUEEZED), PPPOT-T PASSED (PRE-CTD). 02/11/02 MADE SEVERAL ATTEMPTS TO DRIFT TUBING WITH A 20' LONG 3.65" OD WHIPSTOCK DRIFT BUT STARTED SETTING DOWN AT 7561' SLM AND WOULD HARDLY MAKE HOLE AFTER 8900' SLM. WAS ABLE TO RUN A 3.8" BROACH TO TOP SWS NIPPLE WITHOUT SETTING DOWN AND A 3.75" CENT DOWN TO SWN NIPPLE @ 10540' SLM, BRUSHED & FLUSHED TUBING (4 1/2" WIRE BRUSH TO EOT) W/ 10 BBLS OF METH, 27 BBLS OF BIOZAN,45 BBLS OF CRUDE & 6 BBL DIESEL CHASER. WELL SHUT-IN 02/12/02 RAN 20' X 3.625 DUMMY WHIPSTOCK & SET DOWN @ 9131' SLM, BEAT DOWN MAKING ABOUT l' EVERY HIT, CONT' UNTIL TOOLS FELL FREELY @ 10,530' SLM (XN NIPPLE), CONT' IN HOLE & SET DOWN @ 11,100' SLM, POOH. NOTE - ALTHOUGH DUMMY WHIPSTOCK HAD TO BE BEAT DOWN HOLE, TOOLS NEVER STUCK ON PICK-UP CHECKS. WELL RELEASED FOR PRODUCTION 02/14/02 COMPLETED ADPERF. WELL WAS SHOT BALANCED. SHOT 10' INTERVAL FROM 10910-10920 FT WITH 10 FT GUN 3 3/8" PJ 3406 6SPF. TURNED BACK TO OPERATIONS TO POP. 02/19/02 SET CATCHER. FLOWLINE FREEZE PROTECTED BY FREEZE PROTECT CREW. DUMMY OFF GLV 'So 02/20/02 DUMMY OFF GLM'S. MITIA. PUMPED TOTAL 362 CRUDE MIT ON IA FAILED TO HOLD 2500# BLEED TO 0 , TALKED TO COMPo REP. SAID WOULD HAVE DHD COME OUT TO CHECK POSS 1 WAY LEAK UNABLE TO ESTABLISH RATE DUE TO SMALL LEAK. PULLED C-SUB EMPTY. LOAD 50 BBLS DSL, LOAD 65 BBLS DEAD CRUDE, ROAD TO LOCATION, RU TO lA, PUMP 5 BBLS 50/50, PUMP 228 BLS DEAD CRUDE FROM VECO TANKER AT 4.5 BBLS/MIN, PUMP 67 BBLS DEAD CRUDE FROM UNIT AT 3 BBUMIN, STOP - STAND BY FOR ANOTHER TANKER OF DEAD CRUDE, FINISH LOADING lA, PT FOR MIT lA, MIT IA FAILED TESTS, RO lA, RU TO TBG, FREEZE PROTECT TBG, WIT 3 BBLS MEOH AND 45 BBLS DIESEL, RDMO 02/22/02 MIRU CTU #8.1780 PSI TBG ON ARRIVAL. PUT WELL ON FOR 40 MINUTES, PRESSURE CAME DOWN TO 350 PSI. IA ON VAC WITH 1600' FLUID LEVEL. PUMP 50 BBL'S 2~'~ KCL. WELL WENT ON VAC AND SIPHONED ANOTHER 20 BBLS FROM UP RIGHT, SI PUMP IN SUB. RIH WITH 3.81" CAT STANDING VALVE, FOUND FLUID LEVEL @ 1640' CTMD TBG. SET STANDING VALVE IN 'XN' NIPPLE AT 10,544'. PERFORM COMBINATION MIT. P-18L 1, Pre-Coil Tubing Drilling Page 2 02123/02 CONTINUE WITH CMIT. TUBING TESTED GOOD TO 1500 PSIG, IA CLIMBED FROM 150 PSI TO 700 PSI AND THEN HELD. IA TESTED GOOD TO 2000 PSIG, WHILE TBG. CLIMBED FROM 1500 PSI TO 1600 PSI. PULL STANDING VALVE. MU 3.625" X 14.45' WHIPSTOCK DRIFT. RIH TO 11,100' CTMD, POOH. RIH WITH MEMORY GAMMA/CCL, LOG DOWN DOWN & UP PASS FROM 10,700'TO 11,150'. FLAG PIPE @ 10,900' CTMD & POOH. CORRECTED EOP @ FLAG IS 10,879'. LOAD WELL WITH 200 BBLS OF HOT FILTERED 2% KCL. MU AND RIH WITH BAKER PIP. 02124/02 RIH WITH BAKER 'PIP'. CORRECT DEPTH AT FLAG. SET 'PIP' AT 11,050'. POOH. RIH WITH BAKER PERMANENT WHIPSTOCK, CORRECT DEPTH TO 'PIP'. SET WHIPSTOCK, TOP AT 10,950', BOTTOM 10,962'. (RA TAG INSTALLED 9' FROM TOP OF WHIPSTOCK). FREEZE PROTECT TBG TO 2500' WITH MEOH. RIG DOWN. (WHIPSTOCK TRAY 33.8 DEG RIGHT OF HIGH SIDE.) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/26/2002 2/27/2002 2/28/2002 3/1/2002 P-18 P-18 L 1 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Activity Code NPT Phase 12:30-18:30 6.00 MOB N WAIT PRE 18:30 - 00:00 5.50 MOB N WAIT PRE 00:00-14:15 14.25 MOB N WAIT PRE 14:15 - 14:45 0.50 MOB P PRE 14:45 - 22:45 8.00 MOB :P PRE 22:45 - 23:30 0.75 MOB Ip PRE 23:30 - 00:00 0.50 MOB P PRE 00:00 - 13:30 13.50 MOB P PRE 13:30 - 14:00 0.50 RIGU P PRE 14:00 - 14:30 0.50 RIGU P PRE 14:30 - 15:45 1.25 RIGU P PRE 15:45 - 16:00 0.25 RIGU P PRE 16:00 - 18:00 2.00 RIGU Ip PRE 18:00 - 19:00 1.00 RIGU IP PRE 19:00 - 20:30 1.50 RIGU P PRE 20:30 - 23:30 3.00 RIGU P PRE 23:30 - 00:00 0.50 RIGU P PRE 00:00 - 02:00 2.00 RIGU P PRE 02:00 - 06:30 4.50 RIGU P PRE 06:30 - 07: 15 0.75 STWHIP P WEXIT 07: 15 - 07:50 0.58 STWHIP P WEXIT 07:50 - 09:10 1.33 STWHIP P WEXIT 09: 1 0 - 09:40 0.50 STWHIP P WEXIT 09:40 - 10:30 0.83 STWHIP P WEXIT 10:30 - 12:15 1.75 STWHIP P WEXIT 12: 1 5 - 12: 30 0.25 STWHIP P WEXIT 12:30 - 13'20 0.83 STWHIP P WEXIT 13.20 - 13:35 0.25 STWHIP P WEXIT 13'35 - 14.30 0.92 STWHIP P WEXIT 14:30 - 15'20 0 83 STWHIP P WEXIT 15:20 - 1700 1.67 STWHIP P WEXIT 17.00 - 18:00 1 00 STWHIP P WEXIT Page 1 of 5 Start: 2/20/2002 Rig Release: 3/6/2002 Rig Number: Spud Date: 3/1/2002 End: 3/6/2002 Description of Operations Rig released on DS 15-29a. Winds still 15mph gusting to 30 mph. Waiting on wind. Continue to wait on wind. Winds moderated at 15: 15 to below 20 mph. Watched for 1 hour to confirm not just a lull in the wind. Hold safety meeting prior to rigging down wind walls and begining move. Lay down wind walls and derrick. Pre move safety meeting. Review all hazards. Depart DS 15. headed for P pad in the WOA. Continue move from DS 15 to P pad on the WOA. Arrive P Pad. make pad inspection with pad operator. Safety meeting prior to raising derrick. Position rig square to well. but do not move over well yet. leaving fire lane. Raise derrick. Brief safety meeting prior to raising wind walls. Raise wind walls. Shut down rig up for crew change and safety meeting prior to moving over well. Move over well. Set injector on. AOGCC representative waived witnessing test. Rig accepted at 23:30. Waiting on green tank. Green tank on location. Spotted. BOPE test. BOP test completed, all passed ok, except inner reel valve. will need to make up CTC and fill coil before we can test it. Pick up injector. Safety meeting with BOT and rig hands prior to making up milling BHA. Pump dart to fluid pack coil and confirm coil volume. 58.9 bbls to land dart. PT coil inner real valve and CTC to 3500 psi, chart same. Pull test CTC to 35klbs. Make up BHA #1, 3.80" Hughes mill and Baker string reamer-Mud Motor-CS-2 Jts of PH6-Dis-Chk-NRJ-Baker CTC. Rlh with BHA #1 , junking FP fluid on top 40 bbls of well. Dry tag XN nipple, PU at 38klbs. Correct to ELM depth for XN nipple of 10549' (-13' correction). Proced to milling nipple. Free spin 1430 psi. 2.6 bpm. Milled thru nipple easily. Dry drift nipple ok up and down 2X. RIH, tag pinch pomt on whipstock. Make -8' correction to get on depth to ELM depth of whipstock Circulate mud to bit. Yo-Yo while waiting for mud Circulate in 17 bbls of mud accross whipstock. SD pumps, walt 5 minutes. Begin window milling. Draggy and hard to get started milling Several stalls. GOing better now. Have a pattern established, and milling keeping WOB at 2000# maximum Getting drillofts. Weight check, pickup clean. Resume milling. 10956.4', Update at 17.00 Getting good dnll ofts. Good ROP. 3100 Ibs weight on bit. 250 psi motor work. made 54' of Pnntea 3/12/2002 10 17 31 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3/1/2002 3/2/2002 3/3/2002 Date BP EXPLORATION Operations Summary Report P-18 P-18 L 1 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Activity Code NPT Phase 17:00 - 18:00 18:00 - 18:30 18:30 - 19:30 19:30 - 19:40 19:40 - 20:30 20:30 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 00:40 00:40 - 02:15 02: 15 - 02:30 02:30 - 02:45 02:45 - 05: 15 05: 15 - 06:00 06:00 - 06:20 06:20 - 06:30 06:30 - 08:20 08:20 - 08:25 08:25 - 09:05 09:05 - 09:20 09:20 - 09:25 09:25 - 11 :15 11:15-13:10 13:10-13:40 13:40 - 15:50 15:50 - 16:05 16'05 - 17:50 17:50 - 18:30 18:30 - 18:55 18:55 - 20.10 20.10 - 22.20 22.20 - 00'00 00.00 - 00'15 00: 15 - 03.00 03.00-07:15 07:15 - 07:45 07:45 - 08'00 08.00 - 08 10 1.00 STWHIP P 0.50 STWHIP P 1.00 STWHIP P 0.17 STWHIP P 0.83 STWHIP P 1.50 STWHIP P 1.00 STWHIPIP 1.00 STWHIPlp 0.67 STWHIPIP 1.58 STWHIPIP 0.25 DRILL P 0.25 DRILL P 2.50 DRILL P 0.75 DRILL P 0.33 DRILL P 0.17 DRILL P 1.83 DRILL P 0.08 DRILL 0.67 DRILL 0.25 DRILL 0.08 DRILL 1.83 DRILL 1.92 DRILL P P P P P P 0.50 DRILL P 2.17 DRILL P 0.25 DRILL P 1 75 DRILL P 0.67 DRILL 0 42 DRILL 1 25 DRILL 2.17 DRILL 1.67 DRILL 025 DRILL 2.75 DRILL 4.25 DRILL 0.50 DRILL 0.25 DRILL P P P P P P P P P P 0 17 DRILL P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD 1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD 1 PROD1 PROD1 PROD 1 PROD1 PROD1 PROD1 PROD 1 PROD1 PROD 1 PROD1 Page 2 of 5 Start: 2/20/2002 Rig Release: 3/6/2002 Rig Number: Spud Date: 3/1/2002 End: 3/6/2002 Description of Operations window so far. Expect 10' total. 10958.6', Update at 18:00. Getting good ROP still. 1500 Ibs weight on bit. Weight has dropped off but still getting good motor work. 300 Ibs motor work. 10960.3'. Pump sweep pill. 300lbs motor work. 1200 #s WOB. 10961'. Drill out window. Start drilling 10' of formation. 2.8/2350 psi. 3500 Ibs WOB. Drill to 10971'. Pump sweep pilI. PU to work window. Reaming/ Back reaming through window. Some motor work at 10953'. Window looks good. RIH with pumps off. Tag dry twice. OK. POH. TOW @10951'. BOW @ 10961'. Drill formation to 10971'. Flag pipe. EOP @ 10700'. POH. Displacing well to flo-pro. OOH. LD milling tools. P/U 2.0 deg motor. MU build up assembly. Safety meeting. Discuss drilling hazards. RIH w/build assembly. Shallow hole test. OK. Test Orientor. OK. Continue RIH. Log tie in. 5' correction. Orienting 2.7/3770 psi/74L. 10991', drilling build section. 2.6/2.6/3500 psi. Last PU weight - 25klbs. 11065', Clean pickup at 32klbs, Take 1 click and a survey. Resume drilling. TF97L, 2.5/2.5/3360 psi. 11099', Wiper trip to shoe. Clean pickup off bottom at 34klbs. Orient 2 clicks. Continue drilling. 11187' POOH to change motor bend. Have been getting 20 deg build with a 2 deg motor. Needed minimum of 23 deg to make build. Will end up landing 30' TVD too deep. This is not acceptable to asset. POOH to pick up 3 deg motor. This should give us 34-39 deg builds. Tag up at surface with BHA #2, stand back MWD. Readjust motor. Inspect bit. All looks ok, rig back on well. RIH with BHA #3. Tag up at TD. Make -18' correction to last tag at 11187'. Pick up and orient to high side. Drill build section 2.6/2.6/3400, 3100 psi free spin. TF=O, ROP=80 fph. 11300', Wiper tnp to shoe. Clean pickup off bottom at 35klbs. Orienting. Drill 2.7/3500/14R. Drill to 11374'. Getting 27 deg builds Finished build up section. POH to P/U lateral assembly OOH. UD bUild assembly. P/U 1.37 deg motor. Continue MU BHA. RIH w/lateral assembly. BHA # 4. SHT OK. Tie in log, Add 13'. Mad pass. MAD pass finished, RIH to onent and resume drilling. Tag up at 11379.4', Free Spin 3200 psi at 2.7 bpm. Begin dnlllng 2.7/2.7/3400 psi, no losses. Onent to 45R. Printed ~/12/2002 10 1 7 31 AM BP EXPLORATION Operations Summary Report Page 3 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P-18 P-18 L 1 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/20/2002 Rig Release: 3/6/2002 Rig Number: Spud Date: 3/1/2002 End: 3/6/2002 Date From - To Hours Activity Code NPT Phase Description of Operations 3/3/2002 08: 1 0 - 09:00 0.83 DRILL P PROD 1 Resume drilling. 09:00 - 09:20 0.33 DRILL P PROD1 11440', back ream 100'. 09:20 - 09:45 0.42 DRILL P PROD1 Orient to 1 OOL. 09:45 - 10:05 0.33 DRILL P PROD1 Drilling ROP has gotten very difficult due to weight transfer. Suspect poor sliding from old mud. Midnight MR showed only 0.4% drill solids, but this is a used mud system. Mix 1/2 bbl of lubtex with 30 bbls of mud and see how that helps us drill. Call for mud swap. Trucks not available until mid afternoon. Call for 4 additional bbls of lubtex from MI shop to help us drill in the meantime. 10:05 - 10:40 0.58 DRILL P PROD1 Pump 30 bbl sweep of mud with an additional 1/2 bbl of lubtex. Appears to drill fine with sweep around. Will add 4 bbls to current system when it arrives on location. 10:40 - 11 :55 1.25 DRILL P PROD1 11482', sweep of 1.5% additionallubtex made a big difference. Was able to drill. Will add an additional 4 bbls (1 %+) to system when it gets here from MI. Orient around to 120L. 11 :55 - 11 :40 23.75 DRILL P PROD1 Resume drilling, 2.5/2.5/3500 psi, TF128L. 11:40-12:30 0.83 DRILL P PROD1 11504', Wiper trip to shoe. 12:30 - 13:00 0.50 DRILL P PROD 1 Resume drilling 2.5/2.5/3400 149L TF. 13:00 - 13:40 0.67 DRILL P PROD1 Lubtex is in mud now, ROP has picked up, able to drill ahead ok. Checked mud at noon. Drill solids up to 1.1 %. Definately need mud swap as soon as trucks are available. 13:40 - 13:50 0.17 DRILL P PROD1 11587', PU, orient to 90R. 13:50 - 14:45 0.92 DRILL P PROD1 Resume drilling 14:45 - 15:30 0.75 DRILL P PROD 1 11658', Wiper trip to shoe. Clean pickup off bottom, 32klbs. No overpulls or problems on way out or in. 15:30 - 16:10 0.67 DRILL P PROD1 Resume drilling. 2.5/2.5/3450 TF=123R. 16:10-17:05 0.92 DRILL P PROD1 New mud on location. Begin mud swap. Taking returns to clean vac truck for return to MI for base mud for rotary rig. 17:05 - 18.00 0.92 DRILL P PROD 1 11726', Wiper trip. 18:00 - 18:20 0.33 DRILL P PROD 1 Orient 18:20 - 19:30 1.17 DRILL P PROD1 Resume drilling. Free spin 3500 free spin (New mud - needs to shear). 2.5/2.5/3600. Good returns. lots of reactive torque. Drill to 11773'. 19:30 - 20:30 1.00 DRILL P PROD 1 Continue drilling 2.6/3620/132R. 20:30 - 21 :00 0.50 DRILL P PROD 1 2.7/3700/135R. Dtrill to 11815'. 21 :00 - 21 :20 0.33 DRILL P PROD 1 Orienting 21:20-22'15 0.92 DRILL P PROD 1 Resume drilling 2.5/3700/90R. Drill to 11838'. 22: 15 - 23:00 0.75 DRILL P PROD1 2 5/3740/164R. Drill to 11872'. 23:00 - 00:00 1.00 DRILL P PROD1 Wiper trip to the window. Clean trip. 3/4/2002 00:00 - 00'45 0.75 DRILL P PROD 1 Tie- in w/GR. Add 14'. RIH. 00:45 - 01,30 0.75 DRILL P PROD 1 Orienting. 01 :30 - 03:45 2 25 DRILL P PROD 1 Resume drilling 2.4/3650/109 R. Some weight transfer problems. Had some changes on drilling parameters. Looks like crossing fault Drill to 12003' 03:45 - 04'10 0.42 DRILL P PROD1 Orienting 04: 10 - 05:30 1.33 DRILL P PROD1 Drilling 2 5/3780/65R Drill to 12100'. 05'30 - 07:00 1 50 DRILL P PROD 1 Short trip to the window. 07 00 - 07 15 0.25 DRILL P PROD1 12100', Resume drilling 2.6/2.6/3600 pSI free Spin Drilling at 3700 psi. Making 45 fph, TF97R. dropping at 86 deg as per plan 07: 15 - 07'30 0.25 DRILL P PROD 1 PU off bottom at 39klbs. A little sticky off bottom. Orient 07:30 - 07 40 0.17 DRILL P PROD 1 Resume drilling. Pr,nted 3/12/2002 101731 AM BP EXPLORATION Operations Summary Report Page 4 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P-18 P-18 L 1 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/20/2002 Rig Release: 3/6/2002 Rig Number: Spud Date: 3/1/2002 End: 3/6/2002 Date From - To Hours Activity Code NPT Phase Description of Operations 3/4/2002 07:40 - 08: 15 0.58 DRILL P PROD1 Having trouble getting weight to bit. Make 100' wiperlbackreaming pass. PU at 40 klbs. Cleaned up to 34klbs. Slightly sticky on pickup. 08: 15 - 09:45 1.50 DRILL P PROD1 Resume drilling. 09:45 - 10:00 0.25 DRILL P PROD1 12173'. Currently drilling with -5000 Ibs weight at surface. Not getting great weight to bit. Drilling a 20' TVD shale which is hard to drill. Add an additional 1 % of lubtex to mud to improve sliding. Started adding at 09:45. 10:00 - 10:05 0.08 DRILL P PROD1 Pick up 2 clicks 10:05 - 11 :30 1.42 DRILL P PROD1 New mud 30 bbls around bit. Free spin with lubtex added=3600 psi. Resume drilling 2.6/2.6/3850 psi. Weight at surface now +2000 Ibs. ROP 80 fph. 11 :30 - 12:45 1.25 DRILL P PROD 1 12263', wiper trip to shoe. Good pickup, some small drag and tugs while tripping. Possible cuttings in hole. 12:45 - 13:45 1.00 DRILL P PROD 1 Resume drilling. 13:45 - 13:50 0.08 DRILL P PROD1 Catch 2 clicks. 13:50 - 15:10 1.33 DRILL P PROD1 12285', Resume drilling. 2.6/2.6/4200 psi. 15: 10 - 15:45 0.58 DRILL P PROD 1 12331', Getting significant reactive torque. and ROP has slowed way down. suspect we may be up against fault #3. Make wiper trip while consulting with town. Recommend this is called TD. 15:45-16:10 0.42 DRILL P PROD1 Log tie in pass from 11110'. Make + 16' correction. 16:10 - 16:45 0.58 DRILL P PROD1 RIH to tag corrected TD. Pump 22 bbl sweep of high vis mud while RIH to sweep off of bottom. 16:45 - 17: 1 0 0.42 DRILL P PROD1 Tag bottom 12345', Yo-Yo while circulating hi vis sweep to bottom. 17:10-20:15 3.08 DRILL P PROD 1 Pump sweep around bit. POOH chasing sweep. 20.15 - 21 :00 0.75 DRILL P PROD1 OOH. LD drilling assembly. 21 :00 - 21: 15 0.25 CASE P COMP PJSM on liner run. 21 :15 - 00:00 2.75 CASE P COMP MU 2 7/8" liner. 3/5/2002 00.00 - 01 :00 1.00 CASE P COMP Continue MU liner. 01 :00 - 02:00 1.00 CASE N WAIT COMP Wait on 3 1/2" C plate. 02:00 - 04: 15 2.25 CASE P COMP MU CS Hydrill. 04: 15 - 06:00 1.75 CASE P COMP RIH wIllner. Up wt liner 39K. Dwn wt 18K. Catch flag, make -19' correction. Tag up at top of liner. Stack at 10941'. 06:00 - 06:50 0.83 CASE N DFAL COMP Tag up at 10941'. Top of whipstock at 10951'. Could be hanging up at top of whipstock. Set down 10 times at various speeds and down weights. Could not get through. Pickup, consult with Baker in Deadhorse. Decided to POOH to standback liner and inspect bottom nose. 06:50 - 08.25 1 58 CASE N DFAL COMP POOH with liner. 08:25 - 08:40 0.25 CASE N DFAL COMP Safety meeting prior to rigging back CS hydril work string and 2-7/8 x 3-3/16 liner 08.40 - 09.10 0.50 CASE N DFAL COMP Stand back Injector. 09'10 - 10:10 1.00 CASE N DFAL COMP Stand back CS hydril work string. 10.10 - 12.50 2.67 CASE N DFAL COMP Stand back liner 12:50 - 13.30 067 CASE N DFAL COMP At surface with guide shoe. Found deep grooves on both sides of the bottom nose which look like damage from the bottom of the window. Consult with town. Decide to make a tnp with rounded bottom nose instead of cone bottom nose 13 30 - 15:00 1.50 CASE N DFAL COMP Make up Liner BHA to run back In hole. As per proceedure. Same liner with exception of different bottom nose. Bottom joint left slick. All other 2-7/8" joints have turbos. Pr,nlea 3/12/2002 1ü 1 ~ 31 AM BP EXPLORATION Operations Summary Report Page 5 of 5 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P-18 P-18 L 1 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/20/2002 Rig Release: 3/6/2002 Rig Number: Spud Date: 3/1/2002 End: 3/6/2002 Date From - To Hours Activity Code NPT Phase Description of Operations 3/5/2002 15:00 - 15:15 0.25 CASE N DFAL COMP Make up CTLRT 15:15-16:00 0.75 CASE N DFAL COMP Change out coil connector, pull test 50k, PT 4000 psi. stab onto well 16:00 - 17:30 1.50 CASE N DFAL COMP RIH with liner. Correct -15 ft CTD at flag. RIH. 17:30 - 18:45 1.25 CASE P COMP Ran thru window with no wt. loss. Sat down at 11,155' and 11.210' in build section. RIH clean to 12,220 ft. Sat down full wt 5 times at various RIH speeds. Fell thru. RIH to 12,260'. Sat down at 12,310 ft CTD. Sat down at several speeds up to 140 fpm. Sat down 10 times with no progress. Firm TD. Liner appears to be at TD of 12,345 ft BKB. 18:45 - 19:30 0.75 CASE P COMP Insert 5/8" steel ball. Displ. with FloPro. Reduce rate to 1 . Obpm/ 1860psi @ 40bbls. Ball on seat @ 46.1 bbls. Pressure up to 4000psi & shear out ball. P/U @ 34k (6k wt loss) & confim release. 19:30 - 20:20 0.83 CASE P COMP Displace well to 2% KCI @ 2.7bpm/3260psi. Pump 40 bbls around slick stick. 20:20 - 22:00 1.67 CASE P COMP POOH to 2000' displacing mud @ 2.6bpm/3200psi. 22:00 - 22:25 0.42 RIGD P COMP Freeze protect well with 30 bbls MeOH. 22:25 - 23:00 0.58 CASE P COMP POOH to surface. 23:00 - 00:00 1.00 CASE P COMP OOH. Stand back injector. UD CTLRT. Rack back 1-1/4" CSH. 3/6/2002 00:00 - 00:20 0.33 CASE P COMP Continue racking back 1-1/4" CSH & UD slick stick. SI master & swab valves. 00:20 - 01 :00 0.67 RIGD P COMP PJSM. R/U hard lines for pumping N2. 01 :00 - 02:30 1.50 RIGD N WAIT COMP N2 truck acting up. Hook-up portable heater to warm-up engine/battery. 02:30 - 04:30 2.00 RIGD P COMP Blow down CT with N2 & blow down mud lines to tlgger tank. 04:30 - 07:30 3.00 RIGD P COMP PJSM for ND. Nipple down BOP. Nipple up & pressure test tree cap. Meanwhile clean out pits & tanks. Rig Released at 06:00 on 3/6/2002. Total time on well was 5 days, 6.5 hours. 07:30 - 07:45 0.25 RIGD P COMP SAFETY MEETING. Review procedure to move off well with crew. 07:45 - 09:30 1.75 RIGD P COMP Move rig off well. Move tanks and remove berms. 09:30 - 10:00 0.50 RIGD P COMP SAFETY MEETING. Held pre-rig move meeting with Security, Nordic. DS and Tool service personnel. Reviewed hazards. route and move plan. 10:00 - 00:00 14.00 RIGD P COMP Move rig to DS 18-10. Printed 3/12/2002 101731 AM AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well P-18 L 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 10,941 .74' M D 'MD (if applicable) 12,345.00' MD a aa - 08<=} 18-Mar-02 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED t 1 ~~. '"! en ilO? , I: \... L Io.-W... Alaska Oil & Gas Cons. Commission A'1cborage DEF'NlrlVE North Slope Alaska BPXA PBU_WOA P Pad, Slot P-18 P-18 L 1 Job No. AKMW22040, Surveyed: 4 March, 2002 SUR VE Y R E PO R T 15 March, 2002 Your Ref: 500292209760 Surface Coordinates: 5947078.00 N, 631362.00 E (70015' 48.6368" N, 148056'16.6477" W) Kelly Bushing: 91. 85ft above Mean Sea Level Sr-=ai .1 .Y-5Ur-, CRILLING sERVices A Halliburton Company Survey Ref: svy11128 Sperry-Sun Drilling Services . SUlVey Report for P.18 L 1 DEF Your Ref: 500292209760 NITVE Job No. AKMW22040, SUIVeyed: 4 March, 2002 BPXA North Slope Alaska PBU_WOA P Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (D/100ft) 1094 1 .7 4 4 1 630 173 620 8776.52 8868.37 3576.47 S 3412.96 E 5943561.62 N 634836.84 E 4528.08 10950.00 41 570 173 700 8782.70 8874.55 3581.92 S 3413.56 E 5943556.18 N 634837.54 E 0.971 4533.41 Window Whipstock 10988.54 43860 166.800 8811.03 8902.88 3607.65 S 3418.02 E 5943530.53 N 634842.44 E 13.514 4559.11 11031 97 4 7 200 159,720 8841 .4 7 8933.32 3637.27 S 3426.99 E 5943501.07 N 634851.92 E 13.937 4590.01 11 061 67 48 950 155 280 8861.32 8953.17 3657.67 S 3435.45 E 5943480.82 N 634860.74 E 12.585 4612 08 11091.75 49 480 138 480 8881.05 8972.90 3676.61 S 3447.82 E 5943462.10 N 634873.44 E 42.260 4634 11 1112167 50 890 1 3 1 900 8900.22 8992.07 3692.89 S 3464.01 E 5943446.11 N 634889.91 E 1 7.532 4654.94 1116197 55 750 122 280 8924.32 9016.17 3712.27 S 3489.78 E 5943427.18 N 634916.02 E 22.606 4681 97 11217,44 68 910 119,950 8950.03 9041 .88 3737.54 S 3531.78 E 5943402.64 N 634958.45 E 24.012 4720.08 11249.87 76 550 120 120 8959.65 9051 50 3753.03 S 3558.57 E 5943387.62 N 634985.50 E 23.564 474380 1128796 86.750 121 880 8965.17 9057 02 3772.42 S 3590.82 E 5943368.80 N 635018.09 E 27.165 477305 1131924 90.7 50 125 640 8965.85 9057,70 3789.79 S 3616.81 E 5943351.88 N 635044.38 E 1 7.547 4798.26 1135796 97 920 129 290 8962.93 9054 78 3813.26 S 3647.43 E 5943328.96 N 635075.41 E 20 764 4830 78 11388.36 103 000 129.870 8957.41 9049.26 3832.30 S 3670.47 E 5943310.32 N 635098.77 E 16.815 4856.55 1142031 107 840 131.810 8948.92 9040.77 3852.43 S 3693.77 E 5943290.60 N 635122.42 E 16.239 4883.44 11451.89 109340 133.920 8938.85 9030.70 3872.78 S 3715.70 E 5943270.63 N 635144.71 E 7.916 491007 1148908 107930 126.700 8926.95 9018,80 3895.56 S 3742.56 E 5943248.33 N 635171.96E 18.781 4940.66 1152054 103 720 123.520 8918.37 9010.22 3912.95 S 3767.32 E 5943231.37 N 635197.01 E 16.541 4965 4 7 11554 52 102470 122.290 8910.67 9002.52 3930.93 S 3795.10 E 5943213.88 N 635225.11 E 5.095 4991.87 1158728 105810 126.520 8902.67 8994.52 3948.86 S 3821.31 E 5943196.41 N 635251.62 E 16.145 5017 68 11616.66 105290 1 3 1 980 8894.79 8986.64 3966.77 S 3843.22 E 5943178.89 N 635273.84 E 1 7.991 5042 00 1164831 103440 136.570 8886.93 8978.78 3988.17 S 3865.16 E 5943157.87 N 635296.15 E 15.216 5069 61 11680.80 100440 14 1 320 8880.21 8972.06 4012.13 S 3886.02 E 5943134.28 N 635317.43 E 17 023 5099.27 11718.99 98 770 146960 8873.83 8965.68 4042.64 S 3908.07 E 5943104.16 N 635340.00 E 15 203 5135.47 11753 29 96 390 149 250 8869.30 8961.15 4071.50 S 3926.03 E 5943075.61 N 635358.46 E 9.588 5168.74 11791. 16 91.720 152 250 8866.63 8958.48 4104.45 S 3944.47 E 5943042.99 N 635377.48 E 14.645 5206,01 1182955 90 660 158.420 8865.83 8957.68 4139.31 S 3960.48 E 5943008.42 N 635394.10 E 16.304 5244 24 1186938 85 900 158,770 8867.02 8958.87 4176.37 S 3975.01 E 5942971.62 N 635409.27 E 11 983 5284.03 11904 56 84 140 164 410 887008 8961.93 4209.60 S 3986.07 E 5942938.58 N 635420.91 E 16.736 5319.05 1194368 83 880 170 750 8874.17 8966.02 4247.58 S 3994.44 E 5942900.76 N 635429.94 E 16.132 5357.60 - - - -- - --. -- - -- ----.- - --- 15 March, 2002 - 7:40 Page 20f4 D,iIIQUfJst 20009.003 Sperry-Sun Drilling Services . Survey Report for P-18 L 1 Your Ref: 500292209760 Job No. AKMW22040, Surveyed: 4 March, 2002 BPXA North Slope Alaska PBU - WOA P Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) ("/1 OOft) 11972 83 83.350 1 76 390 8877.41 8969.26 4276.35 S 3997.68 E 5942872.04 N 635433.68 E 19.314 5385.75 12003.01 83 880 182.030 8880 77 8972.62 4306.33 S 3998.09 E 5942842.08 N 635434.62 E 18.655 5414.06 1204083 87 750 186.610 8883.53 8975.38 4343.93 S 3995.25 E 5942804.44 N 635432.43 E 15.828 5448 4 1 12073 76 87 220 191.370 8884.98 8976.83 4376.41 S 3990.11 E 5942771.87 N 635427.86 E 14.530 5477. 18 12099 36 87670 195.070 8886.12 8977.97 4401.30 S 3984.26 E 5942746.88 N 635422.44 E 14 .54 5 5498.57 12133.08 85 990 200.180 8887.98 8979.83 4433.38 S 3974.07 E 5942714.63 N 635412.82 E 15.930 5525.23 12154 77 84 580 200 71 0 8889.77 8981.62 4453.63 S 3966.52 E 5942694.25 N 635405.62 E 6.942 5541.68 12185.81 79470 199.300 8894.07 8985.92 4482.51 S 3956.01 E 5942665.19 N 635395.61 E 1 7.066 5565 21 12233 37 77 270 191. 190 8903.67 8995.52 4527.41 S 3943.76 E 5942620.09 N 635384.15 E 17.329 5603.22 1226636 78 240 186.430 8910.67 9002.52 4559.26 S 3938.83 E 5942588.16 N 635379.77 E 14 403 5631 46 12301 83 83 350 18 1 .680 8916.35 9008.20 4594.16 S 3936.36 E 5942553.22 N 635377.91 E 19.549 5663 4 1 1234500 83 350 18 1 680 8921.35 9013.20 4637.02 S 3935.10 E 5942510.34 N 635377.41 E 0.000 5703.26 Projected Survey All data is In Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Ver1ical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.241" (13-Mar-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 160.000" (True). Based upon Minimum Curvature type calculations. at a Measured Depth of 12345.00ft., The Bottom Hole Displacement is 6081.69ft.. in the Direction of 139.681" (True). --- -- 15 March. 2002 - 7:40 Page 3 of 4 Dr;/IQuest 2.00.09.003 Sperry-Sun Drilling Services Survey Report for P-18 L 1 Your Ref: 500292209760 Job No. AKMW22040, Surveyed: 4 March, 2002 . North Slope Alaska BPXA PBU_WOA P Pad Comments Measured Depth (ft) Station Coordinates TVD Northlngs Eastings (ft) (ft) (ft) Comment 10950 00 12345 00 8874.55 9013.20 3581.92 S 4637.02 S 3413.56 E 3935.10 E Window Whipstock Projected Survey Survey tool program for P-18 L 1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 000 0.00 12345.00 9013.20 MWD Magnetic (P-18 L 1) 15 March, 2002 - 7:40 Page 4 of4 Dril/Qllest 2,0009.003 '} ~~~~E :f ~~!Æ~~~~ AlASKA. OIL AM) GAS CONSERVATION COMMISSION / / TONY KNOWLES, GOVERNOR 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska), Inc PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit P-18LI BP Exploration (Alaska), Inc Pennit No: 202-039 Sur Loc: 2348' NSL, 2076' EWL, Sec. 31, T1IN, R13E, UM Btmhole Loc. 2391' SNL, 1010' EWL, Sec. 05, T10N, R13E. UM Dear Mr. Endacott: Enclosed is the approved application for pennit to redrill the above referenced well. The pennit to redrill does not exempt you trom obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pe1111itting detenninations are made. The permit is for a new well bore segment of existing well PBU PI8, Permit No, API 50-029- 22097 -00. Production should continue to be reported as a function of the original API number stated above. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit P-I8LI. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole, Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607, Sincerely, /'", 7 I I"~ ' UUJ ~/ J.;.l¿ /1.')--f,,- ..J& j'~L------ Canuny œchsli Taylor Chair BY ORDER OF THE COMMISSION DATED this~y of February, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation wlo encl. STATE OF ALASKA ~L AND GAS CONSERVATION COMl PERMIT TO DRILL 20 AAC 25.005 ALASKI 1 a. Type of work 0 Drill 181 Redrill 0 Re-Entry D Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2348' NSL. 2076' EWL. SEC. 31, T11 N, R13E, UM At top of productive interval 1298' SNL. 476' EWL. SEC. 05, T10N, R13E, UM At total depth 23911 SNL, 1010' EWL, SEC. 05, T10N, R13E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028288,2391' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 10950' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole CasinQ WeiQht Grade CouplinQ LenQth 3-3/4" 3-3116" x 2-7/8' 6.2 x 6.1611 L-80 ST-L 22001 1 b. Type of well 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 Casing Structural Conductor Surface Intermediate Production Li ner 11520 feet 9296 feet 11398 feet 9208 feet Length Size 110' 20" 2690' 10-3/4" 10828' 7-5/8" 961' 5-1/2" )SION k J6)- Revised: 02/19/02, Changed to Multi Lat 0 Exploratory 0 Stratigraphic Test 181 Development Oil D Service 0 Development Gas [B'Single zone)b D Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 91.85' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ~z. :r'2S'lš .,..ADL 028289 4Þ 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number P-18L 1 I 9. Approximate spud date 02/25/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 12500' MD / 8935' TVDss 17. Anticipated pressure {sE}e 20 AAC 25.035 (e) (2)} 990 Maximum surface 2294 Jpsig, At total depth (TVD) 8800' / 3350 psig Setting Depth Top Bottom Quantitv of Cement MD TVD MD TVD (include staQe data) 10500' 8475' 12500' 8935' Uncemented Solid & Slotted Liner ...... 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 ",~\¡'iÞ""'D ~t:l.;I::"'~ t: Plugs (measured) FEE .' u {'DOL Junk (measured) Cemented Alaska'OiI & Gas COII~. Commisslo~ M[j\nchorage TVD To Surface 2891 cu ft Permafrost 1588 cu ft Class 'G' 110' 2690' 108281 110' 2690' 8785' 191 cu ft Class 'G' 10559' - 11520' 8605' - 9296' true vertical 11062'-11100', 111261_11144, 11154'-11170', 11180'-11191' Perforation depth: measured 8959' - 8988', 9008' - 90211, 9029' - 9041', 9048' - 9056' 20. Attachments 181 Filing Fee 0 Property Plat 181 BOP Sketch 0 Diverter Sketch 181 Drilling Program 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report D 20 AAC 25.050 Requirements Contact Engmeer NamelNumber: Mary Endacott, 564-4388 21. I hereby certify that the f~r~going is true and correct to the best of my knowledge Signed Mary Endacott ;1;;' r - j\ /..1 I' k{ ({ (' c.Tr-- Title CT Drilling Engineer Commission Use Only Permit Number API Number /:) A~'S>~ ~te See cover letter :2.C '2. -C)S¡ 50- 029-22097-60 ,-~-, ,. )) ()'..¿... for other requirements Conditions of Approval: Samples Required 0 Yes [8 No Mud Log ec uired 0 Yes ~No Hydrogen Sulfide Measures 6i Yes 0 No Directional Survey Required œI Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K ~ 3.5K psi for CTU Other: Approved By Form 10-401 Rev. 12-01-85 Original Signed BV t,;ammV Oechsli Prepared By Name/Number: Terrie Hubble. 564-4628 Date :/(1/( :- by order of Commissioner the commission .-. 6 ... ~ .. .. ! ~" J ,\ L ¡ i ¡ J , t 'ï I ~1', I¡ ,.:-. ':,> ¡ ". ~ ~. j ~ i 'u' ~ Date ~ / 7¡~ h"J... S':1o:nit In ~ri~icate BP P-18L 1 Lateral Summary of Operations: I A crD through tubing lateral is planned for well P-18. The lateral, P-18L 1, will exit the 5 1/2" liner in the Shublik formation ,nd target Zone 4B. Because of a CNL showing gas in the Sag River, perfs were shot in, the Sag (2/14/02) to determine if it was capable of flow, flow tests did not indicate an increase in gas flow .-' and the perfs will be left open during drilling and completion.v" Existing Zone 4 perfs will be isolated with an inflatable bridge plug with a standing valve set in the 5 Y2" liner". A mechanical whipstock will be set. J Phase 1: Prep work. Planned for Feb. 19-25, 2001. 1. Drift tubing and liner with dummy whipstock. 2. Dummy off all GLM's and perform IA MIT to 2500 psi. ./ 3. Use coil to set a PIP with standing valve at approx. 11 ,050'MD (8859ss). 4. Use coil to set a mechanical whipstock at approx. 10,950'MD (8783ss). 5. Window will be milled with drilling coil. ,/ Phase 3: Mill window, Drill and Complete sidetrack: Planned for Feb. 25, 2002. Drilling coil will be used to mill the window then drill and complete the directional hole as per attached plan. Maximum hole angle will be 100~egrees. The production liner will be a 3 3/16" x 2 7/8" un- cemented solid/slotted liner. ..~ Mud Program: . Phase 1 &2: Seawater . Phase 3: Mill with seawater/biozan, drill with Flo-Pro (8.6 - 8.7 ppg) Disposal: ' . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: The production liner will be a 3 3/16" TC II x 2 7/8" ST-L un-cemented solid/slotted liner from TD to approx. 10,500'MD (8475ss). The X-O between 3 3/16" x 2 7/8" will be at 11,100' MD (8896ss). ,. Well Control: . BOP diagram is attached. / . Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. . The annular preventer will be tested to 400 psi and 2500 psi. Directional . See attached directional plan. Max. planned hole angle is 100 deg. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . An MWD Gamma Ray / Resistivity log will be run over all of the open hole section. Hazards . The highest H2S recorded to date on P-18 was 30 ppm on 8/9/01. Crossing two faults, with moderate risk of lost circulation. . Reservoir Pressure Res. press. is estimated to be 3350 psi at 8800'ss (7.2ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2294psi. . 4" CrN FMC OTIS 91.85' 55.82' 3594' 52 @ 10377' - ----- - . -- -- 10973' 8800' SS TREE = WELlHEA D = ACTUATOR = -- .- KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = --. - . -. - - Datum TV D = Pro~osed P-18L ~ 110-3/4" CSG, 45.5#, L-80, ID = 9.953" 1-1 2690' Minimum ID = 14-1/2" TBG,12.6#, L-80, TDS, 0.0152 bpf, ID = 3.958" 11 10563' I I TOP OF 5-1/2" TrN LNR HNGR 1-1 10559' I 17-5/8" CSG, 29.7#, NT-95HS, ID = 6.875" 1-1 10828' 1 I Proposed Sag perfs 1-110,910'-10,920' r- ÆRFORA TION SUMMARY REF LOG: ATLAS BHCA 11/14/90 ANGLEAT TOP ÆRF: 40 @ 11062' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 4 11062-11100 0 03/06/91 3-3/8" 4 11126-11144 0 01/06/91 3-3/8" 4 11154-11170 0 01/06/91 3-3/8" 4 11180-11191 0 01/06/91 1 PBTD 1-1 11398' I 15-1/2" LNR, 17#, NT-13Cr-80, FL4S, 1-1 11520' 0.0232 bpf, ID = 4.892N I DATE 11/19/90 03/04/01 03/05/01 07/15/01 02/19/02 COMMENTS ORIGINAL COMA..ETION SIS-SL T CONVERTED TO CANV AS SIS-MD FINAL RNIKAK CORRECTIONS MSE PROPOSED LATERAL DA TE REV BY REV BY ) NOTES @ 2077' 1-14-1/2" OTIS SSSV NIP. ID = 3.813" I ~ ~ ST MD TVD 6 3016 2924 5 5443 5098 4 7835 6708 3 9317 7704 2 9934 8111 1 10433 8434 L I I 10460' I 10465' I /1 I I I 10563' 1 10550' I z 10467' 10500' 10524' 10544' ~ ~ ~ , ~ GAS LIFT MANDRELS DEV TV PE VL V LATCH PORT DATE 0 CAMCO BK 46 CAMCO BK 49 CAMCO BK 49 CAMCO BK 49 CAMCO BK 52 CA MCO BK 1-14-1/2" PKR SWS NIP, ID = 3.813" 1 1-1 RIGHT HAND RELEASE LA TCH I 1-17-5/8" X 4-1/2" TrN HBBP PKR. ID = 4.0" I 1-1 Top of Proposed 3-3/16"x2-7/8" Liner 1-14-1/2" PKR SWS NIP, ID = 3.813" I 1-14-1/2" OTIS XN NIP, ID = 3.725" 1 1-15-1/2" TrN SEAL ASSY W/O SEALS 1 1-1 ELMD TT LOGGED 02/03/91 I ~ ~ ~' - ~ 10950'I--MiII Window off Mechanical Whipstock 1 -[ / Ih~~ 111~O'1 I 3-3/16"x2-7/8"XO I 0 XDX °0 d -"" 6 Ò 0 0 0 0 0 0 0 0 0 I - ì ~1050' ~IPlPwl standing valve 1 12-7/8" L-80 Liner, Pre-drilled ~ COMMENTS 1-112500' 1 PRUDHOE BA Y UNIT WELL: P-18L 1 ÆRMIT No' API No: 50-029-22097-60 Sec. 31,T11N,R13E BP Exploration (Alaska) All Measurements are from top of Riser top of bag bttm of bag middle of slips middle of pipes middle of flow cross middle of blind/shears middle of pipe/slips NORD\C .i. '- (1) en a: 'I 11111 r~\~ 11;)11[;)_1 - n Blind/Shears 2 3/811 combi ram/slips ~ Mud Cross ,~ variable bore pipe 3 1/2"-27/8" 2 3/811 combi ram/slips Flow Tee tJPE .. _, L; ........,.,.......,..,., ~,~/,./-'"'' 1'""'""""""\ --...I ',...,"....""..." ......,.....,...,....,~' 2/19/2002 P-If3L\ BAG TOTs ... Mud Cross TOTs / -- ----- T ^M ¿ BP Amoco R.. BL.,.. - ----- I~TIi.Q LE':.EP,[, - F.lf'IFOlf, ¡:. ,r, IF. Ir-L I) - F' ,~iF.I."I - F'/._.r.44 F. HIA. Fï_rilt:J ObP (' WILl PATH DETAILS P'u'" P i,A 500J12200701 , I ~ , '" ."" , -. ..~" ..................::." P.N"~:.~~:'~' ~~I!!IO~O "'" lI.f D.h,ftI 21 I U 10"10'1"0 OD~O v.a., 11011 1uI11. 0.':1"': ::::~ \ :-¡------ ~~~ :j:.on _:_- ~- I REF EF<E N( E ",r ORMA 11('" ."\6no -:'-- ---______L --- ----L...---...l-- - -- - - ------- - , n-+=l£:---,-MI)'¡ - _n~__, - ----+-- - - -- - -' - - - - -- - - -- , -- - -- - - ' -- - - --' - - -- - - 3~-~-~~'-~- . ~ ~ .._-~-~ .-~;~~~~-~~'-;~I~t~-~-~~-~\,~ ~~~f~~~-~~-=~c - - --- - - --- - I - ~.1O(J --- __n , - --- ( ,-I 1.r..1lrI.Jt.... INfE I J;1-'1I...lfo,r,(.;r 'lV't"1I c..-:,.(,trt:. f:' HI 11\.1". "..I'Jnrl M:~F":;:;r~:~~~\ ~=¡:::;:~:: ~fir:'J~ ~~~~'~::~~J~~~ ~:_: C' ""k",I~'I",rl M...."....J ""~Lr,,'TI~lrTl r.. I.Jr",,,,,IIJII;" '.H tl~, 3700- -==-= .1.... D18¡ ".1'8 V"'L Juri lIIriJ.4IU4111113f11 l17au 3!1'"'' 2 IWSO 00 .1 81 In '0 1781 'I' .I~I 113 J IOMOOO ., II H12. "8008 3&881:1 . UOIO Du U 52 11512 88'ZJ '''' J825 II II IU.las 8000 "114 1"1108' :11114.20 8 IUI2N HIJO 8111. 88:1185 ".lSn 7 un' N .1'8 112.0 ...~ Jii' .J8.&IS 1':1 8 IIII'N Nil 187 n "'11711 ...t04.2ðl 8 II""'" 80 00 117 U ...88 II -4OW'I1 1011"'.81 14.00 Ifl7 U 8.1'0 'Zs -4IH 81S 11 1110' II' 1:1... 200 In u... U ...JWOZ n UJI' IS' ... U I"" 8811 II "'''8''' 2. U U'5o'J(I 00 ""01 IIfI U .In II 4'1.'. 1412 W 0.00 0 no .!oI8 ðiIo ,..n~ 0" IU.SI 4513.,2 ,..I4.'UI 2'OnD :11000 .'WOOO lunll~ TVO ND AaIlDl8UDII 1718..52 .ON'.7. TIP 1712.70 '0110-00 tCOP 1710.01 '0'8000 , 1',1.21 no,o 00 2 IMo.l. ttUJ.8S 1 "17.'1 ItIU I' . 180'.32 , US'I.I 5 11'12.'1' . 171'1 II . II" .1 . '&4'7.8' 7 .170.21 '1817 5' . I.....,. n'O'l.8, . "17.17 '132'1.1' '0 ..11 n nlOD 00 TO ~: ~~;;':~~;7--" . -I, 0' "." I S'" ~ .-~. ..r.,.., ".0'" . '.'" ¡.. .. ,..'" .0-" III :.-., I ..~.. ,,, . .., J".J:", 0 "'''''':00' -- - -- -- -- --- --- -------- - - -----.--- - -- ------- 8_\~,O ------- ---- --- -- ---- - -- -- - --- -- 840Ll 84 ~.(J _8~.(l0 C ~8')~1I &I) RWO -- .c ;, 8t;:.O GJ Q 8700 .5.,no-~__- - ------- --. ---- , " 2700 .,800 2900 30(10 31011 -don 33UO J4t"IU ~\:IO(l :\6(11) :1700 :\800 ~\9ÒO 40UO 41(10 42011 43'00 44'00 4500 4600 470il 4800 4000 ~.ooo 5100 :.20U 5:~00 West(-)/East(+) [100ft/in] ----- - --- ---,-- - --- -- - - - - - --------- - ~--~~'...- l!:---'.':.~- ,-" :' i' 43:,(] 4401l 44:~1 4~.(1I) 4~:.0 4t~I.I(1 46:,0 47UI.I 47:.0 4800 4W,U 49011 49:.0 :,1100 5U~,U ~.HIn ~.150 5"01) 5i511 ~.3(iI) ~13:.0 5400 ~0450 :,:.00 ~Ó~I(J 56uO ~6')ll 5700 ~,7~U :":'011 ~18:.0 59011 :.9~0 woo 6050 61(111 b15u t;.,I)(i 6"~.r Vertical Section at 160.00° [50ft/in] ~ ~ 'ii U 875U :e GJ /:JUOO > GJ 13f\~u 2 ... 8~~lILJ ~ OKI /~I '. J::i:: ',.,_.:lIi --- ' - . _no' : ---Œ:l ':if'! --'~ .. }""ill '\-- ~ - , ' . ___-=C1 "..."/---- ,,,..,.., --- .. ---- ~---~-- , - - - ---- - o~. - - - -I I I ;:II ~ ~-- i I ----r- M~ ~œ ~ ~ ~~ [ ~'...!.u¡::-__'~~}I ------ Az,rrlulr'5 II) TruE' Nonh Magneloc Nonrl .,6.'U'- MagnE'lil: Field' SIIE.nglh: 57482nT Dip Arrgle' 80 74" Dale 1/11/2002 M.:.dE'1. BC(,M¿(J(J 1 F'IJrl ~1.:Jr¡ I:t.4 IP 1fii:'I..)r~ F' H:A1 ..: 1>:0 JI":o,::J Etv 80"1 F\.rr.... [1";11..' 1/11/'llll~' 1:_1 '(110.1'-1 IrIIL¡r.'I,)TII¡rl [Jllt-Lt 1':,;-.J7j.'f...11 tA,1_~ E r¡¡.JII t,nt [1II-I\rII,...'I'lIlr""r" I ,illl £: ,~~I tlr_'"tl-o HJTf') (':'-(17. .r,;' ;:t-,I II I -- - ------ --- ----- - - ----- , -- - - -- ---;--- - -- - -- - - ---- - ¡ - ------- ------ -----~---- -- - ---- -- -- --- c - ----- -- -- ---- ------ - ------ -- --.....--- ----- - ---- I-- I . - - ----- --- I -- -: /~-~- --~~--- :~ F' I:~::-_- -~- --~ - - ""\.;:-----:-- :'F:-;;~f:-'-;:~ - -I ~~ 'I F' "'A l' -'1 o~: " ---~J~-1-12002 10:-53 AM ~~), b ~", P BP Amoco Baker Hughes INTEQ Planning Report llii. BAK.. IUGIIIS ..".- -. -.. _0. -~.__.~. . . N n~!.Q BP Amoco Prudhoe Bay PB P Pad P-18 Plan#4 P-18A Prudhoe Bay North Slope UNITED STATES i\lap S~'!item:US Slate Plane Coordinate System 1927 Ceo Datum: NAD27 (Clarke 1866) S~'i Datum: Mean Sea Level Com pan~ : Field: Site: Well : \\'ellpath: I Field: I Site: I PB P Pad TR-11-13 UNITED STATES: North Slope Site PO!iition: Northing: From: Map Ea!iting: PO'iition lincertaint~': 0.00 ft Ground Lc\'el: 0.00 ft 5949377.17 ft 623154.06 ft :-.\\ ell: P-18 P.18 \\ ell Po~ition: +N/-S -2434.07 ft ~orthing: 5947077.29 ft +£1-\\ 8169.82 ft Ea'iting: 631361.94 ft PO'iition llncertaint~: 0.00 ft ---- -- ---- \\ ('IIpath: Plan#4 P-18A 500292209701 Curn'nt Datum: 26: 1810/30/199000:00 I\lagnetic Data: 1111/2002 Fi('ld Strength: 57482 nT Vertical Section: Depth From (T\ D) ft ------ 0.00 Height 91.85 ft +~/-S ft 0.00 1- IIPlan: ~:~t:1 to Lamar's Plan #3 - 200' cut from TD Principal: Yes I Targeh Date: 1/11/2002 Time: 10:53:38 Co-ordinate(NE) Reference: Well: P-18. True North \'erUcal (TVD) Referenc(': System: Mean Sea Level Section (\'S) Reference: Well (0.00N,0.00E.160.00Azi) Suney Calculation Method: Minimum Curvature Db: Page: Oracle I\lap Zone: Coordinate S~'item: Geomagnetic !\Iodel: Alaska, Zone 4 Well Centre BGGM2001 Latitude: Longitud~': North Reference: Grid Com ergence: 70 16 12.612 N 149 0 14.402 W True 0.94 deg Slot Name: 18 Latitud(': Longitude: 70 15 48.630 N 148 56 16.650 W --- Drillt'd From: Tie-on Dcpth: .-\boH' S~ 'item Datum: Declination: I\lag J)jp Angle: + E/- \\ ft 0.00 P-18 10950.00 ft Mean Sea Level 26.27 deg 80.74 deg Direction deg 160.00 Date Compo'ied: \ ersion: Tied-to: 1/11/2002 1 From: Definitive Path -- I\lap !\lap <--- Latitude ---> <-- Longitude ---> Name Description T\'D +N/-S +E/-W Northing Easting Deg I\lIn See Deg l\lin Sec ft ft ft ft ft "--- P-18A T3.1 8940.00 -3751.11 3669.50 5943391.07 635096.02 70 15 11.729 N 148 54 29.916 W P-18A T3.2 8867.00 -4062.93 4046.81 5943085.90 635478.68 70 15 8.660 N 148 54 18.946 W P-18A T3.3 8955.00 -4952.81 3896.18 5942193.60 635343.62 70 14 59.909 N 148 54 23.340 W P-18A Polygon3.1 0.00 -3655.73 3383.89 5943481.45 634808.82 70 15 12.668 N 148 54 38.222 W -Polygon 1 0.00 -3655.73 3383.89 5943481.45 634808.82 70 15 12.668 N 148 54 38.222 W -Polygon 2 0.00 -4171.79 3905.12 5942974.60 635338.93 70 15 7.590 N 148 54 23.069 W I -Polygon 3 0.00 -4976.02 3843.82 5942169.49 635291.68 70 14 59.681 N 148 54 24.864 W -Polygon 4 0.00 -5097.06 3976.00 5942050.78 635425.94 70 14 58.490 N 148 54 21.021 W -Polygon 5 0.00 -3984.04 4120.03 5943166.06 635550.52 70 15 9.436 N 148 54 16.815 W -Polygon 6 0.00 -3533.59 3703.83 5943609.14 635126.55 70 15 13.868 N 148 54 28.914 W I I -Polygon 7 0.00 -3521.62 3378 94 5943615 44 634801 53 70 15 13.987 N 148 54 38.364 W I ..\nnotation - I I'ID r\"D ft ft I ! 10941 74 8776.52 TIP 1 10950.00 8782.70 KOP , 10960.00 8790.08 1 : 11010 00 8823.25 2 11134385 8940.61 3 , 11382 98 8937.55 4 I 11557.98 8909.32 5 , 11787 98 8872.79 6 - I Company: Field: Site: Well : Wellparh: .\nnorarion MD ft 11847.51 11887.51 1210751 12327.51 1250000 C~) :,' ,,','1 bp BP Amoco Prudhoe Bay PB P Pad P-18 Plan#4 P-18A T\'D ft 8868.16 8870.25 8894.14 8917.37 8935.17 7 8 9 10 TD Plan Section Informarion ~ID ft 10941.74 10950.00 10960.00 11010.00 11343.85 11382.98 11557.98 11787.98 11847.51 11887.51 12107.51 12327.51 1~2500.00 Incl deg 41.63 41.57 43.31 53.52 90.00 99.00 98.79 98.93 90.00 84.00 83.88 84.33 84.03 Azim deg 173.62 173.70 172.24 165.12 91.64 91.64 132.40 167.33 167.33 167.33 200.52 167.34 193.35 BP Amoco Baker Hughes INTEQ Planning Report T\'D ft 8776.52 8782.70 8790.08 8823.25 8940.61 8937.55 8909.32 8872.79 8868.16 8870.25 8894.14 8917.37 8935.17 Sun e) I--~D h- I~~g ---~\~:g SS~t\'D 10941.74 41.63 173.62 8776.52 10950.00 41.57 173.70 8782.70 10960.00 43.31 172.24 8790.08 10975.00 46.32 169.86 8800.72 11000.00 51.44 166.37 8817.16 +N/-S ft -3576.48 -3581.93 -3588.63 -3625.17 -3784.20 -3785.32 -3848.73 -4042.08 -4099.92 -4138.88 -4354.02 -4569.24 -4739.34 N/S ft -3576.48 -3581.93 -3588.63 -3599.07 -3617 .49 Bíl8 BAK" HUGIIIS .-. ~ -. ... ---- .-. -... - IN." H',} Date: 1/11/2002 Time: 10:53:38 Co-ordinate(NE) Reference: Well: P-18, True North Vertical (TVD) Reference: System: Mean Sea Level Section (\'S) Reference: Well (0.00N.0.00E,160.00Azi) Sun'e~' Calculation !\Iethod: Minimum Curvature Db: Oracle +E/-\\! ft 3412.94 3413.55 3414.38 3421.88 3659.94 3698.90 3855.64 3967.90 3980.91 3989.66 3974.91 3960.15 3959.14 E/W ft 3412.94 3413.55 3414.38 3416.03 3419.92 DLS Build Turn deg/100ft deg/100ft deg/100ft 0.00 0.00 0.00 0.97 -0.73 0.97 20.00 17.41 -14.58 23.00 20.41 -14.24 23.00 10.93 -22.01 23.00 23.00 0.00 23.00 -0.12 23.29 15.00 0.06 15.19 15.00 -15.00 0.00 15.00 -15.00 0.00 15.00 -0.05 15.09 15.00 0.20 -15.08 15.00 -0.17 15.08 TFO deg 0.00 138.51 330.00 330.00 280.00 0.00 87.00 87.00 180.00 180.00 92.00 269.00 91.99 Target Page: 2 ------- l\IapN ft 5943561.18 5943555.74 5943549.06 5943538.65 5943520.31 !\JapE ft 634836.48 634837.18 634838.12 634839.96 634844.17 DLS deg/100ft 0.00 0.97 20.00 23.00 23.00 \'S ft 4528.09 4533.42 4540.00 4550.37 4569.01 TFO deg 0.00 TIP 138.51 KOP 330.00 1 330.00 MWD 331.69 MWD Tool 11010.00 53.52 165.12 8823.25 -3625.17 3421.88 5943512.66 634846.26 23.00 4576.90 333.992 11025.00 54.19 160.93 8832.10 -3636.75 3425.41 5943501.14 634850.00 23.00 4588.99 280.00 MWD 11050.00 55.62 154.12 8846.48 -3655.63 3433.24 5943482.40 634858.15 23.00 4609.41 282.47 MWD 11075.00 57.42 147.57 8860.28 -3673.82 3443.40 5943464.40 634868.62 23.00 4629.97 286.39 MWD 11087.66 58.46 144.36 8867.00 -3682.71 3449.40 5943455.62 634874.78 23.00 4640.38 290.01 P-18A 11100.00 59.55 141.30 8873.36 -3691.14 3455.79 5943447.30 634881.32 23.00 4650.48 291.71 MWD 11125.00 61.96 135.32 8885.58 -3707.40 3470.30 5943431.29 634896.10 23.00 4670.73 293.29 MWD 11150.00 64.61 129.61 8896.83 -3722.46 3486.77 5943416.53 634912.83 23.00 4690.51 296.21 MWD 1117500 67.48 124.15 8906.98 -3736.15 3505.04 5943403.15 634931.34 23.00 4709.63 298.78 MWD 11200.00 70.52 118.93 8915.94 -3748.35 3524.93 5943391.31 634951.43 23.00 4727.89 301.00 MWD 11225.00 73.71 11250.00 77 .02 11275.00 80.41 11300.00 83.86 11325.00 87.35 11343.85 90.00 11350.00 91.41 11375.00 97.16 11382.98 99.00 11400.00 99 18 113.90 8923.62 -3758.92 3546.23 5943381.12 634972.92 23.00 4745.11 30287 MWD 109.03 8929.94 -3767.76 3568.73 5943372.67 634995.57 23.00 4761.11 304.42 MWD 104.30 8934.84 -377478 3592.21 5943366.06 635019.16 23.00 4775.74 305.65 MWD 99.65 8938.26 -3779.91 3616.43 5943361.35 635043.46 23.00 4788.84 306.58 MWD 95.07 8940.18 -3783.10 3641.14 5943358.59 635068.22 23.00 4800.29 307.21 MWD 91.64 894061 -3784.20 3659.94 5943357.82 635087.05 23.00 4807.76 307.57 3 91 64 8940.54 -3784.38 3666.09 594335775 635093.20 23.00 4810.03 360.00 MWD 91.64 8938.67 -3785.09 3691.00 5943357.47 635118.11 23.00 4819.22 360.00 MWD 91.64 8937.55 -378532 3698.90 5943357.38 635126.01 23.00 4822.13 0.00 4 95.60 8934.86 -3786.38 371567 5943356.62 635142.79 23.00 4828.86 8700 MWD 1142500 99.37 101.42 8930.82 -3790.03 374006 5943353.39 63516724 2300 4840.64 11450.00 99.47 10725 8926.73 -3796.13 3763.94 594334771 635191.23 2300 4854.54 11475.00 99.47 11308 8922.61 -3804.63 378708 5943339.62 63521451 2300 487044 11500.00 99.37 118.91 891851 -381543 3809.24 594332920 635236.85 2300 488817 11525.00 99 18 124.73 8914.48 -382843 3830 19 5943316.57 63525803 23.00 4907.55 87.63 MWD 88.57 MWD 89 52 MWD 90 48 MWD 9144 MWD ObP BP Amoco Baker Hughes INTEQ Planning Report I Company: Field: Site: Well : \\ ellparh: BP Amoco Prudhoe Bay PB P Pad P-18 Plan#4 P-18A Dare: 1/11/2002 Time: 10:53:38 Co-ordinate(NE) Reference: Well: P-18, True North Vertical (TV D) Reference: System: Mean Sea Level Section (YS) Reference: Well (0.00N,O.00E.160.00Azi) Sun'e)' Calculation Method: Minimum Curvature Db: Oracle Sun'e) 1\10 ft 11550.00 11557.98 11575.00 11600.00 11625.00 SST\'D ft l\1apN ft 5943301.84 5943296.72 5943285.32 5943267.60 5943248.79 DLS deg/100ft 23.00 23.00 15.00 15.00 15.00 VS ft 4928.40 4935.33 4950.40 4973.10 4996.39 Incl deg 98.90 98.79 98.91 99.06 99.18 Azim deg 130.54 132.40 134.98 138.77 142.57 N/S ft I\lapE ft 635277 .83 635283.82 635296.18 635313.37 635329.34 E/W ft 3849.73 3855.64 3867.80 3884.68 3900.32 8910.55 -3843.50 8909.32 -3848.73 8906.70 -3860.34 8902.79 -3878.36 8898.83 -3897.45 11650.00 99.25 146.37 8894.82 -3917.53 3914.66 5943228.97 635344.03 15.00 5020.16 11675.00 99.28 150.17 8890.80 -3938.51 3927.63 5943208.22 635357.36 15.00 5044.32 11700.00 99.27 153.97 8886.77 -3960.30 3939.19 5943186.63 635369.30 15.00 5068.75 11725.00 99.23 157.77 8882.75 -3982.82 3949.27 5943164.30 635379.77 15.00 5093.36 11750.00 99.14 161.56 8878.76 -4005.96 3957.85 5943141.31 635388.75 15.00 5118.03 Biì8 BAKU IUGfIIS .-- -"' -..,.. .------. fN'I'EQ Page: 3 TFO deg 92.38 MWD 93.29 5 87.00 MWD 87.40 MWD 87.99 MWD Tool 88.59 MWD 89.20 MWD 89.81 MWD 90.43 MWD 91.04 MWD 11775.00 99.01 165.36 8874.81 -4029.62 3964.87 5943117.78 635396.19 15.00 5142.67 91.64 MWD 11787.98 98.93 167.33 8872.79 -404208 3967.90 5943105.38 635399.43 15.00 5155.41 92.24 6 11800.00 97.13 167.33 8871.11 -4053.69 3970.51 5943093.82 635402.24 15.00 5167.21 180.00 MWD 11825.00 93.38 167.33 8868.82 -4077.97 3975.97 5943069.63 635408.13 15.00 5191.90 180.00 MWD 11847.51 90.00 167.33 8868.16 -4099.92 3980.91 5943047.77 635413.44 15.00 5214.22 180.00 7 11850.00 89.63 167.33 8868.17 -4102.35 3981.45 5943045.35 635414.03 15.00 5216.69 180.00 MWD 11875.00 85.88 167.33 8869.15 -4126.72 3986.93 5943021.09 635419.93 15.00 5241.46 180.00 MWD 11887.51 84.00 167.33 8870.25 -4138.88 3989.66 5943008.98 635422.88 15.00 5253.82 180.00 8 11900.00 83.94 169.21 8871.56 -4151.04 3992.19 5942996.87 635425.61 15.00 5266.11 92.00 MWD 11925.00 83.83 172.98 8874.23 -4175.59 3996.04 5942972.39 635429.89 15.00 5290.50 91.80 MWD 11950.00 83.75 176.75 8876.93 -4200.34 3998.26 5942947.68 635432.54 15.00 5314.51 11975.00 83.70 180.53 8879.66 -4225.18 3998.85 5942922.86635433.57 15.00 5338.06 12000.00 83.68 184.30 8882.41 -4250.00 3997.80 5942898.02 635432.95 15.00 5361.02 12025.00 83.68 188.07 8885.16 -4274.70 3995.13 5942873.28 635430.71 15.00 5383.32 12050.00 83.71 191.84 8887.91 -4299.17 3990.83 5942848.75 635426.84 15.00 5404.84 91.40 MWD 90.99 MWD 90.58 MWD 90.17 MWD 89.75 MWD 12075.00 83.77 195.62 8890.64 -4323.31 3984.93 5942824.51 635421.37 15.00 5425.51 89.34 MWD 12100.00 83.85 199.39 8893.33 -4347.00 3977.46 5942800.69 635414.31 15.00 5445.22 88.92 MWD 12107.51 83.88 200.52 8894.14 -4354.02 3974.91 5942793.63 635411.88 15.00 5450.94 88.529 12125.00 83.84 197.88 8896.01 -4370.44 3969.20 5942777.11 635406.45 15.00 5464.42 269.00 MWD 12150.00 83.81 194.11 8898.69 -4394.33 3962.35 5942753.11 635400.02 15.00 5484.52 269.28 MWD 12175.00 83.80 190.34 8901.39 -4418.62 3957.09 5942728.73 635395.19 15.00 5505.55 269.69 MWD 12200.00 83.82 186.57 8904.09 -4443.20 3953.43 5942704.10 635391.96 15.00 5527.39 270.10 MWD 12225.00 83.87 182.79 8906.77 -4467.97 3951.41 5942679.30 635390.37 15.00 5549.98 270.50 MWD 12250.00 83.94 179.02 8909.43 -4492.82 3951.01 5942654.45 635390.41 15.00 5573.19 270.91 MWD 12275.00 84.04 175.25 8912.04 -4517.64 3952.25 5942629.65 635392.08 15.00 5596.95 271.31 MWD 12300.00 84.16 171.49 8914.62 -4542.34 3955.12 5942605.01 635395.38 15.00 5621.14 271.70 MWD 12325.00 84.31 167.72 8917.13 -4566.80 3959.61 5942580.63 635400.30 15.00 564566 272.09 MWD 12327.51 84.33 167.34 8917.37 -4569.24 3960.15 5942578.20 635400.88 15.00 5648.13 272.4710 12350.00 84.22 170.73 8919.62 -4591.21 3964.41 5942556.31 635405.52 15.00 5670.23 9199 MWD 12375.00 8413 174.50 8922.16 -4615.87 3967.60 5942531.72 635409.14 15.00 5694.50 91.65 MWD 1240000 84.05 178.27 8924.73 -4640.68 3969.17 5942506.94635411.14 15.00 5718.35 12425.00 84.01 182.04 8927.33 -4665.54 3969.11 5942482.08 635411.51 15.00 5741.69 12450.00 83.99 185.81 8929.95 -4690.34 3967.40 5942457.26 635410.24 15.00 576441 12475.00 84.00 189.58 8932.56 -4714.97 3964.08 5942432.57 635407.35 1500 5786.42 12500.00 84.03 193 35 8935.17 -4739.34 3959.14 5942408.13 635402.83 15 00 5807.62 91.27 MWD 90.88 MWD 90.49 MWD 90.10 MWD I 89 70 TD_--.1 TRANSI\lIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BEINCLUDEDINTRANSNDTTALLETTER WELL NAME iJg¿{' (21i' L ! CHECK] ST ANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL ¿/' EXPLORATION INJECTION WELL INJECTION WELL REDRILL CHECK 'VIlA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) v/ PILOT HOLE (PH) ANNUL~~P'OSAL NO ANNULAR DISPOSAL L-> YES ANNULAR DISPOSAL THIS WELL "CLUE" h'l$-':,ermit ~s for a new wellbore segment of,e.istinJ; weD $tC t:=. Permit No, J?O-lc;rAPI No. Sl)-02-7'- Z2¿'9 7-4.) Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for tbe pilot bole 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). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS L-> YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the apprm'ed application for permit to drill tbe above referenced well. The permit is approved . subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume tbe liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY /t),q~ - WELL NAME It/ß¿¡ f'/8'LI FIELD & POOL c;,VÙ/G) INITCLASS ~Ev li)/L- ADMINISTRATION 1. Permit fee attached. . . . , . . . . . . . . . . . . , , . . . . 2. Lease number appropriate. r. , , , . . , , . . , . , . . . . 3. Unique well name and number. .. . . . . . . . . , . , . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . 7, Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . 11. Permit can be issued without conservation order. . , . . . . . AP~ DATI; '}~' Permit can be issued without administrative approval. . N lJ) 2- þ( D £.....-13. Can permit be approved before 15-day wait.. . . . . . N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . -Y N I'-'/^ . / . 15. Surface casing protects all known USDWs. . . , . . . . . . . .A.lo1l.....;-w- ~Æ c../- '// ..,L)G-/ S'h ~S I<-H../ / 16. CMT vol adequate to circulate on conductor & surf csg. Y--N- ,.J /A C--- 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ¥--N- . 18. CMT will cover all known productive horizons. . . . . . . . . . -¥-.-N- slolkd {¡V\i?~/. 19. Casing designs adequate for C, T, B & permafrost. . . . . . . k N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . ,;,' N 21. If a re-drill, has a 10-403 for abandonment been approved. . . cy' N I"\-f p. II{ 3¡)i () l . 22. Adequate well bore separation proposed.. . . . . . . . . . . . ¥-N- ""fA 23. If diverter required, does it meet regulations. . . . . . . . . . ¥-N- '" IA 24. Drilling fluid program schematic & equip list adequate. . . . . 6¿-' N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . G:?' N 26. BOPE press rating appropriate; test to 36 ClC' psig. ~ N N{Æ.t; P :- ¿ ZC¡ 'i ¡J 5.,<.', 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . ~ N 28. Work will occur without operation shutdown. . . . . . . . . . . . N - , . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . N )¿¿ Ju ¿'¡L~ 30, Permit can be issuedw/o hydrogen sulfide measures, , , , , y~, P /~ /1,f'r!J.-ð~ .30 ~L ¿5 31. Data presented on potential overpressure zones. . . . . . . Y. f'J/ A#'t.lr.c. '- >~ 4.::1 -e ~ vo,' y I~ ~ 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . y.--1\j r .. AP..eR DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . A Y N ./rT) -¡". Z-I .~, 34. Contact name/phone for weekly progress reports [exploratOjÝÓnlyj Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RPC TEM 49- '1ft) ~j COT CC~, ~ SFD.A--' WGA DTSO¥¿2/ C '2- JMH ~ ~fTE Mj.:.' "I I.;)'d GEOLOGY APPR DATE PROGRAM: Exp - Dev - Redrll /serv - Wellbore seg --.L'Ann. disposal para req - GEOLAREA ffl() UNIT# D/I~Ç() ON/OFF SHORE Dr} Y N) ~~ VI5I,]t.rx æ-r1h ,,Iv - ~i::?u.d - /7(.) fe.~ J-ëfi¡/'J~"'¡' - ,_r~p¿rL~ if< -:)~1~ ~~. þÞ7-0. i."¿ .~L CY2~?:2~, g~' '7C' /./ ~, v~ v.~ N 0 -40<-W -r: b t.-k. /II:> '- C' 2. g- 2-.,0;("7 -< ~ ~) I (J N N 3=' I - Z3.S o/y0> , , 7, ¿ rtJ1) Eørw .~~ Y N Y N !'i-I"} [uLn£.,.t. &t,/ ¿A S f (.) Ç..(.:...( ýo ~6 ~Lt:~' s fed. Com mentsllnstructions: G :\geology\permits\checklist. doc Well History File APPENDIX Infonnation of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. 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