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Home My WebLink About198-012Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: [(~,/~ F/~ Poor Quality Original- Pages: D Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of vadous kinds [] Other COMMENTS: Scanned by~ Mildred Daretha Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is~ STATE OF ALASKA ALASKA ~,~~ AND GAS CONSERVATION COMMISSI(. WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil ^ Gas ^ SPLUG ^ Other ^ Abandoned 0 Suspended ^ zonaczaioe zonacz5.iio GINJ ^ WINJ ^ WAG ^ WDSPL ^ No. of Completions: _ N/A P & A Work Only 1 b. Well Class: P & A'd to sidetrack Development ~ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: SAVANT ALASKA LLC 5. Date Abandoned: February 17, 2010 12. Permit to Drill Number: 198-012 3. Address: P.O. Box 112212, Anchora e, Alaska 99511-2212 6. Date Spudded: March 6, 1998 13. API Number: 50-02922857 4a. Location of Well (Governmental Section): Surface: 3856' FSL & 86' FEL, Sec. 8, T9N, R20E UM 7. Date TD Reached: March 27, 1998 14. Well Name and Number: B1-18 Top of Productive Horizon: nj/A 8. KB (ft above MSL): 54.4 GL (ft above MSL): 19.5 15. Field/Pool(s): Total Depth: 5179' NSL & 420' EWL, Sec. 9, T9N, R20E, UM 9. plug Back Depth(MD+ND>: 8,398' MD 8,130' TVD Badami Field ~ Badami Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 363925.67 Y- 5906425.04 zone- 3 10. Total Depth (MD + ND): 10724' MD 10,423' ND 16. Property Designation: ADL 365533 TPI: x- N/A y- N/A Zone- N!A Total Depth: x- 364455.13 Y- 5907738.55 Zone- 3 11. SSSV Depth (MD + ND): N/A . 17. Land Use Permit: N/A 18. Directional Survey: Yes 0 No Q (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: nj/A (ft MSL) 20. Thickness of Permafrost MDfTVD: 1 886' MD 1 882' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): None 22.Re-drill/Lateral Top Window MD/ND: N/A 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT FT in LBS TOP BOTTOM TOP BOTTOM PULLED 20" 91.1 H-40 36' 116' 36' 116' 24" - 260 sxs Arctic Set 0 95/" 40 L-80 34' 4,550' 34' 4,545' 12%" a,2os sxs PF°E" + Sao sxs G 0 7" 29 USS95 38' 8,855' 38' 8,575' 8%Z" 200 sxs Class "G" 0 4%:" 12.6 L-80 8,687' 10,724' 8443' 10,423' 6" 273 sxs Class "G" 0 24. Open to production or injection? Yes ^ No ~ If Yes, list each 25. TUBING RECORD interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/ND) All plugged 4YZ' 12.6#, L-80 8623' 573' MD 8301' TV `, R~4l~~ d E~ 4%", 12.6#, L-80 U er Stub 8548' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.. JUN X d 2~1~ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Oit Ft Gaz ~~• Cammissori k A1 a 8S e ra t A g ~e nc 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24-Hour Rate ~- Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity -API (corn): 28. CORE DATA Conventional Core(s) Acquired? Yes ^ No ~ Sidewall Cores Acquired? Yes ^ No If Yes to either question, list formations and intervals cored (MD+ND of top and Lwttom of each), and summarize lithology and presence. of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. is ;~1-j'yE'^~1''~ J 4J! ~ .~ ~! L~~ Form 10-407 Revised 12/2009 ONTINUED ON REVERSE ~ Submit original only RBDAAS 1UN 10 ~ ~ ~ lS- /v 29. GEOLOGIC MARKERS {List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ^ Yes ~ No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Top 43' 43' needed, and submit detailed test information per 20 AAC 25.071. Permafrost -Base 1,886' 1,882' No formations tests were run! The previous production interval was plugged and abandoned. Top Badami K3 Sand 10,094' 9,795' Following that P & A, the well was prepared for Top Badami F5 Sand 10,280' g,ggp~ milling a window in the 7" casing and for drilling a new high-angle (~ 85°) lateral to a distinctly Bottom Badami F5 Sand 10,425' 10,125' different BHL. Formation at total depth: Bottom Badami F5 Sand 10,425' 10,125' 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Erik Opstad 907-244-5210 Printed Name: Eflk A. O stad Title: General Mana er Signature: Phone: 907-868-1258 Ext. 101 ~ Date: 6/10/2010 ~~~ 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 b: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 RECEIVE APR ~. ~ 2010 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSIO, REPORT OF SUNDRY WELL OPERATIONS ~ Repair Well ^ Plug Perforations ~ Stimulate ^ Other ~ Plug off perfS & Performed: !A~Iter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver ^ Time Extension^ prepare well for Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well^ horizonal sidetrack 2. Operator Savant Alaska LLC 4. Well Class Before Work: 5. Permit to Drill Numb„er: Name: Development Q Exploratory ^ T'g$_Q12 , 3. Address: P.O. BOx 112212, Anchorage, AK Stratigraphic^ Service ^ 6. API Number. 99511-2212 50-02922857 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 365533 Badami B1-18 9. Field/Pool(s): Badami Field -Badami Oil Pool 10. Present Well Condition Summary: Total Depth measured 10,724 feet Plugs (measured) $ 400 feet true vertical 10,443 feet Junk (measured) None feet Effective Depth measured $ 398 feet Packer(measured) #2 at $,398 feet #1 at 8,530 fee true vertical $,131 feet (true vertical) $,131 feet g 258 fee Casing Length Size MD TVD Burst Collapse Structural Conductor gp' 20" 116' 116' 1,520 psi 520 psi Surface 4,516' 13-3/8" 4,551' 4,491' 5,750 psi 3,090 psi Intermediate 8,822, 7" 8,855' 8,575' 8,160 psi 7,020 psi Production Liner Perforation depth: Measured depth: 10,396' - 10.416' MD (Plugged) ~~°°~~-- ~~ V True Vertical depth: 10.095' - 10,115' TVD (Plugged Tubing (size, grade, measured and true vertical depth): N/A Tubing Pulled Ki y" vim[/,' A .. ~ ~i_ 1~ rti l d th d SSSV d d t P k t ~ rue ve ep ( ype, measure an ca ers an ac ): N/A Tubing Pulled 11. Cement squeeze summary: Attempted to squeeze wellbore below EZSV packer @ 8530' MD .Pressured-up to 4,000 psi, but perforations already Intervals treated (measured): plugged with LCM would not break-down. Placed 70' cement plug atop packer. TOC @ 8,400' MD. R/H and set EZSV #2 @ 8,398' MD as a base for the oriented whipstock. Top of whipstock -- 8,380' MD Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut-In Shut-In Shut-In 0 0 Subsequent to operation: P & A P & A P & A 0 No tubin in well 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development(] Service ^ Daily Report of Well Operations IADC Tour Reports 15. Well Status after work: Oil Q Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ^ WINJ^ SPLUG^ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-366 contact Erik Opstad or Gary Hammon (W) 907-868-1258 Printed Name Erik A. O stad Title General Manager Signature Phone 907-244-5210 Date 5-Apr-10 ~ RSDMS APR 1 ~ 1010 =~'~'1 ~ ~/Y Form 10-404 Revised 7/2009 i %~ Submit Original Only • Kelly bushing to wellhead (ft) 54.4 P & A Configuration Prior to Cuttin Window & Sidetrack to 61-18A Lateral Oa inch tta inch Weight LbsNt Langih ft fi~1D rhtr XvD : rs 10.840 2.950 Conductor 20.000 19.124 91.5 80 115.3 60.5 13-3/8" 68# L-80 BTC 10.750 12.415 68 4516 4551.3 4490.8 Baker Hughes "G2" Whipstock -Top of Whipstock @ 8380.38' MD 7.000 8326 8380.38 8040.6 ~ EZSV 48" 8344 8398 8057.9 Top of Cement Plug ~ 8346 8400 8059.9 EZSV 48" 8476 8530 8186.3 4-1 /2" Tubing Stub 8510 8564 8219 7" x 4-1/2" HES TNT PKR 7.000 3.875 8822 8855 8555.5 4-1 /2" X NIP 3.813 8536 8590 8263 4-1/2" XN NIP 3.725 8557 8611 8283 4-1 /2" W LEG 3.958 8569 8623 8294.7 7" x 4-1/2" Liner Hanger/Pkr. 4.375 8653 8707 8376.3 7" 29# P-110 BTC 7.000 6.184 29 8822 8855 8520.7 Top Perforations 10342 10396 10141 Bottom Perforations 10362 10416 10081 PBTD 10586 10640 10320 4-1/2" 12.6# L-80 BTC MOD Liner 4.500 3.958 12.6 10670 10724 10424 No. Rev. by Comments/Date 1 G. Vigil Plugged and Abandoned on February 18, 2010 prior to B1-18A sidetrack 2 E. Opstad Add Top of Whipstock MD & Comments 3 E. Opstad Add TVDss Badami Unit API No. 50-029-228577-00 Loc: Section 8, TWN: 9N RNG: 20E 1424' FNL & 86' FEL -rT ALASKA TF2EE _ ~ 4-1/16" / 5000 PSI / CIW WELLHEAD= 13-5/8" / 10000 PSI /FMC ACTUATOR = KB. ELEV = 54.4' BF. H.EV = 19.5' KOP = _ Max Angle = 30 @ 6754' Datum MD = Datum ND = ~ ~ (~ 13-3l8" CSG, 68#, L-80 BTC, ID =12.415" Minimum ID = 3.725" @ 8611' 4-1/2" XN NIPPLE 61-18 • 7" X 4-112" HES TNT PKR, ~ = 3.875" 4-112" X Nom, ~ = 3.813" 4-1/2" TBG, 12.6#, L-80 ~T MOD, .0152 bpf, ID = 3.958" 7" LNR, 29#, P110 BTC, ID = 6.184" PERFORATION SUMMARY REF LOG: MWD ON 03!27/98 A NGLE AT TOP PERF: 4 @ 10396' Note: Refer to Production DB for historical pert data SIZE SPF IM732VAL (MD) Opn/Sqz DATE 10396 - 10416 FRACD 04/17/98 PBTD 4-1/2" LNR, 12.6#, L-SO BTC MOD .0152 bpf, ID = 3.958" ..~ I--iBPV (02/04/08) I 2219' 4-1l2" HES HXO SSSV NIP, ~ = 3.813" GAS LfFf M ANDRELS 3T MD ND DEV TYPE VLV LATCH POF 6 3022 2963 0 KBG2LS 5 4042 3983 0 KBG2LS 4 5676 5614 9 KBG-2LS 3 7466 7218 29 KBG-2LS 2 8312 7994 14 KBG2LS 1 8505 8180 14 KBG2LS 8611 -i4-1/2" XN NIP, ID = 3.725" 8611' 4-1/2" XXN PLUG (02!02!08) 8623' 4-1/2" WLEG, ID = 3.958" L~ ELMD TT NOT LOGGED 8707' 7" X 4-112" LNR HNGR PKR, ID = 4.375" DATE REV BY COMMENTS DATE REV BY COMMENTS ???? OWGINAL COMPLETION 03/30/99 JTP UPDATE WFORMATgN 08/30/06 WRR(T1.H FORMATCOFtFtECTIONS 09/03/07 SWGPJC SET XXN PLUG & BPV 02/09/08 RCTlPJC SET BPV & XXN PLUG (02/02/08) 02/09/08 PJC LOCATION CORRECTION BADAMI WELL: B1-18 PERMfT No: 1980120 API No: 50-029-22857-00 SEC 8, T9N, R20E, 1424' FNL & 86' FEL BP 6cploration (Alaska) • No. 393063156125 DAILY DRILLING REPORT REPORT N0. 1 • No. 393063156126 DAILY DRILLING REPORT REPORT NO. 2 • No. 393063156127 DAILY DRILLING REPORT REPORT N0. 3 • No. 393063158128 DAILY DRILLING REPORT REPORT N0. 4 No. 393063156129 DAILY DRILLING REPORT REPORT N0. 5 f 1 ~J No. 393663156130 DAILY DRILLING REPORT REPORT N0. fi ~I 11 LJ No. 393fifi3158137 DAILY DRILLING REPORT REPORT N0. 7 • No. 393063158132 DAILY DRILLING REPORT REPORT N0. 8 l No. 393963158133 DAILY DRILLING REPORT REPORT N0. 9 N0.393063158134 Ron HQ"' OPEaAnON RIG uPAxD DDWN ALTUN. s REAMING ' BL"RL~~TN cATERIc 8 REPPIP RIG s CNTOFF wulrWGre LvwTloN SUevEv EuxELacs scEw7Ex~ c+r CEMENT PPLEWB.OP IDIwusTan TEST 11 PI.UGRACN IDaOllEEIECEMDdI rsfwllNc A OIR WORN 21 BPoNO BHAiO ~~ CHECK MWDM Ta PJSI4 PN WXI RAZING ~~~ B NSINO TRIRS swPeeNNc EDTWG DAILY DRILLING REPORT REPORT N0. 10 WELL NO. (WELL NUMBER wArERm 61.1SA 50-029.22857-01.00 CONTRACTOR LLC Doyon Drilling Inc 1R'S REPRESENTATIVE SIGNATURE OF CONTRACTOR'S TOGL PUSHER S.Dambacherl D.Evans OE TOOL JT 0.0. TYPE THREAD STRING NO. PUMP NO. PUMP MANUFACTURER TYPE i 4.8757(739 496 1 SKYTOPBREWSTER 1680 2 SKYTOP RREWSTER 1600 18 111"' I BIT NO. TIME SIZE WEIGHT IADC CODE PRESSURE MANUFACTURER GRADIENT FUNNEL TYPE VISCOSITY SERIAL NO. PVl1'P JETS GEL TFA STRENGTH DEPTH OUT FLUID LOSS DEPTH IN TOTAL DRILLED PH SOLIDS TOTAL HOURS CUTTNG STRUCTURE INNER ouTER ouu CHAR LUCanoN MUUB VDB O P TYPE AM . . ALDACDE iLES D. LY DOW N e sEn~s 1 cA~ ouLL CxaR PuAiiEOO W'~N ~ bardd 47 TING ND ACCIDENTS 180PE DRILL @ 17',001 MIN RESPONSE TIME DAILY DRILLING REPORT WELL B1-0BA REPORT N0. 10 DATE 18Peb-2010 FlFLDOR DISTRICT Badami COUNTY NDM Slope STATEICWNTRV AK ( United States WIfff LINE RECORD RD1N0 S DRILLING CREW PAYROLL DATA WEIGHT N0. ENGwI RKS.TO SET AT 511E No LMES LENGTH SLIPPED DATE S2E MPJ(E GRADE JOINTS L CSG HD. 1.375 10 0 18Feb2010 IAST 8855 LENGTHCUTOFf PREEENTLENGiH WELL NAMES N0. cnslNG T ~a enR 0 5600 Bademl BL78A NEING oR LINER 9.625 a`50 WEARORiRIPe SINCE LASTLUi 1970 COMPANY Oayon D~llinglne DEVIATION RECORD N fiw~ 7 I 7:00 7 G 7:15 10 H T 10:15 11 11:00 14 14:30 15 T 15:45 tfi O 16:70 18 2t BRING BNA TO FLOOR FOR WHIPSTOCKRUNIMILLS,JARS, FLIX JT,) 23 PJSNA PIUWHIPSTOCK 22 PN WHIPSTOCK ASSEMBLY wl LWp T00LS 11M~P STOCK, MILLS , N1WD , FLDAT, UHB0,1 JT DRILL COLLARS 21 SHALLOW PULSETEST 1280GPM 119%FLOWOUT 1690 PSI)BID TOPDRNE 22 PN BHA (B DRILLCOLLARS, I5 HWDPI 6 IH wl WHIPSTOCK FI B40'MD T13171'MD I UP WF=140 K I DOWN tai=140 K 22 CHECK MWD w1304 GPM 1875PM 121%FLOW OUF 11190 P51 6 IH wl WHIPSTOCK FI 317TMD T15510'MD! UP Wf =170 K I DOWN RR =165 K Welder Randall5pencer 12 SPO Dennis Allen 18 IXPEDITE PARTS f1GENSET#283 WORK OVER wMC MACHINE on GENk3 DAYS SINCE LAST LOST TIME ACCIDENT BIT NO. TIME BaaD as:Do SIZE WEIGHT 10 4 10 6 IADC CDOE PRESSURE . . DEVIATON RECORD MANUFACTURER GRADIENT 0.53976 0.54495 FUNNEL TYPE VISCOSITY 53 54 X SERIAL NO. PvnP 18:00 21 D JETS TFA GEL STRENGTH A DEPTH OUT F1111D Loss Y 21:15 22 DEPTH IN 22:45 23 rarnL DRILLED PH T SOLIDS TOTAL HOURS CUTTING STRUCTURE u 23:00 E IrvNER ouTLR DULL CHAR LOCATION R MU08 CHEMI CAL ADD ED TYPE AMOUNT TYPE AMOUNT BARA7AN 10 c~nwme 1 eEPPINGeI GAGE OTHER Duu CHAR REASgJ Puueo baf08ft 2 sEALS bamia41 106 3 COMPLETE, PJSM PRIOR TO EACH TASK, INSPECT DRILL LINE 8 TIE DOWN, NOACC. NO SPILLS N0. 393063158134 3:15 6 CONT. TIH ON ELEVATORS WI WHIPTOCKIMILL58HA ASPER 807 REP. FI5,510'MO 718,327 MD, P!U SINGLE 31.47 CONT. TIH ORIENTING SLIDE TI 71 DEGEES LEFT 718,398' MO 8 SET DOWN 6 K, POOH 718,392' MD, PIU WT= 220K, 510 WF=1B8 K 1:30 5 PUMP 32 BBL HI NS SPACERSDISPLACE 7110.3 PPG L5ND W1170 GPM, 1,000 P51.11°lP FLOW our 0:15 6 IH AS PER BOT REP. Fl8,397 MD TI8,398'MDBSET DOWNI5KTOOLFACESHOWS 71 DEGREES LEFT, PN 8 OVERPULL 5K, Sb 8 SEF DOWN 30K OBSERVE SHEAR, PN WI NO OVERPULL, _ _ 7:00 2 MILL61116'WINDOW 820'NEW HOLE AS PER BOT REP.80A. F18,380.38'MD(TOW1T18,391 MO WI10 K WOB, 290 GPM, 2,025 P51, 16 % FLOW OUT, 120 RPM, 5E KTq OFF, 1 SPR Q 8,380' MD M1 M.P.24 SPM = 520 P51. 36 SPM = 700 P51. M2 M.P.24 SPM= 520 PSI. 36 SPM = 700 PSI. No. 393063156134 N0. DAYS SINCE LAST LOST TINE ACCIDENT ®wx~, m„ No. 393063158134 ~ State of AI, ka MEMORANDUM Alaska Oil and Gas Conservation Commission TO: Jim Regg I DATE: February 17, 2010 P.I. Supervisor 4 Z(Z ~ ~~o THRU: FROM: Lou Grimaldi Petroleum Inspector SUBJECT: Well Bore Plug B1-18 Savant Oil Badami Oil Pool PTD #198-012 Section: 8 Township: 9N Range: 20E Meridian: Umiat ` Drilling Rig: Doyon 15 Rig Elevation: 48 Total Depth: ? Lease No.: ADL 365533 Operator Rep.: Casino/Tubing Data: Casing Removal: Conductor: O.D. Shoe@ Casing Cut@ Feet Surface: O.D. Shoe@ Casing Cut@ Feet Intermediate: O.D. Shoe@ Casing Cut@ Feet Production: O.D. Shoe@ Casing Cut@ Feet Liner: O.D. Shoe@ Casing Cut@ Feet Tubing: O.D. Tail@ Casing Cut@ Feet Plugging Data: Tvpe Plug Bottom of T.O.C. Mud Weight Pressure (bottom up) Founded on Cement T.O.C. Depth Verified? above plug Test Casin Retainer ? 8400 WL Ta 10.4 3600 P Tvpe Plug Founded on: Open Hole Bottom Perforation Bridge plug Annulus Balanced Casing Stub Retainer Surface Verified? Drillpipe tag Wireline tag C.T. Tag ef' t%,. Tagged plug w/E-line. Pressure test plug to 3600 psi for thirty minutes, good solid test. Plug to be used for sidetrack. ~ cc; Attachments: none Distribution: -Well File (original) -Read File -DN R/DOG Regg, James B (DOA) . Page 1 of 3 From: Regg, James B (DOA) Sent: Thursday, February 11, 2010 12:10 PM ~~~ Z~ I{~~`~ To: 'Gary Hammon'; rig15@doyondrilling.com; 'eopstad@alaska.net' Cc: DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA) Subject: RE: BOP 10K configuration (B1-18A) Badami B1-18; PTD 1980120 Badami B1-18A; PTD 2100030 Doyon 15 I spoke with AOGCC Inspector Chuck Scheve this morning regarding status of B1-18 rig up and BOPS test plan. To reiterate Chuck's discussion with rig personnel this morning, please make sure to contact Commission Inspector after rig-up of 10K system and well in advance of initial BOPE test so we can do site visit and assure there are no concerns. Also, he advised that there may still be some confusion among Savant and Doyon 15 rig crew about BOPS test pressures (Inspector was the told rig plans to test rams/valves to 3500psi and annular to 2500psi for the P&A of 61-18). I have attached the 1/14/2010 and 1/15/2010 emails where required test pressures have been addressed; test pressures for both P&A and sidetrack drilling are as follows: > Rams, Valves - 6500psi > Annular - 2500psi (minimum) Jim Regg AOGCC 333 W.7th Avenue, Suite 100 ~''~~'~~~"{ ~`!~~ `~ "~ ~~ t`j Anchorage, AK 99501 907-793-1236 From: Gary Hammon [mailto:ghammon@offshoresystemsinc.com] Sent: Wednesday, February 10, 2010 4:32 PM To: DOA AOGCC Prudhoe Bay Cc: rig15@doyondrilling.com Subject: FW: BOP 10K configuration (61-18A) FYI. See below email from Guy Schwartz. Please consider this as a 48 hour notice as to when we will be ready for the initial BOPE test of the 10K ROPE on 81-18 well at Badami with DDI 15. Gary Hammon Drilling Manager Savant Alaska, LLC Cell: 206-963-6151 NS Cell: 907-448-6011 Savant Office 907-868-1258 ext. 105 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, February 10, 2010 4:04 PM 2/11/2010 To: Gary Hammon Cc: Erik Opstad; Maunder, Thomas E (DOA) Subject: RE: BOP 10K configuration (61-18A) Page 2 of 3 Gary/Erik, The commission does not object to the proposed rig-up of the 10K choke system and in particular the bypass route through the 5K rig choke manifold. As long as the specified valves (5,13,17) on the existing 5K rig choke manifold are locked open this rig-up meets AOGCC 20 AAC 25.035 (e)(5) and AOGCC 20 AAC 25.035 (e)(6) . All connections must be flanged (no hammer unions) as per AAC 25.035 (e)(6)(F) and secured properly. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office} 444-3433 (cell) From: Gary Hammon [mailto:ghammon@offshoresystemsinc.com] Sent: Tuesday, February 09, 2010 2:04 PM To: Schwartz, Guy L (DOA) Cc: Erik Opstad Subject: FW: BOP 10K configuration (B1-18A) Guy the attached documents were sent yesterday to Jim Regg & John Crisp from Steve Dumbacher, DDI 15 Toolpusher. The drawings depict how the 10K manifold choke system would be tied into DDI 15 existing 5K manifold for purposes of routing the down stream flow after 10K choke to the rig's gasbuster. The 3 valves #5, 13, 17 shown on the attached DDI 15 5K manifold would be chained with a lock in the open position & tagged such that they could not be closed. These are the valves that would be needed down stream of the lOK choke in order to direct after 10K choke flow to the rig's gasbuster. A waiver from AOGCC is being requested to allow this hookup in order to minimize potential choke line freeze up issues by keeping the after 10K choke flaw in heated areas of rig as much as possible. Gary Hammon Drilling Manager Savant Alaska, LLC Cell: 206-963-6151 NS Cell: 907-448-6011 Savant Office 907-868-125$ ext. 105 From: Erik Opstad [mailto:eopstad@alaska.net] Sent: Tuesday, February 09, 2010 6:26 AM To: 'Gary Hammon' Subject: FW: BOP lOK configuration (B1-18A) From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Monday, February 08, 2010 4:55 PM To: Erik Opstad; Erik Opstad 2/11/2010 • Page 3 of 3 Cc: Regg, James B (DOA); Crisp, John H (DOA) Subject: BOP lOK configuration (61-18A) Erik, We need to discuss the BOP configuration and piping for B1-18A. There have been some issues that have come up that will require a variance request from Savant. Please call me at your earliest convenience. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 2/11/2010 Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, January 15, 2010 11:38 AM To: 'Erik Opstad' Cc: Maunder, Thomas E (DOA); Regg, James B (DOA); 'Gary Hammon' Subject: RE: Initial BOP test for Doyon 15 (10K stack) (B1-18A) ~7-./~ / ~ ~ - 0 f Z Erik, We still have to use a 0.1 psi/ft gradient by regulation which gives a MASP of 5400 psi. 1 am therefore recommending a BOP test pressure of 6500 psi. The annular can be tested to 2500 psi (min) . The slope AOGCC inspectors would be best utilized if the full pressure (6500 psi) testis done right away. Unless the 10K Cameron BOPs were used very recently this is what will most likely be required. Regards, Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) ~~~N~~ .J~1~ ~ ~ 2010 From: Erik Opstad [mailto:eopstad@alaska.net] Sent: Friday, January 15, 2010 11:17 AM To: Schwartz, Guy L (DOA) Cc: Maunder, Thomas E (DOA); Regg, James B (DOA); 'Gary Hammon' Subject: RE: Initial BOP test for Doyon 15 (10K stack) (Bi-18A) Morning Guy: What we were planning to do, is run your approved 3,500 psi BOP test relative to the P&A Sundry activities, then POOH to pick up our sidetrack drilling BHA, at which time we would run a second test on the 10K BOPE at higher pressure, as required, thereby giving us a full 7-days to hopefully complete the horizontal sidetrack before the next test was due. As per box #17 on the PTD application, we're conservatively assuming a virgin reservoir pressure of 6,400 psi at the target. Since the Badami oil pool has a very low GOR, in our view the worst case for MASP would be a column of 30 API oil, which is about the lightest we see around the Badami oil pool. Given a pressure gradient for 30 API of ~.38 psi/ft, TVD 10,200 and virgin pressure @ 6,400 psi we'd expect a MASP somewhere either side 2,500 psi depending on the actual crude density. So really a 3,500 psi BOPS should be adequate for the sidetrack section as well or maybe 4,500 psi if we are being really conservative. I'll be in the office after lunch, so give me a shout if you want to discuss this some more. Thanks, Erik 1/15/2010 Erik A. Opstad General Manager w r Midtown Anchorage Office: 907-868-1258 Blackberry Cell Phone: 907-244-5210 From: Schwartz, Guy L (DOA) [mailto:guy.schwariz@alaska.gov] Sent: Thursday, January 14, 2010 4:37 PM To: Erik Opstad; Erik Opstad Cc: Maunder, Thomas E (DOA); Regg, James B (DOA) Subject: Initial BOP test for Doyon 15 (10K stack} (B1-18A) Page 2 of 2 Eric, Based on the data given to me( MASP = 1500 psi) for the P & A segment of the rig work I recommended a 3500 psi BOP test. After reviewing the PTD for the B1-18A sidetrack and realizing that the BHP for the Sidetrack is very much higher (in the order of 6400 psi at TVD of approx 10,200 ft) we will need to do a full pressure test of the BOP stack at initial rig-up of the well to a mucher pressure. When I get the actual MASP from you I'll recommend a test pressure for the initial BOP test. This will need to be conveyed to the slope inspectors which I will do. Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 1115/2010 • w/s~ti~~ ~~-3~~ B1-18 Production Interval P&A Operations Program 1. COMMENCE 81-18 SUNDRY OPERATIONS (Revised 11-06-09) 2. MIRU DOYON RIG-15 on B1-18, ALONG WITH CAMP AND SERVICE COMPANIES. 3. BLEED ANY PRESSURES FROM TUBING AND ANNULUS. 4. ND 11" 10K psi 4 1/16" TREE AND NU 11" 10K psi Cameron BOPE. 5. CONDUCT STATE RECUIRED BOPS TEST. 6. REMOVE BPV, RETRIEVE PLUGIN XXN NIPPLE AT 8610'MD. RU SWS RIH AND CUT TUBING AT 8559' MD. HES TNT PERMANENT PACKER AT 8573'MD. 7. RU AND PUMP MUD DOWN ANNULUS AND RECOVER DIESEL FROM TUBING. MAKE SURE WELL IS DEAD BEFORE PROCEEDING TO NEXT STEP. 8. POOH W/ 4 %' TUBING AND JEWELRY AND LAY DOWN. .- 9. MAKE CLEAN OUT RUN TO TOP OF HES TNT (packer at 8573' MD). 10. CIRCULATE & CONDITION MUD. 11. POOH AND LAY DOWN CLEAN OUT ASSY. 12. MU 7" 29# CEMENT RETAINER AND RIH AND SET 50' ABOVE TOP OF Permanent Packer AT 8523' MD (top of HES TNT permanent packer at 8573' MD). ESTABLISH INJECTION RATE, RELEASE FROM EZSV MIX AND PUMP 37.2 BBLS (183 SKS) 15.8 PPG CEMENT W/ .05% HALAD 344, .3% CFR-3, .3°/a HR-5 AS REQUIRED, STING INTO EZSV AND PUMP 37.2 BBLS INTO BOTTOM ZONE PERFS, RELEASE FROM EZSV AND PUMP 1.8 BBLS CEMENT OR 50' OF CEMENT ON TOP OF EZSV. CEMENTTOP TO BEAT ^'8473'. 13. STING OUT PULL 3 STANDS DRILLPIPE AND REVERSE CIRCULATE TWO BOTTOMS UP OR UNTIL RETURNS OR CLEAN FROM CEMENT RESIDUEPOOH Wi DRILLPIPE. WAIT ON CEMENT, PICK UP CLEAN OUT ASSEMBLY AND RIH TO TOP OF CEMENT. CIRCULATE HOLE CLEAN. PRESSURE TEST CEMENT PLUG TO 2,000 PSI. Note: -f for some reason a casing test was not performed prior to rig arrival, a casing test would be done at this time. 14. POOH WITH CLEAN OUT ASSEMBLY AND LAY DOWN. 15. MAKE UP SMITH HYDRAULIC SET WHIPSTOCK FOR 7" CASING ON DP, RIH AND SET WITH CORRELATION CCL TO PUT WINDOW AT ±8450' 16. END 81-18 SUNDRY OPERATIONS Notes: 1. See attached schematic for well status prior to rig arrival. 2. A chart recorded casing test to 3500 psi for 30 minutes is expected to be performed prior to rig arrival. -~ ro ~ ~ 0 ~ c~ ~ ~ n E 0 W U T- v~ ~U i.. ~ ~ M ~ W ~ Z W m ~ 9J,1 ..1 ~ ~ W ~ 4!~ ~ ~~~ ~ ~i~~ 1 ~~- ~r Z L L C. fz ~. , ~,~~5 ~5- _ _ ~ ~p ~ .L ~~ I ~. ~' ` ~~~~ ~ ~~~ ~ A ..il:.J ~~ ~~ ~ :i Y N 1 ~ ~ ` 6 p ,~ ; ~6.~ a ~ r~' ~~~ k ~~ a~ y ~a ~~ g ~ ~ ~ k ~ ~ t , ~ ~ ~ . , ~'" ~~ ~ ~ ;, ~ ~ ~ ~ ~ ~` ~ ` ~ i ~ ~ ~~ ~ `'~ ~~ ~ ~~ ' ~ ~ ~ ~ ~ ~ ~ ~ SEAN PARNELL, GOVERNOR ~~ ~ ~ ~ ~ d ~ e .'' t~ ~~ C y ~ ",~~ ~~ ~ `' ~ _1 ~ ~ ~ ' ~.~ ~ ' ~ ~ ~.F 'u~-, ~, 7~; t ~ ~~..v ~ 4' ~~.78~ OI~ ~`a~ Vrny,7 ~, 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATIOI~T CODII-IISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 i' FAX (907) 276-7542 Mr. Erik A. Opsta.d General Manager Savant Alaska, LLC P.O. Box 112212 Anchorage, AK 99511-2212 ~`~~~~~~ ~~~~ ~& ~ ZQ~~ ~~ ~ ~~ Re: Badami Field, Badami Oil Pool, Badami B 1-18 `(~ Sundry Number: 309-366 Dear Mr. Opstad: Enclosed is the approved Application for Sundry Approval relating to the above refereneed well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Comxnission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~ DATED this ~ day of November Daniel T. Seamount, Jr. Chair , 2009 Encl. ~~~ ~ ~ ~ /~l ~ ~ J~~1 Mail To: P.O. Box 112212 Anchorage, Alaska 99511-2212 Phone: 907-868-1258 Fax: 907-868-1455 Physical Location 4720 Business Park Blvd Suite G40 Anchorage, Alaska 99503 ~E~EIVEL~ November 2, 2009 oCT ~ o zao~ Mr. Dan Seamount, Commissioner Alaska Oil & Gas Cons. Cammi~sian Alaska Oil & Gas Conservation Commission Anchorage 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 N r~, Re: Submittal of Form 10-403 - Applications for Sundry Approvals on B1-18 \C1\~ Dear Mr. Seamount: The Badami 61-18 well was spudded on March 5th, 1998 and brought on production in November, 1998. The well was completed in the F5 Lobe of the Badami sands and initial production rates exceeded 4,500 BOPD. However, due to reservoir behavior, paraffin problems and a well design that was not compatible with targeted geologic characteristics, production fell off prematurely relative to the reserves theoretically available for drainage. The last well test conducted on July 8`h 2007 before the field was placed on warm shutdown delivered only 49 BOPD. As part of the ongoing Badami Unit Redevelopment Project, Savant Afaska LLC is proposing to plug the well back, abandoning the original completion, then sidetrack the well into a~2,000' MD, nearly horizontal, well that will connect the F-5 and A-5 sand lobes. To that end, we are herewith submitting our Application for Sundry Approvals for that work. A Permit to Drill application for the subsequent sidetrack operations will follow shortly. Please call me at (907) 868-1258 should the AOGCC need any additional supporting materials for this application or wish to discuss any aspects of this submittal. Sincerely, SAVANT ALASKA, LLC ~.--- -- -- _ Erik A. Opstad, General Manager Submitted in Duplicate Cc: Greg Vigil, SALLC Gary Hammon, SALLC L,~ ,~~,~ ~~~EI~'~~~~ STATEOFALASKA ~(~~ oCT ~ 0 2aos ALASKA OIL AND GAS CONSERVAT'ION COMMISSION ~~eS~~ ~i~ ~~as Cons. Cq(il~l11SSI0~1 APP~ICATIQN FOR SUNDRY APPROVALS ~ ,.~•~ ~n aac ~S ~an Anchara~e 1. Type of Request: Abandon Suspend ^ Operational shutdown ^~~.Per~orafe ^ Waiver^ Other Q ~~ ~ u Alter casing ^ Repair well [~ Plug PerforaUons [~ ~~timulate ^ 7ime Exfension ^ Prepare wetl for Change approved program^ Pull Tubing[Y~' Perfa~ate New Pool ^ Re-ente~ Suspended Weli ^ horizontal sidetrack 2. Operator Name: 4. Current Well Class: 5. Permft ko Drill Number: Savant Alaska L~C Development Q Exploratory ~ ~9g_~~~~ 3. Address: 5uatigraphic ~ 5ervice ~ 6. API Number: P. O. Box 112212 Anchorage, Alaska 99511-2212 5D-02922857' 7. !f perforating, closeskapproach in poof(s} opened 6y this apeeation to nearest 8. Well Name and Number. property line where ownership or landawnership changes: 5pacing Exception Required? Yes ^ No ~ B2dami 61-1$ ' 9. Properly DesignaGon: 10. KB Elevation {ft): 1 i. FieldJPool(s): ADL 36~5 3 44.3' AGL Badami Field - 6roelrie~~ee!- /1~ U ~~~ Pi2E5ENT WELL CONbITION SUMMARY Total Depth MD (ft): Totai Depth TVD (ft}: EFfective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Jun~C (measured): 10724' - 9,873' i4724' 9,873' Nane None Casing Length Size MD TVD Burst Collapse Struckural Conductor 80' 20" ii6' 116' 1520psi 520psi Surface 4523' 9 5t8" 4550' 4491' 5750psi 3090psi Intermediate 8775' 7" 8890' 8600' 8160psi 7020psi Production Liner 2017' 41/2" 10724' 90369" 7780psi 6350psi PerForation Depth MD {ft): Perforalion Depth TVD (ft}: Tubing Size: Tubing Grade: Tubing MO (k): 1 Q,396'-10,416' 10,049'-10,061' 4.5" 12.6# L-8Q 8623' Packers and SSSV Type: Packers and SSSV MD {ft): HES TNT Packer No SSSV lnstaUed HES TNT Packer @ 8573' 13. Attachments: Descrlption Summary of Proposal ~ 14. Wel! Class after proposed work: ~,/,.. ~•• Detaiied Operations Program QQ BOP Sketch Q Exploratory [~ Development /~ Service ^ 15. Estimated Dal~ for Commencing OperaUons: ti!landay, February 01, 2090 ~ 6. well Status after proposed work: ~(. t.~• o~t ] Yo Abandoned 1[~ Oii ^ Gas ~ Ptugged ,~ , 17. Verbal Approval: WAG ~ GiN.I ^ WINJ ~ WpSPL ^ Commission Representative: 78. I hereby certity (hat the foregoing is true and correct t4 ihe best of my knowledge. Contacf Erik Opstad or Greg Vigil Printed Name ~• a~ ,~~ Title General Manager Signakure hone 9a~_$68-1258 or 244-5210 Date 10/23/20t19 COMMISSION USE ONLY S~nd ber: 3 D~ ~/ c~ ~ C diG f l N Gf C i io lh t t li it N ry on ons o approva : o y omm ss n so a represen ve may w ness um a a ~ ~ BOP Test Mechanical integrity Test ^ Location Ciearance ^ Plug Integrlty [] Oiher. JiC ~~~ ,O S cr ~~ I c5~ ~ ~t~ ~ ~ ~ - ~ ~ S ~ ~ ..~, S u t n J( ~ ~ Z~c ~ $ - , l i jt~ ~'21r-~n~ l~e'ta-'-.. i r` ~~ e m~ E'- P,"a o, ~.Q ~ a r oZ (~ A~4 e, ~ p p ~ ~+ ~ G 5 1 r ~~ J D 0 " f r o /+~ ~ Q, r' Subsequent Farm Required: 1~ ~ ~~ ~ APPROVED BY 1 r r q ~/ Approved by~ COMMISSIONER THE COMMiSStON Date: r~ b ~ ~ ~ ~~ `,b ~ ,~ ~~ i K~~ ~w a~y~o9 Form 10-403 Revised 66/2d06 + Q ~ ~ ~ ~ ~ ~ %~ ~/' J '0 / ~~~~~~t in ~~pi~~ ~~ ~ (~ ~. i~ ~/~'/vf ~A~'~-1"~rT ALASKA, 5UMMARY OF PROPOSAL The Badami B1-18 well was spudded on March 5`h, 1998 and brought an production in November, 1998. The weli was completed in the F5 Lobe of the Badami sands and initial praduction rates exceeded 4,500 BOPD. However, due to reservoir behavior, paraffin problems and a weil design that was not compatible with targeted geologic characteristics, production fell of~ prematurely relative to the reserves thearetically available for drainage. The (ast well test conducted on luly 8t" 2003 before the field was placed on warm shutdown delivered only 49 BOPD (See attached well test data). As part of the ongoing 8adami Unit Redevelopment Project Savant Alaska LLC is proposing to plug the well back, abarrdoning the original comp[etion, then sidetrack the wel! into a~2,000' MD, nearly horizantal weil that will connect the F-5 and A-5 sand lobes at a location that transits the old Badami 1 location that also serves as a control point for the 81-18A directional drilling program. Using Doyon Drilling Rig-15, Savant Alaska LLC intends to P&A the existing B1-18 production interval with the packer left in place. To accomplish this goal, an EZSV will be set 50' MD above the HES TNT permanent packer at a depth of 8523' MD and cement pumped through permanent packer (1D=3.81"), down the 4~" liner and then squeezed into the existing perforations (See accompanying procedure details). Once the P&A has been performed sidetrack operations will commence. n~ ~~ ' ` ~ %~~~~~ SAVANT ALASKA LLC ~ E~ik A tad, General anager B 1-18 WELL TEST DATA QATE [J-p/MM/YY WELL tb TAG CHOKE SE71"ING 64ths ' WELL W~AC) PSI WEL.~ HEAD TEMP BOPQ -, BWPC- P~20D GAS RATE LIFT GAS RATE . GOR API GRAVITY BS~W : DENSITY 01/14J02 B1-18 100% 432 65 288 0.000 10.8 0 37496 36.3 0.1 04/22/02 B1-18 100% 463 64 232 0.000 14.4 0 62003 36.3 02 05/18l02 B1-18 100% 444 64 214 O.Q00 14.6 0 68423 36.3 02 11/19102 81-18 19% 2031 -7 b4 0.000 9.4 0 50753 36.3 0.2 12l13102 61-18 80% 2408 63 168 0.000 4.4 0 26611 36.3 0.2 01/2$/03 B1-1$ 80% 2647 64 68 0.000 0.313 0 55162 36.3 0.2 03/20/03 B1-18 25% 2544 83 74 0.910 5.27 0 71094 36.3 0.2 d4l13103 B1-'18 25% 2502 84 72 0.145 3.186 0 52724 36.3 0.2 05/17/03 61-18 25% 2271 87 134 0.115 6.5 0 43726 36.3 0.2 06/09/03 B1-18 25% 2108 88 136 0.273 6.529 0 47947 36.3 02 10/08/05 B1-18 31% 1301 58 380 0.390 7.669 0 19667 31.4 0.2 Q.S677 10/17/05 B1-18 90% 1788 36 67 OA71 0.957 0 14222 31.4 0.2 0.8677 10/19/05 61-18 13% 1500 38 542 0.022 2.369 0 4369 31.4 0.2 0.8677 10/27/05 B1-18 10% 1284 67 872 0.09 8,336 0 9554 31.4 Q.2 0.8677 10/29/05 61-18 10% 1204 68 289 0 8.344 0 28854 31.4 0.2 0.8677 11 /03/05 B 1-18 1 d% 984 66 296 0 8.403 0 28530 31.4 .0.2 0.8677 11/~5/05 81-18 17% 955 69 298 Q 8.881 0 29769 31.4 .0.2 0.8677 11/20/05 B1-18 39% 647 66 374 0 8299 0 22145 31.4 0.2 0.8677 12/97/05 B1-18 100% 27~ 6 254 0 7.26 0 28597 31.4 0,2 0.8677 12/26/05 B1-18 75% 331 61 318 0 6.Q99 0 19166 31.4 02 0.8677 01 /05/06 B1-18 104 250 58 444 0 5.171 0 11646 31.4 0.2 0.8677 02/08/06 B1-18 104 208 50 567 0.06 3.199 0 5640 39.4 0.2 0.8677 02110/06 B 1-1 B 104 242 55 367 0 4.45 0 12127 31.4 0.2 0.8677 02/12/06 B1-18 10d 245 56 3Q4 Q 4.916 0 16175 31.~ 02 Q.8677 02/13/06 61-18 104 245 56 272 0 5.072 0 18660 31.4 O.Z 0.8677 02125/06 B1-18 25 424 53 449 0 3.93$ 0 8809 31.4 0.2 0.$677 02/28l06 B1-18 47 449 56 273 0 4.549 0 16673 41.4 0.2 0.8677 03/02l06 61-18 47 444 56 251 0 4.535 0 18088 41.4 Q.2 0.8677 03/Q7l06 81-18 47 452 55 222 0 4.623 0 20806 03(09/06 B1-18 47 445 55 202 0 4.543 0 22422 03/13/06 81-18 62 292 54 192 0 4.$56 0 2fi226 B 1--18 WELL TEST DATA t3A"fE Dfl/MM/YY WELL ID TAG ' cwoxE - ~~TTtNG° 64ths WELL WEAD. P'SI wE~.~. ' NEAC} TEMF" ~C}PD BW~'L) ; PROD GAS RATE LIFT GAS RAT~ GOR API GRA1/tTY BSB~W DENSITY 03/17/06 81-18 62 301 55 156 0 4.742 0 30348 03/19/06 B1-18 47 431 55 138 0 4.567 0 32998 fl3120/06 B1-18 36 822 52 173 0 3.1$4 0 18426 04l09/06 B1-18 47 503 48 386 0 3.095 0 8019 35.8 02 0.8677 04/11 /06 B 1-18 40 499 51 326 0 3.359 0 10310 04/9 3l06 B 1-18 40 516 53 229 0 3.59 0 15659 04IZ5/06 B1-18 40 499 53 199 0 3.732 0 18739 04/17/06 B1-1$ 60 323 53 201 0 4.32 0 21512 04/21/06 81-18 40 553 53 140 0 3.973 0 28375 04/24/06 B1-18 40 534 53 132 0 3:823 0 28939 04/26/06 B1-18 40 530 54 273 0 3.755 0 13729 04/28/06 B1-18 40 585 52 97 0 3.65 0 37601 36.3 04/30l06 B1-18 40 5$2 52 121 0 3.766 0 31081 05/15/06 B1-18 47 394 46 1144 0.108 3.678 0 3214 32.4 02 0,8677 05l16/06 B1-18 47 371 SQ 246 0 3.646 0 14814 05/20/06 B1-18 47 380 52 162 0 3.828 0 23607 06/08/06 B1-1$ 46 379 50 109 0 3.663 0 33823 33.6 0.2 0.8572 06/12/08 81-18 47 393 49 490 0.03'1 4.252 0 8679 06/17l06 81-1$ 47 145 49 145 0.031 4.13 Q 28444 07l01106 B1-18 104 270 45 264 0.031 4.096 0 155047 33.3 0.245 0.8571 07/02/06 B1-18 104 209 47 193 0.031 3.971 0 20508 07/05/06 81-1$ 104 223 49 129 4.031 3.902 0 30291 07/09/06 B 1-18 104 237 49 1 Q3 0.031 3.899 0 37990 07/31/06 61-18 104 211 45 312 0.031 3.904 0 12498 33.7 0.245 0.8557 08/03/06 61-18 104 212 49 150 0.031 3:768 0 25062 08/14/06 B1-18 104 207 48 84 0.031 3.905 0 46420 08t16106 B1-18 104 204 48 85 0.031 3.849 0 44910 08l18106 B1-18 104 220 48 99 0.031 3.7648 a 37648 08i22/06 B 1-'i 8 104 2'15 48 81 0.031 3.747 0 46058 08/22/06 B 1-1$ 104 222 48 $5 0.0031 3.715 0 43321 08/27/06 B1-18 104 219 48 152 0.031 3.678 0 24137 09/07/06 B1-18 104 207 46 66 OA31 3.819 0 57566 • ~ B 1-18 V"irELL TEST DATA DATE DD/MM1YY WELL ID TAG CHOKE ~ETTING` 6dths WELL H~AL~:PSI WELL H~AD ' TEMP BOPD BYUPC~ ' PRC1C~ GAS RATE tIFT GAS RATE, GOR' API GRAVITY BS~W DEN~ITY 09l09/06 B1-18 104 196 47 61 0.031 3.997 0 65429 09/18/06 B1-18 47 317 48 62 OA31 3.497 0 5601'i 09/22/06 B1-18 40 400 49 96 0.031 3.175 0 32885 28 0.245 0.8871 09/27/06 B 1-18 47 389 48 68 0.031 3.248 0 47615 10/05l06 B 1-18 52 312 46 49 0.031 3.2 0 65924 10/06/06 B1-18 104 222 43 48 0.031 3.307 0 68370 19/01 !06 B'I -'i 8 104 200 44 4$ 0.031 3.25 0 68208 11107/06 B1-18 104 201 45 67 0.031 3.558 0 52776 11/10106 61-18 104 200 45 56 0.031 3.527 0 63040 11l20/06 B1-18 104 194 45 39 0.031 3.215 0 82211 34.4 2.53 0.852 11/25l06 B1-18 104 188 45 49 0.031 3.192 0 65604 12/01l06 81-18 1Q4 192 45 38 0.031 3.109 0 80666 12/13106 B1-18 104 199 45 41 0.031 3.062 0 74606 01/0$107 B1-18 104 187 44 31 0.031 2.93 0 94151 40.7 3.282 0.8209 01 /17l07 B 1-18 104 200 43 38 0.015 2.758 0 72164 02/03J07 81-18 104 186 41 31 0.015 2,63 0 84719 02l08/07 B1-18 104 194 40 30 Q.015 2.489 0 83793 38.6 3.282 0.8209 02/17/07 81-18 104 195 30 41 0.015 1.936 0 47198 03/11 t07 B 1-18 104 184 40 28 d.015 2.4b9 0 $6213 03/17/07 B1-18 104 184 41 27 0.015 2.358 0 87934 32.4 0.8627 03124/07 B1-18 104 193 41 27 0.015 2.313 0 84628 04/021Q7 B~-18 904 182 41 47 0.015 2,337 0 49380 37.7 18.869 0.8357 4110/047 81-18 104 178 41 82 0.015 2.255 0 27598 04/20/07 81-18 104 186 42 30 Q.015 2.124 0 70399 05J19/07 B1-18 104 184 39 139 0.015 2,428 0 17524 05121/07 81-18 404 '177 40 34 0.015 2.303 0 67105 33.9 Q.155 0.8545 05/31l07 61-18 104 182 40 29 0.015 1.978 0 67805 06/09/07 61-18 104 185 40 51 0.015 1.875 0 36470 32.5 0.862 06l2010? 81-18 104 175 40 27 0.015 1.84 0 678$9 06/25/07 81-18 104 171 39 45 0.015 1.852 0 49116 07/03/07 B1-18 104 170 38 89 0.015 1.713 0 19251 32.5 2.$29 0.$62 07/08/07 81-18 104 178 38 49 0.015 1.638 0 33390 ~ • ~J • B1-18 Production Interval P&A Operations Program See Attached Well Schematic for Well Status Prior to Rip Arrival 1. MIRU DOYON RIG-15 on 61-18, ALONG WITH CAMP AND SERVICE COMPANIES. 2. BLEED ANY PRESSURES FROM TUBING AND ANNULUS. 3. ND 11" 10,000 psi 4 1/16" TREE AND NU 11" 10,000 psi Cameron BOPE. 4. CONDUCT STATE REQUIRED BOPE TEST. : 5. REMOVE BPV, RETRIEVE PLUGIN XXN NIPPLE AT 8610'MD. RU SWS RIH AND CUT TUBING AT 8559' MD. HES TNT PERMANENT PACKER AT 8573'MD. 6. RU AND PUMP MUD DOWN ANNULUS AND RECOVER DIESEL FROM TUBING. MAKE SURE WELL IS DEAD BEFORE PROCEEDING TO NEXT STEP. 7. POOH W/ 4%" TUBING AND JEWELRY AND LAY DOWN. 8. MAKE CLEAN OUT RUN TO TOP OF HES TNT PACKER at 8573' MD. , ! 'J! , vg' 9. CIRCULATE & CONDITION MUD. TEST CASING 3500 PSI FOR 3 MINUTES. ~/~'~ `J 4~~ L~ 7-,CS~-- r e~E+~d2G /4' 10. POOH AND lAY DOWN CLEAN OUT ASSY. ~~ ~LS 4- 11. MU 7" 29# CEMENT RETAINER AND RIH AND SET 50' ABOVE TOP OF PERMANENT ~~s PACKER AT 8523' MD (Top of HES TNT permanent Packer at 8573' MD). MIX AND PUMP 38 BBLS (183 SKS) 15.8 PPG CEMENT W/ .05% HALAD 344, .3% CFR-3, .3% HR-5 AS -- ~,. REQUIRED. ~ 12. STING OUT PULL 3 STANDS DRILLPIPE AND REVERSE CIRCULATE TWO BOTTOMS UP OR UNTIL RETURNS OR CLEAN FROM CEMENT RESIDUE. ~ V,,Y„w,,X~ ~~P T.sf` ~~"~- 13. POOH W/ DRILLPIPE. WAIT ON CEMENT & PREPARE TO SIDETRACK. ~ t9I5 Z ,a~e~~- TREE = 4-1/16" / 5000 PSI / CIW WELLHEAD 13-5/8" / 10000 PSI / FMC ACTUATOR = ,e~.~ __~ __ KB ELEV = . 54.4' BF. ELEV - ~f 19.5 KOP= ~ _ Max Angle = - r .. _ - 30 @ 6754' Datum MD - Datum ND - ~ 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" ~ B1-18 ^ Minimum ID = 3.725" @ 8611' 4-1/2" XN NIPPLE SA OTES: ~ BPV (02/04/08) 2219~ 4-1/2" HES HXO SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 6 3022 2963 0 KBG-2LS 5 4042 3983 0 KBG-2LS 4 5676 5614 9 KBG-2LS 3 7466 7218 29 KBG-2LS 2 8312 7994 14 KBG-2LS 1 8505 8180 14 KBG-2LS 8573~ ~~ 7" X 4-1 /2" HES TNT PKR, ID = 3.875" 4-1/2" X NIP, ID = 3.813" 8611' I-~4-~/2" XN NIP, ID = 3.725" ~ 8611 ~ 4-1/2" XXN PLUG (02/02/O8) 4-1/2" TBG, 12.6#, L-80 IBT MOD, I~ 8623~ ~ ~ ~ 8623~ --I4-1/2" WLEG, ID = 3.958" I .0152 bpf, ID = 3.958" • ~ ELMD TT NOT LOGGED $707~ 7" X 4-1 /2" LNR HNGR PKR, ID = 4.375" 7" LNR, 29#, P110 BTC, ID = 6.184" ~~ 8855~ PERFORATION SUMMARY REF LOG: MWD ON 03/27/98 A NGLE AT TOP PERF: 4@ 10396' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL (MD) Opn/Sqz DATE 10396 - 10416 FRACD 04/17/98 PBTD 1~64~~ 4-1/2" LNR, 12.6#, L-80 BTC MOD ~0724' .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS ???? ORIGINAL COMPLETION ~ 03/30/99 JTP UPDATE INFORMATION 08/30/06 WRR/TLH FORMAT CORRECTIONS 09/03/07 SWC/PJC SET XXN PLUG & BPV 02/09/08 RCT/PJC SEf BPV & XXN PLUG (02/02/08) 02/09/08 PJC LOCATION CORRECTION BA DA MI WELL: B1-18 PERMff No: 1980120 API No: 50-029-22857-00 SEC 8, T9N, R20E, 1424' FNL & 86' FEL BP 6cploration (Alaska) ~ ~ ~~ _ ~ ~~I ~~! ~p ~ ~ ~I r ~ ~~ ~~ = w ~~ G ~I ~f ~.. p y~ .- ~ I z~ ~a ~ ~4~ ~ r_ ~~ ` ~ r ya sx z t~ a ~ y Y ~ z° <~ ~ 4 U~ m ~ J ~f ~z ~ ~ ~ ( w P~ Z ~~ o a d ~ ~ ~ ,~ Z ~ ~ J ~ q~tY = ? ~L ....._ ._. ~ U a w .~~~~ ~~LL w ~ ~~ ~ I w~z ~~ '~8 ~ ~ o z o o~°~a - ~~ i w r g ~ ~ Y~^. Z ~ r I ._ ~ ~ U ~ ..; ~o ~ (~i. ~ "~ .I~ .. ~LL ~ m~ I ~ 4 ~ 1 O ~ ~- U .~n ~ ~ a~ 4 ~ Q~.~ ~ x ~ ~ ~ ~ ~ ~ b °- ~- ts m ~ ~~~a _. ~a ~ ~ ~ ~ ~~ ¢ ~ a. ~~~ ` ~ ~ ~ ~ o ~ ~ ~ ° g~g '~ ~6 ~, ~ ~ ~ m ~ ~ ~ I _ ° ~^ ~ ~o ~ ~ ~° _°~ g ~o ~ ~.~ G r g' ~ 'G A ~ ~S ~u~ ~ ~~'i ~ ~ a~~ r t~i~ ~; ~ ~ ~~ n~ _ ~~ a n~~~ ~ °8 n~cgts ~° ~ a ~ ~m~8 8w ~a~°~ ( °~ .a ~~ ~ ~~' ;-'om ~W ~~~e~ I ~~ ~ ^~ ~ ~~ ~- ~ c~~~~ ~ I I --- --- - _ i L z' ~~~ I _ h ; ~; ~ -~,- -~-~-- ~~~ ~{_ ~7 L . n ~ ~ f ~1 ~'~:i;:~~ w1 0~ ~'~'~'~.~." ~_~...~.' ' ' '~ ~.1~ ~ .".,~. -ti+"'.J.'~'~'.y~ ~ ~ +~^ ' I ~~ ~ . ~. ~ _ ~~ . d : . ~ ~ ~ ~ .: """"'_"' ~ v__.. ~ ~ jl ~ ' ~ ~ `} ~ ~ '•=#-~ ~ ~~ _ ~ j ~~ •~< ~ ~~ ~ ~ ~~~ ~ I '~~ ~ ~i I ~ I =~~ I ~~ ~ ?~ i - ~1 m~ lij i Z ~ ~ ~ 1~ ~ ~ „ h I ~ _.L ~ - --- ~ i~~ ~~ z ~ a~~ ~ , ~ ~ ' ~ ~; ~=~ a7c c s~ ~ ~ ~i ' tz ! _'.. _ i ~_._ V' ~ ~ 4 _.., ~ ~ ~ Q1 v ~ ~ w I i a ~a~ a ~ ` ~ Y Q ~ n. ~ ' j } ~m J~c~ ~ v ~ m z m a fl ~z a~~ ~ N.M. tl' N W h `~ ~ ~ ~ ' \ ~ i s _ fl~ ~~ oa °~ p~ vp~ p~ o~ o~ ~~ I ~ ~ ~ nQ ~~~ '~~I ~ ~ ~~ . . .~-~..:,. „, ~ u~r~ ~~~~~~~~ Savant Ataska LLC PO Box 2212 Anchorage, AK 99511 Badami Bl-I8 B 1-18 P&A tt~ S idetra~ck Badami Exploration Prepared for: Ron Jaye Drilling Supervisor October 28, 2009 Version: 1 Submitted by: Phillip Clingmen Halliburton 6900 Arctic Bivd Anchorage, Alaska 99518 (9fl7) 275-2fi30 - Office (907) 947-5482 -- Cei! HAE.~IBURTQN ~~ Savant Alaska, LLC Cementing Services B1-18 P~A to Sidetraclc . '~J~"~~~ .,. ,+~kE..A~k"~A,.: Halliburton appreciates the opportunity fo presenf this proposa! and looks forward fo being ot'service to yvu. FQREWORD Enclosed is our recoinme3~ded procedure for cementing the casing strings in d~e referenced well. The infontyation in this proposal includes well data, calculations, and materials requireznents. Tliis proposal is based on infonnation from our tield personnel and previous ceinenting services in the area. Haltiburton Energy Services recognizes the importarice of ineeting society's needs for health, safety, and protection of the environment. It is our intention to proactively work with employees, customers, the public, governments, and others to use natural resources in an environmentally sound manner while protectin~ the health, safety, and environmental processes while supplying high c~uality products and service~ to our customers. We appreciate the opportunity to present this proposal for your consideration and we look fo--~~vard to being of service to you. Our Services for your we[l will be coardinated thrnugh the Service Center listed below. If you require any additiona] infonnation or additiana] designs, please feel free to contact myself or our field representative listed below. Prepared and Submitted by. Phillip Clinginan 5r. Technical Professional -CMTJAF SERVICE CENTER: Deadhorse, Ak ~ERVICE COORDINATOR: Tom Crabiree I Jeff Helms OPEIt. ENGINEER: Phillip Clingman PHONE NUMBER: (907) 259 - 2805 Deadhorse Carnp {90'7) 275 - 2b30 Engineering Suppart NALLIBtJRTClN ~ Savant Alas~ca, LLC Cementing Services B9-18 P8~A to Sidetrack ~ +~'~ ~ ~ ~.., ~~.,A'~F~ A. . EXECUTIVE SUMMARY Current operations for BI-18 require the abandonment of the well belo~~ the TNT packer. An EZSV will be set 50' above the TNT ~~cker and cement ~ullheaded from s~irfac~ to fil[ the ~vellboce from PBTD to the EZSV, Plug #l Dc~wnsqueeze method: 7" 29# EZSV set ~0' above the TNT packer at 8,523. Cement to be placed froni PBTD (10,724') to 50' above EZSV. Total plu~ interval is from 10,724' ta 8,473'. Fluid Summary 14 bbl 39.1 bbl (189 sk) mixed at 15.8 ppg Water Premrum Cement, d.5°lo Halad-344, 0.3Q/o CFR-3 + p,3~/a HR-5 COST ESTIMQTE The price estirnate provided l~elow is based on the job requiring 1 day to coznplete. The recipe for the cement slurry is subject to cl~at~ge. Additional ehar~es may be applicable for crating, personnel, a~td bulk deI i verv. Cement Materials Liner Cement Job ~ Cement - 39.1 bbls 189 sk) Premium Cement + 0.5% Halad-3~, 0.3°lo CFR-3 ~- 0.3% HR-5 mixed at 15.8 PP~ C~ ~ Cementing Unit Charge - 06:d0 - l2:QQ hours Personnel Charges - Personnel - 1 ~iays - 4 each Cementing Crew rnernbers (c~ $1,250.00 /ma»/day Total - t-~iAL,t~„IBIJ R7'[~1\! . ~ Savant Alaska, LLC C/~ ~/~ w ~~ Cementing Services ~7M f^~! \i 61-18 PB~A to Sidetrack Ai,.,.ASKA B1-18 Current Well Design 2~ Ltb' '3 ~J/e~ as3o• ~• 88~5'I 4 ~,2' I ]0724 J i I ~~ HALLlBURTON ENERGY SERVICES Moms Cox, TQChnical Aqviso H A L L I B U RTO N 6900 ArcUt Blvd. Anchoraoe. ~lasl;a 99518 instailation Report ~so~>?aa-2szs ~9 fw4m~r BP Exploration CwN+~~R~Nwer.l~ti+. l~1ASKELL / BOYD W~II 81-18 fi~N Badami D~b 4/~119g4 ~8 C~.i~~S:u 20' C~in~N.i~1e 91~i Grin~firN. H-40 I~w, Surtace T~ 116' I~Iw~~ii~. 4-112~ TJi~.~M.i~M 12 6~ T.~in~G~4 L-BO 7r~'v.~T~~N1 I8T-I+lod I7 Cvb~&n 9-5J8' C~ri+~V~idt 40# Gve~4n1~ L-80 fiun Suriace 1~ 4550~ Tu~in~Si~~ 7.Iiw~M~rM TNin~Q,~4 h~i~~TArN1 ~(~ Ori.~Siu 7' Cui.iW.HM 29~ 6arin~6..J. USS 95 ~nT Surface t. 8855 -I<4lryW.l~\~ 133k S~.ddfM~:~M 113k tl.<4N~i~Ft 27k W~I~Atu4~r~r N1A ~S Li^.r5ia. d-1/2' L~n..M.:~A~ 12.6# l:e.r&.L L-80 f..n. 8707' T. ~072A l•<~~~rTm N1A f.M1~r~/PW.tl~n 6576.23 RKB 31.05' P8T0 ]4 Gwrl~~4nllr~~ 8.6 PPG Brine YHf 6N~ -~rh.~llw No Pertorations ~ 3 Item # Destxi tion 1.D. O.D. Len De th 12 n mal evation ~1.05 0 00 20 F-AC Han er 3.958 0.76 ~1.05 lt 19 4-~+2' 12 ti0~ L-BO NSCT Pu Joint g5 5.000 1]S 31 81 79 4-~12` 12 EOz L-80 X-Oder Pu WSCT Box x Butt Pin 5.000 2. . 33.59 l0 19 4-'I!2° 12.6C1X L-80 IBT-I,lod Tubino 53 Jts. 3.956 F 2173.1d 5.81 79 4-1J2° 12.50z L-80 IBT-1:1od Pu Joint 3.958 ~. fiB 2"0 5 9 78 HES'HXO' Safe Valve Landin fJi le 3.813 5.520 2.94 . 22~8.63 17 4-1;2" 12.60tt L-80 IBT-L1od Pu Joini 9^"8 ~"20 9.66 1. 7 e ~7 »-1P2 12.50~ L-80 IBT-1.1od Tubin (18 Jts.` 3.958 F. 20 7 1, 8 223'1.25 ~ 17 4-1;2' 12 00» L-SO IBT-I.lad Pu Joint 3.9~ F.22G 9.66 1 3 16 Camco Gas Liit L7andrel iffi Shear Valve 3 909 ~., g~ F ~ 15 4-1/2 ~2 60z L-BO IBT-I;tod Pu Joint 3.95 °" 9. 6 30 9J'I 6 15 4-~;Z 12.50~ L-80 IBT-I.lod Tubino 24 Jts.` .220 99". 3039.?7 S 15 4-~;2' 12.50~ L-80 IBT-1.1od Pu Joint 3.956 °. 0 9.57 4032.32 14 Camco Gas Lift L~andrel #5 Dumm Valve 3.909 5.g85 7. 4041.99 13 4-1lZ' 12.60x L-80 IBT-t:lod Pu Joinl 3.958 F.220 . 4 4 4 '4 l 13 4-1,'2' 12 60X L-80 IBT-I,lod Tubina 39 J1s. 3.958 5,220 1607.91 . 4 F 1 13 4-1;2' 12.60~ L-BO IBT-I:lod Pu Jnint 3. 27 =6fi7.09 { 12 Camco Gas Li(t L9andrel #4 Dumm Valve 3.909 5.985 7.~ ~576.36 11 4-1;2" 12.60# L-80 IBT-I.lod Pu Jaint ;. 58 9.65 F583 8 I 11 4-1l2 12 60x L-80 IBT-1,1od Tubin ~43 Jts ~.958 F.220 17 .12 . °093.54 11 4-1i2°'12 60it L-80 IBT-L1ad Pu Joint 958 ~.220 74=" 6 10 Camco Ges Litt 1landrel #3 Dumm Valve 3.909 F gg5 7.55 74 29 ~ 9 4-~;2 12 60~ L-SO IBT-f.tad Pu Joint 3.956 5.2 0 9.64 7473.B5 9 4-1;2' 12 60~ L 80 IBT-I,lod Tubin (20 Jts. F 5. 0 81 . 74 .4 9 4-1;2' 12BOZ L-BO IBT-I.1otl Pu Joint 3 9F8 220 9.61 8 37 ; 2 8 Camco Gas Litt /.7andrel #2 Dumm Valve 3.909 ~ 7.~4 V g3~ .gg 7 4-~/2 12.60z L-80 I8T-btod Pu Joint ~.g g 5. g. ~~ ~ 7 4-1,'2'"12.6Ux L-80 IBT-1~1od Tubin 4Jts. ~. F. 20 '165.k5 7a0."~ 7 4-1;2 12 5Dx L-80 18T-1.1od Pu Joint 3 9~8 5. 8.'0 8495.6? 6 Camco Gas Litt Llandrel ~1 Uumm Valve 3.909 F.g85 7. 4 S^0^.27 5 a-1;2 12 60~ L-80 IBT-I.lotl Pu Joint ~ 2 9.67 8512.81 5 4-112' 12.60x L-80 IBT-I:lod Tubin 1 Jt ~ v F 4. 3 5"2 48 I 5 4-1;2' 12 60~ L-80 X-O~er Pu IBT Box x NSCT Pin .gF ~~220 1 4 HES 7"'TtJT Permanent Packer 7 5.g7~ ~2z 7~.2g 4-112 12.60~ L-80 X-O~er Pu NSCT Box x BuH Pin ~.g58 v F.00 979 6580.~0 3 Hes'X' Landn Ni te . 1 10 ~.14 5 0."9 d-1/2 12 60x L-8018T-1;1od Pu Joint q58 F D 9 67 8 9'1.4 4-1;2 ~2 60~ L-BO IBT-I,tod Pu Joint 3.958 0 0 86 1.10 2 HE5'XN'Landin !~i le 3725 ~. 1 1. 1 6 0. 0 4-ll2' 1~.6Un L-80 IBT-fdOd PU .10'1111 r+ 5. 0 9.7 8612.O1 1 Wireline Ent Guide 3 8 4 1.38 8621.7 End ot Tubi - - - 8623.1 ~ HALLIBURTON • Savant Alaska, LLC Cementing Services 81-1$ P&A to Sidetrack Abandonment Plug Piug #1; Downsqueeze methad ~ ~:~-'~~I~~'~` ~w. ~~.,.~~~I"~~As:,. 7" 29# EZSV set 50' above the TNT packer at 8,523. Ceme~rt to be placed froan ~'BTD (10,724') to 50' above EZSV. Total plu~; interval is f"rom 10,724' ta 8,~73', Ptug Slurry: 39.1 bbls. -189 Sks Pretnium Cement, 0.5% Halad-344, 0.3% CFR-3 + 0.3°l~ HR- 5 (Retarder), as required Plub Slurry Densi#Y (pp~) I S.A Yeld (cu ft / sk} 1.16 ~Vater requirements (gallsk) 5.~8 F}uid Loss {cc130 min.) ~75 Free lVater % p Thickening Time Hr: min. +J_ 3;Op Campressi>>e Strength - PSI l2 hr (est.) >1,000 ~u' 170°F 24 hr (est.) >1,800 (cz; I70"F HALLIBL.)RT~t~ 5 ~ Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, November 05, 2009 2:18 PM To: 'Erik Opstad' Subject: RE: B1-18 P&A Page 1 of 4 ~ _ __ f' ~ ~ -~s-a~z) blush setting the plug and testing the cement plug would be ending the P& A. For our bookkeeping t we lump everything until the window is milled for the new penetration into the P& A sundry. s#or the reservoir info.. I had a feeling the pressure was going to be low due to the faulting. chwartz eum Engineer 226 (office) ~433 (cell) ~: Erik Opstad [mailto:eopstad@gci.net] : Thursday, November 05, 2009 2:10 PM ~chwartz, Guy L (DOA) ect: RE: B1-18 P&A ald have assumed that once we pressure tested the plug that the P&A part of this adventure was and everything forward of that would be under a new PTD, but whatever! We'll add in the other ils into the P&A operations summary and start the PTD with "RIH tag whipstock & commence tg window" or something to that effect as far as the DH portion goes for the sidetrack PTD! ~y case, yes we'll set a whipstock and kickoff out of a window @±8450' MD, depending on what ;Ct tells us about collar focations. ~;: ~': a~~:. 11 /5/2009 Page 2 of 4 ~ ~ 81-18 Monthly Production P~anned Horizontal Sidetrack Cum Oil Prod 915,861 Drill at least 600' Iateral throu h Sadami #1 takeoint 1fl00~00 1~OG00 ]~ODO ~ IT • S 3793 1 ~ • • 104Q --- ~13441d97 163' ~oa ~ ~ tl~W~WMMMIA- I~MM~~'~M'~ y1~ ~~ ~ ___ _- - - . _ __,R _ _ _ __ . -- -. -- _ _ -- --- ---- __._~ _ ~ • • ~ `~~, 1~~ ~~~ \o° 40° ~~~ \~., ~o~, `oti \a~ ~~~ r4~ ~,~` `a`' vQ`' ~Q~ ,~c~ ~o~ `o~ ~o~ ,~o~a ~o~ `o~ ~~ti ~\~ ~~~ ~`~ ~`~ ti $~~ ti ~`~ ti ~\~ ~`~ ~~~ ~~~ ~~~ ry`~ ~`~ ~~~ ~~~ ~~~ ~`~ ti ~~~ Date __-- - ~-- - -- _ ( -~-Oil,:bbls~f --E-GastMCf~ ie chart above shows 1,637 psi for the last static done August 15t this year. I'll need to calculate the ASP tomorrow, but it won't be much! I think the last wellhead SIP was something like 185 psi, but I ~ed to dig up the report, so please standby on that question. Let me know if you want anything else. anks, sA~aNT ALASKA Erik A. Opstad General Manager Blackberry Cell: 907-244-5210 Mid-Town Office: 907-868-1258 X-101 From: Schwar~, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, November 04, 2009 2:42 PM To: Erik Opstad Subject: RE: B1-18 P&A Erik, 11 /5/2009 Page 3 of 4 ~ i a MASP (Max surface pressure) and reservoir pressure from you also. Can you elaborate more on how ~track will be implemented? Assume you will be setting a whipstock and kicking off. What depth? That is r part of the P& A... As soon as you start Milling the window is when the new Permit to Drill is in effect. ~ment plug will have to be pressure tested too. Engineer 226 (ofFce) 433 (cell) c Erik Opstad [mailto:eopstad@gci.net] i Wednesday, November 04, 2009 11:28 AM chwar~, Guy L (DOA) :Ct: B1-18 P&A rise the P&A Operations Program to address your comments. " x 4%2" tubing casing annulus can be pressure tested even now with the BPV being pulled and the XN plug pipe remaining in place or this can be done after rig is on well. Another option would be to pressure test ' casing after setting the EZSV above packer & before squeezing. That said, our intention was to get the ni Wells Engineers to pressure test the 7" x 4%" annulus to 3500 psi prior to rig arrival so that we know ; is good before we rig-up. ng ^'S0' of cement on top of EZSV is fine with us; we'll do it! establish an injection rate into the 61-18 perforations by bull-heading tubing-diesel during the well perations prior to NU of BOPE. 7 ~A'-ANT ALASKA Erik A. Opstad General Manaqer Mail to: Physical Address: ~.0. Box 112212 4720 Business Park Blvd. ~nchorage, AK Suite G40 ~9511-2212 Anchorage, AK 99503 ~lackberrv Cell: 907-244-5210 11 /5/2009 Aid-Town Office Aid-Town Fax: ~orth Slope Cell: :. -. 11 /5/2009 n ~ 907-868-1258 X-101 907-868-1455 907-345-6346 907-448-6010 • Page 4 of 4 .. ., ~ • Page 1 of 2 Schwar#z, Guy L(DOA) 1~~a ~ q~`~ ~ Z- From: Schwartz, Guy L (DOA) Sent: Wednesday, November 04, 2009 11:32 AM To: 'Erik Opstad' Subject: RE: B1-18 P&A ~ sense... thanks for the follow-up!! leum Engineer ~C 226 (office) ~433 (cell) t:'Erik (?pstad [mailto:eopstad@gci.net] : Wednesday, November 04, 2009 11:28 AM ~chwariz, Guy L (DOA) ect: B1-18 P&A Rise the P&A Operations Program to address your comments. ~ T" x 4%Z" tubing casing annulus can be pressure tested even now with the BPV being pulled and the XN plug itpipe remaining in place or this can be done after rig is on well. Another option would be to pressure test '" casing after setting the EZSV above packer & before squeezing. That said, our intention was to get the imi Wells Engineers to pressure test the 7" x 4%° annulus to 3500 psi prior to rig arrival so that we know ig is good before we rig-up. ing'"50' of cement on top of EZSV is fine with us; we'll do it! ~ ~ tan establish an injection rate into the B1-18 perforations by bull-heading tubing-diesel during the well g operations prior to NU of BOPE. ~<sense? Vlai ~".O 4nc SATANT ALASKA Erik A. Opstad Genera/ Manager to: Physical Address: Box 112212 4720 Business Park Blvd. iora~e, AK Suite G40 11 /4/2009 Page 2 of 2 11 /4/2009 ~ Anchorage, AK 99503 ~II: 907-244-5210 fice: 907-868-1258 X-101 x: 907-868-1455 . 907-345-6346 ~ell: 907-448-6010 ~ , . , . Page 1 of 1 ~ ~ Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, November 02, 2009 11:30 AM b To: 'Erik Opstad' ~r Subject: B1-18 P & A ~~ Eric, I am reviewing the procedure submitted with the Sundry request to P& A well 61-18. I have couple of comments and questions: 1) How are you testing the casing in step 9. Looks like you are RIH with a just a clean out assembly ... no RBP is mentioned. There are still open perfs below the perm packer that are open. 2) A post P& A drawing is always helpful if you can have one generated ( showing cement , Retainers, pulled tubing etc. ) 3) I would suggest leaving a 50' cement cap on top of the EZSV in cased the bottom falls out of the cement column below the retainer. 4) You do not mention getting any kind of injection performance into the perfs before setting the EZSV. Give me a call at your convenience and we can discuss the items above. Thanks in advance, Guy Schwartz Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 11 /4/2009 ,?ý"ojJ ¡ j~41'1\ U:1~1 'i 1- -¡~ \. . . Date 02-09-2007 Transmittal Number:92875 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. SW Name Date Contractor Log Run Top Depth 8ottom Depth Log Type 81-18 07-01-2006 PDS STATIC SURVEY CD ROM STATIC TEMPERATURE 81-18 06-30-2006 PDS PRESSURE SURVEY ~EMPERATURE OVERLAY 81-01 09-07-2004 SCH RST WFL WATERFLOW 81-01 08-10-2006 SCH ITEMPERATURE RST ~ll---- Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer Petrotechnical Data Center RECEIVED FEB 1 3 Z001 i~ C1i & Gas coc.s· ccmmisslOO ¡~rege Attn: Kristin Dirks Howard Okland Mike Engle ,..... ~ 5CANNEt~ FEB 1 3 2007 Jq~""Dla Petro technical Data Center LR2·1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 .......... .. .... .. .. .. .. .. .. Static Temperature / Pressure Survey (Pre-Job Ten Minute Stop Inside Lubricator) B.P Exploration (Alaska) Inc. 81-18 Badami North Slope Pre-Job 10 Minute Stop Inside Lubricator Elapsed Time Temperature I Pressure (Minutes) (Deg. F) (psia) 0.0 42.954 1348.071 0.5 47.314 1354.015 1.0 47.993 1354.391 1.5 42.911 1348.137 2.0 43.629 1349.510 2.5 44.654 1350.508 3.0 45.551 1351.032 3.5 46.108 1351.526 4.0 46.633 1351.904 4.5 46.934 1352.192 5.0 47.232 1352.442 5.5 47.47 1352.639 6.0 47.607 1352.811 6.5 47.824 1352.951 7.0 47.939 1353.079 7.5 48.025 1353.183 8.0 48.117 1353.276 8.5 48.205 1353.356 9.0 48.286 1353.422 9.5 48.34 1353.487 10.0 48.412 1353.539 AVERAGE 46.77 1352.17 Date: June 30, 2006 Temperature Data 55 .. .. .. Start time: 23:10:00 50 u. 2' 45 Q 40 35 o 2 3 4 5 Minutes 6 7 8 9 Pressure Data 1400 1375 1350 1325 « ¡jj 1300 CI. 1275 1250 1225 1200 o 456 Minutes 10 2 3 7 8 9 .. .. ...................................... Static Temperature / Pressure Survey 15 Minute Stop @ 9,969' MD B.P Exploration (Alaska) Inc. 81·18 Badami North Slope 9617'SS MD =9,9S9ft Elapsed Time Temperature Pressure (Minutes) (Deg. F) (psia) 0.0 167.30 1853.74 0.5 167.26 1853.71 1.0 167.21 1853.69 1.5 167.13 1853.69 2.0 167.04 1853.70 2.5 167.03 1853.72 3.0 16701 1853.76 3.5 167.05 1853.80 4.0 167.03 1853.86 4.5 167.02 1853.92 5.0 167.02 1853.98 5.5 167.09 1854.06 6.0 167.03 1854.14 6.5 167.04 1854.23 7.0 167.07 1854.31 7.5 167.08 1854.40 8.0 167.13 1854.48 8.5 167.10 1854.57 9.0 167. 13 1854.64 9.5 167.14 1854.72 10.0 167.17 1854.81 10.5 167.20 1854.88 11.0 167.24 1854.96 11.5 167.24 1855.03 12.0 167.28 1855.09 12.5 167.28 1855.16 13.0 167.30 1855.24 13.5 167.29 1855.31 14.0 167.36 1855.38 14.5 167.43 1855.45 15.0 167.50 1855.53 AVERAGE 167.17 1854.45 Date: June 30, 2006 Start time: 1 :27:00 Temperature Data 180 175 170 u. 2' 165 Q 160 155 150 o 2 3 4 5 6 7 8 9 10 11 12 13 Minutes Pressure Data 2000 1950 1900 « ¡¡¡ 1850 CI. 1800 1750 1700 o 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes ------------------- Static Temperature / Pressure Survey 1st 15 Minute Stop @ 10,069' MD B.P Exploration (Alaska) Inc. 81-19 Badami North Slope 8, 716'SS MD = 10,OS9ft Elapsed Time Temperature Pressure (Minutes) (Deg. F) (psia) 0.0 169.35 1859.88 0.5 169.38 1859.91 1.0 169.38 1859.97 1.5 169.42 1860.02 2.0 169.39 1860.06 2.5 169.40 1860.11 3.0 168.42 1860.15 3.5 169.42 1860.20 4.0 169.46 1860.25 4.5 169.44 1860.29 5.0 169.47 1860.33 5.5 169.50 1860.38 6.0 169.50 1860.42 6.5 169.51 1860.47 7.0 169.55 1860.50 7.5 169.53 1860.55 8.0 169.56 1860.59 8.5 169.57 1860.62 9.0 169.58 1860.67 9.5 169.59 1860.70 10.0 169.59 1860.73 10.5 169.64 1860.75 11.0 169.62 1860.78 11.5 169.61 1860.81 12.0 169.63 1860.85 12.5 169.63 1860.90 13.0 169.66 1860.93 13.5 169.66 1860.96 14.0 169.66 1860.99 14.5 169.67 1861.02 15.0 169.69 1861.03 AVERAGE 169.53 1860.51 Date: July 1, 2006 Start time: 1 :42:00 Data 180 175 170 u. g. 165 Q 160 155 150 0 2 3 4 5 8 7 8 9 10 11 12 13 14 15 Minutes Pressure Data 2000 1950 1900 « ¡¡¡ 1850 CI. 1800 1750 1700 o 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes ------------------- Static Temperature / Pressure Survey 15 Minute stop @ 10,169' MD B.P Exploration (Alaska) Inc. 81-18 Badami North Slope 9,816'SS MD = 10,1S9ft Elapsed Time Temperature Pressure (Minutes) (Deg. F) (psi a) 0.0 168.44 1865.63 0.5 168.48 1865.65 1.0 168.45 1865.69 1.5 168.39 1865.72 2.0 168.42 1865.74 2.5 168.39 1865.76 3.0 168.35 1865.78 3.5 168.35 1865.81 4.0 168.34 1865.84 4.5 168.32 1865.87 5.0 168.26 1865.89 5.5 168.26 1865.92 6.0 168.28 1865.93 6.5 168.26 1865.96 7.0 168.26 1865.97 7.5 168.22 1865.99 8.0 168.25 1866.01 8.5 168.21 1866.03 9.0 168.23 1866.06 9.5 168.21 1866.06 10.0 168.21 1866.07 10.5 168.19 1866.09 11.0 168.18 1866.10 11.5 168.17 1866.11 12.0 168.18 1866.12 12.5 168.18 1866.14 13.0 168.20 1866.15 13.5 168.18 1866.17 14.0 168.18 1866.18 14.5 168.12 1866.23 15.0 168.11 1866.25 AVERAGE 168.27 1865.96 Date: July 1, 2006 Start time: 1 :58:00 Temperature Data 180 175 170 u.. 2' 185 Q 160 155 150 o 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Pressure Data 2000 1950 1900 "I: ii$ 1850 a. 1800 1750 1700 o 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes ------..--..---..-....-- Static Temperature / Pressure Survey 2nd 15 Minute Stop @ 10,069' MD B.P Exploration (Alaska) Inc. 81·18 Badami North Slope 9,716' SS MD = 10,069 ft Elapsed Time Temperature Pressure (Minutes) (Deg. F) (psia) 0.0 169.40 1861.67 0.5 169.48 1861.67 1.0 169.51 1861.67 1.5 169.52 1861.67 2.0 169.56 1861.67 2.5 169.60 1861.66 3.0 169.62 1861.68 3.5 169.62 1861.68 4.0 169.64 1861.69 4.5 169.66 1861.70 5.0 169.68 1861.70 5.5 169.69 1861.70 6.0 169.71 1861.70 6.5 169.72 1861.70 7.0 169.72 1861.70 7.5 169.74 1861.70 8.0 169.75 1861.71 8.5 169.76 1861.72 9.0 169.77 1861.72 9.5 169.79 1861.73 10.0 169.80 1861.73 10.5 169.80 1861.72 11.0 169.81 1861.73 11.5 169.83 1861.74 12.0 169.83 1861.73 12.5 169.84 1861.75 13.0 169.85 1861.76 13.5 169.86 1861.76 14.0 169.91 1861.75 14.5 169.92 1861.76 15.0 169.94 1861.76 AVERAGE 169.72 1861.71 Date: July 1, 2006 Start time: 2:14:00 Temperature Data 180 175 170 u. ~ 165 Q 160 155 150 o 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes Pressure Data 2000 1950 1900 « 1ñ 1850 CI. 1800 1750 1700 o 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Minutes ------ ------- - - - - -- Static Temperature / Pressure Survey (Post-Job 10 Minute Stop Inside Lubricator) B.P Exploration (Alaska) Inc. 81-19 Badami North Slope Post-Job 10 Minute Stop Insíde Lubrícator Elapsed Time Temperature Pressure (Minutes) (Deg. F) (psia) 0.0 48.4 1356.6 0.5 48.4 1356.6 1.0 48.5 1356.6 1.5 48.5 1356.6 2.0 48.4 1356.6 2.5 48.3 1356.6 3.0 48.2 1356.6 3.5 48.3 1356.6 4.0 48.3 1356.6 4.5 48.4 1356.6 5.0 48.4 1356.6 5.5 48.5 1356.6 6.0 48.4 1356.6 6.5 48.4 1356.5 7.0 48.3 1356.5 7.5 48.3 1356.5 8.0 48.4 1356.5 8.5 48.5 1356.5 9.0 48.5 1356.5 9.5 48.5 1356.5 10.0 48.6 1356.5 AVERAGE 48.41 1356.56 - Date: July 1, 2006 Start time: 3:45:00 Temperature Data 55 50 1.1. 2' 45 Q 40 35 o 2 3 4 5 6 7 8 9 10 Minutes 1400 1375 1350 1325 Pressure Data <I: 00 1300 C!. 1275 1250 1225 1200 o 2 3 456 Minutes 7 8 9 10 . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Records Department 333 W. 7th Ave Suite 100 Anchorage. Alaska 99501 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection[Caliper / MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 RECE\VED AUG 2 9 L006 AJasI<.a Oil & Gas Cons, Commission AnchOf3gP. 1] EDE Disk 81 - 18 o 1·Jul-06 Jewelry Log 2] / L/¡I.., -;:) .1 I. /1 LI IQ lp j'Pre-:S6Ure. ZJurveëJ· ~ (vÚíe - (.J l-lif 0\!60 11\-0.,.5 ::JTOv~ Ie..· I.Ñ 3] 4] 5] 6] ~ÇANNED AUG 3 0 2006 7] Signed: (\. Ji~- .. Date: ct / ml {r(o Print Name: ~ n~lÅ-e. ()47(~LI/I/(o.......vt PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM IC)L( -01 d tb /4 Cj"~?r C:lDocuments and SettingsIPDS Anchorage - MPL\DeaktopITransmil.Original.doc ('¡:;:"\~'" ~ ®' \ ~ '6 ,illlU,\"" :'!,lÆ'! " II, I' , \ '" l i: i'l, 'i! Ù~ ,,' I \ I, 'L6¡ f"]"! ,,¡, 'I I !: \\~: ,W // \ ~ : ~l' ~¡=:1 f I !, Ii ( i t í ii' '<~) Ii ) rÆ'~i '< :1' fW':fi.' i '\"~ ~: I! ih( \ /..1, \ ¡ 1 !. / I \ ':..'\~! ~ (' .,r' \ , . I : \" ,'\. I '" i I m;' ',,\ i L i ,f-¡ \\ ~')'~ l ; \ / ," \ :: 'l L...::::J iu 'L:\ ~ : I .,J. I ~, ) ALASKA OIL AND GAS CONSERVATION COMMISSION / J .! :¡ j FRANK H. MURKOWSKI, GOVERNOR Carolyn Kirchner Petroleum Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 16 ,,0\1}- \0\ Re: Badami Field, Badami Oil Pool, BI-18 Sundry Number: 306-221 i,¡CANNE:D JUN 2 ~ 2005 Dear Ms. Kirchner: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Dan T. Seamount Commissioner DATED thiS!Zctay of June, 2006 Encl. flmG .b /~ ¡J 0{;; C{/.} ~fz;vl0fp RE ceNEO/2..1-! LOo,," . f'f STATE OF ALASKA ) Ali .!A Oil AND GAS CONSERVATION COMMk. -,ON JUN 2, 0 2006 APPLICATION FOR SUNDRY APPROVAL C--wútt4tÍftß 20 AAC 25.280 Alaska Oil & Gas Cons. UUlIl....... Abandon U Suspend U Operational shutdown U Perforate GJ WaiveAbdhOrage Other U Alter casing D Repair well D Plug Perforations D Stimulate D Time Extension D Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to D0!Number: BP Exploration (Alaska), Inc. Development ~ Exploratory 0 198-0120 /' 3. Address: P.O. Box 196612 0 / 0 6. API Number: c Stratigraphic ' Service , Anchorage, AK 99519-6612 50-029-22857-00-00 /", 7. KB Elevation (ft): 9. Well Name and Number: ,~cg/" 1. Type of Request: 54.4 KB B1-18 "./ 8. Property Designation: ADL-365533 11. Total Depth MD (ft): 10724 Total Depth TVD (ft): 10423.17 10. Field/Pools(s): Badami Field / Badami Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 10640 10339.26 None " Casing Length Size MD / TVD Burst Conductor 80 20" 91.1# H-40 36 116 36 116 1490 Surface 4516 13-3/8" 68# L -80 34 4550 34 4545 5020 Production 8822 7" 29# P-110 33 8855 33 8575 11220 Liner 2017 4-1/2" 12.6# L-80 8707 10724 8430.83 10423 8440 Perforation Depth MD (ft): 10396 - 10416 // Perforation Depth TVD (ft): 10095.68 - 10115.63 Tubing Size: 4-1/2" 12.6# / / Tubing Grade: L-80 Packers and SSSV Type: 8573 /" 8707 HES TNT Packer Liner Top Packer Packers and SSSV MD (ft): 12. Attachments: Descriptive Summary of Proposal ~ Detailed Operations Program 0 BOP Sketch D 14. Estimated Date for /c~\ ¡I Commencing Operations: f/4/3- 06 16. Verbal Approval: V' Date: 13. Well Class after proposed work: Exploratory 0 Development ~ 15. Well Status after proposed work: Oil ~ Gas 0 //Plugged 0 WAG D GINJ D WINJ 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Carolyn Kirchner Title Petroleum Engineer Signature (èl,~.ll( ,y---\[" "I It ¿ ~"" PhORe- 564-4862 Date J COMMISSION USE ONLY Junk (measured): None Collapse 470 2270 8510 7500 Tubing MD (ft): 30 - 8623 Service 0 Abandoned D WDSPL D Prepared by Sharmaine Vestal 564-4424 Carolyn Kirchner 6/20/2006 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: l ~ 19 - d- ~ J Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: RBDMS BFL JUN 23 2D06 Subsequent Form Required: \ 0 Xo - \" "\. ", COMMISSIONER APPROVED BY THE COMMISSION Date: ~ /'¿2! 6 Form 10-403 Revised 7/2005 IGINAL ,~/l .' ,/ .;,; ¿( Submit in Duplicate .-: . 6./~;~-/tJ .,' ,.(.. ... No portion of the belo¥'~ork should be peñormed w/out fir-\ taking time to ensure No Accident~. ,Jo harm to People, and No damagt. .b the Environment To: B. Green / B. Clemens Well Operations Team Leader Date: June 20, 2006 From: Carolyn Kirchner - Badami Production Engineer Subject: B1-18 RePerfs & Adperfs AFE BAWELLOPS Est. Cost: $60,000 Est. lOR: 102 BOPD Type S E lOR 102 102 Current Status: Last Test: Max Inclination: Max Dog Leg: Minimum 10: Last TO tag: DSWL B1-18 B1-18 AFE BAWELLOPS BAWELLOPS Job Description Drift to TO w dummy gun & Bail if needed Re-Perforate 20' of F5 10,396' - 10,416' MD Perforate up to 10' of F5 starting at 10,416' - 10, 426' MD Use one 30' gun to span Perf/Re-Perf distance. (The 30' interval may be shortened based on the TD) Producer 6/12/06: BOPD: 490, BWPD: 0; MMCFPD: 0.87 310 at 6,754' md; 4.50 at Perfs 4.2 deg/100' at 6,187' md 3.75" @ 8,611' md, 4.5" XN Nipple 06/10/06: 10,379' SLM, about 10,420 MD 01/06/06: to 10,357' SLM w/ 3.25" Cent. during BnF 01/29/05: 10387' SLM + 35' = 10422' corrected to MD. (Soft Bottom) 08/08/98: RIH with 3.50" GR. Tagged TO at 10566 ft WLM, 10591 corrected Last Downhole Op: 06/10/06: BnF/HOT -7 380 bbls oil increase Latest H2S value: None anticipated B 1-18 is a Badami producer in the F5 fan lobe. This well is slated to become an injector, /" but before that happens, all possible oil must be produced. Increased production may be achieved through adperf and reperf potential by accessing additional reservoir above and below the existing perforations. The history states that a fracture job was completed in April and August of 1998. This likely opened up additional reservoir, so adperf and reperf operations may have minimal effect on rate. As outlined in the history, B1-18 responds well to Brush and Flushes to remove paraffin buildup. A recent tag, 06/10/06, showed there is possible fill built up over the existing perforations (10,396' - 10,416' MD). This may lead to complications in perforation operations. If fill is not an issue and the gun is able to reach the required perforation depth of 10,426' MD, then shoot using a 30' gun. ) ) If fill partially covers existing perforations and the adperf zone, bail until a minimum depth of 10,420' MD and shoot with a 30' gun. Do not worry about the 6' of perforations that will be shot high, but please do not shoot above 10,390' MD. Please note that the adperf and reperf interval is dependent on the tag depth. In /" the event that the drift is unable to access the entire proposed perforation interval (10,396-10,426'), the proposed adperf and reperf interval may have to be raised, shortened or put on hold entirely. For questions or comments please call Carolyn Kirchner at 564-4862 (w), 345-0336 (h), or (603) 781-4062 (cell). Abbreviated Historv 01/06/06 Tag @ 10357' (SLM) w/ 3.805" GR to 2180'. 12/21/05 BnF-->65 bbls oil increase. 12/20/05 Attempt to pull OGL V at Sta. #1. 01/29/05 Tag @ 10422'. 12/07/98 PBU: Set gauges @ 8611' md, XN nipple. 08/16/98 Frac 08/08/98 Tag TO @ 10591'. 04/20/98 Frac: 10396-10416'. 04/17/98 Perfs (Initial): 10396-10416'. /' P roced u re: Slickline: 1. MIRU 2. Drift with dummy gun to perforation depth. Determine what interval will be shot based on tag depth. Bailing may be required at this stage. E-Line: 3. Rig up E-Line 4. Shoot either 20' or 30' (preferable) gun. Do not shoot perforations above 10,390' , MD. / 5. Move off. ) ) RT. ELEV = 54,8' BF. ELEV = 19,5' MAX. DEV. = 30 @ 6754' MD TREE: 4-1/16" /5000 psi / CIW WELLHEAD: 13-5/8"/10000 psi / FMC 81-18 13-3/8" 68#1ft L-80, BTC. CSG, I 4550 I ~... ~ . HES HXO Safety Valve Nipple 10 (3,813") [illI] 4 1/2" L-80 IBT MOD 12,6#1ft Tubing ... Gas Lift Summary Cameo 1" KBG-2-LS GLM MD TVD DEV Ö 3022 2963 0 [l 5 4042 3983 0 4 5676 5614 9 3 7466 7218 29 2 8312 7994 14 1 8505 8180 14 ~ Z HES TNT I 85731 Permanent Packer U HES X Nipple 9CR 185901 10 (3.813") HES XN Nipple 9CR ~ 10 (3,750") WLEG I 86231 ELMO D ~ tZI 7" X 4 1/2" Liner 187071 Hanger Packer Deviation @ perfs 8 degrees Perforation Summary: MWD 3-27- 98 Date Interval Status 7" 29#1ft P11 0 ~ .... ~ BTC CSG Shoe .... 41/2" L-80 BTC Mod Liner 4-17-98 10396-10416 Fraed PBTD 10640 Casing Shoe 10724 DATE REV. BY COMMENTS JTP Update Information BADAMI WELL B1-18 PERMIT # 98-12 API # 50-029-22857 3-30-99 8P EXPLORATION, INC. Well Compliance Report File on Left .side of folder 198-012-0 BADAMIUNIT Bl-18 50- 029-22857-00 BP EXPLORATION ~///7/~ MD 10724 ~ TVD 10423 - Completion Date: 4/¢/¢8 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D D 8423 ~ SPERRY MPT/GR/EWR4 OH 5/4/98 5/5/98 L 4 ARM CALIPER ~AL 8828-10726 ~.~Oo/~ 5 L CBL/GR/CCL ~F~L 8600-10603 ~10/~ 5 L CNTG ~FI~AL 8600-10603 ~/t~'/~ 5 L NGP/DGR/EWR4-MD F~' 6923-10726 L NGP/DGR/EWR4-TVD t..~'AL 6800-10423 L PERF ,.,F~L 8600-10603 Z 9038 ~'"~' SCHLUM CNTG Daily Well Ops X/~/~ -- Was the well cored? yes OH 5/4/98 5/5/98 CH 3/31/99 4/2/99 CH 3/31/99 4/2/99 OH 5/4/98 5/5/98 OH 5/4/98 5/5/98 OH 5/4/98 5/5/98 CH 5 3/31/99 4/2/99 CH 3/31/99 4/2/99 Are Dry Ditch Samples Required? yes ~_____~_ And Receive *07.--yes-_m~ Analysis Description Received?--~e~--my---~Shmpl~ Comments: Monday, May 01, 2000 Page 1 of 1 BP EXPLORATION Date: 3-31-99 Trans#90413 BPIBadami OPEN HOLE LOGS ~ ~' Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4636 Sw Name Rec Type. Rec Date Company Code Comments B1-18 CH 17-Apr-98 SCH PERFORATING RECORD B1-1@ CH 16-Apr-98 SCH CEMENT BOND LOG (CBT/GR CCL) B1-18 CH 15-Apr-98 SCH COMPENSATED NEUTRON LOG (CNT-G/GR/CCL) 'B1-18 TAPE 15-Apr-98 SCH MAIN & REPEAT CNTG PASSES 'LDWG FORMAT' Please sign and return one copy of this transmittal. Thank-you, Scott LaVoie Petrotechnical Data Center OH LOGS Madellyn Millholland MB 7-1 AOGCC FINA DNR ECE1VED .,.,'_~ 07_. ~999 Petrotechnicai Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 STATE OF ALASKA ALASK,,~-~,.~IL AND GAS CONSERVATION CO~.MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: I--IOperation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing I--~ Repair Well [] Other 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3856' NSL 86' WEL, SEC 8, T9N, R20E, UM At top of productive interval 1296' NSL, 502' EWL, SEC. 9, T9N, R20E, UM At effective depth 2505' NSL, 3686' EWL, SEC 20, TgN, R7W At total depth 5179' NSL, 420' EWL, SEC 9, T9N, R20E., UM t5. Type of well: [] Development [] Exploratory [] Stratigraphic [-]Service 6. Datum Elevation (DF or KB) KB = 54.4' 7. Unit or Property Name Badami 8. Well Number B1-18 9. Permit Number / Approval No. 98-12 10. APl Number 50-029-22857 11. Field and Pool Badami Field/Badami Oil Pool 12. Present well condition summary Total depth: measured 10724' true vertical 10423' Effective depth: measured 10640' true vertical 10339' Casing Length Structural Conductor 80' Surface 4516' Intermediate 8822' Production Liner 2037' feet Plugs (measured) feet feet Junk (measured) feet Size Cemented 20" 260 sx Arctiset (approx) 9-5/8" 4208 sx PF 'E', 340 sx Class 'G' 7" 200 sx Class 'G' 4-1/2" 273 sx Class 'G' MD TVD 116' 116' 4550' 4545' 8855' 8575' 1O724' 1O423' Perforation depth: measured 10396'-10416' true vertical 10095'-10115' Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 @ 8623' Packers and SSSV (type and measured depth) HES TNT packer @ 8573' HES HXO SSSV landing nipple @ 2219' 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure RECEIVED S E? 2,9 1.9.98 Alaska 0il & 6as Cons. (;0mmtssi0rt Anchnrage 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 5. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 7. I hereby certify that the fo~goiD¢, is tru, e and~rrect to t,~_,best of my knowledge Signed MICHAELWlLLIAMS'~~.~~~~.,~ j~ TechnicalAssistantlV Prepared By Name/Number: Date Submit In Duplicate Form 10-404 Rev. 06/15/88 08/16/98 B1-18 DESCRIPTION OF WORK COMPLETED FRAC Operations Performed a Data Fracture using the following fluids: SUMMARY The well had a previous 800 bbl data frac in April 98. Two 300 bbl data fracs were pumped this time. 181 Mlbs of 20/40 proppant were pumped for the frac. The frac was pumped to flush and saw no tip screenout. The equipment was barged out on a Crowley barge with no problems. Problems with the tree saver delayed the job a day. The first tree saver had proppant in it and the bore was scored preventing it from setting. The second probably got scored on the internals of the tree. There are parts of two rubber cups left in the well. A leak in the Tanko open top tank caused another day's delay. This is the only supplier on the slope that could supply an open top tank, and they are probably not worried about quality. Other Tanko tanks on the pad have also given problems. Intended to run the new Spartek 1" memory gauge from Halliburton in the bottom GLM. But tere is a legal case on copyright infringement against Halliburton, so called it oss at the last minute when we discovered this. The second data frac was pumped as the first showed poor gel quality when pumping. The base viscosity was 52 cp when mixed. Due to delays it was in the tank a day and the viscosity degraded somewhat to 45 cp. It tested OK but when pumped, the quality was poor. Xlinker was at 2 gptg. More tests were run with x-linker at 3 and 4 gptg. 3 was strong, 4 was too much and resulted in a weak gel. Pumped the second data frac and the frac with 3 gptg. The first data frac gave a leakoff of .0023, the second gave a leakoff on .0033. A design was done on the second for 142 Mlbs proppant. The pad volume was deliberately conservative. Because of the day's extra delay between the data frac and frac, we pumped 150 bbls of seawater before the pad as a cooldown. We pumped it at 20 bpm and this was probably a mistake. I believe it acted as partial extra pad. Coupled with the conservative pad design, we didn'd achieve tip screen out. With the 9ppg stage on the perfs, the Nolte (calculated from surface pressures and hydrostatic) showed unconfined growth. It is possible the frac hit additional sand, or a fault. Height growth is also possible. Pumped all the excess sand in the silo and got to 181 Mlbs before calling flush. Got 170 Mlbs behind pipe, left 2600 lbs in the liner, approx 270 ft of fill. Expect tag at 10370 ft md bkb. Fluids Pumped BBLS. Description 1225 Inj Test & Data Frac 78 50# x/1 gel pad 97 dirty 1 ppg to 6.6 ppg ramp up 1400 Total Pumped STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG REVISED 10/05/98 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 98-12 398-057, 398-099 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22857 4. Location of well at surface ~ ; ;;,,.,'i!:i. ii':?~i~' '! 9. Unit or Lease Name 3856' NSL, 86' WEL, SEC. 8, T9N, R20E, UM i '~" ~:" ~ ~~ Badami At top of productive interval ......... ~ ~% ii 10. Well Number 1296'NSL'502'EWL'SEC'S'TON'R20E'UM i 'i!:~(!~ i ~'~-'~'~I BI-18 At total depth .._ ~~i 11 Field and Pool 5179' NSL, 420' EWL, SEC. 9, T9N, R20E, UM ~'~'-'%'~ .... -..-~... ;:~-7- '~'~' ;~ ' Badami 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 54.4'I ADL365533 12. Date Spudded3/6/98 I 13' Date T'D' Reached i 14' Date C°rnp" Susp" °r Aband'l15' Water depth' if OffshOre I 16' NO' Of cOmpletiOns3/27/98 4/17/98 N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 10724 10423 FTI 10640 10339 FTI []Yes []No! (nipple) 2219' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD/GR/RES, GR/Temp f/WLTD, LWD, RFT/GR, CBL/CNT-G/GR 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1 # H-40 36' 116' 24" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 34' 4550' 12-1/4" 4208 sx PF 'E', 340 sx 'G' 7" 29# USS95 33' 8855' 8-1/2" 200 sx Class 'G' 4-1/2" 12.6# L-80 8687' 10724' 6" 273 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 8623' 8573' MD TVD MD TVD 10396'-10416 10096'-10116' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH iNTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 137 bbls diesel 27. ~RODUCTI~N TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) August 27, 1998I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAW~'-API (CORR) 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. Form 10-407 Rev. 07-01-80 Submit In Duolicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Top Badami Sand K3 10094' 9795' Top Badami Sand F5 10280' 9980' Bottom Badami Sand F5 10425' 10125' 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 (,¢,/~I,¢~ Signed -~ -~/~4~ Title Badami Drilling Team Leader Date Mike E. Miller B1-18 98-12 398-057, Prepared By Name/Number: Carol Withey, 564-4114 Well Number Permit No. / Approval No. 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 JUL Z4, i99~ STATE OF ALASKA ~AI_ASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL or Operator BP Exploration (Alaska) 3, Address P.O,Box 1966 ! 2, Anchorage, Alaska 99516-6612 Location of well at surface 3866' NSL 86' WEL SEC. 8. TeN, R2C~, UM Af fop of productive ~terval 1296' NSL ~02' EWL SI:C 0. TeN. R20E UM At effective depth At total depth 5179' NSL, 420' EWL SEC 9, T~N. R20E, UM Present well condition summary Type o¢ well: J~-JOeveloprnent J~EXPloratory ~---'-JStratlgraphlc J~serv!ce J~'~Perforate Datum Elevatlon (DF or KB) KBE = 7, Unit or Property Name ~ADAMI 8, Well Number B1-15 9, Permit Number 98-12 10, APl Number .~0-029.22857 1 I. Field and ~ool Badaml Field / Bad.m! 011 Pool Total depth: measured 10724 {eot true verrcal 10423 feet Effective depth: measured 10640 feet true vertical 10339 feet Plugs (measured) Junk (measured) Casing Length Size Structural Conductor 8(7 20' Surface ~516' 9-5/~" Intermediate ~22' 7" Production Uner 2037' 4 1/2" Cemented MD ~ 2~ ~x Ar¢fiset (approX) 116' 116' 4208 ~x PF 'E', 340 sx Cla~s 'g' 45,50' 4545' 200 sx Class 'G' ~855' 8575' 273 sx Clas~ Perforation depth: measured 10396- 1041h Tubing (size, grade, and measured depth) 4 1/2" 12.64t 1-80 at $623'MD Packers and ,SSSV (type and measured depth) 10724' 10zi23' HES TNT packer a~ 8573'MD H~$ HXO $SSV landing nipple at 2~, 19TvlD 13. Attachments XL JDesortption summary of proposal L~ Detailed operations program ~--~BOP sketch 14, Estimated date for commencing operation J 15. Status of wel~ classifications as: 08/0 !/~8 propo,ol was verbally approved ] b~oll E~¢a, r-~suspe,,d~d I Name of approver Dote ~pprovedJ. 8ervlae COnta=t EnCneer Nome / Number: Pot Collins 564-4363 ~e~cred By Nome/hlt~mloe~. Pat Collins 564-4363 ¢ that the Core ;}olng Is true and correct to the best of my knovAedge Conditions o~ Aoprov~: Nogfy Commission so represeht~ve may wl~e~ Plug Int~gd~ BOP Test Loca~on clear, ce Mech~lc~ Jnfegd~ Test Sub. quit form required ~ ~ Approved by order of ~e ~mmlsslon ORIGIN~ 8IGN~D.~ Comm~oner ro,m I0-~o~ ~v. 06n s/8~ Ro~d N. Chds~nj~ Submit In Triplicate Memo~ndum To: L Purdom / R. Warner WSA Team Leader Date: July 20, 1998 From: P.Collins AND PE Subject: BADAMi B1-18 Frac Pro0_ramme B1-18 was completed with a 4 '/~" cemented liner on 4/6/98, A data frac was conducted on 4/20/98, but a frac was postponed when the ice road went out, This programme is an update of the programme used then. Frac equipment will be barged from West Dock, Water will be drawn from the lake and heated by a hot oil truck, 2% KCI will be added to the water and mixed on the vac truck. The CTU will be barged out after this and Bl-11a fracs are done if cleanouts are necessary. PTS frac separator will be barged out shodly before startup, 1. Pull the BPV and XN plug. 2. Pull the bottom GL dummy and run a Spartek 1" memory gauge. 3. Pump a 300 bbl data frac. 4. Redesign and pump the frac. Initial calculations give 82,000 lbs 20/40 proppant, 5, Conduct a CTU cleanout if necessary. 6. Pull the Spatrek gauge. 7. Leave the well freeze protected for startup 8. After startup, flow the well back through lhe PTS flowbaok separator to clean up proppant. 9. Once the well has been cleaned up, and a welltest obtained, more perforations will be added. These will be on a future programme. The Deviation across the perforated interval is 5°, at an azimuth of 74°. Attachments to this program include: Well completion diagram and minilog. Detailed data frac and propped frac program. Design of Slurry Schedule for Tip Screen-out Fracture Technique. Tubing Movement Calculations for Well El 1-18. PC cc S.Benoit Wellfile Badami B1-18 Frac proceedure Attention ' Bob Thayer / Wes Wilder Preliminary Work 1, Pressure test and grease lock Master and Wing Valve. 2. DO NOT EXCEED 8,500 surface pressure. Pre -Frac Treatment 1. Pull BPV and XN plug. Pull the dummy can lift valve from the boffom station. Run a Spadek 1" memory gauge and set in the mandrel. Haltibu~on will provide the gauge and running tools. Programme it to cover the data frac and frac. 2. Pressure test annulus to 5,000 psi. 3. Equipment will be brought out by barge from West Dock. Rig up equipment so that B1- 18 and B1-11 a can be done without moving units. 4. Water wilt be sucked from the lake by vac truck. KCI is available in 55 lb sacks from Badam[ drilling and can be sucked onto a partly filled vac truck before being topped ~p. Keep the vac truck agitated. Water will be heated to 90OF using a hot oiler, Heating can be done before or after KCL is added, as convenient. The water should be pumped into DS tiger tanks via a 3 ~m filter. Hydraulic Fracturing Procedure Badami F5 Objective: To create a frac of 250 feet Xfin the Badami F5 sand, Pump injectivity test and datafrac followed by the main fracture treatment. Rig up and stab tree saver, (4" Cameron tree, 4 1,~,, L-80 tubing). The friction pressure is estimated to be 873 psi at 20 bpm, with a surface pressure of 5,009 psi for pad using a fracture gradient of 0.85 psi/foot and a near wellbore friction of 500 psi. Azimuth = 740 Deviation: 5° 2) Pressure test surface lines to 10,000 psi. Expected treating pressure is between 4,000 and 8,000 psi. Observe trip-out of each pump. After verifying the pump trips, reset the trips to 200 psi above maximum treating pressure, 8,500 psi. 3) Perform injectivity test: Bullhead 100 bbls of crosslinked gel down to perforation top at 5 bpm. With gel at the perfs, bring the rate up as fast as possible to 20 bpm. Displace injectivity with 30 bbls of 50# linear gel followed by 2% KCI with friction reducer. Over displace all gelled fluid into the peris by 5 bbls. Shut down and monitor the surface pressure for at least 15 minutes. If the near wellbore I'~U. JU!D f. O/{-,LI' friction is > 1,000 psi pump a large fluid slug - 50 bbls and flush. Monitor the decline, if near welibore friction still high, repeat the procedure. Look at both the value and the rate of change of the near wellbore friction. If, required a proppant slug will then be pumped, see Table 1 berow. Once near welibore friction is ~-500 psi proceed to Datafrac. Note: Have sufficient fluid on site to flush cross linked fluid slugs. 4) Perform 300 bbl Data frac with crosslinked fluid; Pump data frac down to perforations at 5 bpm. With gel at the perfs, bring up rate as quickly as possible to 20 bpm, Over displace data frac by 5 bbls. Displace the data frac with 30 bbl 40 # linear gel followed by 2% KCI water. Stop pumping and monitor the pressure decline, Transmit the data to Anchorage for interpretation, 5) Discuss closures and leakoff with town. Redesign the TSO. Pump 90,000 lbs fracture treatment at 20 bpm per modified ramp. 7) Freeze protect the tubing with 30 bbls diesel, Table 1 Volumes Volume to Top Perfs 160 bbls Under Flush 5.0 bbls Flush 160 bbls Post- Frac Treatment 1. Determine proppant top with slickline if necessary. 2. If a clean out is necessary, it will be done once B1-18 and 1 la fracs are complete and the frac equipment out of the way. A CTU will be barged from West Dock. An additional programme will be prepared if the operation is necessary. 3. Pull Spartek gauge and replace dummy. 4. A PTS flowback will be barged to location prior to startup. After startup, flow the well through the separator to clean up proppant. A separate procedure will be sent for this. Well will be produced for 2 to 5 days to clean up of the frac. ATTACHMENT 1: Pre-frac Diagnostic Tests PR..OPOSE.D Jadami Bl-18 FET'.s . · ..... FL[JiD RATE VOI~UME VOLU'ME TOTAL ....... STAGE TYPE {CPM) (_G_ALS) {BBLS) (B,.B. LS) REMARKS ....... lnjectivity 50 # x-I~nked ge! 20 4,200 100 100 Datafrac 50 # x-linked gel 20 12,600 300 400 , Totals: ........ '~6~,8._00 ', 4~? '. ; ' ' FLUSH ALL STAGES WITH SOft UNEAR GEL & Kcl with friction reducers as outlined in the procedure * Add bacteflacide and surfactant to 2% KCl, ATTACHMENT 2 PROPOSED Badami B f , f 8 FRACTURE TREATMENT Slurry Rate Clean VoL Clean Vol. St"ge Time Fluid Proppant Total ..... Stage SlUrry Cur~ Slurr~ STAGE (bpm) (gals) (bbls) (rain) Type Type. Pmppant (bbls) (bbls) Pad 20 9,000 2~4 10.70 YFISOD none 0 214.00 214.00 * 1 20 3,600 86 4.50 YF150D 20/40 Carb 3,599 89.60 304 2 20 2,500 "60. "' 3.20 "YF15'0D, 20/40 Carl) 4,999 64~90 36.9 3 20 2,000 48 2.70 YF150D 20/40 Carb 5,999 $4,10 423 4 20 2,000 48 2...80 YF150D 20140 Carb 7,998 .....56.20 479 5 20 , 2,000 .48 2.90 ..YF150D 201.40 Carb 9,998 .....58.40 537 , 6 20 2~000 .4.8 3.00 YF150D 2 0140 .. .Ca rb1.~,997 60.50. 598 .. , 7' , 20 2,500 60 3.90 .yF150D 201d0._C_arb .17,496 78,40 676 8 20 2,500 60 4.10 YF150D 20140 Carb 20,000 81.10 F-lush 20 940 '22 ...... 1.10 40~ gel ~,,~ne" ,,, 0 "2~.40 ,,, 78~)" Totals" 29,040 "69~ ..... 38.90 82..~86.Q0 77t).60 780 YFf SOD DELAYED BORATE F~.UID SYHTEM SHOULD CO~t. TA(N THE FOLLO. I/VING ADDIT;IVEST. Crosslinker L-10 BREAKER J-2~8 and J-475 Bactericide - M-275 Activator J-899 Surfactant F-75N On 50~1 gel flush stage; simply cut the L-t0 and J-899, .. Breaker schedule J-~75- J-218 Injectivity, Datafrac & Pad 1.0 ppt 0 ppt Stages 2 to 6 (ramp) 2 -5 ppt 0 ppt Stage 7 & 8 6 ppt 0.5 ppt Fluid Loss Silica Flour Adomite Regain 45 ppt 40 ppt 0 0 0 0 tubing Movement Calculalions for Well B1-18 Anchoret L80 Tubing ~iston & Plug_ Elfect .... 8allotting Eff~t pressure .~foss Packer -L_pr = -73,15 inches -L_bal = 14,14 ~nche 'P = -52T9 psia (up) 'F_pr = -76740 lbs -F_bal = -14835 lbs Pressur.~ Buckling Temperatur, e Effect F_tp = '87422 lbs (up) -L_hb = 0,00 Inches 'L_tmp = -24,32 inche F_pc = -182621 lbs (up) 2 Sldngs Ver 3.2d 1'oral Length Chanqe 0 inches 0.0 ~eet ii ii ii tubing -> packer fore packer -> casing for( n = 0 feet 'FJ'mp' = 25517 rbs Minimum. D.esign Factor.' 1.55 VME S,?n_g ! ! Input, ail striCtUre to I~ottom for Instruction's) Options: ("X" to select) ' J' 90 Final Surfac~ T~mp,' (~l~'i '" II- Jo.ore Pipe TOlerance f~)r '~~lJJl~l~k to use APl Tolerance 8.500 Final Applied Tubing Pressure(ps~lx Anchored Tubing (Leave Blank for Floartlng/Plnned tubing 5000 Final AppJied Annular Pres.sure (psi) 13Cr Tl~ank fo~ L80. Use Tubing option to d~llne o'[her lubing) 50 Initial SurfaceTemperc~ure (°F) Il Tubing(type) ~ B~ IJ~ 5000 Initial Applied Tbg, Pressure (psi)ii Sour Servfce (Leave B~ank for Sweet Sewice) 0 Initial Applied Ann. Pressure (psi)ii Mechanical set Completion (Leave Bank for J-lydrau [c Set) 3.875 Packerseal bo re diameter (in) JJ Plug in Tailplp.e Pbe!ow plugL__.~psia ~krSetj x ~ 0 SIc~ckoff (lbs) -Compress.. +Tension Pinned at J lbs ~ve b,!ank f,.or Free tvlovement) SITing l j String 2 JSlring 31 .... 2 i~rings ! Design Fa~tors at T~p an~ Bofto~n of Each ~tring ' 2D00J 82531 JTVDbottom(ft) I SJT " J.7~'lTe'~s ' 2.09J~ens 3.79 J~'ens 5.68 3.9.~8i 3.9.58j JTbgI.D.(in)I~IS,r.~ 2.41 Jaurst 2.07JBurst 2.41 JBurst 2.07 4.51 4.5J ITbg O.D. (in) j jCollar NIA ICe,lap NJA ICo~la[ N/A jCollar N/A 0001 8cx 0! ITbg ~d(p~i) I ~ ~.66 V~E ~.36 VME ~.22 12,6J 12.6J JTbgWeighf(Ibs/ff) SJTens 2,09 jTens 4,8.5 JTens 5.68 JComp 10.25 6. i84j 6.~84J JCa~,g,.D.(~n) IT[Burs, 2.07ll~urst ~.62JB~,sr 2.aTJBurst ].62 ~2.81 12,~l Jbs/goltbg Jicol~ar N/A ICollap N/Aico, r NtA ica,ar N/A 7,21 8.7~ Ir'~°~lbs/gal tbg I ~IVME,?.66 IVME ~.74 IVME 2.22 IVME __1.49 7' l IFinallbs/gajO'"I slT "" JJens JComl~ Jcomr: ...... 7.21 8.7J Jlnltlal lbs/gal ann J J [Burst I~.r~ I,.~ ISurst ' 9sI ]10J bat Te~p C°~) ICoila~ ice,rap JColla[ [Collar 50r 1841 Jrni~albotTemp("FI3~M~~E ._ _____J~ME~E 0t 01 ~-P friction Cpsl/MYr) -1- ~ -~'~m---~ Top'-'--'~-'"--~ ~ _ 0l gl ._J Dogleg ,) II ' Den°tes,,D~'~!gn Factors I~. I°w BP':; Su,ggested MJn'J~um BPX Suggested design minimums j~.LOad capacity Te~'~lon 1.50' ' 'Load capaoily CollapSe "1.10 vME (sweet ~ervice) 1":25J cad capacity Comp~e: 1,20 Load capa..c, ity Burst 1.30 VME (.s~. ur service) 1,3..3. j N0fe: Tubing rr~verTlen-i-~alcL~iafil~n.~ 'ar'e fr~m tt~e BP Completion D~sign Man~al VOlume'il ' ' ! ,) For Anchored tubing, weak link is top of tubing or Anchor Seal: keep Tension and VME factors above minimu :2,) i:or Floating .seal assembly over slipsfil~lmap Tolol negative Lenglh Change << Slipstick Lenglh 3,) For Pinned seal assembly over slipstick pins will shear and tubing wllJ rtiS_~if> Pin $ffenglh ' C Well: B 1-18 i I i · z= ~EDP 1 V~H ~1~ MIRROR ,, , ~, 1, i ~ 10200 - - .. ...... ~r ~o~oo ....... Kelly bushing ~o wellhead Conductor H.40 20.000 19,124 91.5 116.0 61.6 IL-80 IBT-MOD Production Tubing 4.500 3.9S8 12.6 HES "HXO" ..e,a, tety Valve Landing Nipple 4,500 3.813 2218.6 2159.6 Surface Casing L-e0 9,625 8.83,6 40 4550,0 4490.8 Camco 4 1/2" x 1" GLM 3022.2 2963.0 Camco 4 1/2"x 1" GLM 4042.0 3982.8 Cameo 4 1/2"x 1" GLM 5676.4 5614.3 Camco 4 1/2"x 1" GLM 7466,3 7217,6 Camco 4 1/2" x 1" GLM 8313,0 7993,8 Camco 4 1/2"x 1" GLM 8505.3 1~180.$ HES 'q'NT" Permanent Packer ~;.a75 3.958 8573,3 8346,5 HES "X" Landing Nipple 3,813 8~90.3 82~.0 HES '3(N" Landing Nipple 4,500 3.725 8610.8 8282.9 Wireline Entry Guide 5,250 3.959 8023.1 8294.7 7"x 4 1/2" Liner Henger/Pa~er 8707.0 8376.3 Interrnedia[e Casing USS 95 7.000 8.184 29 8855.0 8520.7 Top Pert 10396,0 10041.1 2,7/g"HSD 38C CP RDX 8 ~pf, 60 degree phasing Boltom Porf 10416.0 10061.1 PBTD 10640.0 10284.7 Production Casin g L-80 4.500 3,958 12.8 10724,0 10368,6 Dale Rev by Commenls ... o~'/ B,Turnbull Inillal design ~/o-z~ B.Turnbull Revi~ed direclionsl plat1 14/o4/~ B.Tumbull As buill 2~/o4/es B.Turnbull Post peff/dal~ ~fao , · ,JUL A~aska 0il & Gas C~s. Co,m, mis~9~ 09:20 ~1/07/.~ To: S.Benoit From: Subject: P.Collins AND PE Date: July 22, 1998 BADAMI B1-18 Post Startup Perfo. ratlon Proqrammn B1-18 has a frac programme awaiting completion. The F5 amalgamated sands will be fracced. After startup, the well will be flowed through a PTS separator to clean up. Once a welltest has been obtained, more perfs will be added as detailed below. 1. Run a TD tag to determine proppant fill. 2. Perforate 10416 - 10424 ft md bkb 8' 10388 - 10396 ft md bkb 8' F5 amalgamated F5 amalgamated 3. When the WHT has stabilised, obtain a welltest. Perforation should be with 2 %" guns, 6 spf, 60/180° phasing, Predator deep penetrating charges. Perforation should be underbalanced with the well flowing at a Iow rate, choked back as necessary to prevent tool movement'. The Deviation across the perforated interval is 5°. PBTD is at 10640 ft MD bkb. Attachments to this program include: · Well completion diagram · Minilog PC cc L Koenn, Atlas Wellfile JUL, Well: B 1-18 lO//.~, ~.0200 ~0300 10500 IOSSO.O 0.= · Kelly bus;nine to wellllead Wellhead to (;;onductor H-40 20,000 19.t24 91.5 116,0 81_6 -L-80 IBT-MOD Produc'llon Tubing 4.,~00 3.9,58 12.6 HE$ "HXO' 8~fe~y Valve Landlng Nipple 4,600 3,813 2218.6 2159.6 Surface Gas'lng L-I~0 9,625 8.835 40 4550.0 4400.81 Oamo~ 4 1/2" x l" 61LM 3022.2 2963,0 Camco 4 1/Z' x 1" GLM 4042,0 3982.81 Camco 4 1/2" x 1" GLM 5676.4 5614.3 Qarnco 4 1/'2' x 1" GLM 7466.3 7217.6 Camco 4 1/2" X 1" GLM 8313,0 7993_8 Camco 4 1/2" x 1" GLM 850~.3 8180,5 HE$ "TNT" Permanenl Pa~er ~.B75 3.958 8573.3 8246.5 HE$ "X" Lending NIpple 3.813 85g0,3 8283,0 HE~ "XN" Landing Nipple 4.500 3.725 9610,8 8282.9 wrreline Enlry Guide 5,250 3,~S8 8623,1 8294.7 7" x 4 1/2~ Liner Hanger/Packer 8707.0 8376,3 Intermediate Casing U~S 95 7,000 6.184 29 8855,0 8~;20,7 Top Perf 10396.0 10041.1 2,7/8" HSD $8C CP RDX 6 spf, 60 ~groe phasing Bottom Perf 10416,0 10061.1 PI~TD 10840,0 10284.7 ~ ProduClion Casing L-80 4.500 3,958 12.6 10724,0 10368.6 Rev by Comments o~n~./s? ! B.Tumbufl Inllial design -- B,Tumbull Revised direcffonal plan B.Tumbutl As built B,Tumbull Post ped/daia linc ,, Withe)/, Carol L/NANA! From: Sent: To: Cc: Subject: Scott Bittner[SMTP:bittners 1 @ prudhoe-bay.wireline.slb.com] Friday, June 05, 1998 10:01 PM Stuart, Graham (Schlum) Withey, Carol L (NANA) Re: Badami B1-18 perf information Carol: The gun shot at B1-18 on April 17 was: 2 7/8" HSD 10396' to 10416' (20') 38C CP, RDX BigHole 6 shots per foot 60 degree phased 15 gram explosive load 0.62" entrance hole 8.38" penetration Scott At 04:09 PM 6/4/98 -0400, Stuart, Graham (Schlum) wrote: >Scott, >Could you please provide Carol the perforation information for this >well. >(interval,gun size/type/charge/spf) This is so she can close a report >for the State. >Graham > >Graham Stuart >WSA "electric" line co-ordinator >WSA home page BP intranet(under construction): >http://slb.nsprod.com >> Wsa home page SOS net work(under construction): >> http://www.anchoraqe.oilfield.slb.com >Connect Schlumberger: >Visit our Website at: http://www.connect.slb.com > >Room Mb1048b >Office (907) 564-5692 >Mobile (907) 250-0138 >Fax (907) 564-4637 (A4) or (907) 564 5530(rolling fax for logs >etc) >Mail Stop Mb 10-3 >WSA North Slope 24hr 1 907 659 2487 >WSA North Slope fax 1 907 659 2486 Scott Bittner District Manager Schlumberger Well Services Prudhoe Bay, Alaska (907) 659-2487 Page 1 Progress Report Facility Badami CPF Well B 1-18 Page Rig Nabors 28E Date 02 June 98 Date/Time 04 Mar 98 15:00-16:00 16:00-19:00 19:00-20:30 20:30-23:00 23:00-00:00 05 Mar 98 00:00-00:30 00:30-02:30 02:30-04:30 04:30-06:00 06:00-09:00 09:00-11:00 11:00-14:00 14:00-15:30 15:30-16:30 16:30-21:30 21:30-00:00 06 Mar 98 00:00-00:30 00:30-01:30 01:30-03:30 03:30-06:00 06:00-06:30 06:30-08:30 08:30-06:00 07 Mar 98 06:00-10:30 10:30-11:00 11:00-11:30 11:30-13:00 13:00-14:00 14:00-15:00 15:00-06:00 08 Mar 98 06:00-14:15 14:15-15:30 15:30-17:00 17:00-18:30 18:30-04:30 09 Mar 98 04:30-06:00 06:00-09:00 09:00-11:30 11:30-12:00 12:00-12:30 12:30-18:45 18:45-23:30 23:30-00:00 lOMar 98 00:00-00:30 00:30-01:30 O1:30-02:15 02:15-03:00 03:00-06:00 06:00-08:00 08:00-12:00 12:00-12:30 12:30-13:00 13:00-17:00 17:00-17:30 Duration lhr 3hr 1-1/2 hr 2-1/2 hr lhr 1/2 hr 2hr 2hr 1-1/2 hr 3hr 2hr 3hr 1-1/2 hr lhr 5hr 2-1/2 hr 1/2 hr lhr 2hr 2-1/2 hr 1/2 hr 2hr 21-1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr lhr lhr 15hr 8-1/4 hr 1-1/4 hr 1-1/2 hr 1-1/2 hr 10hr 1-1/2 hr 3 hr 2-1/2 hr 1/2 hr 1/2 hr 6-1/4 hr 4-3/4 hr 1/2 hr 1/2 hr lhr 3/4 hr 3/4 hr 3hr 2hr 4hr 1/2 hr 1/2hr 4hr 1/2hr Activity Rig moved 0.05 % Rig moved 25.00 % Rig moved 25.00 % Rig moved 25.00 % Rig moved 25.00 % Held safety meeting Rig moved 50.00 % Rig moved 75.00 % Rig moved 80.00 % Rig moved 100.00 % Installed Fluid system Installed Additional services Installed Kelly Rigged up Rig services Rigged up Bell nipple Made up BHA no. 1 R.I.H. to 58.0 ft Held safety meeting Circulated at 58.0 ft Drilled to 225.0 ft Laid down 186.0 ft of 5in OD drill pipe Made up BHA no. 1 Drilled to 1502.0 ft Drilled to 1721.0 ft Circulated at 1721.0 ft Pulled out of hole to 1112.0 ft Pulled BHA Made up BHA no. 2 R.I.H. to 1721.0 ft Drilled to 3070.0 ft Drilled to 3854.0 ft Circulated at 3854.0 ft Pulled out of hole to 1112.0 ft R.I.H. to 3854.0 ft Drilled to 4563.0 ft Circulated at 4563.0 fit Pulled out of hole to 1112.0 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 4550.0 ft (9-5/8in OD) Circulated at 4550.0 ft Held safety meeting Pumped Water spacers - volume 70.000 Mixed and pumped slurry - 205.000 bbl Displaced slurry - 318.000 bbl Circulated at 2180.0 ft Circulated at 2180.0 ft Ckculated at 2180.0 fit Rig waited' Equipment Held safety meeting Pumped Water spacers- volume 110.000 Mixed and pumped slurry - 1250.000 bbl Displaced slurry - 165.500 bbl Progress Report Facility Badami CPF Well BI-18 Rig Nabors 28E Page 2 Date 02 June 98 Date/Time 17:30-19:00 19:00-22:00 22:00-03:30 11 Mar 98 03:30-04:30 04:30-05:30 05:30-06:00 06:00-08:00 08:00-10:00 10:00-12:00 12:00-15:30 15:30-19:30 19:30-22:30 22:30-01:00 12 Mar 98 01:00-02:30 02:30-06:00 06:00-15:00 15:00-21:00 21:00-21:30 21:30-01:00 13 Mar98 01:00-01:30 01:30-02:00 02:00-03:30 03:30-04:30 04:30-05:30 05:30-06:00 06:00-07:00 07:00-08:00 08:00-09:00 09:00-05:00 14 Mar 98 05:00-06:00 06:00-07:00 07:00-08:00 08:00-09:00 09:00-06:00 15 Mar 98 06:00-06:30 06:30-07:45 07:45-12:30 12:30-17:30 17:30-06:00 16 Mar 98 06:00-22:30 22:30-23:30 23:30-02:30 17 Mar 98 02:30-03:30 03:30-05:30 05:30-06:00 06:00-09:30 09:30-06:00 18 Mar 98 06:00-03:00 19 Mar 98 03:00-04:00 04:00-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-07:30 Duration 1-1/2 hr 3hr 5-1/2 hr lhr lhr 1/2hr 2hr 2hr 2hr 3-1/2 hr 4hr 3hr 2-1/2 hr 1-1/2 hr 3-1/2 hr 9hr 6hr 1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr lhr lhr 1/2 hr lhr lhr lhr 20 hr lhr lhr lhr lhr 21hr 1/2 hr 1-1/4 hr 4-3/4 hr 5hr 12-1/2 hr 16-1/2 hr 1 hr 3hr lhr 2hr 1/2hr 3-1/2 hr 20-1/2 hr 21 hr lhr lhr 1/2hr 1/2 hr 1/2 hr lhr Activity Rigged down Cement head Removed Divertor Ran Tubing to 545.0 ft (1-1/4in OD) Installed High pressure lines Circulated at 545.0 ft Pulled out of hole to 450.0 ft Pulled out of hole to 0.0 ft (cont...) Ran Tubing in stands to 500.0 ft Circulated at 500.0 ft Mixed and pumped slurry - 230.000 bbl Wait on cement Ran Tubing to 140.0 ft (1-1/4in OD) Mixed and pumped slurry - 100.000 bbl Installed Casing head Installed BOP stack Installed BOP stack (cont...) Tested BOP stack Laid down 450.0 ft of 5in OD drill pipe Made up BHA no. 3 R.I.H. to 2177.0 ft Drilled installed equipment - DV collar R.I.H. to 4464.0 ft Circulated at 4464.0 ft Tested Casing - Via annulus and string Drilled cement to 4500.0 ft Drilled cement to 4588.0 ft (cont...) Circulated at 4588.0 ft Performed formation integrity test Drilled to 5985.0 ft Circulated at 5985.0 ft Pulled out of hole to 4550.0 ft Circulated at 4550.0 ft R.I.H. to 5985.0 ft Drilled to 6900.0 ft Drilled to 6924.0 ft (cont...) Circulated at 6924.0 ft Pulled out of hole to 0.0 ft R.I.H. to 6924.0 ft Drilled to 7465.0 ft Drilled to 7867.0 ft Circulated at 7867.0 ft Pulled out of hole to 202.0 ft Pulled BHA Made up BHA no. 5 R.I.H. to 610.0 ft R.I.H. to 610.0 ft (cont...) Drilled to 8410.0 ft Drilled to 8865.0 ft (cont...) Circulated at 8865.0 ft Pulled out of hole to 7440.0 ft R.I.H. to 8865.0 ft Circulated at 8865.0 ft Circulated at 8865.0 ft (cont...) Flow check Progress Report Facility Badami CPF Well B1-18 Rig Nabors 28E Page 3 Date 02 June 98 Date/Time 20 Mar 98 21 Mar 98 22 Mar 98 23 Mar 98 24 Mar 98 25 Mar 98 26 Mar 98 07:30-12:00 12:00-14:00 14:00-17:00 17:00-17:30 17:30-18:00 18:00-00:30 00:30-01:00 01:00-06:00 06:00-07:00 07:00-07:30 07:30-09:30 09:30-10:30 10:30-11:30 11:30-12:30 12:30-13:30 13:30-15:30 15:30-18:30 18:30-21:30 21:30-05:00 05:00-06:00 06:00-06:30 06:30-13:00 13:00-13:30 13:30-14:00 14:00-14:30 14:30-18:00 18:00-01:00 01:00-01:30 01:30-02:00 02:00-03:30 03:30-04:30 04:30-06:00 06:00-09:00 09:00-09:30 09:30-10:30 10:30-12:30 12:30-14:00 14:00-14:30 14:30-16:00 16:00-17:30 17:30-06:00 06:00-01:30 01:30-04:00 04:00-06:00 06:00-06:30 06:30-07:00 07:00-08:00 08:00-06:00 06:00-07:00 07:00-08:30 08:30-10:00 10:00-11:00 11:00-06:00 06:00-06:00 Duration 4-1/2 hr 2hr 3hr 1/2 hr 1/2 hr 6-1/2 hr 1/2 hr 5hr lhr 1/2hr 2hr lhr lhr lhr lhr 2hr 3hr 3hr 7-1/2 hr lhr 1/2 hr 6-1/2 hr 1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 7hr 1/2 hr 1/2 hr 1-1/2 hr lhr 1-1/2 hr 3hr 1/2 hr lhr 2hr 1-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 12-1/2 hr 19-1/2 hr 2-1/2 hr 2hr 1/2 hr 1/2hr lhr 22 hr lhr 1-1/2 hr 1-1/2 hr lhr 19 hr 24 hr Activity Pulled out of hole to 660.0 ft Pulled BHA Rigged up Top ram Held safety meeting Installed Casing handling equipment Ran Casing to 4540.0 ft (7in OD) Circulated at 4540.0 ft Ran Casing to 7in (7775.0 ft OD) Ran Casing to 8855.0 ft (7in OD) (cont...) Rigged up High pressure lines Circulated at 8855.0 ft Mixed and pumped slurry - 41.000 bbl Displaced slurry - 326.000 bbl Rigged down High pressure lines Installed Seal assembly Installed B ore protector Installed Kelly Laid down 6500.0 ft of Drillpipe Laid down 6500.0 ft of 4in OD drill pipe Rigged up High pressure lines Rigged up High pressure lines (cont...) Tested BOP stack Installed Bore protector Held safety meeting Serviced Drillfloor / Derrick Made up BHA no. 6 R.I.H. to 7000.0 ft Held safety meeting Held drill (Kick (well kill)) R.I.H. to 8730.0 ft Laid down 450.0 ft of 4in OD drill pipe Drilled cement to 8470.0 ft Drilled cement to 8470.0 ft (cont...) Circulated at 8767.0 ft Tested Casing - Via annulus and string Drilled cement to 8865.0 ft Circulated at 8865.0 ft Drilled to 8885.0 ft Circulated at 8885.0 ft Performed formation integrity test Drilled to 9091.0 ft Drilled to 9454.0 ft Investigated pressure change Investigated pressure change Investigated pressure change Drilled to 9478.0 ft Investigated pressure change Drilled to 9845.0 ft Drilled to 9876.0 ft (cont...) Circulated at 9876.0 ft Pulled out of hole to 8840.0 ft R.I.H. to 9866.0 ft Drilled to 10230.0 ft Drilled to 10700.0 ft (cont...) Progress Report Facility Badami CPF Well Bl-18 Rig Nabors 28E Page 4 Date 02 June 98 Date/Time 27 Mar 98 28 Mar 98 29 Mar 98 30 Mar 98 31 Mar 98 06:00-06:30 06:30-08:30 08:30-10:30 10:30-12:00 12:00-14:30 14:30-15:00 15:00-16:30 16:30-17:00 17:00-20:30 20:30-22:00 22:00-03:00 03:00-03:30 03:30-06:00 06:00-10:30 10:30-14:00 14:00-14:30 14:30-15:30 15:30-16:00 16:00-18:30 18:30-19:30 19:30-21:00 21:00-22:30 22:30-04:00 04:00-06:00 06:00-07:00 07:00-15:30 15:30-18:00 18:00-18:30 18:30-20:30 20:30-22:00 22:00-22:30 22:30-03:00 03:00-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-11:30 11:30-13:30 13:30-15:00 15:00-16:30 16:30-18:00 18:00-20:00 20:00-20:30 20:30-02:00 02:00-03:00 03:00-04:00 04:00-06:00 06:00-06:30 06:30-10:00 10:00-11:00 11:00-15:00 15:00-16:00 16:00-18:30 18:30-23:30 Duration 1/2 hr 2hr 2hr 1-1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 3-1/2 hr 1-1/2 hr 5hr 1/2 hr 2-1/2 hr 4-1/2 hr 3-1/2 hr 1/2 hr lhr 1/2 hr 2-1/2 hr lhr 1-1/2 hr 1-1/2 hr 5-1/2 hr 2hr lhr 8-1/2 hr 2-1/2 hr 1/2 hr 2hr 1-1/2 hr 1/2 hr 4-1/2 hr lhr lhr lhr 1/2 hr 5hr 2hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 2hr 1/2 hr 5-1/2 hr lhr lhr 2hr 1/2 hr 3-1/2 hr lhr 4hr lhr 2-1/2 hr 5hr Activity Drilled to 10724.0 ft (cont...) Circulated at 10724.0 ft Pulled out of hole to 8854.0 ft R.I.H. to 10724.0 ft Circulated at 10724.0 ft Flow check Pulled out of hole to 8855.0 ft Flow check Pulled out of hole to 1114.0 ft Pulled BHA Conducted electric cable operations Retrieved B ore protector Tested BOP stack Tested BOP stack (cont...) Rigged up Upper annular Tested Top ram Rigged down High pressure lines Rigged up Drillstring handling equipment Ran Drillpipe to 1953.0 ft (2-7/8in OD) Serviced Block line Pulled Drillpipe in stands to 1953.0 ft Installed Formation logs R.I.H. to 8810.0 ft Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Circulated at 1049.0 ft Flow check Pulled out of hole to 8810.0 ft Pulled out of hole to 0.0 ft Circulated at 8810.0 ft Pulled Drillpipe in stands to 50.0 ft Retrieved Formation logs Tested CDL-CNL-DLL-MLL-GR - Via string Conducted electric cable operations Conducted electric cable operations (cont...) Ran Drillpipe in stands to 8753.0 ft Serviced Block line Conducted electric cable operations Pulled out of hole to 8653.0 ft Repaired Formation logs R.I.H. to 8653.0 ft Circulated at 8653.0 ft Pulled Drillpipe in stands to 100.0 ft Conducted electric cable operations Ran Drillpipe to 1950.0 ft (2-7/8in OD) Laid down Drillpipe of 1000.0 ft Laid down 1950.0 ft of Drillpipe (cont...) Tested Top ram Made up BHA no. 7 R.I.H. to 10545.0 ft Washed to 10724.0 ft Circulated at 10724.0 ft Pulled out of hole to 950.0 ft Facility Badami CPF Progress Report Well B 1-18 Page 5 Rig Nabors 28E Date 02 June 91i Date/Time 01 Apr 98 02 Apr 98 03 Apr 98 23:30-00:30 00:30-04:00 04:00-06:00 06:00-07:00 07:00-07:30 07:30-12:00 12:00-13:00 13:00-14:00 14:00-16:00 16:00-17:00 17:00-19:00 19:00-19:30 19:30-21:30 21:30-22:00 22:00-03:00 03:00-04:00 04:00-06:00 06:00-11:00 11:00-14:30 14:30-15:00 15:00-00:00 00:00-03:00 03:00-06:00 06:00-06:30 06:30-09:30 09:30-10:30 10:30-12:30 12:30-14:00 14:00-15:00 15:00-16:15 16:15-18:15 18:15-21:00 Duration lhr 3-1/2 hr 2hr lhr 1/2 hr 4-1/2 hr lhr lhr 2hr lhr 2hr 1/2 hr 2hr 1/2 hr 5hr lhr 2hr 5hr 3-1/2 hr 1/2 hr 9hr 3hr 3hr 1/2 hr 3hr lhr 2hr 1-1/2 hr lhr 1-1/4 hr 2hr 2-3/4 hr Activity Pulled BHA Ran Liner to 2000.0 ft (4-1/2in OD) Ran Tubing to 2-7/8in (1894.0 ft OD) Ran Tubing to 2037.0 ft (2-7/8in OD) (cont...) Circulated at 2036.0 ft Ran Drillpipe in stands to 8850.0 ft Circulated at 8850.0 ft Ran Drillpipe in stands to 10724.0 ft Circulated at 10724.0 ft Pumped Water based mud spacers - volume 40.000 bbl Mixed and pumped slurry - 56.000 bbl Displaced slurry - 80.000 bbl Circulated at 10724.0 ft Tested Liner Circulated at 10605.0 ft Tested Liner Laid down 1250.0 ft of 4in OD drill pipe Laid down 7437.0 ft of Drillpipe Laid down 1894.0 ft of Tubing Retrieved B ore protector Ran Tubing to 8620.9 ft (4-1/2in OD) Tested Tubing hanger Removed BOP stack Removed BOP stack (cont...) Rigged up Wellhead integral components Retrieved Hanger plug Circulated at 8623.0 ft Set packer at 8573.0 ft with 5000.0 psi Tested Casing Circulated at 2200.0 ft Circulated at 2200.0 ft Installed Hanger plug Performance Enquiry Report Operator BP Exploration Date 17:09, 02 Jun 98 Page The analysis is from - 09:00, 13 Mar 98 - to - 17:30, 22 Mar 98 Programs in Result Table: B 1-18 Well Type Bl-18 Event Bl-18 Event Time From Time To Duration Description E.M.W.(equivalent mud weight) 09:00, 13 Mar 98 09:00, 13 Mar 98 0 hr 0 min Obtained leak off 13.8 17:30, 22 Mar 98 17:30, 22 Mar 98 0 hr 0 min Obtained required level of integrity 15.5 Hole Size MDR 8-1/2 6 Kelly bushing to wellhead (ft) Wellhead to sea level (ft) ! i~!'! : ;.::i..iifiiChi: : ~stft : rkb ss Conductor H-40 20.000 19.124 91.5 116.00 61.60 L-80 IBT-MOD Production Tubing 4.500 3.958 12.6 HES "HXO" Safety Valve Landing Nipp 4.500 3.813 2221.57 2162.53 Surface Casing L-80 9.625 8.835 40 4550.00 4490.77 Camco 4 1/2" x 1" GLM 3029.71 2970.53 Camco 4 1/2" x 1" GLM 4049.54 3990.34 Camco 4 1/2" x 1" GLM 5683.89 5621.70 Camco 4 1/2" x 1" GLM 7473.85 7224.06 Camco 4 1/2" x 1" GLM 8320.52 8000.93 Camco 4 1/2" x 1" GLM 8512.81 8187.63 HES "TNT" Permanent Packer 5.875 3.958 23-29 8580.50 8253.36 HES ,,X,, Landing Nipple 3.813 8591.43 8263.97~ HES "XN" Landing Nipple 4.500 3.725 8612.01 8283.95 Wireline Entry Guide 5.250 3.958 8623.11 8294.72 7"x 4 1/2" Liner Hanger/Packer 8707.00 8376.31 Intermediate Casing USS 95 7.000 6.184 29 8855.00 8520.66 Top Perf 10396.00 10041.13 2-7/8" HSD 38C CP RDX 6 spf,, 60 degree phasing Bottom Perf 10416.00 10061.07 PBTD 10640.00 10284.70 Production Casing L-80 4.500 3.958 12.6 10724.00 10368.61 Date Rev by Comments 12/1/97 B.Turnbull 'Initial design 2/26/98 B.Turnbull Revised directional plan 4114198 B.Turnbull As built 4/22/98 B.Turnbull Post perf/data frac STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of [~--~ Oil E~Gas E~] Suspended [---1Abandoned [~ Service BP Exploration (Alaska)~n¢. . ~ 3. Address 8. APl Number P.O. Box '1966'12, Anchorage, Alaska 995'1r:~-66`12 50-029-22857 4. Location of well at surface 19. Unit or Lease Name T9N R20E Sec 8; 1517' FN L & 86' FEL ~ ' ;I'I''I'! ~ ' i: i '.~ i~-' '~ _ ,~..,~,~,~.... At top of productive interval ; "S/~.~ ~ BADAMI ..~_/i i'ri 10. Well Numt~r T9N R20E Sec 9; 98' FNL & 327' FWL ~' 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Sedal No. Badami Field/Badami Oil Pool KBE = 54.4' amslI ADL 365533 3~998 ~7~ 998 ~998 ~a MSL I One 17.Tot~ ~pth (MD+~D) 118.Plug Back Depth(MD+~D) 119. Dire~ion~ Suwey 120. ~pth where SSSV set 121. ~ic~s of Pe~afr~t ~a 10724'MD~, 10423~D, I1~0'MD~,10~9~ I ~Yes ~No ~ MDI 1900' approx 22. Type El~tdc or O~er Logs mn 23. CASING, LINER AND CEMENTING RECORD CASING S~ING DEPTH HOLE SIZE ~.PER ~. GRADE TOP BOSOM SIZE CEMENTING RECORD AMOUNT PULLED 20' 91 · I~ ~0 Suda~ 116' ~a ~t~60 sx A~t ~" 40 I~ L~0 SuHa~ ~50' 12-114" 1~0 ~ PF 'E' 7" 29 I~ U~ g5 Suda~ ~5' ~1~' 41 b~ ~1~' 12.6 I~ L~0 ~07' 10724' 6' ~ ~ 15.8 ~ 24. Pedorafions open to Production (MD+~D of Top and ' 25. TUBING RECORD BoSom and intewal, size and number) SIZE DEPTH S~ (MD) PACKER S~ (MD) ~1~" 12.6~ ~0 8623' 8580' MD ~D MD ~D 10396' 10041' 10416' 10061' 26. ACID, FRACTURE, CEMENT SQUEEZE, ~C. 20' 2-7~" HSD 38C CP RDX, 6 spf, 60 degr~ phasing Dep~ Intewal (MD) Amount & ~nd of Matedal Used 10396' - 10416' Unpropped da~ frac; 1555 bbls gel nupii C Date First Produc~on Mekod of Opera~on (Flowing, gas Ii~, etc.) ~ W~ll shut in pending compl~on of sudace facili~ conslru~fion, Date of Test l Hours Tested Production For OiI-BBL Gas-Mcf Water-BBL Choke Size l Gas-Oil Ratio I I Test Pe~d Flow Tubing leasing Pressure Calculated Oi BBL :Gas-Mcf Water-BBL Oil Gravi~- APl (corr) Press.~ 24-Hour Rate 28. CORE DATA . Brief descrip~on of li~ology, porosi~, fractures, apparent dips and presence of oil, gas and water. Submit core chips. . . Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids Depth Depth recovered and gravity, GOR, and time of each phase. 31. List of Attachments 32. I hereby certifYlthat,t;he foregoing is true and correct to the best .of knowledge Title Bea,~mi Sub~ur/a,~ T~ Leeaor Date B1-18 98-099 Prepared by Name / Number:. Bill Turnbull 564-4662 We~l Number Pen'nit No./Approval No. 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 Kelly bushing to wellhead (ft) Wellhead to Conductor H-40 L-80 IBT-MOD Production Tubing HES "HXO" Safety Valve Landing Ni Surface Casing L-80 Camco 4 1/2" x 1" GLM Camco 4 1/2" x 1" GLM , Camco 4 1/2" x 1" GLM Camco 4 1/2" x 1" GLM Camco 4 1/2" x 1" GLM Camco 4 1/2" x 1" GLM HES 'q-N~' Permanent Packer HES '~(" Landing Nipple HES "XN" Landing Nipple Wireline Entry Guide 7" x 4 1/2" Uner Hanger / Packer Intermediate Casing USS 95 Top Perf 2-7/8" HSD 38C CP RDX 6 spf, 60 degree phasing Bottom Perf PBTD Production Casing L-80 Date Rev by Comments 12/1/97 B.Tumbull Initial design 2/26/98 B.Tumbull Revised directional plan 4/14/98 B.Tumbull As built 4/22/98 B.Turnbull Post peri/data frac RECEIVED HAY II 1998 BPXA PDC Badami Alaska State Plane Zone 3 Badami CPF BI.18 SURVEY REPORT May, '/998 Your Reft API.500292285700 Last Survey 27.March-98 Job Number AKVCSO'I SO KBE- 54.4' 13RII--L. I NB '=;ERVICE~ Survey Ref: sv72~2 Badami Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -54,40 0.00 35.30 0.000 0.000 -19.10 35.30 75.46 0.000 0.000 21.06 75.46 123.39 0.300 348.800 68.99 123.39 222.00 0.600 11.900 167.60 222.00 317.23 0.700 11.400 262.82 317.22 406.48 0.900 18.500 352.06 406.46 494.06 0.500 18.400 439.64 494.04 583.39 0.100 10.600 528.96 583.36 674.84 0.700 185.700 620.41 674.81 767.61 1.100 185.100 713.17 767.57 860.00 1.400 185.200 805.54 859.94 952.27 2.300 190.900 897.76 952.16 1044.50 3.800 187.000 989.86 1044.26 1139.08 5.500 183.700 1084.12 1138.52 1232.96 6.700 185.700 1177.47 1231.87 '~, 1327.24 6.300 186.200 1271.14 1325.54 " 1421.67 6.400 185.200 1364.99 1419.39 1514.32 6.200 184.200 1457.08 1511.48 1609.00 6.000 179.900 1551.23 1605.63 1702.95 4.900 184.300 1644.75 1699.15 1797.72 4.200 183.700 1739.22 1793.62 1892.52 3.700 181.000 1833.80 1888.20 1987.02 2.800 173.000 1928.14 1982.54 2082.28 1.900 150.500 2023.33 2077.73 2174.80 2.000 123.000 2115.79 2170.19 2268.71 2.200 121.300 2209.64 2264.04 2363.42 1.900 125.400 2304.29 2358.69 2457.83 1.200 125.600 2398.66 2453.06 2550.47 0.300 155.200 2491.30 2545.70 Sperry-Sun Drilling Services Survey Report for B1-18 Your Ref: API-500292285700 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 0.00 N 0.00 E 5906425.04 N 363925.67 E 0.00 0.00 N 0.00 E 5906425.04 N 363925.67 E 0.000 0.00 0.00 N 0.00 E 5906425.04 N 363925.67 E 0.000 0.00 0.12 N 0.02 W 5906425.16 N 363925.65 E 0.626 0.11 0.88 N 0.03 E 5906425.92 N 363925.72 E 0.350 0.85 1.94 N 0.25 E 5906426.97 N 363925.95 E 0.105 1.93 3.14 N 0.58 E 5906428.17 N 363926.31 E 0.250 3.17 4.15 N 0.92 E 5906429.18 N 363926.66 E 0.457 4.24 4.60 N 1.06 E 5906429.62 N 363926.81 E 0.449 4.71 4.12 N 1.02 E 5906429.14 N 363926.76 E 0.874 4.24 2.67 N 0.88 E 5906427.70 N 363926.60 E 0.431 2.81 0.66 N 0.70 E 5906425.69 N 363926.38 E 0.325 0.84 2.28 S 0.25 E 5906422.76 N 363925.88 E 0.994 -2.10 7.13 S 0.48 W 5906417.92 N 363925.07 E 1.641 -6.95 14.76 S 1.15 W 5906410.30 N 363924.25 E 1.819 -14.44 24.70 S 1.98 W 5906400.38 N 363923.24 E 1.298 -24.18 35.32 S 3.09 W 5906389.78 N 363921.95 E 0.428 -34.65 45.71 S 4.13 W 5906379.41 N 363920.72 E 0.158 -44.88 55.84 S 4.96 W 5906369.30 N 363919.71 E 0.246 -54.81 65.89 S 5.33 W 5906359.26 N 363919.16 E 0.527 -64.52 74.80 S 5.62 W 5906350.35 N 363918.71 E 1.252 -73.12 82.30 S 6.15 W 5906342.86 N 363918.05 E 0.740 -80.44 88.82 S 6.42 W 5906336.35 N 363917.65 E 0.563 -86.75 94.16 S 6.20 W 5906331.01 N 363917.78 E 1.064 -91.78 97.85 S 5.13 W 5906327.30 N 363918.78 E 1.336 -94.99 100.06 S 3.02 W 5906325.05 N 363920.85 E 1.007 -96.48 101.89 S 0.11 W 5906323.17 N 363923.73 E 0.223 -97.36 103.74 S 2.72 E 5906321.27 N 363926.53 E 0.352 -98.30 105.22 S 4.80 E 5906319.75 N 363928.58 E 0.741 -99.10 106.01 S 5.69 E 5906318.95 N 363929.46 E 1.026 -99.59 Comment Alaska State Plane Zone 3 Badami CPF Continued... 11 May, 1998 - 8:02 - 2 - DrillQuest Badami Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (fi) (fi) (fi) 2644,46 0.100 171.500 2585.29 2639.69 2739.12 0.400 151.900 2679.94 2734.34 2833.13 0.400 147.200 2773.95 2828.35 2927.82 0,200 78.600 2868.64 2923.04 3021.14 0.400 26,900 2961.96 3016.36 3115.21 0.500 39.300 3056.03 3110.43 3208.95 0.600 29.200 3149.76 3204.16 3303.41 0.300 11.900 3244.22 3298.62 3397.80 0.200 349.800 3338.61 3393.01 3491.70 0.100 143.000 3432.51 3486.91 3584.90 0.100 220.400 3525.71 3580.11 3679.40 0.200 166.700 3620.21 3674.61 3772.56 0.300 169.000 3713.37 3767.77 3868.22 0.300 308.700 3809.03 3863.43 3963.97 0.700 324.900 3904.77 3959.17 4057.87 0.500 322,600 3998.67 4053.07 4152.25 0.400 311.000 4093.05 4147.45 4245.11 0.400 270.200 4185.90 4240.30 4339.80 0.500 242.000 4280.59 4334.99 4434.39 0.600 215.100 4375.18 4429,58 4484.63 0.500 223.100 4425.41 4479.81 4584.65 1.300 332.200 4525.42 4579.82 4679.35 0.600 333.400 4620.11 4674.51 4773.80 0.300 256.300 4714.56 4768.96 4868.55 0.500 263.800 4809.31 4863.71 4962.99 0.300 241.100 4903.74 4958.14 5057.54 0.600 212.200 4998.29 5052.69 5151.89 0.900 42.500 5092.64 5147.04 5245.19 2.500 24.600 5185.89 5240.29 5338.61 4.900 19.200 5279.11 5333.51 Sperry-Sun Drilling Services Survey Report for Bl-18 Your Ref: API-500292285700 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 106.31 S 5.81 E 5906318.64 N 363929.57 E 0.219 -99.84 106.69 S 5.98 E 5906318.26 N 363929.73 E 0.325 -100.15 107.25 S 6.31E 5906317.69 N 363930.05 E 0.035 -100.59 107.50 S 6.65 E 5906317.44 N 363930.39 E 0.397 -100.72 107.18 S 6.96 E 5906317.76 N 363930.70 E 0.340 -100.32 106.56 S 7.36 E 5906318.36 N 363931.12 E 0.148 -99.62 105.82 S 7.86 E 5906319.10 N 363931.63 E 0.148 -98.76 105.15 S 8.16 E 5906319.76 N 363931.94 E 0.345 -98.03 104.74 S 8.18 E 5906320.17 N 363931.96 E 0.145 -97.64 104.65 S 8.20 E 5906320.26 N 363931.99 E 0.312 -97.54 104.77 S 8.19 E 5906320.14 N 363931.98 E 0.134 -97.66 105.00 S 8.18 E 5906319.91 N 363931.96 E 0.172 -97.88 105.39 S 8.26 E 5906319.51N 363932.04 E 0.108 -98.24 105.48 S 8.11 E 5906319.43 N 363931,89 E 0.589 -98.37 104.85 S 7.58 E 5906320.07 N 363931.37 E 0.439 -97.92 104.05 S 7.00 E 5906320.88 N 363930.80 E 0.214 -97.33 103.51S 6.51 E 5906321.43 N 363930.31 E 0.143 -96.96 103.30 S 5.94 E 5906321.65 N 363929.75 E 0.300 -96.92 103.49 S 5.24 E 5906321.47 N 363929.05 E 0.253 -97.31 104.09 S 4.59 E 5906320.89 N 363928.39 E 0.289 -98.07 104.46 S 4.29 E 5906320.52 N 363928.08 E 0.251 -98.52 103.78 S 3.46 E 5906321.22 N 363927.27 E 1.538 -98.11 102.38 S 2.74 E 5906322.62 N 363926.57 E 0.739 -97.00 102.00 S 2.28 E 5906323.01 N 363926.12 E 0.644 -96.77 102.10 S 1.63 E 5906322.92 N 363925.46 E 0.218 -97.06 102.27 S 1.00 E 5906322.77 N 363924.83 E 0.266 -97.40 102.81 S 0.52 E 5906322.24 N 363924.34E 0.388 -98.06 102.68 S 0.76 E 5906322.36 N 363924.58 E 1.564 -97.86 100.29 S 2.10 E 5906324.73 N 363925.97 E 1.786 -95.18 94.67 S 4.26 E 5906330.31 N 363928.23 E 2.593 -89.17 Comment Alaska State Plane Zone 3 Badami CPF Continued... 11 May, 1998 - 8:02 - 3 - DrillQuest Badami Measured Depth (ft) 5433.75 5526.60 5620.45 5715.53 5809.69 5903.96 5998.09 6093.50 6187.34 6282.47 6377.83 6471,25 6566.49 6659,82 6754.47 6849.80 6949.30 7045.78 7140.46 7234.02 7328.57 7422.22 7517.92 7611.28 7706.41 7801.6O 789O.56 7985.97 8O78.73 8173.57 Incl. 6.800 6.800 7.900 10.000 13.600 16.000 18.500 22.100 26.000 29.200 28.40O 28.100 27.400 28.900 30.900 30.800 30,200 30.400 28.900 29.100 29.600 29.200 29.000 28.500 27.9O0 26.500 24.400 21.600 18.800 15.200 27.3OO 33.100 32.7OO 34.200 29.000 28.500 30.500 29.700 29.700 29.600 32.500 31.600 28.400 27.900 32.200 31.500 29.800 27.900 23.700 22.500 20.200 20.100 18.200 18.100 17.000 16.200 13.700 12.200 10.900 8.300 Sub-Sea Depth (ft) 5373.76 5465.95 5559.03 5652.95 5745.11 5836.24 5926.13 6015.60 6101.28 6185.57 6269.14 6351.43 6435.72 6518.01 66O0.07 6681:91 6767.64 6850.95 6933.24 '7015.07 7097.48 7179.07 7262.69 7344.54 7428.38 7513.04 7593.37 7681.19 7768.23 7858.92 Vertical Depth (ft) 5428.16 552O.35 5613.43 5707.35 5799.51 589O.64 598O.53 6070.00 6155.68 6239.97 6323.54 6405.83 6490.12 6572.41 6654.47 6736.31 6822.O4 6905.35 6987.64 7069.47 7151.88 7233.47 7317.09 7398.94 7482.78 7567.44 7647.77 7735.59 7822.63 7913.32 Sperry-Sun Drilling Services Survey Report for Bl-18 Your Ref: API-500292285700 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 85.82 S 8.18 E 5906339.08 N 363932.31 E 2.173 -79.57 76.33 S 13.70 E 5906348.47 N 363938.00 E 0.739 -68.87 66.25 S 20.22 E 5906358.44 N 363944.70 E 1.173 -57.31 53.92 S 28.39 E 5906370.61 N 363953.09 E 2.222 -43.12 37.47 S 38.36 E 5906386.88 N 363963.35 E 3.983 -24.45 16.36 S 49.93 E 5906407.79 N 363975,30 E 2.549 -0.86 7.91N 63.71E 5906431.81N 363989.51E 2.729 26.40 36.56 N 80.29 E 5906460,15 N 364006.60 E 3.784 58.66 69.77 N 99.23 E 5906493.01 N 364026.14 E 4.156 95.99 108.07 N 121.03 E 5906530.91 N 364048.62 E 3.364 139.02 147,42 N 144.70 E 5906569.84 N 364073.00 E 1.688 183.62 184.90 N 168.17 E 5906606.89 N 364097.13 E 0.558 226.36 223.28 N 190.35 E 5906644.87 N 364120.00 E 1.728 269.58 262.10 N 211.12 E 5906683.31 N 364141.46 E 1.627 312,81 302.89 N 234.77 E 5906723.67 N 364165.85 E 3.096 358.77 344.41N 260.57 E 5906764.72 N 364192,38 E 0.391 406.06 387.85 N 286.32 E 5906807.69 N 364218.91 E 1.056 455.17 430.48 N 309.80 E 5906849.89 N 364243.15 E 1.015 502.84 472.61 N 330.21 E 5906891.64 N 364264.32 E 2.706 549.12 514.33 N 348.00 E 5906933.04 N 364282.86 E 0.658 594.24 557.49 N 364.87 E 5906975.89 N 364300.49 E 1.304 640.45 600.65 N 380.70 E 5907018.75 N 364317.10 E 0.430 686.36 644.61 N 395.97 E 5907062.43 N 364333.16 E 0.988 732.87 687.28 N 409.96 E 5907104.85 N 364347.91E 0.538 777.77 730.14 N 423.52 E 5907147.45 N 364362.23 E 0.834 822.72 771.83 N 435.95 E 5907188.92 N 364375.42 E 1.520 866.23 808.75 N 445.85 E 5907225.65 N 364385.97 E 2.651 904.42 845.07 N 454.23 E 5907261.81 N 364395.00 E 2.998 941.59 876.44N 460.66 E 5907293.06 N 364402.00 E 3.057 973.46 903.76 N 465.35 E 5907320.29 N 364407.18 E 3.879 1000.95 Comment Alaska State Plane Zone 3 Badami CPF Continued... May, 1998 - 8:02 - 4 - DrillQuest Badami Measured Depth (ft) 8268.38 8359.71 8454.63 8549.64 8643.07 8737.63 8834.79 8929.O7 9024.74 9119.03 9214.07 9306.84 9401.39 9496.28 9589.37 9683.93 9778.50 9872.24 9965.42 10060.62 10155.44 10248.38 I O343.00 10438.15 10532.81 10627.17 10660.81 1 O724.00 14.500 14.000 13.500 14.000 13.800 12.800 12.400 13.000 12.200 11.800 11.600 10.900 10.3O0 9.600 9.200 8.700 8.200 7.700 7.400 6.900 6.400 5.600 4.600 4.000 3.100 2.600 2.600 2.600 7.600 7.700 4.000 2.700 2.600 2.500 2.400 2.300 3.400 2.800 3.800 4.900 4.000 6.300 7.200 8.300 9.200 8.000 10.100 9.400 9.600 10.800 17.200 11.000 358.800 359.800 356.4OO 356.400 Sub-Sea Depth (ft) 7950.56 8039.08 8131.28 8223.57 8314.26 8406.28 8501.10 8593.08 8686.44 8778.6'7 8871.74 8962.72 9055.66 9149.12 9240.96 9334.37 9427.91 9520.75 9613.12 9707.58 9801.77 9894.20 9988.44 10083.32 10177.80 10272.04 10305.65 1 O368.77 Vertical Depth (ft) 8004.96 8093.48 8185.68 8277.97 8368.66 8460.68 8555.5O 8647.48 8740.84 8833.07 8926.14 9017.12 9110.06 9203.52 9295.36 9388.77 9482.31 9575.15 9667.52 9761.98 9856.17 9948.60 10042.84 10137.72 10232.20 1 O326.44 10360.05 1 O423.17 Sperry-Sun Drilling Services Survey Report for BI-18 Your Ref: API-500292285700 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 927.82 N 468.71 E 5907344.29 N 364410.97 E 0.762 1024.93 950.10 N 471.70 E 5907366.52 N 364414.36 E 0.548 1047.10 972.53 N 474.01 E 5907388.90 N 364417.08 E 1.066 1069.21 995.08 N 475.33 E 5907411.42 N 364418.80 E 0.619 1091.13 1017.50 N 476.37 E 5907433.82 N 364420.24 E 0.216 1112.86 1039.23 N 477.34 E 5907455.53 N 364421.60 E 1.058 1133.90 1060.40 N 478.24 E 5907476.68 N 364422.88 E 0.412 1154.40 1081.11 N 479.09 E 5907497.37 N 364424.10 E 0.637 1174.44 1101.96 N 480.12 E 5907518.19 N 364425.51 E 0.873 1194.65 1121.53 N 481.19 E 5907537.75 N 364426.92 E 0.444 1213.66 1140.77 N 482.29 E 5907556.96 N 364428.38 E 0.300 1232.37 1158.82 N 483.66 E 5907574.98 N 364430.07 E 0.789 1250.02 1176.16 N 485.01 E 5907592.29 N 364431.73 E 0.658 1266.98 1192.48 N 486.47 E 5907608.59 N 364433.49 E 0.848 1283.01 1207.58 N 488.26 E 5907623.66 N 364435.54 E 0.458 1297.96 1222.16 N 490.24 E 5907638.20 N 364437.78 E 0.559 1312.47 1235.89 N 492.35 E 5907651.89 N 364440.14 E 0.547 1326.21 1248.71 N 494.29 E 5907664.67 N 364442.31 E 0.562 1339.03 1260.80 N 496.21 E 5907676.72 N 364444.45 E 0.437 1351.15 1272.48 N 498.22 E 5907688.36 N 364446.67 E 0.533 1362.90 1283.31 N 500.03 E 5907699.16 N 364448.67 E 0.528 1373.78 1292.87 N 501.75 E 5907708.69 N 364450.56 E 0.871 1383.42 1301.03 N 503.73 E 5907716.81 N 364452.69 E 1.214 1391.80 1307.93 N 505.50 E 5907723.68 N 364454.58 E 0.797 1398.92 1313.73 N 506.07 E 5907729.47 N 364455.26 E 1.236 1404.63 1318.42 N 506.01 E 5907734.16 N 364455.28 E 0.532 1409.09 1319.95 N 505.96 E 5907735.69 N 364455.26 E 0.458 1410.53 1322.81 N 505.78 E 5907738.55 N 364455.13 E 0.000 1413.21 Comment Projected TD Alaska State Plane Zone 3 Badami CPF Continued... May, 1998 - 8:02 - 5 - DrillQuest Badami Sperry-Sun Drilling Services Survey Report for BI-18 Your Ref: API.500292285700 Alaska State Plane Zone 3 Badami CPF All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. ~lertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. ? The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 17.200° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10724.00ft., The Bottom Hole Displacement is 1416.21ft., in the Direction of 20.925° (True). 11 May, 1998- 8:02 - 6- DrillQuest BP EXPLORATION, Alaska .. Date: 05-04-98 Trans# 89075 BADAMI LOG DATA & DISKS Enclosed is the materials listed below. If you have any questions please contact me in the Petrotechnical Data Center at (907) 564-4944. Sw Name Rec Type Log Type Meas Depth Meas Depth Comments Top Base B1-18 OH BOREHOLE 8,828. 10,726. 4-ARM CALIPER GAMMA RAY LOG BOREHOLE PROFILE PROFILE B1-18 OH FMT 9,119. 10,420. FORMATION MULTI-TESTER GAMMA RAY LOG B1-18 :OH MWD DGR/EWR 6,923. 10,726. MWD ROP NGP DGR EWR4 B1-18 !OH MWD DGR/EWR 6,800. 10,423. TVD -MWD NGP DGR EWR4 B1-11 OH MWD GR 5,075. 13,350. MWD ROP NGP B1-11 OH MWD GR 4,545. 10,580. TVD - MWD NGP B1-11A OH MWD DGR/EWR 5,075. 13,375. MWD ROP NGP DGR EWR4 B1-11A OH MWD DGR/EWR 4,545. 10,475. TVD -MWD NGP DGR EWR4 B1-18 DISK MWD DGR/EWR 6,856. 10,673. NWD MPT GR EWR4 ROP ASCII FORMAT Please sign and return one copy of this transmittal to: Nadene Reichert Petrotechnical Data Center LOG DATA AOGCC- 1 disk/1 blueline/1 sepia PETROFINA- 1 disk/1 blueline/1 sepia DNR- 1 disk/1 blueline BP - - 1 blueline BP---1 correlation Icg blueline Howard Oakland Mike Magalski Tim Rhyherd Jill Kanosh Ken Lemley Petrotechnical Data Center, MB3-3 900 East Benson Boulevard, P.O. Box 196612, Anchorage, Alaska 99519-6612 ... STATE OF ALASKA ALASKA OIL AND (]AS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Ty0e of Request: []Abandon ~,'$uspend ~ Plugging [~]Time Ezt~r~ion ~ Peri.t* ~ Al~r Css~g ~ Repair Well~ Pull T~lng ~ Varies ~ O[~r ~ Change Approved Program ~Opsra~on Sbu[down ~ Re-Enler Sus~e~o~ Well ~ Stimulate 2. N~e of Oper~or 5. Type of well: O. D~{~ Elevation (DF or KB) BP Exploration (AI~)Inc. ~ Developme~ ~E~4,4' ~ E~lorato~ ~ ~ or Pro~ Name 3~' ~ddm~ ~ Stratlgraphlc ~ADAMI P,O. ~ox 1~12, Anc~rage, Al~k~ gg51g~12 ~Se~ice _.. 4'."~o~tlon of well at su~ace 8, Well Number ~1-18 TgN R20E S~ 8; 15t7' ~L& 86' FEL 9,~Numbe~ ~ At ~ of productNe inte~ , At e~e~ive Oepth 50.n~.~o~. tl. Fle~ and Pool At total de~h ~d~l Reid / Badami Oil Pool TgN R20 E See g; 98' ~L& 327' ~L ......... 12. Proem well condition summa~ Total ~Dth: me~ur~ 10724 f~t Plu~ (me~ed) t~e re,cai 10423 Effective de,h: me~ured 10~0 feet Junk(me.urea) t~e venial 10339 f~t C~ing ~nglh Size Ceme~ed MD S~ural Co~umor 80' ~' ~t. 2~ ~ Armlaet 116' 115' Sudaee 4514' ~5~" 1480 bbls PF 'E' 4~0' 45~ Imermedlate 881g' 7" 41 b~ 8~5' 8575 Production Uner 2016' 4-1~" ~ b~ 15,8 ppg 10724' 10423 Pedoration aleph', me~ed N/A IGINAL P~kers and SSSV Cype ~d me~umd depth) H~8 "~O' SSSV ~ndi~ nipple at 2222'MD; HE~ ~T packer 8t 8580'MD 13~achments ~ Description s~ma~ of pmp~al ~ Detailed op~atfo~ pmg~ ~ BOP sketch 14, ~flmated ~te for comme~fng operati~ 15. Stat~ of well c~cat~ 4/15/98 16. E prop~al w~ verbally approved ~OII ~me of approver Dine approveu ~m~ Uae On~ iCo~ltlons of Approval: Notl~ Commission so ~prese~ve ~y w~s J ~proval No. Mech~l~el Imegrl~y Tern .... ~ub~m lorm required ~0. . ~n:~ Signed By Approved by o~er of the Comml~lon 0a. vid W, Johnston Comm~slo~r U~e Form 10,.403 Rev. 0~15/88 Memorandum To: From: L Purdom / R. Warner WSA Team Leader B.Turnbull AEX/AND PE Date: April 15, 1998 Subject: BADAMI B1-18 Frac Proqram B1-18 was completed with a 4 V2" cemented liner on 4/6/98. The well will be put on production following plant statrtup. Earliest start-up for Badami could be at the beginning of September 1998. Development drilling and construction operations are currently progressing on site. The hydraulic propped fracture operation requested in this program will have been preceded by a cement bond icg and perforation of the liner. These operations are the subject of previous wellwork request documents (copy attached). All well operations are subiect to daily STEA environmental and operational safety assessment. The assessment review will additionally be carried out prior to any operation and prior to any deviation from the agreed procedures. It will be the responsibility of the Badami Well Operations Team Leader on site, or his designate should he not be on location, to ensure these procedures are complied with. The operations to be carried out are' Rig up Dowell Schlumberger frac equipment and perform two data fracs as per attached detailed procedure. Analyze data frac information, revise detailed frac program if appropriate, then carry out propped frac. Design calls for 96 mlbs of 20/40 Carbolite pumped at 20 bpm, This is estimated to deliver a frac with a half length of 200ft, · Rig up slick line and carry out a TD tag to determine degree of fill in the hole following the frae. .~,rx, 5, 998 '4AM If deemed necessary rig up coiled tubing and flow back tanks and perform a fill clean out to PBTD. Flow back the well through the PTS portable test separation equipment · Freeze protect and suspend well The initial post frac rate is expected to be 2.200 bopd at 0% water cut and a GOR of 500 scf/stb. The Deviation across the perforated interval is 5°, at an azimuth of 117°, Attachments to this program include: Perforation program including completion diagram and base GR log. Detailed data frac and prepped frac program' · Design of Slurry Schedule for Tip Screen-out Fracture Technique' · Tubing Movement Calculations for Welt B1-18' ('supplied by Oowell Schlumberger) BT APR, '=~, '098 ""5~M Badami Bl-18 04/14/98 Attention: Bob Thayer / Wes Wilder Preliminary Work 1. Pres~are test annulus to 3,500 psi 2. Pressure test and grease lock Master and Wing Valve. Freeze protect flowline 3. Put and maintain 3,500 psi on the annulus. 4. DO NOT EXCEED 8,000 surface pressure. Hydraulic Fracmhng Procedure ' B 1 - 18 Object, Ye: To create a frae of 200 feet Xfin the Badami. Pump injectivity test, 2 Datafracs followed by the main fracture treatmem. Service Company: Schlumberger Dowell 1) Load clean frac tanks with 90 deg 2% KC1 flesh water treated with friction reducer. Filter all water to 3 [tm 2) Rig up and stab tree saver, (4" Cameron tree, 4 W' L-SO tubing). The friction pressure is estimated to be 862 psi at 20 bpra with a surface pressure of 5,479 psi for pad using a fracture gradient of 0.85 psi/foot and a near wellbore friction of 500 psi. Azimuth-- 117° Deviation = 5° 3) Rig up Dowetl to perform the fracture treatment. 4) Pressure test surface lines to 10,000 psi. Expected treating pressure is between 6,000 and 6,500 psi. Observe trip-out of each pump. After verifying the pump trips, reset the trips to 200 psi above maximum treating pressure, 7,500 psi. 5) Perform injeetivity test: Bullhead 100 bbls of crosslinked gel down to perforation top at 5 bpm. Stop pumping for 2 minutes then bring the rate up as fast as possible to 20 bpm. Displace injectivity with 30 bbls of 50/~ linear gel followed by 2% KC1 with friction reducer. Over displace all gelled fluid into the perfs by 5 bbls. Shut down and monitor the surface pressure for at least 15 minutes. Repeat this procedure, paying particular attention to the near wellbore pressures. If the' near welibore friction is > 1,000.psi pump a large fluid slug - 50 bbls and flush. Monitor the decline, if near wellbore friction still high, repeat the procedure. Look at both the value and the rate of change of the near wellbore friction. If, required a proppant slug will then be pumped, see Table 1 below. Once near wellbore frictionis -- 500 psi proceed to Datafi-ac. Note: Have sufficient fluid on site to flush cross linked fluid slugs. 6) Perform 220 bbl Data frac with crosslinked fluid: Pump data frac down to' perforations at 5 bpm. Stop pumping for 2 minutes then bring up rate as ;2R, '5, '998 ""SA1;[ Badami Bl-18 ..... 04/14/98 ..... 't.lO. ' ? 2 quickly as possible to 20 bpm. Undor displace data frao by 20 bbls. Displace the data frae with 30 bb140 # linear gel followed by 2% KCI water. Stop pumping and monitor the pressure d¢oline. Transmit the data to Anchorage for interpretation. 7) Discuss closures and leakoffwith town. 8) Re-mn the Datafra¢ as per (6) above. 9) Discuss closures and leakoffwith town_ The TSO will be r~-designed based on Datafrac interpretation. 10) Pump 96,478 lbs fracture treatment at 20 bpm per modified ramp. 11) Pump adequate ~eeze protection knowing that it will be - 12 hours for wellbore to bleed down. Table 1 Sand Slug volumes Stage Volume Cobls) Pad 25 1 PPA 30 Flush 25 Table 2 Volumes Volume to Top Perfs Under Flush 161 bbls 5.0 bbls Flush 156 bbls Post -Frac Treatment 1. Tag proppant top with slickline. Pull Petredat gauge and replace GLV's." 2. RIH with CT and clean out Carbolite per established procedure. 3. Flow well back, through portable separator per established procedures. Obtain a comparison test with the WPS during the last 12 hours offlowback. Well will be produced for 4 to 6 days to clean up of the frae. Signed WSA Stimulation Engineer WSA Operations Team Leader Attachments 1. Tubing Movement Catculations 2. Pump schedule Ramp .T. ubing Movement Calculations for Well BI,' Anchored.l$Cr Tubing _2 Strings Ver~.2_d Pistoq & Plu.q Effect ' I~aJlooninO Efreci pressure ii,cross P~lcL~er - ~Total Lenqlh -L_pr = -72.72 Inches -L_bal = 3.80 Inche.~ -P = - -624t psia (up) I -0 inches -F_pr = -73130 lbs -F_bal = -3844 lbs iO.o fe~_ .~ Pressure Bucklirlq 'l'emPe[ature Effect F_tp - -89355 lbs (up) tubing -> packer force -L_hb = 0.00 Inches 'L_tmp = -19.93 Inche.' F_pc = -244556 lbs (up) packer-> casing f~0rce n = 0 feet 'F Imp = 20043 lbs Mi~imbm-Dei~ignFa~ctOr: "J.3.~ B~rst - -S~i_n!; 2 90 Final Surface Temp. ("FI I IgnOre Pipe TOlerance for VM~.~iankto Use APl Tolerahbe)I 800(3 Final Applied Tubing Pressune (psi) x Anchored Tubing (Leave Blank for Floating/Pinned tubl'ng)l 3500 Final Applied Annular Pressure (psi~ X 13Cr T~te Blank for L80. Use Tubing option to define other tuU/.;ng)I .50 Initial Surface Temperature (°F) Tubind NB0 l(type) El 3E+~I SI 7E-61' PI 0~301 SD00 Initial Applied Tbg. Pressure (psi) Sour Service (Leave Blank t~or Sweet Serv_!ce)l 0 Initial Applied Ann. Pressure (psi) Mechanical set Completion (Leave Blank for Hydraulic 3.95 Packer seal bore diameter (in) Plug in Tailpipe P below plug[ ' .']pale ~kr Set~ o slac~off (lbs) -compress. +T.nsion Pinned a! ] lbs _...=w ~l.,, ~o; F~. boy. re.?)I Siring 11 ,~ ,1ring 2 IString 3~ 2 IStrings I Design Factors at Top and Bottom of Each String - 20001 "~62311 9q621MD b°ttom <f~) - I AnchomdTubing -m - FlOating Tubing ~' 20001 e3751 a4211Tv~b~om(,> I SITens 1.70 Imens ' 1.~9 ITens -3,$9 lmens--5-;23 TM I rleurst 1.s? leurst l.aS IBu~ 1.~7 leu~ 4.~I 4.$I 4.$1TbSO.~. (in) I I¢°llap ~/A ICc,apN/A ICollap N/A /Colmap 80o001 8oo0oI 80000lTbg Yield(psi] m I IVME 1.46 IVME 1.51 IVh;E 1.96 tVME 1~.~I12.~I 12.S[TUoWeight(~)I Slmens .... 1~9~ ITe,s4:;~a-ITens S.23 tComp l~;,1 ~'~1 ~'~1~=.~lF~,~l,b~a.,tbg I ICo,,p ~/^ po,ap ,~^ ICollap NtA ICollap 8.7i 8.71 S.711nitial lbs/gal tbg m ~IVME 1,5q IVME 1.48 IVME 1.a0 IVlV1E ' 8'61Fina"~'~"'~"ITM "! Icomp - s.71 s.71 8.71Initial I~,s/~al ~,.n I rlBurst IBu~ IBu~ Ie~'~ ' 951 ~oI l'~01Final Lot Temp ("F) /Collap ICoHap ICol~ap ICc[lap 50, 184, 221 ~lnitie, bot T. rn, (°F: I,VME ~VME I'VN1E T. Op I B O~inl~VMEo-tt'"' 01 01 01-P friction (psi/Mit) I ...... - Top I - Bottom 0[ 01 0JDogleg (°1100 ft) I * Denotes Design Factors BeI(~W BP's suggested uinimurfl: EJPX Sug.( eared design minimums ' ' ....... I Load capa~it~ Tension '1.50-- 'L~;~d capacity Collapse 1.10 VME (sweet's~'rvice) 1.25i L_o.ad capacity.~o_.rniS_r.e.s..s, i( 1.20 Load capacity Burst 1.30 VlV1E (sour service) 1.33J Note: Tubing movement calculations are Imm the BP Completion Design Manual Volume II 1.) For Anchored tubing, weak link Is top of lubin§ or Anchor Seal: keep Tension and VME factors above minimum 2.) For Floating seal assembly over slip. stiaeep Total negative Lenglth Change << Slipstick Length - ~'I~) For Pinned seaiassembly over slipstick, pins will shear and tubing will m(tFe_t~l > Pin Strength ATTACHM I~N'r I:PU{FJ' SCH. i,~ULE hd~m{ BI.{8 m TYlq I Bml~,m 50# Del~ad XL STAGE {68 168 32 !73 SD ~d eb~le I$1P& ~:; ~aalt,~ izma,,m. __ DIRTY ¥OLU],li; D/liT l~)l. Oitl~ FROPPANT 16N 7661 7061 168 16~ 2,0 2.0 6~0 ~ 729 71J61 $ll632 168 1611 ?&l 1.939 31972 32 32 2.0 6,11 934 7271 39242 1'73 173 0.0 0,0 mRtn"nowN ~oa ~ M~s. MON'fIOR rRE:SaURL DATA z x ~'e^ 51~ Delqd XL 20 ~ J~hub 5~ I)elq, ed XL ~ 4 2 PPA 51~8 Ddqed XL 2~i ~ PUMP bTAcm AVnbXOE COMaO..'~'TS TYFE SA'r~ ] 0 r~ S0~ l]M,,{rd XL 2~ 2 I mt 50~ Del,pa XL 20 3 $ ~ ~ Deln~d XL 20 4 8 r.~ S0~ Deja}ed XL 21) S0~ De~are~ XL 20 Delqecl XL 20 Delqed X% 20 Delu~l XL Relayed lo o R~d~le .rd~ l~eln~ed XL FRAC VOL- 200 bbb 5O 218 50 311] 193 S~I 55 55 989 ,5~ Ill 1045 511 1445 3O 541 1475 6'7 60'; 1542 13 621 15SS 0 688 '[622 0 21 O0 916t 2100 11261 2100 13361 2100 13461 D l~ r~ ' R1L fJM E 2305 2305 168170 19145 1260 20405 566 23771 280O 26571 2011 2011 2W40 .._ 0 0 0 2155 2155 0 6B829 681129 16/2~ 7452 7452 I(g20 18042 1S042 16;'20 0 0 16/20 0 0 16/20 4~ 4~ 50 50 328 48 67 5O 193 9~8 328' :2. O 6.0 60~0 2.0 6.O 2.0 6.0 ~ (LO 0,0 6O0O 1.0 6.0 60~ 1.0 6,0 / 1.0 6.0 ~ 2.0 to ~ zo 6.0 ~ 2.0 6.0 2.0 6.0 20 61~ 16L1 0 25571 0 0 16~r20 0 O 2.0 6.0 20 0 68ti 162,2 0 26571 0 0 16'20 0 0 7,.0 6.0 211 0 688 1622 0 26571 0 0 0 681~ 1622 7 6~5 1629 0 26571' 294 26865 ! t o RAMe SO~ ~1~ XL 20 4981 31846 7 ~ !19 119 O 0 16/20 0 0 16/'20 S FI,U~H DELAY-XL GW ~ s F'LImlX NON-XL O1',' 2.e 119 813 1~47 2.0 6.0 2.0 6,0 ~ zo 6,0 ~ S SLICK D~L 20 ]O 844 17T~ 1277 33123 ~0 TOTAI~ 777 $3123 9~478 685 6f~ 3D TANK~= VOL 0 bbb 3o bhk ~0 bbb C.I~RAI. JOB/NFO · ~Umald Talal ~ O[VB UPPER ~IBINO kODDLE '~q'o , ~ 'ZIIB~G 31ZR ~_P.~1O ~ 4..~0 IXOl_~ M4s.~A <<Aanub Vn4mmn? ]0 Modified Ramp Proppant Ramp 100 200 700 800 300 400 500 600 Volume O~bls) Page Memo~ndum To: From'. Sublect: L Purdom / R, Warner WSA Team Leader Date: April 14, 1998 B.Turnbull AEX/AND PE BADAMI B1-18 CB_L,..Neutron, Perforation Program B1-18 was completed on 4/3t98. The well has a conventional cased completion with 41/='' liner. It is the intention to perform a propped fracture on the well, the timing of which is presently uncertain. Construction and development drilling is still ongoing at Badami, and earliest plant start-up for Badami could late August 1998_ All well operations are subject to daily STEA environmental and operational safety assessment. The assessment review will additionally be carried out prior to any operation and prior to any deviation from the agreed procedures. It will be the responsibility of the Badami Well Operations Team Leader on site, or his designate should he not be on location, to ensure these procedures are complied with. The operations to be carried out are: · Pull the BPV. Rig up slickline and pull the ball and rod from the tailpipe. · Rig up E-Line and run an CBL / CNT-G / GR from TD to top of liner. Run the bond log under pressure. Perforate the interval 10,396 to 10,416 ft MD (reference Sperry Sun MWD) with 2-7~8 HSD 38C CP RDX at a shot density of 6 spf, 60 deg phasing. Safe out the well in preparation for the frac job. The Deviation across the perforated interval is 5°, at an azimuth of 117°. Plug back TD is at 10640 ft MD bkb. Attaohment9 to this program inolude: · Well completion diagram · Copy of Sperry Sun MWD GR log to correlate with BT Work: (907)-564-4662 Home: (907)-345-1403 Kelly bunhlng to Wellho~l (R) Wellhead t~ loyal, Conductor t-80 lET-MOD Production Tubing ~HE$ "HXO" Safety Valve Lancrmg S uff.~m~ Ca~ing Cameo 4 1/2" x 1" GLM Carn~o 4 112" × 1" GLM C,~mco 4 112" X 1" GLM Camco 4 1/2' x 1" GLM Camco 4 1/2" x 1" GLM Camco 4 1/2" x t" GLM HE$ "rNa' Perme~ant Packer HES "'X" Landing Nipple HES "×N" Landing Nipple Wimline Entry Guide 7" x 41/2" Ilne~ Hanger/Packer lnbarrnediate Casing PBTC) ~1 ~ ~. Produc~on Ca~ing Date Rev by Cornment~ 1~7, 8.Tumbull InltlaJ design 2~ B.Turnbull RevL~ad direc~on~ ~/~ B.Tumbull As built STATE OF ALASKA ~. ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging ~] Time Extension [] Perforate [] Alter Casing [~ Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program E~]Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Diverter Waiver 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1424' SNL, 86' WEL, SEC. 8, T9N, R20E, UM At top of productive interval 103' SNL, 334' EWL, SEC. 9, T9N, R20E, UM (Planned) At effective depth N/A At total depth 98' SNL, 327' EWL, SEC. 9, T9N, R20E, UM (Planned) 5. Type of well: [] Development E~ Exploratory E~ Stratigraphic E~ Service 6. Datum Elevation (DF or KB) Plan KBE = 54.4' 7. Unit or Property Name Badami 8. Well Number B1-18 9. Permit Number 98-12 10. APl Number 50-029-22857 11. Field and Pool Badami 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length 80' feet feet feet feet Size 20" Plugs (measured) Junk (measured) Cemented 260 sx Arcticset I (Approx.) Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) MD 116' ORiGiNAL TVD 116' Conditions of Approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- Approved by order of the Commission ,~avid W. Joh~st0Q __~~~:~ - _ ~ uomm~ssioner Form 10-403 Rev. 06/15/88 ¢.._.--~.~?--~~ -7 Submit In Triplicate 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed MikeMiller'~ ~.~ ) Title Badami Drilling Team Leader Commission Use Only Kathy Campoamor, 564-5122 14. Estimated date for commencing operation t 15. Status of well classifications as: March 4, 1998 i 6. If proposal was verbally approved [] Oil [~ Gas [] Suspended Blair Wondzell Service Name of approver Date appr. oved Contact Engineer Name/Number: Mike Miller, 564-5066 ~ /44/~¢.~. ~.,~'z~74. ~ ~ ~ ~ Prepared By Name/Number: 13. Attachments [~ Description summary of proposal [~] Detailed operations program [~ BOP sketch Shared Services Drilling Well: B1-18 Wp4 I DriHQuest' 01 1200 ----~KOP: Start Nudge @ 1.000°/100fl: 500.00fl MD, 500.00It 'FVD ~End Dir, Sail @ 6.000°: 1100.00{l MD, 1098,001I TVD @ 1.000°/100fl: 1400.0011 MD, 1397.26flTVD Propolal Data for B1-18 Wp4 VmlJc81 Origin: Well Reference Horizontal Origin: Well Reference MeasurementUnlts:ft North Reference: True North Dogleg Severl[y: Degrees per lOOtt Vertical Section Azimuth: 17.175' Vedlcal Section Description:Well Reference Vertical Secllon OrlCn: 0,00 N,O,O0 E Mealured Incl. Azlm. Vertical Northlnga Eeatlng= Ver[Ical Dogleg Depth Depth Section Rate O.(X} 0.000 358.971 O.0O 0.00 N 0.00 E O.(X} 300.00 0.000 351L971 5(X).00 0.00 N 0.(}O E O.(X} I I00.00 fi.oooI go.ooO 1098.90 31.39 $ 0.00 E-29.99 I,(Xx) 1400.00 fi.000180.000 1397.26 62.73 $ 0,00 E-39.93 0.(XX) 2000.00 0.0gO 35R.97[ I~)fi. lfi 94.13S O.0OE .89.94 I.{XX} 43.q8.24 0,000 338,971 4554,40 94.13 S 0.{X} E .88.94 3338.24 0.000 .t58.971 5354.40 94.13 $ 0.00 E.89.04 0.(XX} 6324.90 29.(X~028.C'~0 6280.32 117.30 N I 12.42 E 145.26 7009.87 27.000 23,000 ~85.16 407.09 N 251.16 E 4,53.10 0.450 7408.71 25.000 20.000 7243.~4 569,65 N 315.37 E 637.3R 8084.49 21,000 12.000 7865.72 822.44 N 389.43 E g(X).76 0.730 1('~501.fi2 ,1.827 308.421 10320,40 1320.6~ N 417.{57 E 1.11~5,12 10781.47 2.223 292.357 10300.00 1.325.73 N 409.73 E 1387.61 I.¢XX} 2400 3600 PROPOSAL TARGET SUMMARY Target N~me ,' TVDS8 TVDRKB: Wellhead Ofllall:G~bal C~t.i: New B1-18 Ta~et 10~8.~ 10320.40 13~.88 N, 417.67 E 5~7738.~ N, 384387.~ E C~ (~'R~lu~) 4800 6000 7200 )60O 6400 L g 5/8" Casing- 4558.24 MD, 4554,40 TVD KOI': .~lnrl Ul~ ¢J 3.000"/100fl: b3b0.24fl MD, 6354.4011TVD SURFACE LOCATION IPLOT DATE: 2/'._~6_/__~8 ..... Horizontal Coom'lnata,: 5gO~42B.O4 N, 383925.87 E J Cm~led By' ~ ~'"~'" - t'IKB Elev~ll~fl: 3fi,30 fi, Rig (E8T) J ' ~,~_ ~"~-'""'_..,_.. ........ 19.1011 W,~I(CBE) I tV~. / -!._'---./¥ 54.4OII RKB.AMSLI CheckedBy: ! · ~" C~le Sy~: Z~e 3, US F~I I ~ ~: ...... . BHA Tendency @ 0,450'/10011: 8324,90ft MD, 8280.32ll TVD I ~.l)ll, @ 0.600'/100~t: 7009,87fl MD, 8886.18ft TVD -- BHA Tendency @ 0.750'/100lt: 7408.711'1 MD, 7243,84f/TVD ~400.00 BI IA Tanrl~.nay O 0.77fl"/I0011: 8084,4011 MD, 788§3211TVD · '"'''''''-'''''''''''''"*''' o.-o.---..-o.-... · o,-..~w; .7.'t .C::,- a.8 inej- -- 89.1,3:4,2- M D; .8654.-4~. :FV D ...... .,,-,-~, I · New HI.Il{ T;u~cl - ('1u. 1¢ (2lXl'R;~dhl,O IIt.I.'~O.40 TVD - I]2i168 N, 417.6') E i I 0 1200 Scnlo: linch. 1200fi BHA Tendency {3 1,000°/100fl: 10601.621t MD, 10320.401t TVD Tolal Depth: 10781.47fl MD, 10500.0Oft TVD 1/g" Liner - 10781,47 MD, 10500.00 TVD I 2400 3600 Section Azimuth: 17,175' (True North) Vertical Section Pemm 2-sunI Shared Services Drilling Well: B1-18 Wp4 DrillQuest Scale: linch = 300f! -300 Eastlngs 300 600 I I 900 1500 - 1200 - 900 - 300 - 0 - -300 - N,w D I. I ~1T~i.i · CI~I. (2flO'lb,.quO 10~120.40 TVl). 1320.~1~ N. 41"/.6'/E [0200. 9600.0C 9200.00 8800,00 8400.00 8200.00 8000.00' 7800.00 7600,00 7400,00 7200.00 7000.00 6800.00 6600.00 4 1/2" L ~er- 10781.47 MD, 10500.0 0781,47[t MD, 10500.00f! TVD O 1.000'/100ft: 10801,821t MD, 1032(: 7" Casing - 8913.42 MD, 8654.40 T' Tendency · 0.778°/100ft: 8084.4g{t MD, 7885,72ft · , 0,750°/100ft: 7408,71ft MD, 7243,64ft TVD :y e 0.800'/100ft: 7009.87ft MD, 6885.16tt TVD 6400.00 6200.00 e 0.450°/100ft: 6324.90ft MD, 6280.32ft TVD 6000 1400.00 Start Nudge 0 1.0OO°/100tt: 500.0Oft MD, 500.00fl TVD DIr, Sail 0 6.000': 1100.00fl MD, 1098.90ft TVD @ 1,000°/lO0ft: 1400.O0ft MD, 1397.26fITVD Sail O 0.000°: 2000.00ft MD, 1998.16ft'l'VD KOP: Start DIr @ 3.000°/100fl: 5358.24ff MD, 5354.40ft TVD - 1500 TVD 10fl TVD tD r'VD -0 I -300 Scale: linch m 300ff I I I 300 600 900 r=,~sfln.S Reference Is True North Targel Name ' New B1-18 Targel Circle (200'Radius) PROPOSAL TARGET SUMMARY 1-VDSS T'VDRKB: Wellhead Offsets: 10266 00 10320.40 1320.68 N. 417.67 E 1 Global Coordinates: 1 1 5907738.00 N, 364367.00 E SURFACE LOCATION PLOT DATE: 2/26/98 RKB Elevation: 35.30 II Rig (EST) { ~ ~ '---'- ..... 54.40 fl RKB · AMSL I Checked By: v. ~ - ~ z; _% · ~ NAD27 Alaska Slate Planes. I 7'~*~... ~.---. Coordinate System: Zona 3. US Fool I Approved By: ~ r---- Sperry-Sun Drilling Services Proposal Report for B1-18 Wp4 Badami Alaska State Plane Zone 3 Badami CPF Measured Vertical Closure Depth Incl. Azim. Depth Northings Eastings Distance Direct'n (ft) (ft) (ft) (ft) (ft) Vertical Dogleg Section Rate (ft) (°/100ft) 0.00 0.000 0.000 0.00 0.00 N 0.00 E 0.00 0.000 500.00 0.000 0.000 500.00 0.00 N 0.00 E 0.00 0.000 1100.00 6.000 180.000 1098,90 31.39 S 0.00 E 31.39 180.000 1400.00 6.000 180.000 1397.26 62.75 S 0.00 E 62.75 180.000 2000.00 0.000 0.000 1996.16 94.13 S 0.00 E 94.13 180.000 4558.24 0.000 0.000 4554.40 94.13 S 0.00 E 94.13 180.000 5358.24 0.000 0.000 5354.40 94.13 S 0.00 E 94.13 180.000 6324.90 29.000 28.000 6280.32 117.30 N 112.42 E 162.47 43.784 7009.87 27.000 23.000 6885.16 407.09 N 251.16 E 478.34 31.672 7408,71 25.000 20.000 7243.64 569.65 N 315.37 E 651.12 28.969 8084.49 21,000 12,000 7865.72 822.44 N 389.43 E 909.98 25.338 10601,62 3,827 308.421 10320,40 1320.68 N 417.67 E 1385.15 17,550 10781,47 2.223 292.357 10500,00 1325.73 N 409.75 E 1387.61 17.175 0.00 0.00 0.000 -29.99 1.000 -59.95 0.000 -89.94 1.000 -89.94 0.000 -89.94 0.000 145.26 3.000 463.10 0.450 637.38 0.600 900.76 0.750 1385.12 0.778 1387.61 1.000 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100ft. Vedical Section is from Well Reference and calculated along an Azimuth of 17.175° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10781.47ft., The Bottom Hole Displacement is 1387.61ft., in the Direction of 17.175° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 500,00 500,00 0,00 N 0.00 E 1100,00 1098.90 31.39 S 0.00 E 1400,00 1397.26 62.75 S 0.00 E 2000,00 1996.16 94.13 S 0.00 E 5358,24 5354.40 94.13 S 0.00 E 6324,90 6280.32 117.30 N 112.42 E 7009,87 6885.16 407,09 N 251,16 E 7408,71 7243.64 569.65 N 315.37 E 8084.49 7865,72 822,44 N 389.43 E 10001,02 10320.40 1320.68 N 417.67 E 10781.47 10500.00 1325,73 N 409.75 E Comment KOP: Start Nudge @ 1,000°/100ft: 500.00ft MD, 500.00ft TVD End DIr, Sail @ 6.000°: 1100.00ft MD, 1098.90ft TVD Start DIr @ 1.000°/100ft: 1400.00ft MD, 1397.26ft TVD End DIr, Sail @ 0,000°: 2000.00ft MD, 1996.16ft TVD KOP: Start DIr @ 3,000°/100ft: 5358,24ft MD, 5354,40ft TVD BHA Tendency @ 0,450°/100ft: 6324.90ft MD, 6280.32ft TVD BHA Tendency @ 0.600°/100ft: 7009,87ft MD, 6885.16ft TVD BHA Tendency @ 0,750°/100ft: 7408.71ft MD, 7243,64ft TVD BHA Tendency @ 0,778°/100ft: 8084,49ft MD, 7865,72ft TVD TB~DA Tendency @ 1.000°/100ff: 10601.62ft MD, 10320.40ft Total Depth: 10781.47ft MD, 10500.00fl TVD Formation Tops Measured Vertical Sub-Sea Depth Depth Depth Northings (ft) (ft) (ft) (fi) 1943,23 1939.40 1885.00 93.85 S 7143.29 7004.40 6950.00 462.40 N 8285.58 8054.40 8000.00 890.56 N 8757.92 8504.40 8450.00 1031.67 N 9189.94 8923.08 8868.68 1137.14 N 9291.57 9022.40 8968.00 1158.64 N 9293.24 9024.03 8969.63 1158.98 N 10066.71 9787.53 9733.13 1280.47 N 10288.02 10007.72 9953.32 1301,47 N 10387,17 10106.52 10052.12 1308.88 N Eastings Formation Name (ft) 0.00 E Base Permafrost 274.09 E Top Mid Brooklan 403.41 E M90 428.29 E Base West Sak (M85) 441.22 E C2 442.90 E Shallowest Badaml Sand 442.92 E F2 438.45 E A1 431.60 E K3 427,73 E F5 Continued.,. 26 February, 1998 - 14:17 - 1 - DriliQuest Sperry-Sun Drilling Services Proposal Report for B 1-18 Wp4 Badami Alaska State Plane Zone 3 Badami CPF Casing details From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) Vertical Depth (ft) Casing Detail <Surface> <Surface> 4558.24 4554.40 9 5/8" Casing <Surface> <Surface> 8913.42 8654.40 7' Casing <Surface> <Surface> 10781.47 10500.00 4 1/2" Liner Targets associated with this wellpath Target Name New B1-18 Target Target Entry Coordinates TVD Northlngs Eastings (ft) (ft) (ft) 10320.40 1320.68 N 417.67 E Target Target Shape Type Circle Geologlcal 26 February, 1998 - 14:17 - 2. DrlllQuest Sperry-Sun Drilling Services Proposal Report for B 1-18 Wp4 Badami Measured Depth- Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 0.00 0.000 0.000 -54.40 0.00 100.00 0.000 0.000 45.60 100.00 200.00 0.000 0.000 145.60 200.00 300.00 0.000 0.000 245.60 300.00 400.00 0.000 0.000 345.60 400.00 500.00 0.000 0.000 445.60 500.00 600.00 1.000 180.000 545.59 599.99 700.00 2.000 180.000 645.56 699.96 800.00 3.000 180.000 745.46 799.86 900.00 4.000 180.000 845.28 899.68 1000.00 5.000 180.000 944.97 999.37 1100.00 6.000 180.000 1044.50 1098.90 1200.00 6.000 180.000 1145.96 1198.36 1300.00 6.000 180.000 1243.41 1297.81 1400.00 6.000 180.000 1342.86 1397.26 1500.00 5.000 180.000 1442.40 1496.80 1600.00 4.000 180.000 1542.09 1596.49 1700.00 3.000 180.000 1641.90 1696.30 1800.00 2.000 180.000 1741.81 1796.21 1900.00 1.000 180.000 1841.77 1896.17 1943.23 0.568 180.000 1885.00 1939.40 2000.00 0.000 0.000 1941.76 1996.16 2100.00 0.000 0.000 2041.76 2096.16 2200.00 0.000 0.000 2141.76 2196.16 2300.00 0.000 0.000 2241.76 2296.16 2400.00 0.000 0.000 2341.76 2396.16 2500.00 0.000 0.000 2441.76 2496.16 2600.00 0.000 0.000 2541.76 2596.16 2700.00 0.000 0.000 2641.76 2696.16 2800.00 0.000 0.000 2741.76 2796.16 0.00 N 0.00 E 0.O0 N 0.00 E 0.00 N 0.00 E 0.O0 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.87 S 0.00 E 3.49 S 0.00 E 7.85 S 0.00 E 13.96 S 0.00 E 21.80 S 0.00 E 31.39 S 0.00 E 41.84 S 0.00 E 52.29 S 0.00 E 62.75 S 0.00 E 72.33 S 0.00 E 80.18 S 0.00 E 86.28 S 0.00 E 90.64 S 0.00 E 93.26 S 0.00 E 93.85 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°n 00ft) (ft) 5906425.04 N 363925.67 E 0.00 5906425.04 N 363925.67 E 0.000 0.00 5906425.04 N 363925.67 E 0.000 0.00 5906425.04 N 363925.67 E 0.000 0.00 5906425.04 N 363925.67 E 0.000 0.00 5906425.04 N 363925.67 E 0.000 0.00 5906424.17 N 363925.65 E 1.000 -0.83 5906421.55 N 363925.61 E 1.000 -3.33 5906417.19 N 363925.53 E 1.000 -7.50 5906411.09 N 363925.42 E 1.000 -13.33 5906403.24 N 363925.28 E 1.000 -20.83 5906393.66 N 363925.11 E 1.000 -29.99 5906383.21 N 363924.92 E 0.000 -39.97 5906372.76 N 363924.73 E 0.000 -49.96 5906362.30 N 363924.54 E 0.000 -59.95 5906352.72 N 363924.37 E 1.000 -69.10 5906344.88 N 363924.23 E 1.000 -76.60 5906338.77 N 363924.12 E 1.000 -82.43 5906334.41 N 363924.04 E 1.000 -86.60 5906331.79 N 363923.99 E 1.000 -89.10 5906331.20 N 363923.98 E 1.000 -89.67 5906330.92 N 363923.98 E 1.000 -89.94 5906.330.92 N 363923.98 E 0.000 -89.94 5906.330.92 N 363923.98 E 0.000 -89.94 5906.330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.0(30 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 Alaska State Plane Zone 3 Badami CPF Comment KOP: Start Nudge @ 1.000°/100ft: 500.00ft MD, 500.0Oft TVD End Dir, Sail @ 6.000°- 1100.00ft MD, 1098.90ft 'I'VD Start Dir @ 1.000°/100ft: 1400.00ft MD, 1397.26ft TVD Base Permafrost End Dir, Sail @ 0.000°: 2000.00ft MD, 1996.16ft TVD Continued... 26 February, 1998 - 14:19 - I - DrillQuest Sperry-Sun Drilling Services Proposal Rep,orr for B 1-18 Wp4 Badami Measured Depth- Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2900.00 0.000 0.000 2841.76 2896.16 3000.00 0.000 0.000 2941.76 2996.16 3100.00 0.000 0.000 3041.76 3096.16 3200.00 0.000 0.000 3141.76 3196.16 3300.00 0.000 0.000 3241.76 3296.16 3400.00 0,000 0.000 3341.76 3396.16 3500.00 0.000 0,000 3441.76 3496.16 3600.00 0.000 0.000 3541.76 3596.16 3700.00 0.000 0.000 3641.76 3696.16 3800.00 0.000 0.000 3741.76 3796.16 3900.00 0.000 0.000 3841.76 3896.16 4000.00 0.000 0.000 3941.76 39<J6.16 4100.00 0.000 0.000 4041.76 4096.16 4200.00 0.000 0.000 4141.76 4196.16 4300.00 0.000 0.000 4241.76 4296.16 4400.00 0.000 0.000 4341.76 4396.16 4500.00 0.000 0.000 4441.76 4496.16 4558.24 0.000 0.000 4500.00 4554.40 4600.00 0.000 0.000 4541.76 4596.16 4700.00 0.000 0.000 4641.76 4696.16 4800.00 0.000 0.000 4741.76 4796.16 4900.00 0.000 0.000 4841.76 4896.16 5000.00 0.000 0.000 4941.76 4996.16 5100.00 0.000 0.000 5041.76 5096.16 5200.00 0.000 0.000 5141.76 5196.16 5300.00 0.000 0.000 5241.76 5296.16 5358.24 0.000 0.000 5300.00 5354.40 5400.00 1.253 28.000 5,341.76 5396,16 5500.00 4.253 28.000 5441.63 5496.03 5600.00 7.253 28.000 5541.12 5595.52 Local Coordinates Northings Eastings (ft) (ft) 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 94.13 S 0.00 E 93.73 S 0.21 E 89.49 S 2.47 E 80.64 S 7.17 E Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/'~ 00ft) (ft) 5906330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0~000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906,3,30.92 N 363923.98 E 0.000 -89.94 5906,3,30.92 N 363923.98 E 0.000 -89.94 59063,30.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906.3,.30.92 N 363923.98 E 0.000 -89.94 5906,330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906330.92 N 363923.98 E 0.000 -89.94 5906331.32 N 363924.20 E 3.000 -89.49 5906335.52 N 363926.53 E 3.000 -84.77 5906344.28 N 363931.39 E 3.000 -74.93 Alaska State Plane Zone 3 Badami CPF Comment 9 5/8" Casing KOP: Start Dir Ct 3.000°/100ff: 5358.24ft MD, 5354,40ft TVD ContJnued... 26 February, 1998 - 14:19 - 2 - DrillQuest Sperry-Sun Drilling Services Proposal Report for B 1-18 Wp4 Badami Measured Depth' (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 5700.00 10.253 28.000 5639.94 5694.34 5800.00 13,253 28.000 5737.84 5792.24 5900.00 16.253 28.000 5834.53 5888.93 6000.00 19.253 28.000 5929.76 5984.16 6100.00 22.253 28.000 6023.26 6077.66 6200.00 25.253 28.000 6114.77 6169.17 6300.00 28.253 28.000 6204.06 6258.46 6324.90 29.000 28.000 6225.92 6280.32 6400.00 28.772 27.483 6291.67 6346.07 6500.00 28.472 26.784 6379.45 6433.85 6600.00 28.175 26.071 6467.48 6521.88 6700.00 27.882 25.343 6555.75 6610.15 6800.00 27.593 24.602 6644.26 6698.66 6900.00 27.308 23.847 6733.00 6787.40 7000.00 27.027 23.077 6821.97 6876.37 7009.87 27.000 23.000 6830.76 6885.16 7100.00 26.543 22.359 6911.23 6965.63 7143.29 26.324 22.044 6950.00 7004.40 7200.00 26.039 21.623 7000.89 7055.29 7300.00 25.539 20.861 7090.93 7145.33 7400.00 25.043 20.070 7181.34 7235.74 7408.71 25.000 20.000 7189.24 7243.64 7500.00 24.438 19.066 7272.16 7326.56 7600.00 23.829 17.995 7363.42 7417.82 7700.00 23.227 16.872 7455.11 7509.51 7800.00 22.635 15.693 7547.20 7601.60 7900.00 22.051 14.454 7639.70 7694.10 8000.00 21.477 13.152 7732.57 7786.97 8084.49 21.000 12.000 7811.32 7865.72 8100.00 20.881 11.940 7825.81 7880.21 67.21S 14.32 E 49.22 S 23.88 E 26.74 S 35.83 E 0.18 N 50.15 E 31.46 N 66.78 E 67.02 N 85.69 E 106.76 N 106.82 E 117.30 N 112.42 E 149.40 N 129.31 E 192.03 N 151.15 E 234.52 N 172~7 E 276.86 N 192.65E 319.05 N 212.31 E 361.09 N 231.22E 402.97 N 249.4OE 407.09 N 251.16 E 444.55 N 266.81 E 462.40 N 274.09E 485.62 N 283.40E 526.17 N 299.16 E 566.19 N 314.10 E 569.65 N 315.37 E 605.63 N 328.13 E 644.39 N 341.13 E 682.47 N 353.09E 719.87 N 364.02E 756.57 N 373.91 E 792.58 N 382.76 E 822.44N 389.43E 827.87 N 390.58 E Global Coordinates Dogleg Vertical Northings Eastings Rate Section (fi) (fi) (°/100fi) (ft) 5906357.59 N 363938.78 E 3.000 -59.98 5906375.40N 363948.66 E 3.000 -39.98 5906397.66 N 363961.02 E 3.000 -14.97 5906424.32 N 363975.81 E 3.000 14.98 5906455.30 N 363993.00 E 3.000 49.78 5906490.51N 364012.55 E 3.000 89.34 5906529.87 N 364034.39 E 3.000 133.54 5906540.30 N 364040.18 E 3.000 145.26 5906572.10 N 364057.64 E 0.450 180.92 5906614.33N 364080.25 E 0.450 228.10 5906656.43N 364102.13 E 0.450 274.93 5906698.39 N 364123.27 E 0.450 321.40 5906740.22N 364143.67 E 0.450 367.51 5906781.91 N 364163.34 E 0.450 413.26 5906823.46N 364182.27 E 0.450 458.65 5906827.56 N 364184.10 E 0.450 463.10 5906864.73 N 364200.42 E 0.600 503.51 5906882.44N 364208.03 E 0.600 522.71 5906905.49 N 364217.75 E 0.600 547.65 5906945.75 N 364234.24 E 0.600 591.04 5906985.50 N 364249.89 E 0.600 633.69 5906988.94 N 364251.22 E 0.600 637.38 5907024.68 N 364264.63E 0.750 675.51 5907063.20 N 364278.32 E 0.750 716.39 5907101.06 N 364290.96 E 0.750 756.30 5907138.25 N 364302.56 E 0.750 795.26 5907174.77N 364313.11 E 0.750 833.25 5907210.61N 364322.61E 0.750 870.26 5907240.36 N 364329.81 E 0.750 900.76 5907245.76 N 364331.06 E 0.778 906.29 Alaska State Plane Zone 3 Badami CPF Comment BHA Tendency @ 0.450°/100ft: 6324.90ft MD, 6280.32ft 'i'VD BHA Tendency @ 0.600°/100ft: 7009.87ff MD, 6885.16ft 'I-VD Top Mid Brookian BHA Tendency @ 0.750°/100ft: 7408.71ft MD, 7243.64ft TVD BHA Tendency @ 0.778°/100ft: 8084.49ft MD, 7865.72ft 'I'VD Continued.., 26 February, 1998 - 14:19 - 3 - DrillQuest Sperry-Sun Drilling Services Proposal Report for B1-18 Wp4 Badami Measured Depth' (ft) Incl, Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 8200.00 20.116 11.534 7919.47 7973.87 8285.58 19.462 11.163 8000.00 8054.40 8300.00 19.352 11.098 8013.60 8068.00 8400.00 18.589 10.627 8108.17 8162.57 8500.00 17.828 10.118 8203.16 8257.56 8600.00 17.067 9.565 8298.56 8352.96 8700,00 16,309 8,961 8394,35 8448,75 8757,92 15,870 8,586 8450,00 8504,40 8800,00 15.552 8,301 8490,50 8544,90 8900,00 14,798 7.575 8587,02 8641,42 8913,42 14,696 7,472 8600,00 8654,40 9000,00 14,046 6,773 8683,87 8738,27 9100,00 13,296 5,882 8781,03 8835,43 9189,94 12,626 4,993 8868,68 8923,08 9200,00 12,551 4,888 8878,50 8932,90 9291,57 11,872 3,869 8968,00 9022,40 9293,24 11,859 3,850 8969,63 9024,03 9300,00 11,809 3,770 8976,25 9030,65 9400,00 11,073 2,505 9074,26 9128,66 9500.00 10.342 1,063 9172,52 9226,92 9600,00 9,619 359,405 9271,00 9325,40 9700,00 8,905 357,483 9369,70 9424,10 9800,00 8.202 355,231 9468,59 9522,99 9900,00 7,515 352,566 9567,65 9622,05 10000.00 6,846 349,375 9666,86 9721,26 10066,71 6,414 346.884 9733,13 9787,53 10100,00 6,203 345.513 9766.22 9820,62 10200.00 5,595 340,789 9865,69 9920,09 10288,02 5,097 335,731 9953,32 10007,72 10300.00 5.033 334,966 9965,26 10019,66 862,15 N 397.70 E 890.56 N 403.41E 895,26 N 404.33E 927,19 N 410.46E 957,92 N 416,09E 987.46 N 421,22E 1015.81 N 425,84E 1031,67 N 428.29E 1042,94 N 429,97 E 1068.86 N 433.,58E 1072.25 N 434.03E 1093.57 N 436.70 E 1117.06 N 439.31 E 1137.14 N 441.22. E 1139.33 N 441.41 E 1158.64 N 442.9OE 1158.98 N 442.92E 1160.36 N 443.01E 1180.17 N 444.10 E 1198.74 N 444.69 E 1216.07 N 444.77E 1232.15 N 444.34E 1246.99 N 443.41E 1260.59 N 441.97 E 1272.93 N 440.03 E 1280.47 N 438.45E 1284.02 N 437.58 E 1293.85 N 434.62 E 1301.47 N 431,60 E 1302.43 N 431.16 E Global Coordinates Dogleg Vertical Northings Eastings Rate Section (fi) (fi) (°/lOOff) (fi) 5907279.91 N 364338,80 E 0,778 941,15 5907308.21 N 364345,01 E 0,778 969,97 5907312.90 N 364346,02 E. 0,778 974.74 5907344,71 N 364352.72 E 0,778 1007,05 5907375.34N 364358.90 E 0,778 1038,07 5907404,78 N 364364,56 E 0,778 1067,81 5907433.03 N 364369,69 E 0,778 1096,26 5907448.85 N 364372,42 E 0,778 1112,14 5907460,09 N 364374,30 E 0,778 1123,40 5907485.94 N 364378.38 E 0,778 1149,23 5907489,32 N 364378,89 E 0,778 1152,60 5907510,59 N 364381,94 E 0,778 1173,76 5907534,03 N 364384,97 E 0,778 1196,97 5907554,07 N 364387,25 E 0,778 1216,72 5907556.26 N 364387,48 E 0,778 1218,87 5907575,54N 364389,31 E 0,778 1237,76 5907575,88 N 364389,34E 0,778 1238,09 5907577.26 N 364389,45E 0,778 1239,44 5907597.04N 364390,90 E 0,778 1258,68 5907615.60 N 364391,82 E 0,778 1276,60 5907632,92 N 364392,21 E 0,778 1293,18 5907649,01N 364392,07 E 0,778 1308,42 5907663.87 N 364391,41 E 0,778 1322,32 5907677,49 N 364390,21 E 0,778 1334,88 5907689,86 N 364388,49 E 0,778 1346,10 5907697,43N 364387,05 E 0,778 1352,84 5907700.99 N 364386,24 E 0,778 1355,97 5907710.88 N 364383,46 E 0,778 1364,50 5907718,55 N 364380,58 E 0,778 1370.88 5907719,52 N 364380,16 E 0,778 1371,67 Comment M90 Base West Sak (M85) 7' Casing C2 Shallowest Badami Sand F2 A1 K3 Alaska State Plane Zone 3 Badami CPF Continued... 26 February, 1998- 14:19 - 4 - DrillQuest Sperry-Sun Drilling Services Proposal Report for B 1-18 Wp4 Badami Measured Sub-Sea Vertical Local Coordinates Depth' Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/lOOft) (ft) 10387.17 4.595 328.788 10052.12 10106.52 1308.88 N 427.73 E 10400.00 4.535 327.781 10064.91 10119.31 1309.75 N 427.20 E 10500.00 4,125 319.005 10164.62 10219.02 1315.81 N 422.73 E 10600.00 3.830 308.602 10264.38 10318.78 1320.61 N 417.76 E 10601.62 3.827 308.421 10266.00 10320.40 1320.68 N 417.67 E 5907726.03 N 364376.84 E 0.778 1376.82 5907726.91 N 364376.32 E 0.778 1377.49 5907733.04 N 364371 °97 E 0.778 1381.96 5907737.93 N 364367.08 E 0.778 1385.08 5907738.00 N 364367.00 E 0.778 1385.12 10700.00 2.921 301.805 10364.21 10418.61 1324.04 N 412.97 E 10781.47 2.223 292.357 10445.60 10500.00 1325.73 N 409.75 E 5907741.45 N 364362.36 E 1.000 1386.94 5907743.20 N 364359.16 E 1.000 1387.61 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per lOOft. Vertical Section is from Well Reference and calculated along an Azimuth of 17.175° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10781.47ft., The Bottom Hole Displacement is 1387.61ft., in the Direction of 17.175° (True). Alaska State Plane Zone 3 Badami CPF Comment F5 BHA Tendency @ 1.000°/100ft: 10601.62ft MD. 10320.40ft TVD Target: New B'1-18 Target, 200.00 Radius., Geological Total Depth · 10781.47ft MD, 10500.00ft TVD 4 1/2' Liher 26 February, 1998 - 14:19 - 5 - DrillQuest TONY KNOWLE$, GOVEI~NOF~ ~LASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 January 29. 1998 Mike Miller Badami Drilling Team Leader BP Exploration ('Alaska) Inc. P O Box 196612 ,Anchorage, AK 99519 Re: Badami B 1 - 18 BP Exploration (.Alaska') Inc. Permit No. 98-12 Sur. Loc.: 1424'SNL. 86'WEL. Sec. 8. T9N, R20E. UM Btmhole Loc: 334'SNL. 10I'EWL. Sec. 9. T9N. R20E. UM Dear Mr. Miller: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of(be Commission may witness the test. Notice max,' be given by contacting the Commission petroleum field inspector on the North David W. J~ston Chairman BY ORDER OF THE COMMISSION dlf;enclosures CC; Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Consemation w/o encl. STATE OF ALASKA A~oKA OIL AND GAS CONSERVATION'~COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI I--IService [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 54.4' Badami 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 365533 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1424' SNL, 86' WEL, SEC. 8, T9N, R20E, UM Badami At top of productive interval 8. Well Number Number 2S100302630-277 334' SNL, 101' EWL, SEC. 9, T9N, R20E, UM B1-18 At total depth 9. Approximate spud date Amount $200,000.00 334' SNL, 101' EWL, SEC. 9, T9N, R20E, UM 02/01/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 367011, 101'I B1-21,26.58' at 700' MD 5120 10962' MD / 10654' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 500' MD Maximum Hole Angle 35.30° Maximum surface 4400 psig, At total depth (TVD) 10094' / 6326 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H~40 Weld 80' 37' 37' 116' 116' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 4523' 35' 35' 4558' 4554' 1485 sx PF 'E', 340 sx 'G' 8-1/2" 7" 29# USS95 BTC-Mod 8777' 33' 33' 8810' 8654' 165 sx Class 'G' 6" 4-1/2" 12.6# L-80 BTC-Mod 2301' 8660' 8531' 10961' 10654' 285 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface IntermediateE'?' ~,~,~ 9 Production R '{ F! Liner ~- -' Perforation depth: measured 'N~Sga 0ii c.c. true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mike Miller, 564-5066 Prepared By Name/Number: Kathy Campoamor, 564-5122 ,21.1Signedhereby certify that the foregoing,~,¢ ,, .-'¢~..--~_is true and correct to the best of my knowledge/il/~'~l~ Mike Miller~l¢' ~../'~~__~') Title Badami Drilling Team Leader Date [ Oommission Use Only Permit Number J AP, Number I App. rova, Da_ts J See cover letter ~"-/2... 50- C:~ ~-. ~ - .~. 2_ 22.5- ~ l[g~-~ R~ for other requirements Conditions of Approval: Samples Required []Yes [] No Mud Log Requi~red I J-lYes []No Hydrogen Sulfide Measures []Yes ~ No Directional Survey Required J~Yes [] No Required Working Pressure for BOPE ['-I2M; I--I3M; I--I5M; J~IOM; F-I15M Other: '7-¢'~2"7" ~oj::)~" ~r/~/~.igned By by order of Approved By David W. J0hnst~mmissioner the commission Date llicate Form 10-401 Rev. 12-01-85 Submit' Shared Services Drilling Contact: I Well Name: Type of Well (producer or injector): Mike Miller I B1-18 I Well Plan Summary IPr°ducer I 564-5066 Surface Location: 1424'FNL 86' FEL SEC 8, T9N, R20E, UM, AK Badami Sand F5 Primary 334' FNL 101'FWL SEC 9, T9N, R20E, UM, AK target Bottom Hole Location (TD) 334' FNL 101' FWL, SEC 9, T9N, R20E, UM AK ]AFE Number: J 880453 I Rig: I Nabors 28E Estimated Start Date: I FEB. 10, 1998 I ! Operatin~l days to complete: 1 22 IKBE: AMSL 54.4 I Well Desitin: Ultra slimhole Formation Markers: Formation Tops MD TVD (bkb) Remarks base permafrost 1943 1939 Base West Sak 8626 8054 Shallowest Badami Sand 9261 9022 Badami Sand F2 9263 9024 Badami Sand A1 10093 9787 Badami Sand K3 10315 10007 Badami Sand F5 10414 10106 Primary Sand Total Depth 10962 10654 Casin~lrrub in~l Pro~lram: Hole ~ize - Csg'/ Wt/Ft Grade Conn Length Top Btm Tb~l O.D. . MDrrVD MD/TVD brt 24" 20" 91.1# H-40 Weld 80 37/37 116/116 12-1/4" 9-5/8" 40# L-80 BTC 4523 35/35 4558/4554 8-1/2" 7" 29fl USS95 BTC 8777 33/33 8810/8654 mod 6" 4-1/2" 12.6# L-80 BTC 2301 (150' 8660/8531 10961/10654 mod lap into 7") Internal yield pressure of the 7" 29#/ft USS95 casing is 9690 psi, which is greater than the maximum anticipated surface pressure of 4400 psi (6326 psi at 10094' tvd; gas, 0.1 psi/ft, surface to 6570'; oil, 0.36 psi/ft, 6570 to 10094' tvd). Wellhead rating is 5000 psi for starting head (intermediate casing) and 10,000 psi for tubing head (10,000 psi is required not for drilling, but for injection, during which surface pressures will reach 5500 psi). BOPE is 10000 psi to match the wellhead rating and to allow for any remote chance that a higher pressure sand is encountered that would exceed 5000 psi shut-in surface pressures. Logging Program' Open Hole Lo~ls: Surface None Intermediate MWD/GR on last bit trip Final Cased Hole Logs: run 1' HIDL/MRIL/STAR, run 2: ZDL/CN/MAC,Core 120 ft. MWD/GR last bit trip · SBT not required per 20 AAC 25.030 Mud Pro~lram: I Special design considerations I None Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~lel ~lel Loss 8.6 150 25 20 45 9 10 to to to to to to to 9.8 300 60 30 60 9.5 15 Intermediate Mud Properties: I KCL polymer Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~lel gel Loss 9.2 45 15 8 15 8.5 6-8 to to to to to to to ,. 10.1 55 20 10 25 9.5 4-6 'Production Mud Properties: I KCL polymer Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~lel ~lel Loss 12.0 45 10 8 15 8.5 4-5 . to to to to to to to 13.5 55 15 10 20 9.5 4-5 Well Control (Secondary): Well control equipment consisting of 10,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics on file. Directional: IKOP: 11%500'MD 2"a.7203'md I Maximum Hole Angle: 35.30° Close Approach Well: B1-21=26.58'@ 700'md, B1-21=86.17'@ 2587'md Waste Manaqement: Cuttings Handling: the cuttings will be processed through the onsite Grind and Inject facility and injected into disposal well B1-01. Surface gravels will be washed and stored for construction purposes. Fluid Handling: All drilling and completion fluids will be processed through the onsite Grind and Inject facility and injected into disposal well B1-01. Annular Injection: No annular injection is planned at this time. Badami B1-18 Proposed Summary of Operations 1. The 20" conductor and cellar are already installed (all cellars and conductors were installed in winter 1997). Weld a starting head on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 28E drilling rig. //~,,.~f~ ~-~r~¢'. 4. Build Spud Mud. 5. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD from surface to TD. 6. Run 9-5/8" casing and cement to surface in two stages. 7. ND 20 diverter and NU 13-5/8" 10M BOPE. Test BOPE to 6000 psi minimum. 8. Pick up BHA. RIH, test casing to 3000 psi. Drill out Float Equipment and 20' of new formation. Perform LEAKOFF TEST as per SSD Standard Operating Procedure. Contact-Badami Team Leader or SSD Superintendent with LOT results before drilling ahead. 9. Drill 8-1/2" hole to intermediate TD as per direCtional plan with MWD directional surveys. Run open hole logs. 10. Run 7" casing. Cement as per Cement Basis of Design. 11. Test casing to 3500 psig for 30 min. 12. Drill out shoe joint, perform a FIT to 15.5 ppg EMW (to leak off to obtain rock strength data), and drill to TD as per directional plan with MWD directional tool. Run LWD/GR on last bit trip. Planned core interval in 6" production hole is 120' md. 13. Run open hole logs as per plan. 14. Run and cement 4-1/2" 12.6# L80 production liner with 2-7/8" VAM inner string, displace cement with drilling fluid. Set liner hanger and liner top packer. Release off of 4-1/2" 12.6# L80 BTCmod production liner, pick up and clear top of tieback extension and circulate excess cement/contaminated mud to surface the Iongway. 15. Test 4-1/2" 12.6# BTC mod production liner and 7" 29# BTC mod casing to 3500 psi for 30 minutes to confirm liner and lap pressure integrity. Circulate well to completion fluid (fresh water) with 25gals/100 bbl of 7726 Corexit corrosion inhibitor. 16. Run 4-1/2"12.6# L80 tubing per completion procedure. Set two way check in FMC 4-1/2" tubing hanger. 17. ND 13-5/8" 10M Hydril BOPE, NU 11" 10M x 4-1/16" 5M FMC tubing head adaptor and 4-1/16" 5M Cameron tree and test tree to 5000 psi. Pull two way check, drop packer setting ball/rod assembly. Set HES TNT permanent packer with 5000 psi. Test 4-1/2" 12.6# L80 tubing to 3500 psi for 30 minutes. Test annulus above packer to 3500 psi for 30 minutes. Shear RP valve & freeze protect 4-1/2" 12.6# L-80 tubing and 4-1/2" tubing x 7" annulus. Set BPV in 4-1/16 10M FMC tubing hanger. 18. Rig down and move rig to next well. DRILLING HAZARDS AND RISKS: Nearest offset wellbore - B1-21=26.48' @ 700' md, B1-21=86.17' @ 2587' md, B1-11=91'@ 2790'md Stuck pipe - UGNU sands, West Sak Sands - differential Coals - stringers throughout well, 4500' to Canning formations at 9500' tvd. Well Control- Badami sands are overpressured- mud weight of 12.0 to 13.5 ppg will be required. CASING SIZE: 9-5/8" SPACER: Badami B1-18 SURFACE CASING CEMENT PROGRAM - HALLIBURTON 50 bbls fresh water. STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: STAGE1 TAIL: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 350SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on gauge hole annular capacity from 750' above the casing shoe to the ES cementer at 2200' md, plus 50% excess. Premium 2% calcium chloride 15.8 ppg YIELD:l.15 ft3/sx MIX WATER: 5.0 gal/sk 340 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ' Volume based on 750' md of fill in the gauge hole plus 50% excess plus 80' shoe joint. SPACER: 50 BBLS FRESH WATER STAGE 2: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 1115 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on gauge hole annular capacity from the ES Cementer at 2200' surface plus 250% excess, plus casing capacity from surface to the stage collar. Note: Pump until cement returns are observed at surface. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY WITH APPROVAL OF APPROPRIATE SUPERINTENDENT IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 Badami 131-18 INTERMEDIATE CASING CEMENT PROGRAM- HALLIBURTON CASING SIZE: 7" SPACER: 20 bbls fresh water preflush followed by 50 bbls alpha spacer weighted 1ppg above current mud weight. CEMENT: ADDITIVES: WEIGHT: APPROX #SACKS: Premium HR-5 as required (retarder), .2% Halad-344 (fluid loss), 0.2% CFR-3 (dispersant) 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 165 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on 1000' md of gauge hole annular capacity from shoe, plus 50% excess, plus 80' shoe joint. Badami B1-18 LINER CEMENT PROGRAM- HALLIBURTON CASING SIZE: 4-1/2" SPACER: 20 bbls fresh water preflush followed by 50 bbls alpha spacer weighted 1ppg above current mud weight (adjust weight to ECD if critical) CEMENT: ADDITIVES: WEIGHT: APPROX #SACKS: Premium HR-5 as required (retarder), .45% Halad-344 (fluid loss), 0.2% CFR-3 (dispersant) 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 285 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. Volume based on open gauge hole annular capacity, plus 50% excess, plus 80' shoe joint, plus liner lap plus 200' above liner top with drillpipe in hole. BP Exploration B1-18 llVp2 I DrillQuesi 0 1.000°/100ft: 500,(]Oft MD, 500.00ft TVD I 6.000': 110~.0~fl MD. 10~8.g011TVD 1.000'1100~1:1400.0~t MD, 1397.26fl 1-VD End DIr, Sail O 0.000': 2000.0Oft MD, 1996.16fl TVD 9 5/8" Casing - 4558.24 MD, 4554.40 TVD Proposal Data for B1-18 Wp2 Ve~J Odgtn: W~ Reference I Ho~zon~ OHgtn: We~ Referee Me~t ~: ~ Ref~e: Tree ~ ~ ~: ~s per Ve~ ~ D~:We~ Refere~e V~ ~ ~; 0.~ N,0,~ E M~u~ Ind. ~1~ V~I N~ng~ ~=Ung= V~cal ~1~ 0.00 O.OD935 g.9'/I 0.00 0.00 N 0.~30 E O.00 500.(30O.O~O358.97 [ 500.00 0.00 N O.O9 E 0.00 0.0(~] 1100.006.0~O180.O00IO98.90 31.39 S O.0OE -30.93 1400.GO6.C~O180.O~}1397.26 62.75 S O.OO E -61.86 O.0~O 2000.09O.0~O358.9711996.16 94.13 S 0.C(J E -92,81 1.0~O 7203.84O.00[] 358.9717200.09 94.13 S 0.OOE -92.81 0.000 8380.6135..303 8.864 8303.71 252.88 N 54.12 E 258.37 3.000 9237.O835.3(D 8.864 9CO2,69 741.93 N 130.38 E753.29 0.0~3 10413.85 0.0(]0 358,97110106.40 1088.95 N 184.50 E1104.473.009 10961.85 0.000358.97110654.40 10~8.95 N 184.50 E1104.47 l SURFACE LOCATION REFERENCE PLOT DATE: 29 - DECEMBER - 1997 Horlz~nf~l Coordlnate~: 5S436425.04 N. 363925.67 E Created By: flKa Elevation:35.30 fl Rig (EST) 19.1D ft W~ (CSE) Com~In~ta System: NAD27 Alnska Slate PI~"~, Zone 3, US Foot Approved By I Proposal Target Summa~ Target Name: TVI~: 'I~Drkb: W,'lll~ul Off~*.l~: Gl(fi~a! Ctx~rdinates: I T^RGET (634408)IIX152.00 10106.40 1088.95 N, 1~.50 E 5907510.50 N, 364129.70 E DIr 0 3.000'/10Oft: 7203.84fl MD, 7200.0Oft TVD ; Sail ~ 35.303°: 8380.61ft MD, 8303.71ft TVD 7' Casing - 8810.32 MD, 8C~4.40.1VD I 0 Scale: linch = 1200ft Tota~ []ep~: 10961.85fl MD, 10654.40fi TVD 4 1/2' Liner- 10961.85 MD, 10654.40 'T'VD I I I 1200 2400 3600 Vertical Section Section Azimuth: 9.616° (True North) BP Exploration - B1-18 Wp2 I DrillQuest Targc[ Nanl¢: TARGET (6344! X) Scale: linch = 200ft Eastings -200 0 200 400 600 I I I I tTotal Depth: 10961.85f1 MD. 1065-..4Oft TVO :. 100<30.01~l=..~_Target (634408}. End DiG Sail O 0.300': 10413.85ft MD, 10 O( 4 1/2' Casl g - 10961.85 VID..10654.40TVD · _ i 9~o. .69f1TVD / ~"--End D{r, Salt O 35.303': 8380161ft MO, 8303.71 ~t TVD ~ 800 L1 1500.0(~--,~.~Sta.,t Olr O I 00~/100ft - 1400 (X)ff MD 1397.26ft TV~ ' D 558.24 MD, 4554.40TVD 'I ~End Dlr, Sall ~3 0.000°: 2000.04~'I1 MD. 1996.16ft TVD Start D(r ~' 3.000'/100fl: 7205.84ft MD. 7200.00fl TVD I I I I -200 0 200 400 600 Scale: 1 inch = 200ft Eastings Reference is True North 4OO 200 o 1400 1200 9 5/8" Casing - ~06.40ft 'I"V D 10oD 80O 600 o Z 4OO 2O0 Proposal Target Summary TVD~: TVDrkb: Wellhead O£fs~s: Global Ceqxtlin*~:s: 111052.00 10106.40 108g.95 N, 184.50 E 5{YJ?510.50 N, 364129.?0 E II SURFACE LOCATION REFERENCE I PLOT DATE: 29 - DEC.~EMBER ~ IHo~o~Coordlnate,: 5SOS425.04N, 30392S.O7E {Createdey: ~ ~ J RKB E~afl~: ~.30 ~ ~ (ES~ I ~~ I ~9.~o. we~(~ I ~' ~2~2' _, ./ /I · I · BP Exploration Badami Sperry-Sun Drilling Services Measured Sub-Sea Vertical Local Coordinates Depth Incl, Azim, Depth Depth Northlngs Eastings (ft) (ft) (ft) (ft) (ft) 0.00 0,000 0.000 -54.40 0.00 0.00 N 0.00 E 100.00 0.000 0.000 45.60 100.00 0.00 N 0.00 E 200,00 0,000 0,000 145.60 200.00 0.00 N 0.00 E 300.00 0.000 0,000 245.60 300.00 0.00 N 0.00 E 400.00 0.000 0.000 345.60 400,00 0.00 N 0.00 E 500,00 0,000 0,000 445.60 500,00 0.00 N 0.00 E 600.00 1.000 180.000 545.59 599.99 0.87 S 0.00 E 700.00 2.000 180.000 645.56 699.96 3.49 S 0,00 E 800.00 3.000 180,000 745.46 799.86 7.85 S 0.00 E 900.00 4.000 180.000 845.28 899.68 13.96 S 0.00 E 1000.00 5.000 180,000 944.97 999.37 21,80 S 0,00 E 1100.00 6,000 180,000 1044,50 1098.90 31.39 S 0.00 E 1200.00 6.'000 180.000 1143.96 1198.36 41,84 S 0.00 E 1300.00 6,000 180.000 1243.41 1297.81 52.29 S 0.00 E 1400.00 6,000 180.000 1342.86 1397.26 62,75 S 0.00 E 1500.00 5,000 180.000 1442.40 1496.80 72.33 S 0.00 E 1600.00 4.000 180.000 1542.09 1596.49 80,18 S 0.00 E 1700.00 3.000 180.000 1641,90 1696.30 86.28 S 0.00 E 1800.00 2.000 180.000 1741.81 1796.21 90.64 S 0.00 E 1900.00 1.000 180.000 1841.77 1896.17 93.26 S 0.00 E 1943.23 0.568 180.000 1885.00 1939,40 93.85 S 0.00 E 2000.00 0.000 0.000 1941.76 1996.16 94.13 S 0,00 E 2100.00 0,000 0.000 2041.76 2096.16 94.13 S 0.00 E 2200,00 0.000 0.000 2141.76 2196,16 94,13 S 0.00 E 2300.00 0.000 0.000 2241,76 2296.16 94.13 S 0.00 E 2400.00 0.000 0.000 2341.76 2396.16 94.13 S 0,00 E 2500.00 0.000 0.000 2441.76 2496.16 94.13 S 0.00 E 2600.00 0.000 0.000 2541.76 2596,16 94.13 S 0.00 E 2700.00 0.000 0.000 2641.76 2696.16 94.13 S 0.00 E 2800.00 0.000 0.000 2741.76 2796,16 94,13 S 0.00 E Proposal Report for B1-18 - B1-18 Wp2 Global Coordinates Dogleg Vertical NoHhings Eastings Rate Section (fi) (fi) (°/100fi) (fi) 5906425.04 N 363925,67 E 0.00 5906425,04 N 363925.67 E 0.000 0.00 5906425.04 N 363925.67 E 0.000 0.00 5906425.04 N 363925.67 E 0.000 0.00 5906425.04 N 363925.67 E 0.000 0.00 5906425.04 N 363925.67 E 0,000 0.00 5906424.17 N 363925.65 E 1.000 -0.86 5906421.55 N 363925.61E 1.000 -3.44 5906417,19 N 363925.53 E 1.000 -7.74 5906411.09 N 363925.42 E 1.000 -13.76 5906403.24 N 363925.28 E 1.000 -21.50 5906393.66 N 363925.11E 1.000 -30.95 5906383.21N 363924.92 E 0.000 -41.25 5906372.76 N 363924.73 E 0.000 -51.56 5906362.30 N 363924.54 E 0.000 -61.86 5906352.72 N 363924.37 E 1.000 -71.31 5906344.88 N 363924.23 E 1.000 -79.05 5906338.77 N 363924.12 E 1.000 -85.07 5906334.41 N 363924,04 E 1.000 ,-89.37 5906331.79 N 363923.99 E 1.000 -91.95 5906331.20 N 363923.98 E 1.000 -92.53 5906330.92 N 363923.98 E 1.000 -92,81 5906330.92 N 363923.98 E 0.000 -92.81 5906330.92 N 363923.98 E 0.000 -92.81 5906330.92 N 363923.98 E 0.000 -92.81 5906330.92 N 363923.98 E 0.000 -92.81 5906330.92 N 363923.98 E 0.~00 -92.81 5906330,92 N 363923.98 E 0.000 -92.81 5906330.92 N 363923.98 E 0.000 -92.81 5906330.92 N 363923.98 E 0.000 -92.81 Alaska State Plane Zone 3 Badami CPF Comment KOP: Start Dir @ 1.000°/100ft: 500.00ft MD, 500.0Oft TVD End Dir, Sail @ 6.000°: 1100.00ft MD, 1098.90ft 'r'VD Start Dir @ 1.000°/100ft: 1400.00ft MD, 1397.26ft TVD Base Permafrost End Dir, Sail @ 0.000°: 2000.00ft MD, 1996.16ft TVD Con#nue~.. 29 December, 1997- 15:57 - 1- DrillQuest BP Exploration Badami Measured Depth Incl. Azim. (ft) 2900.00 0.000 0.000 3000,00 0.000 o.000 310o.00 0.000 0.000 3200.00 0.000 0.000 3300.00 0.000 0.000 3400.00 0.000 0.000 3500.00 0.000 0.000 3800.00 0.000 0.000 3700.00 0.000 0.000 3800.00 0.000 0.000 3900.00 0.000 0.000 4000.00 0.000 0.000 4100.00 0.000 0.000 4200.00 0.000 0.000 4300.00 0.000 0,000 4400.00 0.000 0.000 4500.00 0.000 0.000 4558.24 0.000 0.000 4600.00 0.000 0.000 4700.00 0.000 0.000 4800.00 0,000 0.000 4900.00 0.000 0.000 5000.00 0.000 0.000 5100.00 0.000 0.000 5200.00 0,000 0.000 5300,00 0.000 0.000 5400.00 0.000 0.000 5500.00 0.000 0.000 5600.00 0.000 0.000 5700.00 0.000 0.000 Sub-Sea Depth (ft) 2841.76 2941,76 3o41.76 3141.76 3241.76 3341,76 3441.76 3541.76 3641.76 . 3741,76 3841.76 3941.76 4041.76 4141.76 4241.78 4341.76 4441.76 45o0.00 4541.76 4641.76 4741.76 4841.76 4941.76 5041.76 5141.76 5241,76 5341.76 5441.76 5541.76 5641.76 Vertical Depth (fi) 2896.16 2996.16 3096.16 3196.16 3296.16 3396,16 3496.16 3596.16 3696.16 3796.16 3896.16 3996.16 4096,16 4196.16 4296.16 4396.16 4496,16 4554.40 4596.16 4696,16 4796,16 4896.16 4996.16 5096.16 5196.16 5296,16 5396.16 5496.16 5596.16 5696,16 Sperry-Sun Drilling Services Proposal Report for B1-18 - B1-18 Wp2 Local Coordinates Northings (ft) 94.13 S 94.13 S 94.13 S 94.13 S 94.13 S 94.13 S 94,13 S 94.13 S 94.13 S 94.13 S 94.13 $ 94,13 S 94,13 S 94.13 S 94.13 S 94.13 S 94.13 S 94,13 S 94.13 S 94,13 S 94,13'S 94.13 S 94,13 S 94.13 S 94,13 S 94.13 S 94,13 S 94,13 S 94.13 $ 94.13 S Global Coordinates Dogleg Vertical Eastings Northings Eastings Rate Section (~) (~) (~) (°/100~) (~) 0.00 E 5906330.92 N 363923.98 E 0.000 -92.81 0.00 E 5906330.92 N 363923.98 E 0.000 -92,81 0.00 E 5906330.92 N 363923.98 E 0.000 -92.81 0.00 E 5906330.92 N 363923.98 E 0.000 -92.81 0.00 E 5906330.92 N 363923.98 E 0.000 -92.81 0.00 E 5906330.92 N 363923.98 E 0,000 -92.81 0.00 E 5906330,92 N 363923.98 E 0.000 -92.81 0.00 E 5906330.92 N 363923.98 E 0.000 -92,81 0.00 E 5906330,92 N 363923.98 E 0.000 -92.81 0.00 E 5906330.92 N 363923.98 E 0.000 -92.81 0.00 E 5906330,92 N 363923.98 E 0.000 -92.81 0.00 E 5906330.92 N 363923,98 E 0.000 -92.81 0.00 E 5906330.92 N 363923,98 E 0,000 -92,81 0.00 E 5906330.92 N 363923.98 E 0.000 -92.81 0.00 E 5906330,92 N 363923.98 E 0.000 -92.81 0.00 E 5906330,92 N 363923.98 E 0.000 -92,81 0,00 E 5906330.92 N 363923,98 E 0.000 -92.81 0,00 E 5906330.92 N 363923.98 E 0.000 -92.81 0.00 E 5906330.92 N 363923.98 E 0,000 -92,81 0.00 E 5906330.92 N 363923.98 E 0.000 -92.81 0.00 E 5906330.92 N 363923.98 E 0.000 -92,81 0.00 E 5906330.92 N 363923.98 E 0.000 -92.81 0.00 E 5906330.92 N 363923,98 E 0.000 -92.81 0.00 E 5906330,92 N 363923,98 E 0.000 -92.81 0.00 E 5906330,92 N 363923,98 E 0.000 -92.81 0.00 E 5906330.92 N 363923.98 E 0,000 -92,81 0.00 E 5906330.92 N 363923.98 E 0.000 -92,81 0.00 E 5906330.92 N 363923.98 E 0.000 -92,81 0.00 E 5906330.92 N 363923.98 E 0.000 -92.81 0.00 E 5906330.92 N 363923.98 E 0,000 ' -92.81 Comment 9 5/8" Casing Alaska State Plane Zone 3 Badami CPF Continued... 29 December, 1997 - 15:57 - 2 - DrillQuest BP Exploration Badami Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (~) (~) (~) 5800.00 0.000 0.000 5741.76 5796.16 5900.00 0.000 0.000 5841.76 5896.16 8000,00 0,000 0.000 5941.76 5996.16 6100.00 0.000 0.000 6041.76 6096.16 6200.00 0,000. 0.000 6141.76 6196.16 6300.00 0.000 0.000 6241,76 6296,16 6400.00 0.000 0,000 6341.76 6396.16 6500.00 0,000 0.000 6441.76 6496.16 6600.00 0.000 0.000 6541.76 6596.16 6700.00 0.000 0,000 6641.76 6696.16 6800,00 0,000 0.000 6741.76 6796.16 6900.00 0.000 0,000 6841.76 6896.16 7000.00 0,000 0.000 6941,76 6996.16 7008.24 0.000 0.000 6950,00 7004.40 7100.00 0.000 0.000 7041,76 7096.16 7200.00 0.000 0.000 7141.76 7196.16 7203.84 0.000 0.000 7145.60 7200.00 7300.00 2.885 8.864 7241,72 7296.12 7400.00 5.885 8,864 7341.42 7395,82 7500.00 8,885 8.864 7440.58 7494.98 7600.00 11.885 8.864 7538.93 7593.33 7700.00 14.885 8.864 7636.20 7690.60 7800.00 17.885 8.864 7732,13 7786,53 7900.00 20.885 8,864 7826.45 7880.85 8000.00 23,885 8.864 7918,90 7973.30 8089.66 26.575 8.864 8000.00 8054.40 8100.00 26.885 8.864 8009.24 8063.64 8200.00 29.885 8.864 8097.21 8151.61 8300.00 32.885 8.864 8182.57 8236.97 8380.61 35.303 8.864 8249.31 8303.71 Sperry-Sun Drilling Services Proposal Report for B1-18 - B1-18 Wp2 Local Coordinates Northings (ft) 94.13 S 94,13 S 94.13 S 94.13 S 94.13 S 94.13 S 94.13 S 94.13 S 94.13 S 94,13 S 94.13 S 94,13 S 94.13 S 94.13 S 94,13 S 94.13 S 94.13 S 91.74 S 84,19 S 71.49 S 53.68 S 30.81 S 2.94 S 29.85 N 67.47 N 105.23 N 109.83 N 156.79 N 208.24 N 252,88 N Global Coordinates Dogleg Eastings Nothings Eastings Rate (fi) (fi) (fi) (°/100fi) 0.00 E 5906330.92 N 363923.98 E 0.000 0.00 E 5906330.92 N 363923.98 E 0.000 0.00 E 5906330.92 N 363923.98 E 0,000 0.00 E 5906330.92 N 363923.98 E 0.000 0,00 E 5906330.92 N 363923.98 E 0.000 0,00 E 5906330,92 N 363923.98 E 0.000 0,00 E 5906330,92 N 363923.98 E 0.000 0,00 E 5906330.92 N 363923.98 E 0,000 0.00 E 5906330.92 N 363923.98 E 0.000 0,00 E 5906330.92 N 363923.98 E 0,000 0.00 E 5906330.92 N 363923,98 E 0,000 0.00 E 5906330.92 N 363923.98 E 0.000 0,00 E 5906330.92 N 363923.98 E 0.000 0.00 E 5906330.92 N 363923,98 E 0.000 0,00 E 5906330.92 N 363923.98 E 0.000 0.00 E 5906330.92 N 363923.98 E 0.000 0.00 E 5906330,92 N 363923.98 E 0.000 0.37 E 5906333.31 N 363924.39 E 3.000 1,55 E 5906340,84 N 363925.71 E 3.000 3.53 E 5906353.50 N 363927.92 E 3.000 6.31E 5906371.25 N 363931.01E 3.000 9.88 E 5906394.06 N 363934.99 E 3.000 14.22 E 5906421,84 N 363939,84 E 3.000 19.33 E 5906454.54 N 363945.54 E 3,000 25.20 E 5906492.05 N 363952.08 E 3.000 31.09 E 5906529.69 N 363958.65 E 3.000 31.81E 5906534.28 N 363959.44 E 3.000 39.13 E 5906581.10 N 363967.61E 3.000 47,15 E 5906632.40 N 363976,56 E 3,000 54.12 E 5906676.91N 363984.32 E 3.000 Ve~ical Section (fi) -92.81 -92.81 -92.81 -92.81 -92.81 -92.81 -92.81 -92.81 -92.81 -92.81 -92.81 -92.81 -92.81 -92.81 -92.81 -92.81 -92.81 -90.39 -82.75 -69.89 -51.87 -28.73 -0.52 32.66 70.74 108.94 113.60 161.13 213.19 258.37 Alaska State Plane Zone 3 Badami CPF Comment Top Mid Brookian Stad Dir @ 3.000°/100ft: 7203.84ft MD, 7200.00ft TVD M90 End Dir, Sail @ 35.3030: 8380.61ft MD, 8303.71ft TVD Continued.. 29 December, 1997 - 15:57 - 3 - DrillQuest Sperry-Sun Drilling Services Proposal Report for B1-18 - B1-18 Wp2 BP Exploration Badami Measured Sub-Sea Ve~ical Depth Incl. Azim. Depth Depth Northings (ft) (ft) (fi) (fi) 8400.00 35.303 8.864 6265.14 8319.54 263.96 N 8500.00 35.303 8.864 8346.75 8401.15 321.06 N 8600.00 35.303 8.864 8428.36 8482.76 378.16 N 6626.52 35.303 8.864 8450.00 8504.40 393.30 N 8700.00 35.303 8.864 8509.97 8564.37 435.26 N 8800.00 35.303 8.864 8591.58 8645.98 492.36 N 8810.32 35.303 8.864 8600.00 8654.40 498.25 N 8900.00 35.303 8.864 8673.19 8727.59 549.46 N 9000.00 35.303 8.864 8754.80 8809.20 606.56 N 9100.00 35.303 8.864 8836.41 8890.81 663.66 N 9139.54 35.303 8.864 6868.68 8923.08 686.23 N 9200.00 35.303 8.864 8918.02 8972.42 720.76 N 9237.08 35.303 8.864 8948.29 9002.69 741.93 N 9261.13 34.582 8.864 6968.00 9022.40 755.54 N 9263.11 34.522 8.864 8969.63 9024.03 756.65 N 9300.00 33.416 8.864 9000.22 9054.62 777.02 N 9400.00 30.416 8.864 9085.10 9139.50 829.25 N 9500.00 27.416 8.864 9172.62 9227.02 877.01 N 9600.00 24.416 8.864 9262.55 9316.95 920.19 N 9700.00 21.416 8.864 9354.65 9409.05 958.66 N 9800.00 18.416 8.864 9448.66 9503.06 992.31'N 9900.00 15.416 8.864 9544.32 9598.72 1021.06 N 10000.00 12.416 8.864 9641.38 9695.78 1044.82 N 10093.48 9.611 8.864 9733.13 9787.53 1062.46 N 10100.00 9.416 8.864 9739.56 9793.96 1063.53 N 10200.00 6.416 8.864 9838.59 9892.99 1077.13 N 10300.00 3.416 8.864 9938.21 9992.61 1085.60 N 10315.13 2.962 8.864 9953.32 10007.72 1086.43 N 10400.00 0.416 8.864 1.0038.15 10092.55 1088.90 N 10413.85 0.000 0.000 10052.00 10106.40 1088.95 N Local Coordinates Global Coordinates Dogleg Ve~ical Eastings NoHhings Eastings Rate Section (fi) (ft) (fi) (°/100ft) (fi) 55.84 E 5906687.95N 363986.25 E 0.000 269.58 64.75 E 5906744.88 N 363996.17 E 0.000 327.36 73.65 E 5906801,81N 364006.10 E 0.000 385.15 76.01E 5906816.91N 364008.74 E 0.000 400.47 82.56 E 5906858.74N 364016.03 E 0.000 442.93 91.46 E 5906915.68 N 364025.96 E 0.000 500.72 92.38 E 5906921.55 N 364026.99 E 0.000 506.68 100.37 E 5906972.61N 364035.89 E 0.000 558.50 109.27 E 5907029.54 N 364045.82 E 0.000 616.29 118.18 E 5907086.47 N 364055.75 E 0.000 674.07 121.70 E 5907108.98 N 364059.67 E 0.000 696.92 127.08 E 5907143.40 N 364065.68 E 0.000 731.86 130.38 E 5907164.51 N 364069.36 E 0.000 753.29 132.50 E 5907178.08 N 364071.73 E 3.000 767.06 132.68 E 5907179.18 N 364071.92 E 3.000 768.18 135.85 E 5907199.49 N 364075.46 E 3.000 788.79 144.00 E 5907251.57 N 364084.54 E 3.000 841.65 151.45 E 5907299.19 N 364092.85 E 3.000 889.99 158.16 E 5907342.24 N 364100.36 E 3.000 933.69 164:18 E 5907380.60 N 364107.04 E 3.000 972.62 169.43 E 5907414.15 N 364112.90 E 3.000 1006.67 173.91 E 5907442.81 N 364117.89 E 3.000 1035.76 177.62 E 5907466.50 N 364122.03 E 3.000 1059.81 180.37 E 5907484.09 N 364125.09 E 3.000 1077.66 180.53 E 5907485.15 N 364125.28 E 3.000 1078.74 182.66 E 5907498.72 N 364127.65 E 3.000 1092.51 183.98 E 5907507.16 N 364129.12 E 3~00 1101.08 184.11 E 5907507.99 N 364129.26 E 3.000 1101.92 184.49 E 5907510.45 N 364129.69 E 3.000 1104.42 184.50 E 5907510.50 N 364129.70 E 3.000 '1104.47 Alaska State Plane Zone 3 Badami CPF Comment Base West Sak (M85) 7" Casing C2 Start Dir @ 3.000°/100ft: 9237.08ft MD, 9002.69ft TVD Shallowest Badami Sand F2 A1 K3 Tar(~et (634408) End Dir, Sail @ 0.000°: 10413 85ft MD, 10106.40ft 'i-VD Tar{~et: 634408,'300.00 Radius. Geological ' Continued... 29 December, 1997- 15:57 - 4 - DrillQuest Sperry-Sun Drilling Services Proposal Report for B1-18 - B1-18 Wp2 BP Exploration Badami Measured Sub-Sea Ve~ical Depth Incl. Azim. Depth Depth Nothings (~) (~) (~) (~) 10413.97 0,000 0.000 10052,12 10106.52 1088.95 N 10500.00 0.000 0.000 10138,15 10192,55 1088.95 N 10600.00 0.000 0.000 10238,15 10292.55 1088,95 N 10700,00 0.000 0.000 10338.15 10392.55 1088.95 N 10800.00 0.000 0.000 10438.15 10492.55 1088.95 N 10900.00 0,000 0.000 10538.15 10592.55 1088,95 N 10961.85 0,000 0.000 10600.00 10654.40 1088.95 N Local Coordinates Global Coordinates Dogleg Ve~ical Eastings Northings Eastings Rate Section (fi) (fi) (fi) (Vl00ff) (fi) 184.50 E 5907510.50 N 364129.70 E 0.000 1104.47 184.50 E 5907510.50 N 364129.70 E 0.000 1104.47 184.50 E 5907510.50 N 364129.70 E 0.000 1104.47 184.50 E 5907510.50 N 364129.70 E 0.000 1104.47 184.50 E 5907510.50 N 364129.70 E 0.000 1104.47 184.50 E 5907510.50 N 364129.70 E 0.000 1104.47 184.50 E 5907510.50 N 364129.70 E 0.000 1104.47 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Sevedty is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 9.616° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10961.85ft., The Bottom Hole Displacement is 1104.47ft., in the Direction of 9.616° (True). Comment F5 Total Depth: 10961.85ft MD, 10654.40ft TVD 4 1/2" Liher Alaska State Plane Zone 3 Badami CPF 29 December, 1997- 15:57 - 5- DrillQuest 5631 Silverado Way #G Anchorage, Alaska 99518 (907) 563-3256 Fax (907) 563-7252 Shared Services Drilling Select POC Name Approved Well Close Approach Review Badami B1-18 Wp2 Fh'st Name, The above mentioned well has been scanned using standard anti-collision methods via DEAP. The scan wang performed with the following parameters: Start Sca. Inspection Zone End Scan Inspection Zone Starting Scan Radius Rate of Radius Increase (per 1000') 35.30' 10,961.85 ' 200,00' 75.00' Anti-Collision Scan summary: At the planned KOP the Starting Scan Radius is 98.235' larger than DEAP's default settings of 100' Start Scaa Radius increasing at 50' per 1000 'MD for a new-drill well scan, thus DEAP's defaults would be equal to 101.765' at Ihe Start Scan Inspection Zone as stated above. These numbers are used (o produce a final scan radius of 1019.49125' which is 371.39875' la~ger than DEAP's default value of 648.0925' Scan Parameters Comments: At this enlarged radius the following wells were detected during the scan (Basea on cl(~est'Allowable Deviation from Plan'): Note: this list may not include all the wells detected, only those of which are of concern or may effect Tolerance Line drawing! Coml)afisou Subject Well ])lanned Wall ]Relative Allowable Shut-in Re(~uired? (Sevcradon notes) Status Well: ]Depth Seperatio. Azimuth Deviation ('= E~tln~ $urvtwl 1'= We/l f'lan MDt (Point ta Poinl! t'rC D~rec#on} IAapro~_ TL Dbt~ BI-I1 W[~4 2789.56 'MD 90.95 ' 262.00 ° 39.92 ' No, will need tore-run onceBl-ll drills Major B 1-21 Rig Mwd 699.55 'MD 26.58 ' 121.30 ° 12.27 ' No Mojor B1-21 Rig Mwd . 2587.16 'MD 86.17 ' 126.30 ° 38.60 ' No Major ---- Tolerance Plot required: Yes Close Approach Comments: We will need to re-run this scan to obtain new numbers once drilling of the surface hole of B1-11 is done. Close Approach Scan Performed by: Date: Checked by: Date: Approved by: Date: bl-18w-1.xls AWD Prn',rimiI,J I~,,,i .... Sperry-Sun 'Drilling Services Proposal Data - B1-18 - B1-18 Wp2 :~7: 0.000 4 i1088.95 December, 1997- 8:14 " ' STATE OFALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL · Abandon l-~Type of Request. ~A~, ca~og ~,St~l~nd ' ~lPlu~glw .... Q'nme Extension l~Perfo~e , U nepab'Well I-I Pull T~,~blng LIVarbnce ~Othar [.J Chenge Approved Program [] Operation 6hu{dcmm [] Re. Enter Suspended Welt [] SUmulata 2. Name of Operator ...... 5. Type of well: 6, O~rr{ Elevation (DF or KB) BP Exploration (Alaske) Inc. [] Development .... KBE~--~')4.4' 3;' Address I~ Sa~tlgraphlc BADAMI P.O. Box lg6612, Ancherage, Alaska 9951g-8612 I-],~rvice 4~' Location dwell at surface ..... 8; Welt Number B1.18 TgN R2Or: ~ 8; 15t7' FNL& 86' FEI_ 9. ~e~rr~t I~Umber At top of productive interval 97'-174 10. APl Number At effective depth S0-02g-22809 tl. Field and Pool At total depth Badaml Reid / Badami Oil Pool TgN R20 E.Seo ~ 98' FNL& 327, FWL 12. Present well condition summary Tot~! depth: measured 10724 feet Plu~s (measured) true vertical 10423 feet Effective depth: measured '10640 feet Junk(me~ true vert[ceI 10339 feet Casing ~ Sl~e Cemented MD TVD Structural Conductor 80' 20' est. 2~0. ~ Arcttae! 118' 116' Surface 4514' ~-5/8' 1480 bbls PF 'E' 4~.~0' 4545 Intermediate 881g' 7" 41 bbl , 8855' 8575 Production Liner 2016' 4-1/2' ~ bb115.8 ppg 10724' 10423 Perforation depth', me=a'ed N/^ tTUe vertical Tubing (size, grade, and meas~ed dept~ 4-1/2' 12.6~ L.-80 at 8023'MD · 'Packers and S$SV (type and meas~ depth) HF__~ 'HXO" SSSV Landing nipple at PPPP'MD; HES TNT packer at 8580'MD , 13. Atmchmen{s [] Description $[xnmary of ~ [] Detailed operattom program [] BOP sketch 14. Estimated d~te for comrner~ op~ 15. Status of well class~7.ations as: 4/15~8 16. If proposal was verbaJly approved ~}OII [] Gas [] $1~pended Name of approver Date approved - Ca~ Eng/~eer lVama/IWm~. 81fl Breo~ S~l~ ~ l~l~u'~l By NamelNumbec Ooa"~n~ Use Only Form 10403 Rev. 0~15/88 · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~'~/OO INIT CLASS WELL NAME~,o~,'_..,. Z~/-_//<~ PROGRAM: exp [] dev~ redrll [] serv [] wellbore seg F3 ann. disposal para req [] ,~_Y GEOL AREA ~-?'~ UNIT# ,//<:~ ~ ? ON/OFF SHORE /'3'/~ ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ~ N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N ENGINEERING APPR D/~TE 14. Conductor string provided ................... (~ NN 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... ',~.., 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... ,~Y N 22. Adequate wellbore separation proposed ............. ~) N 23. If diverter required, does it meet regulations .......... N ¢'..L- 24. Drilling fluid program schematic & equip list adequate ..... .,.,, N 25. BOPEs, do they meet regulation ..... .., .......... (,,Y-.2, N 26. BOPE press rating appropriate; test to /::>'¢~rz:) "-psig.(~ N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... (.,?2 ~J~-,,' 29. Is presence of H2S gas probable ................. Y GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... ,Y, ,N~.,,,? ,Y N ' ,/~ 31. Data presented on potential overpressure zones ....... .'r 2'~ ?//-~'/ , 32. Seismic analysis of shallow gas zones ............. ,Y,'N 33. Seabed condition survey (if off-shore) ............. / Y N 34. Contact name/phone for we.ekly,oro~lress reDo. rts ..... ./Z. Y N lexp~oramry omyj REMARKS GEOLOGY: ENGINEERING: COMMISSION: JDH ,~:t~ ' R N C_,~L~.____ co co · Comments/Instructions: HOW/lit - A:\FORMS\cheklist rev 09/97 Well History File APPENDIX Information 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. , No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : BP EXPLORATION WELL NAME : Bl-18 FIELD NAME : BADAMI BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292285700 REFERENCE NO : 99137 RECEIVED ;~,PR 02 1999 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1999 13:49~~/ PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 99/03/17 ORIGIN : FLIC REEL NAME : 99137 CONTINUATION # PREVIOUS REEL COGENT : BP EXPLORATION, BADAMI, Bl-18, API# 50-029-22857-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/03/17 ORIGIN : FLIC TAPE NAME : 99137 CONTINUATION # '. 1 PREVIOUS TAPE : CO~4MENT : BP EXPLORATION, BADAMI, Bl-18, API# 50-029-22857-00 TAPE HEADER BADAMI CASED HOLE WIRELINE LOGS WELL NAME: Bl-18 API NUMBER: 500292285700 OPERATOR: BP EXPLORATION LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 17-MAR-99 JOB NUMBER: 99137 LOGGING ENGINEER: Carlo A. Yon OPERATOR WITNESS: Sheridan Whi SURFACE LOCATION SECTION: 8 TOWNSHIP: 9N RANGE: 20E FNL: FSL : 3856 FEL: 86 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 54.40 DERRICK FLOOR: 53.40 GROUND LEVEL: 19.10 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 6. 000 4. 500 10724.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Ver~fzcat&on Listing Schlumberger Alaska Computing Center 17-MAR-1999 13:4~ BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: MWD LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 27-MAR-98 LOGGING COMPANY: SPERRY-SUN BASELINE DEPTH 88888.0 10553.5 10552.5 10547.5 10540.0 10533 0 10522 5 10520 5 10513 0 10511 5 10502 5 10493 5 10484 5 10483 0 10482 5 10476.0 10471.5 10466.5 10459.5 10459.0 10446.5 10441.5 10440.0 10439.5 10432.0 10430.5 10428.5 10423.5 10421.0 10415.5 10407.5 10406.5 10397.0 10389.5 10387.5 10383.0 10381.5 10377.5 10373.5 10369.5 10356.5 10354.0 10348.0 10347.5 10338.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GR CH CNTG 88888.5 10554.0 10547.0 10533.0 10521.5 10509.0 10502.0 10482.5 10475.0 10464.5 10456.5 10438.5 10429.0 10426.0 10420.0 10416.0 10406.5 10396.0 10389 5 10386 5 10381 5 10379 5 10377 0 10372 5 10354.5 10346.0 10338.5 88889.5 10554.0 10540.0 10521.5 10514.5 10495.0 10485.0 10482.5 10470.5 10458.5 10446.0 10439.5 10438.5 10428.5 10421.5 10404.5 10368.5 10352.0 10346.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 10324.0 10323.5 10316.0 10307.5 10304.0 10301.0 10299.5 10287.0 10286.0 10276.5 10270.5 10265.5 10260.5 10257.0 10250.5 10239.5 10225.0 10224.5 10217.0 10216.0 10201.0 10193.5 10191.0 10186.5 10186.0 10180.0 10178 5 10173 5 10162 0 10158 5 10143 5 10140 0 10130 0 10128 5 10118 5 10111 0 10109 5 10103 5 10089 5 10088 5 10081.5 10076.0 10068.5 10065.0 10058.5 10054.5 10054.0 10048.5 10037.5 10032.5 10027.5 10027.0 10021.5 10015.5 10008.5 9997.0 10323.5 10306.5 10304.0 10297.5 10285.0 10271.0 10265.5 10261.5 10250.0 10226.5 10217.0 10200.0 10191.0 10188.0 10178.5 10173 5 10162 5 10160 0 10142 0 10139 0 10129 $ 10119.0 10111.5 10102.5 10090.0 10080.0 10075.0 10069.5 10065.0 10058.0 10054.5 10048.5 10038.5 10034.0 10027.0 10021.0 10015.5 10009.0 10323.5 10314.0 10299.5 10284.5 10274.5 10256.0 10239.5 10226.0 10216.5 10193.0 10184.5 10178.5 10173.5 10129.5 10109.0 10087.0 10054.5 10027.0 9997.5 · 17-MAR-1999 13:4~ PAGE: LIS Tape Verif'"~tion Listing Schlumberger Alaska Computing Center 9996.5 9985.5 9982.5 9980.5 9976.5 9967.0 9955.0 9947.0 9935.0 9917.5 9916.5 9913.0 9905.0 9895.0 9882.5 9882.0 9868.5 9852.5 9845.0 9842.5 9836.5 9814.5 9813.5 9803.5 9799.0 9796.0 9786 5 9779 0 9769 0 9753 0 9752 5 9730 0 9718 0 9715 0 9708 5 9699 0 9698.0 9695.0 9691.0 9680.0 9674.0 9670.0 9664.0 9661.5 9661.0 9656.0 9651.0 9650.5 9642.0 9641.0 9628.0 9624.0 9619.5 9612.5 9612.0 9591.5 9996.0 9986.0 9981.5 9980.5 9976.5 9968.0 9956.5 9949.5 9916.5 9904.5 9896.0 9882.5 9867.0 9847.0 9836.5 9814.0 9796.5 9786.5 9779.5 9753.0 973 O. 5 9719.0 9699.0 9696.0 9673.5 9665.0 9661.5 9656.5 9651.0 9640.0 9625.5 9622.0 9618. 0 9612.5 17-MAR-1999 13:4~ 9980.5 9934.5 9916.5 9912.0 9882.5 9851.5 9841.0 9812.5 9802.5 9796.5 9767.5 9750.5 9727.0 9714.5 9707.5 9697.0 9690.5 9679.5 9670.5 9661.0 9650.0 9640.0 9612.5 9591.5 PAGE: LIS Tape Veri~tion Listing Schlumberger Alaska Computing Center 9587.5 9582.5 9581.5 9570.5 9570.0 9563.5 9562.0 9560.5 9557.5 9554.5 9551.5 9538.5 9529.0 9524 0 9519 0 9508 5 9505 5 9496 0 9495 5 9491.5 9473.0 9472.5 9467.5 9464.0 9451.0 9448.5 9444.5 9444.0 9432.5 9432.0 9414.5 9405.0 9394.0 9393.0 9384.5 9382.5 9376.5 9367.0 93 61.5 9359.5 9348.5 9346.0 9341.0 9340.0 9324.0 9323.5 9321.0 9309.0 9303.0 9281.0 9272.5 9268.5 9263.5 9261.0 9249.0 9240.0 9589.0 9582.0 9572.5 9561 9557.0 9552.0 9541.5 9524.5 9519.0 9496.5 9491.5 9473.0 9451.5 9448.0 9443.5 9432.0 9414.5 9392.5 9384.5 9383.0 93 61.5 9359.0 9348.5 9341.0 9323.0 9322.0 9281.5 9274.5 9270.5 9249.0 9241.0 9582.0 9570.0 9564.0 9560.0 9556.5 9529.0 9518.5 9508.0 9504.0 9496.0 9473.0 9467.5 9463.0 9443.5 9432.0 9404.0 9392.0 9377.0 9366.0 9346.5 9340.0 9323.0 9308.5 9302.0 9263.5 9260.0 17-MAR-1999 13:4~~:~' PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 9236.0 9229.0 9228.5 9227.0 9225.0 9223.5 9214.5 9206.0 9201.5 9198.5 9196.5 9195.0 9194 5 9188 0 9183 5 9181 0 9179 5 9178 0 9173 5 9160.0 9157.5 9151.5 9150.5 9148.0 9135.5 9128.0 9124.0 9123.0 9117.5 9113.0 9106.5 9097.0 9087.5 9082.5 9067.5 9064.0 9062.5 9060.5 9053.5 9047.0 9036.5 9036.0 9035.0 9029.0 9005.0 9003.5 9000.5 8994.5 8990.5 8986.0 8984.5 8983.5 8979.5 8971.5 8963.0 8962.0 9230.0 9226.5 9215.5 9208.5 9204.0 9196.0 9189.0 9183.0 9182.0 9176.5 9160.5 9151.0 9139.5 9130.0 9125.0 9116.5 9114.5 9107.0 9089.5 9083.5 9064.0 9061.5 9054.0 9048.0 9036.0 9030.0 9004.0 9002.5 8991.0 8986.0 8973.0 8963.0 9235.5 9230.0 9228.0 9224.5 9199.0 9197.0 9196.0 9183.5 9177.5 9160.5 9151.0 9148.0 9124.5 9123.0 9098.5 9083.0 9068.5 9065.5 9038.0 9035.5 9000.0 8994.5 8986.0 8983.5 8980.0 8963.0 17-MAR-1999 13:4~' PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1999 13:4~TM 8961.0 8958.5 8950.5 8949.5 8927.0 8926.5 8922.5 8915.0 8906.5 8900 5 8894 5 8890 0 8889 5 8883 0 8876 0 8875 5 8867.5 8864.5 8855.5 8853.0 8839.0 8834.5 8826.0 8818.0 8813.0 8799.0 8793.5 8789.5 8780.0 8772.0 8763.5 8759.5 8752.0 8749.0 8743.0 8726.5 8717.0 8706.5 8704.0 8700.0 8696.0 8687.0 8683.0 8680.0 8672.5 8670.0 8667.5 8666.0 8664.0 8662.0 8659.0 100.0 $ REMARKS: 8958.0 8949.0 8928.0 8924.0 8916.0 8909.5 8890.5 8882.5 8877.0 8869.5 8867.0 8857.5 8855.0 8842.5 8838.5 8819.5 8815 5 8802 5 8795 0 8791 5 8779 0 8770 0 8761 5 8749.5 8742.0 8724.5 8704.0 8699.0 8696.5 8688.0 8679.5 8672.5 8670.0 8668.0 8665.5 8661.0 8659.0 98.5 8961.5 8948.5 8928.0 8902.0 8894.5 8890.5 8877.0 8826.5 8760.0 8749.5 8716.0 8706.5 8684.0 8663.0 100.0 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE CNTG DATA AQUIRED ON BP EXPLORATION'S Bl-18 WELL. THE DEPTH PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1999 13:49~ SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCtI MAIN PASS AND THE MWD GAi~FIA RAY, ALSO MAIN PASS NPHI AND THE MWD GA2~4A RAY, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. NOT ALL SHIFTS MADE ARE DISPLAYED IN THIS FILE BECAUSE THEIR NIJM~ER EXCEEDS THE HEADER PROGRAM BUFFER SIZE. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NTJMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUNPUkRY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10555.5 8559.5 CNTG 10565.5 8561.0 $ CURVE SHIFT DATA - PASS TO PASS (FIEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG REMARKS: THIS FILE CONTAINS THE CASED HOLE CNTG MAIN PASS. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DA TA . $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1999 13:49~J PAGE: ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE- 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) FT 1160722 O0 000 O0 0 1 1 1 4 68 0000000000 DEPT NPHI CNTG PU-S 1160722 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 1160722 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 1160722 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTG 1160722 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 1160722 O0 000 O0 0 1 1 1 4 68 0000000000 ENRA CNTG 1160722 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTG CPS 1160722 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 1160722 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 1160722 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 1160722 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 1160722 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 1160722 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTG GAPI 1160722 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTG LB 1160722 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTG V 1160722 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10565.500 NPHI. CNTG 24.449 ENPH. CNTG 19.913 CPHI.CNTG NRAT. CNTG 2.835 CRAT. CNTG 2.744 ENRA.CNTG 3.538 NCNT. CNTG FCNT. CNTG 984.543 CNTC. CNTG 2724.654 CFTC. CNTG 1047.796 CNEC. CNTG CFEC. CNTG 1280.393 GRCH. CNTG -999.250 TENS. CNTG 4333.000 CCL.CNTG 25.931 2765.756 4530.073 -0.022 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1999 13:4~TM PAGE: 10 DEPT. 8559.500 NPHI.CNTG -999.250 ENPH. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG CFEC. CNTG -999.250 GRCH. CNTG 17.961 TENS.CNTG -999.250 CPHI.CNTG -999.250 NCNT. CNTG -999.250 CNEC. CNTG -999.250 CCL.CNTG -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE : 99/03/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUA~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10564.5 10349.0 CNTG 10572.0 10349.5 $ CURVE SHIFT DATA - PASS TO PASS (FIEASURF~ DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTG .............. LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1999 13:4~ .... ' PAGE: 11 88888.0 10554.5 10548.5 10545.5 10541.5 10538.0 10535.0 10529.5 10523.0 10513.5 10513.0 10500.5 10499.5 10489.0 10487.5 10482.5 10478.5 10476.0 10471 5 10470 5 10461 5 10445 0 10444 0 10443 0 10439 5 10430 0 10427.0 10423.0 10420.5 10418.5 10414.0 10409.0 10406.5 10405.5 10396.5 10389.5 10388.5 10380.5 10375.0 10370.0 10361.0 100.0 $ 88887.5 10545.0 10541.0 10533.5 10527.5 10522.0 10511.5 10499.5 10490.0 10487.5 10483.0 10478.5 10474.5 10469.5 10460.5 10444.0 10426.5 10420.5 10414.0 10409.0 10404.5 10396.0 10390.0 10380.0 10370.0 10360.0 99.0 88890.0 10556.5 10549.5 10538.5 10537.0 10515.0 10502.5 10482.5 10470.5 10446.5 10443.0 10438.5 10428.5 10422.0 10417.5 10404.5 10387.5 10374.5 99.5 REMARKS: THIS FILE CONTAINS CASED HOLE CNTG REPEAT PASS. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCHMAIN PASS AND GRCHREPEAT PASS, ALSO NPHIMAIN PASS AND NPHI REPEAT PASS, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1999 PAGE: 12 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE ~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1160722 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 1160722 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNTG PU-S 1160722 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 1160722 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTG 1160722 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTG 1160722 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNTG 1160722 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTG CPS 1160722 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTG CPS 1160722 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 1160722 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 1160722 O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNTG CPS 1160722 O0 000 O0 0 2 1 1 4 68 0000000000 CFEC CNTG CPS 1160722 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTG GAPI 1160722 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTG LB 1160722 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTG V 1160722 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1999 13:4~~/ PAGE: 13 DEPT. 10572.000 NPHI.CNTG 22.627 ENPH. CNTG NRAT. CNTG 2.748 CRAT. CNTG 2.644 ENRA.CNTG FCNT. CN~rG 1004.625 CNTC. CNTG 2739.825 CFTC. CNTG CFEC. CNTG 1318.784 GRCH. CNTG -999.250 TENS.CNTG DEPT. 10349.000 NPHI.CNTG -999.250 ENPH. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG CFEC. CNTG -999.250 GRCH. CNTG 74.190 TENS. CNTG 18.748 CPHI.CNTG 3.397 NCNT. CNTG 1052.699 CNTEC. CNTG 4289.000 CCL.CNTG -999.250 CPHI.CNTG -999.250 NCNT. CNTG -999.250 CNEC. CNTG -999.250 CCL.CNTG 25.965 2796.685 4479.853 -0.143 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE iVTJMBER 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUA~UkRY VENDOR TOOL CODE START DEPTH CNTG 10612.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): STOP DEPTH 8561.0 15-APR-98 8Cl-205 1530 15-APR-98 10611.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1999 13:49~" PAGE: 14 TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO) TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA2V~4A RAY CNTG NEUTRON POROSITY $ 10603.0 8560.0 10564.0 TOOL NUMBER SG C - SA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 6. 000 10724.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : BRINE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EP I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6400 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger This log was depth correlated to a Sperry-Sun MWD log. dated 27-Mar-98. All depth correlations witnessed by co. rep. SANDSTONE matrix used. THIS FILE CONATINS THE RAW DATA FOR THE MAIN PASS. $ LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 17-MAR-1999 13:49~ PAGE: 15 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUN~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1160722 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI LOG PU 1160722 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH LOG PU 1160722 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH LOG PU 1160722 O0 000 O0 0 3 1 1 4 68 0000000000 TNRA LOG 1160722 O0 000 O0 0 3 1 1 4 68 0000000000 RTNR LOG 1160722 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA LOG 1160722 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC LOG CPS 1160722 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC LOG CPS 1160722 O0 000 O0 0 3 1 1 4 68 0000000000 RCEF LOG CPS 1160722 O0 000 O0 0 3 1 1 4 68 0000000000 RCEN LOG CPS 1160722 O0 000 O0 0 3 1 1 4 68 0000000000 RCNT LOG CPS 1160722 O0 000 O0 0 3 1 1 4 68 0000000000 RCFT LOG CPS 1160722 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC LOG CPS 1160722 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC LOG CPS 1160722 O0 000 O0 0 3 1 1 4 68 0000000000 NPOR LOG PU 1160722 O0 000 O0 0 3 1 1 4 68 0000000000 GR LOG GAPI 1160722 O0 000 O0 0 3 1 1 4 68 0000000000 TENS LOG LB 1160722 O0 000 O0 0 3 1 1 4 68 0000000000 CCL LOG V 1160722 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 17-MAR-1999 13:4~~-t PAGE: 16 ** DATA ** DEPT. 10612.000 NPHI.LOG TNRA.LOG 3.194 RTNR.LOG CNEC.LOG 4745.180 RCEF. LOG RCFT. LOG 757.270 CNTC.LOG GR.LOG 135.000 TENS.LOG DEPT. 8561.000 NPHI.LOG TNRA.LOG 3.351 RTNR.LOG CNEC.LOG 2864.098 RCEF.LOG RCFT. LOG 366.583 CNTC.LOG GR.LOG 17.961 TENS.LOG 32.664 ENPH. LOG 3.333 ENRA.LOG 1270.325 RCEN. LOG 2444.969 CFTC.LOG 2610.000 CCL.LOG 35.524 ENPH.LOG 3.587 ENRA.LOG 517.124 RCEN. LOG 1324.557 CFTC.LOG 3575.000 CCL.LOG 21.527 TNPH. LOG 3. 729 CFEC. LOG 433 6. 058 RCNT. LOG 779. 060 NPOR.LOG -0. 026 39.070 TNPH. LOG 5.535 CFEC.LOG 2662.232 RCNT. LOG 385.314 NPOR.LOG -999.250 34.129 1272.398 2575.992 34.129 38.863 517.448 1416.018 38.211 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NTJ-MBER 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNTG 10618.5 10341.5 $ LOG HEADER DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1999 13:4~-~-'' PAGE: 17 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO)'. 15 -APR-98 8Cl -205 1530 15-APR-98 10611.0 10603.0 8560.0 10564.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY CNTG NEUTRON POROSITY $ TOOL NUMBER SGC - SA CNT-G BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 6. 000 10724.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO .' CHOKE (DEG) : BRINE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): E P I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) .. BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 6400 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger This log was depth correlated to a Sperry-Sun MWD log. dated 27-Mar-98. Ail depth correlations witnessed by co. rep. LIS Tape Verif~ation Listing Schlumberger Alaska Computing Center 17-l~AR-1999 13:4b .... ~ PAGE: 18 SANDSTONE matrix used. THIS FILE CONATINS THE RAW DATA FOR THE REPEAT PASS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1160722 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI RPT PU 1160722 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH RPT PU 1160722 O0 000 O0 0 4 1 1 4 68 0000000000 TNPH RPT PU 1160722 O0 000 O0 0 4 1 1 4 68 0000000000 TNRARPT 1160722 O0 000 O0 0 4 1 1 4 68 0000000000 RTNR RPT 1160722 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA RPT 1160722 O0 000 O0 0 4 1 1 4 68 0000000000 CFEC RPT CPS 1160722 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC RPT CPS 1160722 O0 000 O0 0 4 1 1 4 68 0000000000 RCEF RPT CPS 1160722 O0 000 O0 0 4 1 1 4 68 0000000000 RCEN RPT CPS 1160722 O0 000 O0 0 4 1 1 4 68 0000000000 RCNT RPT CPS 1160722 O0 000 O0 0 4 1 1 4 68 0000000000 RCFT RPT CPS 1160722 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC RPT CPS 1160722 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC RPT CPS 1160722 O0 000 O0 0 4 1 1 4 68 0000000000 NPOR RPT PU 1160722 O0 000 O0 0 4 1 1 4 68 0000000000 GR RPT GAPI 1160722 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1999 PAGE: 19 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TENS RPT LB 1160722 O0 000 O0 0 4 1 1 4 68 0000000000 CCL RPT V 1160722 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10618.500 NPHI.RPT 41.814 ENPH.RPT 20.391 TNPH. RPT TNRA.RPT 3.696 RTNR.RPT 3.857 ENRA.RPT 3.595 CFEC. RPT CNEC.RPT 4810.647 RCEF.RPT 1335.892 RCEN. RPT 4395.881 RCNT. RPT RCFT. RPT 844.860 CNTC.RPT 3180.912 CFTC.RPT 869.170 NPOR.RPT GR.RPT 64.478 TENS.RPT 2678.000 CCL.RPT -0.168 DEPT. 10341.500 NPHI.RPT 21.224 ENPH.RPT 19.780 TNPH. RPT TNRA.RPT 2.562 RTNR.RPT 2.474 ENR~.RPT 3.522 CFEC.RPT CNEC.RPT 4402.824 RCEF. RPT 1247.885 RCEN. RPT 4072.952 RCNT. RPT RCFT. RPT 1096.477 CNTC.RPT 2719.964 CFTC.RPT 1112.136 NPOR.RPT GR.RPT 68.710 TENS.RPT 4122.000 CCL.RPT -999.250 42.457 1338.071 3351.373 42.457 23.651 1250.064 2899.367 23.273 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 99/03/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 99/03/17 ORIGIN : FLIC TAPE NAME : 99137 CONTINUATION # : 1 PREVIOUS TAPE : CO~94ENT : BP EXPLORATION, BADAMI, Bl-18, API# 50-029-22857-00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-MAR-1999 13:4~-~ PAGE: 20 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/03/17 ORIGIN · FLIC REEL NAME : 99137 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, BADAMI, Bl-18, API# 50-029-22857-00 Sperry-Sun Drilling Services LIS Scan Utility Wed Apr 29 16:02:13 1998 Reel Header Service name ............. LISTPE Date ..................... 98/04/29 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/04/29 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER BADAMI MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 4 AK-VC-80150 S. NEUBAUER D. MASKELL Bl-18 500292285700 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 29-APR-98 MWD RUN 5 AK-VC- 80150 S. NEUBAUER D. MASKELL MWD RUN 6 AK-VC-80150 M. HALL M. WHITLY 8 09N 20E 1424 86 54.40 52.90 19.10 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 116.0 12.250 9.625 4550.0 8.500 7.000 8854.0 6.000 10724.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1, 2, AND 3 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUNS 4 AND 5 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). 4. MWD RUN 6 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM D. DOUGLAS FOR D. GOODWIN OF BP EXPLORATION (ALASKA), INC. ON 4/23/98 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10724'MD, 10423'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 6856.0 10673.5 ROP 6923.0 10726.0 FET 8854.0 10680.5 RPD 8854.0 10680.5 RPM 8854.0 10680.5 RPS 8854.0 10680.5 RPX 8854.0 10680.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 4 6923.0 7867.0 5 7867.0 8865.0 6 8865.0 10726.0 MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPM MWD OHMM 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean DEPT 6856 10726 8791 ROP 3.3749 639.844 59.2643 GR 20.6417 112.54 72.8017 RPM 0.101 65.5535 6.85347 RPX 0.709 76.8297 7.25972 RPS 0.967 61.9287 7.16583 RPD 2.806 96.097 7.27104 FET 1.0423 89.6414 3.29718 Nsam 7741 7607 7636 3654 3654 3654 3654 3654 First Reading 6856 6923 6856 8854 8854 8854 8854 8854 Last Reading 10726 10726 10673.5 10680.5 10680.5 10680.5 10680.5 10680.5 First Reading For Entire File .......... 6856 Last Reading For Entire File ........... 10726 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6856 . 0 7798 . 5 ROP 6923 . 0 7867 . 0 $ LOG HEADER DATA DATE LOGGED: 16-MAR- 98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: DEP 3.0 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 7867.0 TOP LOG INTERVAL (FT) : 6923.0 BOTTOM LOG INTERVAL (FT) : 7867.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 26.5 MAXIMUM ANGLE: 30.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: TOOL NUMBER NGP SPC 217 8.500 8.5 GEL CHEM 9.40 49.0 9.1 MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 1700 4.6 .000 .000 .000 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 4 2 ROP MWD 4 FT/H 4 1 68 8 3 46.9 First Name Min Max Mean Nsam Reading DEPT 6856 7867 7361.5 2023 6856 GR 20.6417 84.492 54.5343 1886 6856 ROP 6.1973 639.844 121.003 1889 6923 Last Reading 7867 7798.5 7867 First Reading For Entire File .......... 6856 Last Reading For Entire File ........... 7867 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 7797.5 ROP 7867.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 8787.5 8865.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL 19-MAR-98 ISC 5.06 DEP 3.0 MEMORY 8865.0 7867.0 8865.0 12.2 24.4 TOOL NUMBER NGP SPC 318 8.500 8.5 BENTONITE 10.00 51.0 9.1 1600 4.6 .000 .000 .000 .000 53.9 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 AAPI 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 7797.5 8865 8331.25 2136 7797.5 GR 26.7476 94.6761 63.4054 1981 7797.5 ROP 8.4731 404.246 53.841 1997 7867 Last Reading 8865 8787.5 8865 First Reading For Entire File .......... 7797.5 Last Reading For Entire File ........... 8865 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8785.0 10673.5 FET 8854.0 10680.5 RPD 8854.0 10680.5 RPM 8854.0 10680.5 RPS 8854.0 10680.5 RPX 8854.0 10680.5 ROP 8865.0 10726.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 27-MAR-98 ISC 5.06 DEP 3.0 MEMORY 10726.0 8865.0 10726.0 2.6 14.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER P0961SP4 P0961SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 6.000 6.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: KCL POLYMER 12.30 55.0 9.5 20200 8.4 .3O0 .142 .200 .450 69.5 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .6 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 6 FT/H 4 1 68 RPX MWD 6 OHFIM 4 1 68 RPS MWD 6 OHMM 4 1 68 RPM MWD 6 OHMM 4 1 68 RPD MWD 6 OHMM 4 1 68 ROP MWD 6 FT/H 4 1 68 FET MWD 6 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean DEPT 8785 10726 9755.5 GR 38.9794 112.54 86.8183 RPX 0.709 76.8297 7.25972 RPS 0.967 61.9287 7.16583 RPM 0.101 65.5535 6.85347 RPD 2.806 96.097 7.27104 ROP 3.3749 603.516 30.9038 FET 1.0423 89.6414 3.29718 Nsam 3883 3778 3654 3654 3654 3654 3723 3654 First Reading 8785 8785 8854 8854 8854 8854 8865 8854 Last Reading 10726 10673.5 10680.5 10680.5 10680.5 10680.5 10726 10680.5 First Reading For Entire File .......... 8785 Last Reading For Entire File ........... 10726 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/04/29 Maximum Physical Recordo.65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/04/29 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/04/29 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File