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Home My WebLink About203-047New Plugback Esets 7/26/2024 Well Name API Number PTD Number ESet Number Date CD2-09 PB1 50-103-20496-70-00 204-129 T39280 2-22-2006 CD2-10 PB1 50-103-20473-70-00 203-195 T39281 2-22-2006 CD2-28 PB1 50-103-20435-70-00 202-217 T39282 2-22-2006 CD2-40 PB1 50-103-20464-70-00 203-126 T39283 2-22-2006 CD2-43 PB1 50-103-20474-70-00 203-197 T39284 10-29-2004 Kasilof South 1 PB1 50-133-20520-70-00 202-256 T39285 5-16-2006 E-20AL1 PB1 50-029-22561-70-00 204-055 T39286 2-22-2006 F-57A PB1 50-029-22747-70-00 203-167 T39287 2-22-2006 G-18 PB1 50-029-23194-70-00 204-020 T39288 2-22-2006 H-16 PB2 50-029-23227-71-00 204-190 T39289 1-27-2005 I-17L1 PB1 50-029-23212-70-00 204-099 T39290 2-22-2006 S-01 PB1 50-029-23141-70-00 203-034 T39291 2-22-2006 S-08 PB1 50-029-23168-70-00 203-123 T39292 8-29-2003 S-18 PB1 50-029-23133-70-00 202-242 T39293 2-22-2006 06-23B PB1 50-029-20808-70-00 204-087 T39294 2-22-2006 07-14B PB1 50-029-20339-70-00 203-142 T39295 2-22-2006 15-38A PB1 50-029-22496-70-00 203-016 T39296 2-22-2006 C-16A PB1 50-029-20438-70-00 203-084 T39297 2-22-2006 D-28B PB1 50-029-21556-70-00 209-089 T39298 8-20-2012 E-01A PB1 50-029-20166-70-00 203-033 T39299 2-22-2006 K-03B PB1 50-029-21011-72-00 204-115 T39300 2-22-2006 NK-62A PB1 50-029-22852-70-00 203-047 T39301 2-22-2006 S-102L1 PB1 50-029-22972-70-00 203-156 T39302 10-26-2005 W-09A PB1 50-029-21947-70-00 204-102 T39303 2-22-2006 NK-62A PB1 50-029-22852-70-00 203-047 T39301 2-22-2006 Image ~ . bject Well History File C.Jer Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. & Q3 - 0 if 7 Well History File Identifier Organizing (done) o Two-sided 11111111I1111111111 ~scan Needed RESCAN ¿COlor Items: o Greyscale Items: o Poor Quality Originals: DIGITAL DATA ~iskettes, No. ::t o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: Scanning Preparation BY: Helen ~ ~- x 30 = (/If) o Other:: Date: to :;).9, 'DS Isl YV1 P , /. I Date: 0, ';;;'9, 'OSISI rnf + ,~ = TOTAL PAGES <õ9 v ¡lounrdof/S not~iflude cover Sheet..) In Af Date: (0, ,:) 1/ ÎÌÏ Isl . r v~ BY: Helen ~ Project Proofing BY: Helen çMari~ BY: Production Scanning Stage 1 Page Count from Scanned File: qo (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: / YES NO Date: 0/;;).9 Jos IfJ MP YES NO Helen (~aria) Stage 1 If NO in stage 1, page(s) discrepancies were found: BY: Helen Maria Date: Isl 11I1111111111111111 1111111111111111111 1 " I Date: 151 Quality Checked 11I1111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 July 6, 2011 o Mr. Tom Maunder a 03 7 Alaska Oil and Gas Conservation Commission (0 9-19 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA Niakuk Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA Niakuk that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Mehreen Vazir, at 659-5102. Sincerely, Gerald Murphy BPXA, Well Integrity Coordinator i • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Niakuk Date: 05/15/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal NK -01A 1780280 500292015801 P&A 3/9/91 NA NA NA NA NA NK -02A 1780790 500292018001 P&A 3/13/91 NA NA NA NA NA NK -03 1780940 500292035000 P&A 4/14/80 NA NA NA NA NA NK-04 1842000 500292121700 P&A 4/14/98 NA NA NA NA NA NK -05 1850270 500292129000 P&A 4/15/98 NA NA NA NA NA NK-06 1852780 500292148800 P&A 4/15/98 NA NA NA NA NA NK -07A 2010830 500292241001 0.2 NA 0.2 NA 0.9 4/30/2011 NK-08A 2010290 600292249101 0.2 NA 0.2 NA 0.9 4/30/2011 NK-09 1941400 500292251800 2.1 NA 2.1 NA 17.0 4/30/2011 NK -10 1931840 500292242500 1.5 NA 1.5 NA 11.9 4/30/2011 NK -11A 2020020 500292278901 1.5 NA 1.5 NA 11.9 4/30/2011 NK -12C 2030550 500292241403 1.8 NA 1.8 NA 31.0 4/30/2011 NK -13 1981340 500292289300 2.3 NA 2.3 NA 22.1 5/4/2011 NK -14A 2080310 500292286801 1.8 NA 1.8 NA 17.0 5/4/2011 NK -15 1970320 500292274500 1.8 NA 1.8 NA 18.7 5/4/2011 NK -18 1940220 500292244700 2.5 NA 2.5 NA 20.4 5/4/2011 NK -17 1981850 500292270900 3 NA 3 NA 20.4 5/4/2011 NK -18 1931770 500292242100 2 NA 2 NA 17.0 5/8/2011 NK -19A 2010700 500292250701 1.8 NA 1.8 NA 15.3 5/8/2011 NK -20A 2050400 500292242901 2.1 NA 2.1 NA 13.6 5/9/2011 NK -21 1940880 500292248700 2 NA 2 NA 22.1 5/16/2011 NK -22A 2012280 500292240201 1.5 NA 1.5 NA 11.9 5/11/2011 NK -23 1940350 500292245500 3.6 NA 3.6 NA 20.4 5/10/2011 NK -25 1970880 500292278000 2.5 NA 2.5 NA 15.3 5/11/2011 NK -28 1940050 500292244000 2.9 NA 2.9 NA 17.0 5/11/2011 NK -27 1950210 500292254700 2.3 NA 2.3 NA 13.6 4/30/2011 NK -28 1960930 600292287800 Sealed Conductor NA Sealed Conductor NA NA NA NK -29 1981900 500292272400 1.7 NA 1.7 NA 10.2 4/30/2011 NK-38A 2042410 500292254001 3.1 NA 3.1 NA 13.6 5/8/2011 NK -41A 1971580 500292277801 9.1 NA 9.1 NA 54.0 5/9/2011 NK-42 1941080 500292249900 2 NA 2 NA 13.6 5/9/2011 NK-43 2010010 500292299800 1 NA 1 NA 5.1 5/9/2011 NK-81A 2080350 500292289301 14 NA 14 NA 110.5 5/15/2011 NK-82A 2030470 500292285201 1.3 NA 1.3 NA 13.6 5/4/2011 NK-85A 2050830 500292288901 1 NA _ 1 NA 8.5 5/6/2011 • • -- ~,~:_~-_ -;~~:~ ` ~.. '~`"~ Ta, ~-~" MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATE RiAL UNDER THIS PAGE. F: ~LaserFicheiCvrPgs_Inserts\Microfilm_Marker. doc e e WELL LOG TRANSMITTAL 9D?J~>~-1 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 } 3tt~1 RE: MWD Formation Evaluation Logs NK-62A & NK-62A PBl, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 NK-62A & NK-62A PBl: LAS Data & Digital Log Images: 50-029-22852-01, 70 1 CD Rom ß~ß~iì. /' ci~f:h J.- €f M'-) ^-- ù'0 ¡r- DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Permit to Drill 2030470 MD 13149 ./' REQUIRED INFORMATION Samples No ------- - Well Name/No. PRUDHOE BAY UN NIA NK-62A Operator BP EXPLORATION (ALASKA) INC Jfi.A. J. /7 /Jp ~~ API No. 50-029-22852-01-00 lVD 9271 ~ Completion Date 4/29/2003 ~ Completion Status Mud Log No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, Rap, RES, eeL, CNL Well Log Information: Logl Electr Data Digital Dataset Type Med/Fnnt Number JRPt I I Rpt I ! I ¡ ¡ I J¿D Rpt ~ I ~/ I Rpt I ! ED C Tf I i ED C Pds i ¡ i I ED C Pds ~/ I I ¡ 1___- Name Directional Survey LIS Verification Log Log Run Scale Media No 1 11 ~6 LIS Verification Directional Survey ~tional Survey ..- /- Directional Survey l.A"f 837 LIS Verification LIS Verification 12132 LIS Verification 12132 Neutron 2 12132 Casing collar locator 2 Neutron 2 Blu 1-01L Current Status 1-01L UIC N 6 Directional surve~ (data taken from Logs Portion of Master Well Data Maint) ~_/ Interval OHI Start Stop CH Received Comments 12711 13149 Open 5/13/2003 11722 13124 Open 6/25/2003 An H2S Measurement is required to be submitted. This record automatically created from Permit to Drill Module on: 3/25/2003. 11722 13099 Open 6/25/2003 PB1 11800 13126 Open 5/13/2003 PB1 11800 13126 Open 5/13/2003 PB1 A Directional Survey Log is i required to be submitted. I This record automatically ! created from Permit to Drill Module on: 3/25/2003. - 12711 13149 Open 5/13/2003 11722 13124 Open 6/25/2003 11722 13099 Open 6/25/2003 PB1 11466 13098 Case 7/23/2003 11466 13098 Case 7/23/2003 Compensated Neutron Log - Memory GRlCCUCNL 11466 13098 Case 7/23/2003 Compensated Neutron Log - Memory GRlCCUCNL 11466 13098 Case 7/23/2003 Compensated Neutron Log - Memory GRlCCUCNL 1 11 6 DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Permit to Drill 2030470 Well Name/No. PRUDHOE BAY UN NIA NK-62A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22852-01-00 MD 13149 TVD 9271 Completion Date 4/29/2003 Completion Status 1-01L Current Status 1-01L UIC N ---- I~ Casing collar locator 2 Blu 11466 13098 Case 7/23/2003 Compensated Neutron I Log - Memory I GRlCCUCNL ] ¡ ,(óg Production 25 Blu 11791 13096 Case 8/29/2003 Production Profile - ] SpinfT emp/Press/CaJ/Deft I I ' rcog Spinner 25 Blu 11791 13096 Case 8/29/2003 Production Profile - I SpinfT emp/Press/Cal/Deft I~g Temperature 25 Blu 11791 13096 Case 8/29/2003 Production Profile - SpinfT emp/Press/CaUDeft I -- /log Pressure 25 Blu 11791 13096 Case 8/29/2003 Production Profile - SpinfT emp/Press/CaUDeft ED C Asc 12316 Neutron 11804 13092 Case 12/22/2003 Memory Borax CNL, Memory GRlCCUCNUSTP I Lqg Neutron 2 Blu 11804 13092 Case 12/22/2003 Memory Borax CNL, ] Memory GRlCCUCNUSTP i ~ Injection Profile 2 Blu 11804 13097 Case 12/22/2003 Injection Profile, Memory GRlCCUCNUSTP ..I15g Casing collar locator 2 Blu 11804 13097 Case 12/22/2003 Injection Profile, Memory I GRlCCUCNUSTP ~ Neutron 2 Blu 11804 13097 Case 12/22/2003 Injection Profile, Memory ! GRlCCUCNUSTP lED 0 Las 12356 Casing collar locator 12222 12725 Case 1/20/2004 L Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments .-- ADDITIONAL INFORMATION r;:-...... Well Cored? Y 1(f0 Chips Received? '''V'Tf¡'- Daily History Received? 0N æ, C)N Formation Tops Analysis Received? ~ Comments: DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Permit to Drill 2030470 Well Name/No. PRUDHOE BAY UN NIA NK-62A Operator BP EXPLORATION (ALASKA) INC MD 13149 ND 9271 Completion Date 4/29/2003 Completion Status 1-01L Current Status 1-01L ~ Date: -~~ Compliance Reviewed By: API No. 50-029-22852-01-00 UIC N ;{ 7 cJ"Y-rL M~ J-- ~ --- ") STATE OF ALASKA .." ALASKA OIL AND GAS CONSERVATION corv....JSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 2. Operator Suspend D Repair Well 0 Pull TubingD Operation Shutdown D Plug Perforations E!] Perforate New Pool D 4. Current Well Class: Perforate D WaiverD Stimulate ŒJ Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 203-0470 OtherD Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Development E!] Exploratory 0 59.80 8. Property Designation: ADL-0034635 11. Present Well Condition Summary: StratigraphicD ServiceD 9. Well Name and Number: NK-62A 10. Field/Pool(s): Niakuk Field I Niakuk Oil Pool 6. API Number 50-029-22852-01-00 Total Depth measured 13149 feet true vertical 9271.3 feet Effective Depth measured 13114 feet true vertical 9276.2 feet Plugs (measured) None Junk (measured) None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 94# H-40 42 122 42.0 122.0 1530 520 Liner 50 3-1/2" 9.3# L-80 11624 - 11674 9158.9 - 9191.2 10160 10530 Liner 341 3-3/16" 6.2# L-80 11674 - 12015 9191.2 - 9355.1 Liner 1134 2-7/8" 6.16# L-80 12015 - 13149 9355.1 - 9271.3 13450 13890 Production 11813 7" 26# L-80 38 - 11851 38.0 - 9307.0 7240 5410 Surface 5469 9-5/8" 40# L-80 41 - 5510 41.0 - 5187.7 5750 3090 Perforation deDth: Measured depth: 12179 - 12439, 12459 -12562 1..\\: ~¡ JlÏ True vertical depth: 9344.92 - 9317.47, 9314.19 - 9302.32 Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 36 11647 MAR 1 5 200< ,,' ¡ Packers & SSSV (type & measured depth): 4-1/2" aos SSV Baker S-3 Packer @ 2098 @ 11551 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Prior to well operation: 152 0.1 3120 64 Subsequent to operation: 409 0.2 3714 1825 Tubing Pressure 568 574 14. Attachments: 15. Well Class after proposed work: Exploratory D DevelopmentŒ] Service D Copies of Logs and Surveys run _ 16. Well Status after proposed work: Operational Shutdown D OilE!] GasD WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations. X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature .11~ r LlJt;-~ Form 1 0-404 Revised 12/2003 Title Production Technical Assistant Phone 564-4657 Date 3/11/04 ORIGINAL ~Bfl MAR 1 Ö 10ij~ ) J NK-62A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 12/18/03 CTU #9: IBP, ACID, ORGANASEAL. CONTINUED FROM WSR 18-DEC-03. PREFORM WEEKLY BOP TEST. RIH W/2-1/8/1 BAKER IBP. SET IBP AT 12,6601 ELMD. POOH WHILE CIRCULATING OUT AT 80%. FREEZE PROTECT FLOWLINE W/10 BBLS 60/40. MAKE UP 2-1/8/1 BAKER RETRIEVABLE PACKER AND RIH. TAG IBP & CORRECT, SET TREATMENT PKR ELEMENT AT 12,500'. PUMPED 20 BBLIS 5% HCL & IN THE PROCESS OF PUMPING OVERFLUSH. --CONTINUED ON 12/19/03 WSR-- PRE ACID INJECTION-WHP=600 1 CTP=2640 AT 1 BPM (NOT PUMPING DOWN BACKSIDE). PRE ACID INJECTION-WHP=604 1 CTP=3634 AT 1.5 BPM (NOT PUMPING DOWN BACKSIDE). HAD 2110 PSI BREAK WHEN ACID HIT THE PERFS AND ONLY 30 PSI CHANGE ON THE BACKSIDE. POST ACID INJECTION-WHP=924 1 CTP=2515 AT 1.5 BPM. (PUMPING DOWN BACKSIDE AT MIN RATE) PUMPED OVER FLUSH AT MIN RATE WHILE LOADING ORGANASEAL. WHP=8951 CTP=200 12/19/03 CTU #9 ORGANASEAL TREATMENT. CONTINUED. PUMPING OVER FLUSH AFTER ACID TREATMENT. PUMP 170 BBLIS 2% KCL WATER W/F-103 & J-313 ADDITIVES, 50 BBLIS ORGANASEAL, 35 BBLIS KCLWATER AS PER PROGRAM. RELEASE PKR & POOH REPLACING VOIDAGE WITH METH. WELL FREEZE PROTECTED TO 20001. WELL AND FLOWLINE TAGGED W/FREEZE PROTECT TAGS. «< WELL LEFT SHUT-IN - WAITING 24 HOURS ON GEL»> 12/20103 RIH with 2" JSN. Run through gel at min rate and tag IBP. POOH and MU 2.25/1 00 IBP fishing assembly w/hydraulic cent and w/1.375/1 Sure Catch Overshot and RIH. Could not enter deployment sleeve. POOH. Inspect tools and found small ding on mule shoe from edge of deployment sleeve. MU hydraulic centralizer and hydraulic JDC w/1.375/1 overshot. Latch IBP at 126451 ctmd, POOH. Recovered all elements. Return well to production. 12/26/03 ** CONTINUED FROM 12-25-03 WSR** SAT DOWN WI 3.83" GAUGE RING @ 5861 SLM, UNABLE TO GET THROUGH. DRIFTED WI 3.80" CENT. 3' STEM, 3.80" SWAGE, MADE IT TO SVLN. SET 4 1/2" aos SER # aOS-41 0 @ 2062' SLM, GOOD CLOSURE TEST. ** TURNED WELL OVER TO DSO TO POP** FLUIDS PUMPED BBLS 391 60/40 Methonal 1 Water 290 1 % KCL w/F1 05 & J313 20 50/0 HCL Acid 41 1 % KCL 50 Organaseal 320 1 - 20/0 KCL water w/F-1 03 & J-313 additives 1112 TOTAL Page 1 1Re: = 4-1/16" -5M OW WELLI-EAD= 11" 5MFrvcGEN5 ACTÙAro'R;;;----'--'^" BA KER 'Ri3.-Ë[B/ -;^"-"-.--..-.~^"..._"0···--59:S' ..__..m·___·_·_____··...............,..""'...........~....w"......w.w,.,.,......,,""'....,...................,.................~. BF. ELB/ = 23.75' ...........,.,.,....."'..-...-.~~.,..........'~._,.......~""..,.,."""^".,.,.,.,.~..".....M...,.......·....._"'_""................,............._ KOP = 3700' ...... ~n...... m ........ ...................... .... .... .......~ Max Angle = 100 @ 12419' 'D:ÏtÙiTï Wb 0';; . mmmoomommomomoomm11T79i' 'batum T\i t)';m..mm..mmommomm"oS2 06;0 s~:f ) N K-62A ) I SAFETY NOTES: 9-5/8" CSG, 40#, L-80, ID = 8.835" 1-1 551 0' ~ Minimum ID = 2.372" @ 12016' TOP OF 2-718" LIN ER PERFORATION SUMMARY REF LOG: MCNL ON 04/27/03 ANGLEATTOPÆRF: 92 @ 12179' Note: Refer to R'oduction DB for historical perf data SIZ E SPF INTER\! AL Opn/Sqz DA TE 2" 4 12179 - 12439 0 04/28103 2" 4 12459 - 12579 0 04/28/03 2" 4 12970 - 13060 0 04/28103 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 11647' I 3-1/2"LNR,9.3#,L-80,.0087bpf,ID=2.992" H 11674' Gf3\J 2WHlPSTOO< 1-1 11840' 1 3 RA TAGS H 11850' e 2098' H 4-1 f2" SL VN, I-ES HXO, ID = 3.813" 1 ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DAlE L-5 3238 3176 3 CA-KBG-2-LS Dfv1Y INT 0 08111102 4 4001 3928 16 CA-KBG-2-LS OO~ INT 16 05115103 3 7423 6362 50 CA-KBG-2-LS SO INT 20 05/15103 2 9922 7975 48 CA-KBG-2-LS Dfv1Y INT 0 08111102 1 11430 8979 48 CA-KBG-2-LS Dfv1Y INT 0 08111102 I ~ 6003' 14 4-1/2" HES X NIP, ID = 3.813" 11540' 14 4-1/2" HES X NIP, ID = 3.813" :g ~ 11551' H 7" X 4-1/2" BAKER 8-3 A<R ID= 3.813" ~ 11616' 4-1/2" HES X NIP, ID = 3.813" 1 11620' TOP OF C8v1f3\JT 1 1'\11 '( 1 11624' 1-1 3.75" BKR DEPLOY WENT SLV, ID = 3.0" , i 11637' 1- 4-1/2" HES XN NIP, MLLBJ D = 3.80" ~ (BB-IIND CT LNR) It(' 11644 ' 3-1/2" HOWCO X NIP, ID = 2.750" 1 ){.. 11647' 4-1/2" TUBING TAIL WLEG, D = 4.00" (BB-IIND CT LNR) 11674' 14 3-1/2" X 3-3/16" XO, ID = 2.880" 1 11740' 14 MA.RKER JOINT (B.MD) (BEHIND CT LNR) 11760' 1-1 MARKER JOINT (B.fvD) (BEHIND CT LNR) 1-1 ELfvD IT NOT LOGGED 12015' H 3-3/16" X 2-7/8" XO, D = 2.440" 1 MLLOUT WINDOW 11845' - 11851' 7" CSG, 26#, L-80, D = 6.276" 1-1 12190' 1 3-3116" LNR, 6.2#, L-80, .0076 bpf, ID = 2.805" DATE 02/13198 04/29/03 05/03103 05/08103 05116/03 05/19/03 1 13114' H PBTD 1 1 2-7/8"L(\f{,6.16#,L-80,.OO55bpf,ID=2.372" H 13149' 1 REV BY COMtv'ENTS DA TE REV BY 00 Mv1f3\JTS ORIG COM PLErION, (POOL 7) 07/12/03 BY/KAK OORRECTIONS ~V/KK CTDSIŒTRACK (NK-62A) JBMiKAK GLV C/O DTRiKA K GL V C/O JCMfTLH GLV C/O 1LHfTLH PERF DEPTH CORRECllON I\JAKUKUNrr WB.L: NK-62A ÆRMT No: 2030470 API No: 50-029-22852-01 SEC 36, T12N, R15E. 1393.21' FSL & 883.81' FB. 8P Exploration (Alaska) ') STATE OF ALASKA ) ALASKA JIL AND GAS CONSERVATION corvh...SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Suspend 0 Repair Well 0 Pull Tubing 0 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Perforate D WaiverD Stimulate Œ] Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 203-0470 OtherD Name: BP Exploration (Alaska), Inc. Development I]] ExploratoryD 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 59.80 8. Property Designation: ADL-034635 11. Present Well Condition Summary: StratigraphicD ServiceD 9. Well Name and Number: NK-62A 10. Field/Pool(s): Niakuk Field I Niakuk Oil Pool 6. API Number 50-029-22852-01-00 Total Depth measured 13149 feet true vertical 9271.3 feet Effective Depth measured 13114 feet true vertical 9276.2 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse Intermediate 11815 7" 26# L-80 36 - 11851 36.0 9307.0 7240 5410 Production 50 3-1/2" 9.3# L-80 11624 - 11674 9158.9 9191.2 10160 10530 Production 341 3-3/16" 6.2# L-80 11674 - 12015 9191.2 9355.1 Production 1134 2-7/8" 6.16# L-80 12015 - 13149 9355.1 9271.3 13450 13890 Surface 5474 9-5/8" 40# L-80 36 - 5510 36.0 5187.7 5750 3090 Perforation deDth: Measured depth: 12179 -12439,12459 -12562 True vertical depth: 9344.92 - 9317.47,9314.19 - 9302.32 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 36 11647 RECEIVED JAN 2 8 2004· Packers & SSSV (type & measured depth): 4-1/2" HES HXO SSV Baker S-3 Packer @ 2098 @ 11551 ^,A~ka Oi' & Gas Cons. Commission Anchorage 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure o 3157 . 0 13 Subsequent to operation: 34 0.09 3588 790 Tubing Pressure 573 560 Oil-Bbl Prior to well operation: 3157 14. Attachments: 15. Well Class after proposed work: Exploratory D DevelopmentŒ] ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Operational Shutdown D Oil I]] GasO WAG 0 G1NJO W1NJO WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Daily Report of Well Operations _ X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron lj~ C.c;fJ1:"-\ Title Production Technical Assistant Signature ORIC\NAL"ne 564-4657 K~~t~, Date 1/22/04 tü 0~J -, Form 1 0-404 Revised 12/2003 ') ) NK-62A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/17/03 Bleach W/ WFD treatment pkr. MU WFRD 2 3/16in MHA w/PDC GR/CCL mem log and RIH. Kill well w/5 bbl methanol and 250 bbl filtered 20/0 KCL. Tag w/logging string at 125621 ctmd. Made repeated tags and could not pass and could not jet down. 09/17/03 Tagging at the same depth on all tags. POOH. MU 2.125/1 Motor w/2.25/1 OD Junk Mill and RIH. Start milling at the top of the 2-7/8/1 Inr (12,0151 md). Saw a good wt bobble where the logging tools sat down. Spin through to PBTD & dry tag at 13,1231 ctmd. Backream across lower perfs while pumping 5 bbl flo-pro at surface. Chase out of hole to SO. POOH. 09/18/03 RIH with WFD BHA & PDS memory gamma/ccl in 2.20in carrier & 2.25in JSN. Sat down at 12420in ctmd. Stuck tools had to pump down backside to get free. POOH. 09/18/03 MU 2.25/1 JSN and RIH. Sat down at 12463 and 12851. Pumped 5 bbl sweeps while jetting through 2-7/8/1 liner and underbalancing the well. Tagged PBTD at 131041 ctmd. Pumped a final 15 bbl flo pro sweep from 130981 ctmd with the well underbalanced. Chased out with 2% KCL at max rate and swapped the hole over to 2% KCL while POOH. RIH with PDS memory gamma/ccllogging tools. Sat down at 130341 ctmd. Pump down coil and work tools to 130761 ctmd with out trouble. Log to 12,9001 & flag pipe, log to 11770' ctmd. POOH. 09/19/03 RIH to set straddle pkr and treat lower interval, 130301 - 13050'. Moved to second interval and could not get straddle to set. Made blank pipe test - ok. RBIH and could not get a set w/straddle after numerous attempts under varying conditions of pump pressure, and pulling speeds, dynamic and static conditions. Decide to set straddle at second interval depth and treat from 13010' to 130301 straddle was not set. Treated inerval w/20 bbl 4 ppb Hypochlorite solution and over displace w/20 bbl 2% KCL. Moved uphole to third interval, attempted to set straddle w/o sucess. Treated 129911 to 130111 w/20 bbl 4 ppb Lithium Hypochlorite solution and over displaced w/20 bbl 2% KCL straddle was not set. Pull uphole to 128001 and attempted final blank pipe test, failed. POOH. 09/19/03 CTU #5 flag pipe/bleach treatment -Continued-. POOH with logging tools. MU WFRD 2- 1/8in Jet Pack Straddle Packer. RIH to flag and set counter to top element at flag. RIH to 130881 w/o problems. Performed pre treatment injectivity test: (0.7 BPM WHP=1330 psi, 1.0 BPM WHP=1448 psi, 1.5 BPM WHP=1635 psi). FLUIDS PUMPED BBLS 218 910 975 25 80 2208 60/40 Methonal 2% KCL 2% Slick KCL Water Flo-Pro Lithium Hypochlorite Bleach TOTAL Page 1 TRe:= WELL J-EA 0 = AClUATOR= KB. ELB/= BF.ELB/ = KOP= Wax Angle = ~turri w·"; . Datum"w Ö ,;;; H' ) 4-1/16" -5M aw 11" 5M FfvC GEN 5 BA KER 59.8' 23.75' 3700' 100 @ 12419' 11 179' .......-9"2oeVsS" N K-62A ') I SAÆTY NOTES: e 2098' H 4-1/2"SLVN,I-ESHXO, 10=3.813" I 9-5/8" COO, 40#, L-80, ID = 8.835" H 551 0' ~ Minimum ID = 2.372" @ 12016' TOP OF 2-718" LIN ER PERFORATION SUMvlARY REF LOG: MCI\L. ON 04/27/03 A NGLE A T TOP ÆRF: 92 @ 12179' f\bte: Refer to A'oduction DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz Dð. TE 2" 4 12179 - 12439 0 04/28/03 2" 4 12459 - 12579 0 04/28/03 2" 4 12970 - 13060 0 04/28/03 4-1/2" lBG, 12.6#, L-80,.0152 bpf, 10 =3.958" H 11647' I 3-1/2"LNR,9.3#,L-80,.0087bpf,10=2.992" H 11674' GB\l2WHPSTOO< H 11840' 1 3RATAGSH 11850' ~ GAS LIFT MANDRELS ST MD lVD DEV TYPE VLV LATCH PORT Dð.1E L-5 3238 3176 3 CA-KBG-2-LS av'IY INT 0 08111/02 4 4001 3928 16 CA-KBG-2-LS DOrÆ INT 16 05/15/03 3 7423 6362 50 CA-KBG-2-LS SO INT 20 05/15/03 2 9922 7975 48 CA-KBG-2-LS av'IY INT 0 08111/02 1 11430 8979 48 CA-KBG-2-LS av'IY INT 0 08111/02 [ J 6003' 1-1 4-1/2" HES X NIP, ID = 3.813" 11540' H 4-1/2" HES X NIP, ID = 3.813" :8: ~ 11551' H 7" X 4-1 /'Z' BAKER 8-3 A<R, ID = 3.813" ~ 11616' 4-1/2" HES X NIP, 10 = 3.813" 1 11620' TOP OF CEMB\lT 1 ~ 11624' H K ~ 1 3.75" BKR OEPLOYrvENT SLV, 10 = 3.0" , 1 11637' - 4-1/2" HES XN NIP, MLLED D = 3.80" K (B8-IIND cr LNR) ~ 11644' 3-1/2" HOWCO X NIp, ID = 2.750" I 11647' 4-1/2" TUBING TAIL WLEG, D = 4.00" (B8-IIND cr LNR) 11674' H 3-1/2" X 3-3/16" XO, ID = 2.880" I 11740' H MARKER JOINT (I3..MD) (BEHND CT LNR) 11760' H MARKER JOINT (13..1VD) (BEHND CT LNR) H ELIVD TT I'JOT LOGGED 12015' H 3-3/16" X 2-7/8" XO, D = 2.440" 1 MLLOUT WINDOW 11845' - 11851' 7" CSG, 26#, L-80, D = 6.276" H 12190' I 3-3116" LNR, 6.2#, L-80, .0076 bpf, ID = 2.805" H 12015' 1 DATE REV BY CO MvlB\lTS 07/12/03 BY/KAK CORRB:;TIONS DATE 02/13/98 04/29/03 05/03103 05/08103 05/16103 05/19/03 REV BY COM~S ORIG COM PLErION, (POOl.. 7) Q6. V/KK CTD SIŒTRACK (NK-62A) JBMiKA K Gl V C/O DTRJ1<A K Gl V C/O JCMffLH GlV C/O 1LHffLH PERF DEPTH CORRECllON I 13114' H PBTD 1 1 2-7/8" L~,6.16#,L-80, .OO55bpf, ID = 2.372" H 13149' I\IA KUK UNIT WI3..L: NK-62A ÆRMT No: 2030470 API No: 50-029-22852-01 SEC 36, T12N, R15E 1393.21' FSL & 883.81' FI3.. 8P Exploration (Alaska) ~o3 -0 '-'I 1- k3s OCJ . II- ) WELL LOG TRANSMITTAL ) ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7thStreet Suite # 700 Anchorage. Alaska 99501 RE : Distribution - Final Print( s] 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 : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center lR2-1 900 E. Benson Blvd. Anchorage, AK 99508 WELL DATE LOG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR COLOR Open Hole 1 Res. Eva!. CH 1 1 1 NK-62 12-15-03 Mech. CH 1 Ja{~~ Caliper Survey Signed: ~~. " ~ \~"\.. ~ "- j,\"'-~ '-~ ~~)-y~ Date: Print Name: RECEIVED ~'" ;.' ? (¡ ')004 ....;"\; j '- . L Aja~8 Oil & Gas Cons. Commisakm Anchorage PRoAcTivE DiAGNOSTic SERViCES, INc., PO Box 1 ~69 STAffoRd lX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ~\:Sû~'\ "'~ 11/26/03 Schlumbergep NO. 3050 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD -/ A-D2 i 31 '().:-<;, ~ 10674401 PSP LDL 11/24/03 1 D.S.06-02 ' -01- . 10674399 PSP PROD PROFILE 11/22/03 1 D.S. D7-D4A ¡~J-o(,)' 10687646 PRODUCTION PROFILE 09/19/03 1 J-06 '\ . 7- - 03.C) 10563124 PRODUCTION PROFILE 11/10/03 1 16-21 ~'~i~ 10563125 PROD PROFILE/DEFT 11/11/03 1 N-18 9~- I~ 10674395 SBHP SURVEY 11/03/03 1 C-24 .<J '- I t-\ \ 10703945 LDL 10/30/03 1 R-19A 1 i 1~-rl \ 10703949 SBHP SURVEY 11/03/03 1 D.S.15-01A ~ ~tl' 10703946 SBHP SURVEY 10/31/03 1 2-40/5-22 i . ~ .... L v 10703952 PROD PROFILE/DEFT 11/21/03 1 NK-62A (jp,. - oy 1- 10572999 MEM INJECTION PROFILE 05/30/03 1 0.5. 15-20B ~~-~'n 10669980 MEM PROD PROFILE 10/12/03 1 D.S. 18-06A \ T ~ 10715358 MEM PPROF & IPROF 10/30/03 1 - PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ¡~~hE~r~;~,s~~a~~~d'99508 ;:':,~E C~ E1 \j'E 0 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Date Delivered: ~~,"" '; r) ?003 : ~~-... ~. (-- :--- - , \ ~ Received b~--"-\ ~,'ý'...". \~''-C ~('/'<'" ."'¡>';~!:':·l ~~;:; ;¿\ '';~~S t..,.:....¡ns. vornmission 5~·}1(,~:1(J{tge Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage. AK 99503-5711 ATTN: Beth Well D.S.15-01A \~S ''98~ NK.62A ~-0 '-~) ,:\'-:¡' E-27A l1 - 0 S5- G-03A <i"1 -0 ~O F-16A l<1 { ~.-_l top H-27A By"? ()~q E-05A ) _<-J Lf - Qc ~~ E-04A ) C{ ö -- \ ~ \ Job# 10703946 10572999 10558568 10563449 10558547 10700004 10672314 10662949 SCMT MCNL MCNL MCNL MCNL MCNL RST·SIGMA RST -SIGMA 11/26/03 NO. 3048 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Log Description Color Date Blueline Prints CD ~ -....-' 10/31/03 2 05/30/03 1 1 L~ --)J( Cì 08/09/03 1 1 ~,"3~CS 06/04/03 1 1 /9.5/ ~ 05/08/03 1 1 J)J~ 09/30/03 1 1 I~:} 09/16/03 1 1 09/15/03 1 1 i·" .._ 1- -"- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. F? .~ f~:' ~;.~ Anchorage, Alaska 99508 Date Delivered: ~ ~~\"')\.~~ DEe 2.2. WOE AJaSf~:i ;"',. ~ t-.- "-_ .~ - :., ;... .-", .~ - ~ ~ I~\I h",. ~"-'" '_ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth ~ C· Received b~\,--,.. ,"'i'" \-') ,( ~ ~(' ~ 08/27/03 Schlumberger NO. 2952 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job# Log Description Date Blueline Prints D.H28A @ð\ -1~ LDL 08/17/03 1 L1-15 i-I. RST-GRAVEL PACK 08/20/03 1 GNI-03 b - \ '6, . SHUT-IN TEMP SURVEY 08/18/03 1 NK-62 . ~ <'j...\ , PROD PROFILE/DEFT 05/30/03 1 4-08/P-27 ~---cð~ INJECTION PROFILE 08/20/03 1 2-62/Q-17 . -, F:,9( LDL 08/17/03 1 2-321SN-D3 . 0 - \ \ ~ LDL 08/18/03 1 D-13A ~ -<:-J~ 23402 MCNL 06/23/03 1 1-57/R-23 I~.... J \ 23281 RST -SIGMA 05/07/03 1 CD -..,./ 1 1 J~ I~?! pl )3 '1 -- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 ¡~~h~r:=~,s~~a~~~d'99508 ~~~T:.(:~ 'E ~ \/E 0 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Date Delivered: I~UG 1.1' 1fJJ3 Received ~~: QJ~'-O~ ¡:.j2~(.::t.j" ~ ::'::,:;.~;<:¡;~j._0f¡1rrÚJ&.on /:Ji:fi Cj~ :;~~·S ~~~\\~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 08/06/03, Peri Corrections ) J 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 203-047 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22852-01 4. Location of well at surface 9. Unit or Lease Name 1394' NSL, 884' WEL, SEC. 36, T12N, R15E, UM X::: 721677, Y::: 5979932 Prudhoe Bay Unit 1 Niakuk At top of productive interval 1182' NSL, 1830' EWL, SEC. 30, T12N, R16E, UM X ::: 724239, Y ::: 5985079 10. Well Number At total depth 1319' NSL, 946' EWL, SEC. 30, T12N, R16E, UM X = 723351, Y = 5985189 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Niakuk Oil Pool KBE = 59$ ADL 034635 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 4/17/2003 4/26/2003 4/29/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MO+TVD) 19. Directional Survey 13149 9271 FT 13114 9276 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, ROP, RES, CCL, CNL Classification of Service Well NK-62A 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2099 MD 1800' (Approx.) 23. CASING SIZE 20" 9-5/8" 7" WT. PER FT. 94# 40# 26# 9.3# / 6.2# / 6.16# GRADE H-40 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 116' 30" 41' 5510' 12-1/4" 38' 11845' 8-1/2" 11624' 13149' 3-3/4" CEMENTING RECORD 260 sx Arctic Set (Approx.) 2270 sx PF 'E', 440 sx 'G', 50 sx PF 'C' 400 sx Class 'G' 93 sx Class 'G' AMOUNT PUllED ... 3-1/2" X 3-3116" x 2-7/8" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 4 spf MD TVD 12179' - 12439' 9345' - 9317' 12459' - 12579' 9314' - 9302' 12970' - 13060' 9295' - 9285' 25. SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 11649' PACKER SET (MD) 11551' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11624' Freeze Protected with Diesel 27. Oate First Production May 3, 2003 Date of Test Hours Tested 5/14/2003 6.7 Flow Tubing Casing Pressure Press. 565 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR Oll-BBl TEST PERIOD 222 CALCULATED Oll-BBl 24-HoUR RATE GAs-McF -0- GAs-McF WATER-BBl 1,820 WATER-BBl CHOKE SIZE GAS-Oil RATIO 62 Oil GRAVITY-API (CORR) æ. ~ÆD~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. fR{~)I)~~V~'~ ~r¡~G <'ì t )lllì I Form 10-407 Rev. 07-01-80 OR\C\NAL ~v Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. No New Marker Pics Top of Productive is Top of Kuparuk from NK-62 11779' 9260' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble /fÓ~. ~ Trtle Technical Assistant Date OPyOCo-Ó3 NK-62A 203-047 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Dan Kara, 564-5667 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. 11 EM 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 (OF, 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 OR I G t '\'\, , w ,\ ~', \ Schlumberger NO. 2890 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job# Log Description Date Blueline Prints CD D.S. 2-05A 23376 MCNL 06/02/03 1 1 10.) ?In H-27 A 23319 MCNL 05/09/03 1 1 I~J~ E-02A 23275 MCNL 03/15/03 1 1 NK-62A 23277 MCNL 04/27/03 1 1 J~, - E-01 A 23280 MCNL 04112/03 1 1 ~1:~( P2-54A 23274 MCNL 03/27/03 1 1 D-22B 23348 MCNL OS/22/03 1 1 J~JI ~"4 D.S. 2-08B MEM PROD PROFILE 05/31/03 1 J-26 LDL 06/20/03 1 D.S. 2-29A LDL 06/22/03 1 D.S.15-28 LDL 06/21/03 1 0.5. 12-20 LDL 06/03/03 1 J-08 LDL 06/26/03 1 D.S. 2-25 PRODUCTION PROFILE 06/07/03 1 PSI-01 TEMPERATURE WARMBACK LOG 06/09/03 1 PSI-06 TEMPERATURE WARMBACK LOG 06/13/03 1 PSI-09 TEMPERATURE WARMBACK LOG 06/19/03 1 K-317B SBHP SURVEY 04/05/03 1 C-04A SBHP SURVEY 06/26/03 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth RECEIVED 07/02103 -' .~ Date Delivered: Juldl6 2003 Received ~ ~L~~ ~ G ~ ~~/'{"".... Aiaska OH & Gas Cons. Commi88ton .Anchorage ) ') ~D 3 --04-1 \\'631 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska June 19, 2003 RE: MWD F01mation Evaluation Logs NK-62A, AK-MW-2398939 1 LDWG formatted Disc with verification listing. AùPI#: 50-029-22852-01 . PLEASE ACKNOWLEDGE .RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed:P~ JP~ ~ q r: "1n03 . u r¡ ,~1 ~J ¿ ,: i ~ Date: ) ') ~D3 -O~I l\1S3l? WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation COlTIl11. Attn.: Howard Okland 333 West 7t11 Avenue, Suite 100 Anchorage, Alaska June 19, 2003 RE: MWDFormation Evaluation LogsNK-62A PBI, AK-MW-2398939 1 LDWG formatted Disc with verification listing. ~I#: 50-029-22852-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. ~~~?f~~le,:, Na~~~~ 99518 \1-. '.'~ I:,:~ \\\. ,.<,: I ' /~: ';,\ BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ''''':' .., ~~:; t) Signed: \::-~ ~. ·']])áte.: 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 203-047 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22852-01 4. Location of well at surface 9. Unit or Lease Name 1394' NSL, 884' WEL, SEC. 36, T12N, R15E, UM X = 721677, Y = 5979932 Prudhoe Bay Unit I Niakuk At top of productive interval 1182' NSL, 1830' EWL, SEC. 30, T12N, R16E, UM X = 724239, Y = 5985079 10. Well Number At total depth 1319' NSL, 946' EWL, SEC. 30, T12N, R16E, UM X = 723351, Y = 5985189 11. Field and Pool 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. Niakuk Oil Pool KBE = 59.8' ADL 034635 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 4/17/2003 4/26/2003 4/29/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 13149 9271 FT 13114 9276 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, ROP, RES, CCL, CNL 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 4 spf MD TVD MD TVD 12050' - 12310' 9353' - 9335' 12330' - 12450' 9333' - 9316' 12970' - 13060' 9295' - 9284' Flow Tubing Casing Pressure CALCULATED Press. 565 24-HoUR RATE 28. CORE DATA nCCEIVl:.[ 1 Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core c~i~. 23. CASING SIZE 20" 9-5/8" 7" WT. PER FT. 94# 40# 26# 9.3# / 6.2# / 6.16# 27. Date First Production May 3, 2003 Date of Test Hours Tested 5/14/2003 6.7 No core samples were taken. Form 10-407 Rev. 07-01-80 ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well NK-62A 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2099 MD 1800' (Approx.) GRADE H-40 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 116' 30" 41' 5510' 12-1/4" 38' 11845' 8-1/2" 11624' 13149' 3-3/4" * 3··1/2" x 3-3/16" x 2-7/8" CEMENTING RECORD 260 sx Arctic Set (Approx.) 2270 sx PF 'E', 440 sx 'G', 50 sx PF 'C' 400 sx Class 'G' 93 sx Class 'G' AMOUNT PUllED 25. TUBING RECORD DEPTH SET (MD) 11649' PACKER SET (MD) 11551' SIZE 4-1/2", 12.6#, L-80 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11624' Freeze Protected with Diesel PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR TEST PERIOD Oll-BBl 222 GAs-McF -0- CHOKE SIZE 62 Oil GRAVITY-API (CORR) Oll-BBl GAs-McF WATER-BBl 1,820 WATER-BBl GAS-Oil RATIO MAY 2 8 2003 A\aska on & Gas Cons" Commission Anchorage ORIGIN A tR8DMS BFl Submit In Duplicate AUG 1 1 200] ~ ~ ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. No New Marker Pics Top of Productive is Top of Kuparuk from NK-62 11779' 9260' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~ ~ ~ Title Technical Assistant Date OSþ ;;Z7~03 NK-62A Well Number 203-047 Permit No. I Approval No. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Dan Kara, 564-5667 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, il jjection 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. I-:-EM 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 (OF, 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. II EM 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 ) ') Page 1 of 15 Qperations·Summaty ··Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-62 NK-62 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/14/2003 Rig Release: 4/29/2003 Rig Number: Spud Date: 1/3/1998 End: 4/29/2003 Date From- Tb Hours Task Cbde NPT Phase Déscri þtion.ofOþerations 4/13/2003 15:00 - 22:30 7.50 MOB P PRE Rig Released from E-01A @ 15:00Hrs on 4/13/2003. Made general preparations to move rig & load out trucks. 22:30 - 23:00 0.50 MOB P PRE PJSM on moving rig off well. Jack up rig & pull rig to edge of pad. Conduct post-operations pad inspection. 23:00 - 23: 15 0.25 MOB P PRE Held pre-move safety meeting with security, CPS, tool services & all personnel. 23:15 - 00:00 0.75 MOB P PRE Move rig from E-01A enroute to NK-62. 4/14/2003 00:00 - 20:00 20.00 MOB P PRE Move rig to NK-62. 20:00 - 20:15 0.25 MOB P PRE PJSM & HA/HM for raising derrick & windwalls. 20: 15 - 00:00 3.75 MOB P PRE Raise & scope up derrick. Raise windwalls. 4/15/2003 00:00 - 00:30 0.50 MOB P PRE PJSM & HA/HM on backing rig onto well. Prep well. Confirm Nk-16 & NK-17 are SI & flowline depressured. 00:30 - 01 :30 1.00 MOB P PRE Jack-up & attempt to back rig over well. Observe beaver slide tight against adjacent NK-16 well. 01 :30 - 03:30 2.00 MOB N MISC PRE PJSM. Cut off beaver slide to fit in rig over well. 03:30 - 04:00 0.50 MOB P PRE PJSM. Back rig over well & jack down. Accept rig @ 03:00 Hrs on 4/15/2003. 04:00 - 07:00 3.00 BOPSURP DECOMP N/U BOPE. Meanwhile Spot trailers & tanks. 07:00 - 07: 15 0.25 RIGU P PRE PJSM for R/U injector/gooseneck & stabbing CT. 07:15 -10:00 2.75 RIGU P PRE P/U injecter head. M/U guide arch & stab CT into injecter head. C/O packoff. Cut CT & install OS CTC. Pull test to 35klbs - OK. 10:00 - 15:30 5.50 BOPSURP DECOMP Perform initial BOPE pressure/function test. AOGCC test witness waived by John Crisp. Meanwhile fill rig pits with 1 % KCL water. 15:30 - 18:00 2.50 KILL N RREP DECOMP Changeout 9 broken bearing pins on injector. Grease & service injector. 18:00 - 19:00 1.00 KILL P DECOMP Open up well & observe WHP = 900psi, lAP = 500psi, OAP = 35psi, flowline pressure = 200psi & IA injection line pressure = 300psi. IA injection line is blinded @ the IA & manifold. Bleed down lAP to 40psi. Bleed FLP to zero. FL is blinded at btm of S-riser 19:00 - 19:45 0.75 KILL P DECOMP Pre spud/safety mtg 19:45 - 21:15 1.50 KILL P DECOMP Fill CT w/ KCI. PT inner reel valve. Install cement pup w/ big hole nozzle. Stab onto well 21 :15 - 22:25 1.17 KILL P DECOMP Attempt to liquid pack wellbore w/1 % KCI starting at 2.7 bpm/2600 psi and gradually reduce rate to 2.0 bpm/2600 psi as well not taking fluid (assume plugged perfs from UR ops). Pumped 164 bbls 22:25 - 23:40 1.25 KILL P DECOMP End kill down BS and swap to min rate down CT. RIH w/ BHA #1 at 0.4 bpm/2300 psi WHP at 50-90'/min 23:40 - 00:00 0.33 KILL P DECOMP At 6000', open choke to take returns to flowback tank. Bleed WHP from 2350 to 1000 psi (mostly gas). Maintain 1000 psi while incr rate to 1.0 bpm and circ out gas while continue RIH 4/16/2003 00:00 - 00:45 0.75 KILL P DECOMP Continue RIH while eirc out gas. Most of gas gone by 10000'. Red BP to 500 psi and continue RIH pumping 1.0 bpm dn CT and taking returns to flowback tank. MIRU OS cementers 00:45 - 01 :00 0.25 KILL P DECOMP Tag WS at 11876' CTD and corr to 11840'. PUH 50k to 11750' and flag CT. Check returns and had fair amount of crude in returns. Drop WHP to zero, incr rate to 2.3 bpm/1350 psi CTP 01 :00 - 01 :50 0.83 KILL P DECOMP CBU 2.3 bpm/1350 psi w/ 200 psi WHP w/ choke open. WHP gradually fell to 90 psi after one eirc, but fluid check showed gas and crude w/ KCI (EMW to balance must be closer to 8.5 Printed: 5/5/2003 11 :28:36 AM ) ) Page 2 of15 Ope ratio n55 ï.lmrnáry.. Repo rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-62 NK-62 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/14/2003 Rig Release: 4/29/2003 Rig Number: Spud Date: 1/3/1998 End: 4/29/2003 Date Front~ To Hours Task Code NPT Phase Desëription of Operations 4/16/2003 01 :00 - 01 :50 0.83 KILL P DECOMP ppg) 01:50 - 03:15 1.42 KILL P DECOMP Incr BP to 500 psi and CBU 2.3/1740. Returns check after 1.5 BU's showed sli crude w/ 'out' density of 8.13 ppg. Injection test at 1.0 bpm showed steady rise from 500 psi to 1500 psi over 5 min, but no stabilization. Bleed off WHP to 500 psi. Continue circ 2.3/1750 03:15 - 03:30 0.25 PXA P DECOMP Safety mtg re: cementing 03:30 - 04:00 0.50 PXA P DECOMP Batch up cement while circ 2.3/1750 w/ 500 psi BP taking returns to flowback tank 04:00 - 04:35 0.58 PXA P DECOMP PT OS @ 3500 psi. Load CT w/ 20 bbls 15.8 ppg G cement (TT 6: 11) 1.5/1110 holding 500 psi BP and taking returns thru choke to pits 04:35 - 04:50 0.25 PXA P DECOMP Displace cement w/ KCI 2.3/880 holding 500 psi BP while RIH from 11750' 30k 04:50 - 05:10 0.33 PXA P DECOMP Red rate to 1.0 bpm and PUH from 11835' 53k w/ cement at nozzle at 15'/min. PUH 1 O'/min from 11790'. After 4 bbls out, incr WHP to 1000 psi and had 1/1. Incr WHP to 1500 psi by 11730' 1/1, 2000 psi by 11700' 1/1. Lay in rest of cement at 2000 psi to calc WCTOC at 11503'. Est 6-8 bbls cement into perfs 05:10 - 05:30 0.33 PXA P DECOMP PUH to Safety at 11000'. SO pump and monitor w/ choke closed at 2415 psi WHP. Lost 200 psi in 15 min (due to assumed annulus cooling from lower temp fluids) 05:30 - 06:00 0.50 PXA P DECOMP PUH 5'/min 34k while circ 30 bbls biozan to nozzle at 1.0 bpm/2620 psi holding 2000 psi WHP w/ 1/1 returns 06:00 - 06:45 0.75 PXA P DECOMP RIH from 10840' 20'/min while circ bio to nozzle at 1.0 bpm (KTTCS). Red WHP slowly to 500 psi while RIH. Begin jetting @ 2.7bpm/2500psi & 500psi WHP at 11750'. Make 3 down/up passes from 11640' (EOT) to 11750' (flag depth) intentionally leaving 38' of cement above top perf. 06:45 - 09:00 2.25 PXA P DECOMP Jet out of hole @ 2.9/2.5bpm & 500psi min WHP dumping cement contaminated KCL fluid. POOH. Trap 500psi WHP & SI MV/Swab. 09:00 - 10:30 1.50 PXA P DECOMP M/U & RIH with side jet swizzle nozzle. Jet stack @ 3.1bpm/1420psi. POH & UD nozzle. 10:30 - 10:45 0.25 STWHIP P WEXIT Held pre-operations safety meeting. Reviewed well plan, potential hazards & BHA M/U procedures. 10:45 - 12:45 2.00 PXA P WEXIT WOC to 100psi compressive strength. 12:45 -13:00 0.25 PXA P WEXIT Slowly open up well & flow check - well stable. 13:00 - 13:25 0.42 STWHIP P WEXIT M/U window milling BHA # 2 with HCC DSM, diamond string mill, Baker extreme straight motor, MHA & 2 jts of 2-3/8" PH6 tbg. Stab injector on well. 13:25 - 15:40 2.25 STWHIP P WEXIT RIH with BHA #2 maintaining 500psi WHP. Up wt check @ 11500' = 57.5k & down wt = 26k. Continue RIH & tag @ 11650' - looks like XN (milled out to 3.8"). P/U & retag @ same depth. Bring on pumps & establish freespin @ 2.8bpm/1680psi. 15:40 - 15:55 0.25 STWHIP P WEXIT Ease into milling & mill thru the XN with 2 stalls & 2.8bpm/1750psi. Make few passes with & without pumping to ensure there are no restrictions/overpulls. 15:55 - 16:40 0.75 PXA P WEXIT Lab confirms 1700psi compressive strength. WOC to get to 2000psi. 16:40 - 16:45 0.08 PXA P WEXIT Continue RIH BHA #2. Tag cement/bridge @ 11774'. 16:45 - 18:00 1.25 STWHIP P IWEXIT Mill cement to 11785' with 2.6/2.6bpm, 2200psi, 60fph ave I I Printed: 5/5/2003 11 :28:36 AM ) ) Page 3 of 15 Operations Summ~ryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-62 N K-62 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/14/2003 Rig Release: 4/29/2003 Rig Number: Spud Date: 1/3/1998 End: 4/29/2003 Date From- To Hours . Task Code NPT Phase Description· of Operations 4/16/2003 16:45 - 18:00 1.25 STWHIP P WEXIT ROP. Getting gassy returns. Choke back 500psi & ream in hole @ 100fph from 11785' to W/S tagged @ 11851.9'. 18:00 - 18:15 0.25 STWHIP P WEXIT SID pump & SI well. Observe no WHP increase. Open choke. 18:15 - 18:30 0.25 STWHIP P WEXIT Start motor 2.8/1750 RIH and tag pinch point. Correct to 11844.6' and flag, 59k 18:30 - 21 :40 3.17 STWHIP P WEXIT Begin milling window 2.8/1750 PVT 327, IA 567, OA 215. After one circ thru choke and no further gas, divert returns back to normal circ path 21 :40 - 23:00 1.33 STWHIP P WEXIT 11847.6' 2.8/1790400# diff, 5k wt 23:00 - 00:00 1.00 STWHIP P WEXIT 11849.4' 2.8/1840 300# diff, 2k wt. Mill to 11850.8' and appears mill is working on btm of window 4/17/2003 00:00 - 00:25 0.42 STWHIP P WEXIT Continue milling window with mill working on btm of window at 11850.8'. More motor work at 11851.6', then clean (no stalls thruout window milling ops) 00:25 - 01 :05 0.67 STWHIP P WEXIT Drill open hole from 11852-862' while swap to used 8.7 ppg Flo Pro mud 01 :05 - 02:05 1.00 STWHIP P WEXIT Ream window area w/ no motor work three times 48k, 20k. Dry tag, clean. Official (for now) depths are TOWS 11840, TOW 11844.6', BOW 11851', TO 11862' 02:05 - 04:15 2.17 STWHIP P WEXIT POOH for drilling assy. Pulled 12k over thru XN at 11640' CTD (mills must still be in gauge. .). Ream and backream w/ no motor work 04: 15 - 04:45 0.50 STWHIP P WEXIT LD milling BHA. Mill had center wear. Mill and SR both 3.80". Load out tools 04:45 - 05:00 0.25 DRILL P PROD1 Safety mtg re: MU drilling BHA 05:00 - 05:45 0.75 DRILL P PROD1 MU drilling BHA (4.125" bi DPI w/ 2.57 deg SR motor) 05:45 - 08:00 2.25 DRILL P PROD1 RIH w/ BHA #3 to 2nd flag @ 11833' (7' deep). Wt check: Up wt = 53k, Own wt = 24k. Run thru window with pumps down & tag btm @ 11869'. Correct depth -7' to 11862'. Check TF - @ 30L. 08:00 - 09:50 1.83 DRILL P PROD1 Begin drilling build/turn section with 40LTF, 2.7/2.7bpm, 3500/3800psi & 18fph ave ROP. Drill to 11895' with ocassional motor stalling. See RA PIP tag @ 11850'. 09:50 - 10:45 0.92 DRILL P PROD1 Orient & drill to 11920' with 15-20LTF, 2.7/2.7bpm, 3500/3800psi & 24fph ave ROP. ROP getting better with BHA out of window. Getting only 29degs/1 OOft build rates - need 33degs/100ft. 10:45 - 10:50 0.08 DRILL P PROD1 Wiper trip clean to 11880' for tie-in log. 10:50 -12:15 1.42 DRILL P PROD1 Log up & see RA PIP tag @ 11844'. PUH to above window @ 11830'. Log up GR & tie-in RA PI P tag with Geology PDC log. Geo confirms - 21' correction to CTD. Correct depths to: TOWS = 11819', TOW = 11823.6', BOW = 11830' & RA PIP Tag = 11829'. 12:15 - 14:15 2.00 DRILL N WAIT PROD1 Review logs & tie-ins with ANC Team & agree to stick to the PDC log which is 4' deeper than the OH sonic log of 01/22/1998. Whipstock setting log was tied into SWS GR/CCL Perf log of 2/14/1998 which is on depth with PDC log. Continue checking logs to see if whipstock was set off depth. Meanwhile DO work out new directional plan based on a 11819' KOP. 14:15 -14:25 0.17 DRILL P PROD1 RBIH clean thru window to btm @ 11899'. 14:25 - 14:50 0.42 DRILL P PROD1 Orient TF to 50L. 14:50 - 15:00 0.17 DRILL P PROD1 Drill to 11911' with 70L TF, 2.7/2.7bpm, 3500/3800psi & 24fph ave ROP. Observe wrong tie-in depth correlation. Looks like Printed 5/5/2003 11 :28:36 AM ') ) . Page4 of15 Op~rations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-62 N K-62 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/14/2003 Rig Release: 4/29/2003 Rig Number: Spud Date: 1/3/1998 End: 4/29/2003 Date From- To Hours· Task Code NPT Phase Description ofOperatibns 4/17/2003 14:50 - 15:00 0.17 DRILL P PROD1 whipstock was set on depth afterall - based on uncorrected tagged depths, the XN & WS are 202' apart. 15:00-15:15 0.25 DRILL N MISC PROD1 PUH to log more section. 15:15 - 16:00 0.75 DRILL N MISC PROD1 Log up from 11775' to 11733' & Geo confirms wrong tie-in correlation. Added 21' to CTD & recorrected depths to: TOWS = 11840', TOW = 11844.6', BOW = 11851' & RA PIP Tag = 11850'. 16:00 - 16:30 0.50 DRILL N WAIT PROD1 DO work out new directional plan based on original 11840' KOP - will need a 42degs/100ft build rate to catch-up with plan. Review situation with ANC Team & agree to POOH to check bit & reset motor bend to 2.83degs - may need to land +/-5ftvd deeper. 16:30 - 18:30 2.00 DRILL N PROD1 POOH drilling BHA. 18:30 - 19:25 0.92 DRILL N PROD1 OOH. Adjust motor to 2.83 deg, bit 2-4-' and best available bi for next ru n 19:25 - 21:40 2.25 DRILL N PROD1 RIH w/ BHA #4. RIH thru window w/o pump, clean to 11930'. PUH 52k, start pump. Chk TF at 29R 2.4/3080. RIH and tag at 11941' and corr to 11932' 21 :40 - 22:20 0.67 DRILL P PROD1 Drill from 11932' 2.4/31 00/20-30R w/ 50-200 diff. Drill to 11952' and can't get consistent reactive to keep TF high side 22:20 - 22:40 0.33 DRILL P PROD1 PUH to 11900' and orient around 22:40 - 23: 1 0 0.50 DRILL P PROD1 Drill from 11952' 2.3/31 00/12L. Drill to 11985' 23: 1 0 - 23:30 0.33 DRILL P PROD1 Pump up survey and determine that build has been completed at 9296' TVD 23:30 - 23:55 0.42 DRILL P PROD1 Orient to left side 23:55 - 00:00 0.08 DRILL P PROD1 Drill from 11985-990' 2.4/3140/97L 4/18/2003 00:00 - 00: 15 0.25 DRILL P PROD1 Continue drilling from 11990' 2.4/3000/97L. Drill to 12001' 00:15 - 00:50 0.58 DRILL P PROD1 Orient 1 click (having to orient above 11900' to get clicks). RBIH and TF went HS. Orient around 00:50 - 01 :00 0.17 DRILL P PROD1 Drill from 12001-011' 2.4/3000/74L 01 :00 - 01 :30 0.50 DRILL P PROD1 Orient around. Drill 3' to 12004' at 44L. Need to drill at about 80-85L. Big bend motor (2.83 deg SR) is too hard to get locked in and makes too radical build or drop when not at correct TF. Will pull for a smaller bend standard motor to finish turn and start invert. This will add about 125' MD to hole length from original plan 01 :30 - 02:00 0.50 DRILL P PROD1 Wiper to window. Log tie-in up from 11895' 2.3/3000/65L. Add 4.0' (TO is 12018'). Flag CT at 11800' EOP. PVT 302 02:00 - 04: 10 2.17 DRILL P PROD1 POOH for smaller bend motor 04: 1 0 - 05:00 0.83 DRILL P PROD1 Change to standard motor with 2.0 deg bend. Notice well <- flowing and record 8 bbl gain while MU BHA 05:00 - 05:15 0.25 DRILL P PROD1 RIH w/ BHA #5 to 500'. SI choke and check WHP. After 5 min 230 psi and stabilizing 05:15 - 07:30 2.25 DRILL P PROD1 RIH circ 0.5/1550 holding 500 psi BP. RIH clean thru window & corrected -14' @ to 11878' (EOP flag). Continue RIH & tag TO @ 12014'. PVT 313 07:30 - 08:40 1.17 DRILL N DPRB PROD1 Circulate out influx & 1 x btms up @ 2.8bpm/3450psi. Seeing some crude oil returns over the shakers. PUH to 11750'. 08:40 - 10:00 1.33 DRILL N DPRB PROD1 SI well & observe pressures for 60 mins. WHP stabilize @ 346psi. Reservoir pressure is estimated @ 4600psi (EMW = 9.52ppg) using 8.8ppg mud wt & 9296ftss. Call for more NaCL I to increase new 9.4ppg mud to 9.8ppg. 10:00 - 10:15 0.25 DRILL N DPRB PROD1 SID job, regroup & held an operations safety meeting. I I Printed 5/5/2003 11 :28:36 AM ) ) Page 5 of 15 Operations S uni m:aryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-62 NK-62 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/14/2003 Rig Release: 4/29/2003 Rig Number: Spud Date: 1/3/1998 End: 4/29/2003 Date From .. To Hours . Task Code NPT Phase Descri ptionofOperations 4/18/2003 10:00 -10:15 0.25 DRILL N DPRB PROD1 Reviewed well control situation, change in well plan, future operations plans & procedures to ensure all personnel are on the same page. 10:15 -13:15 3.00 DRILL N DPRB PROD1 Cleanout pits & take in new 9.4ppg mud. Wt up mud to 9.8ppg with NaCL. Ship used mud to Baroid. 13:15 -15:00 1.75 DRILL N DPRB PROD1 Circ in new 9.8ppg mud. SID pump & observe well dead. PVT = 325bbls. Meanwhile informed AOGCC about well control situation & change in reservoir pressure. Tom Maunder responds that the BOPE should be retested to 4000psi when next we POOH. 15:00 - 15:30 0.50 DRILL P PROD1 Orient TF around to 77L. 15:30 - 16:40 1.17 DRILL P PROD1 Drill to 12078' with +/-90L TF, 2.6/2.6bpm, 3300/3700psi & 60fph ave ROP. 16:40 - 17:40 1.00 DRILL P PROD1 Orient & drill to 12101' with +/-80L TF, 2.6/2.6bpm, 3300/3700psi & 50fph ave ROP. TF rolling to the left. 17:40 - 18:00 0.33 DRILL P PROD1 Wiper trip clean to 11870'. Orient TF to 60L. RBIH to btm. 18:00 - 18:15 0.25 DRILL P PROD1 Drill to 12112' with +/-80L TF, 2.6/2.6bpm, 3300/3700psi & 60fph ave ROP. 18:15 -18:20 0.08 DRILL P PROD1 Orient 2 clicks to 77L. PVT 302 18:20 - 18:45 0.42 DRILL P PROD1 Drill from 12112' =2.4/3080/70L and getting good turn, but not enough build to keep up with invert line 18:45 - 19:00 0.25 DRILL P PROD1 Orient 19:00 - 19:20 0.33 DRILL P PROD1 Drill to 12151' 2.4/3090/33L and building now 19:20 - 19:55 0.58 DRILL P PROD1 Orient around 19:55 - 23:30 3.58 DRILL P PROD1 Drill from 12151' 2.5/3150/95L-80L building angle and holding avg 93 deg. Drill to 12278' (9279' TVD) 23:30 - 00:00 0.50 DRILL P PROD1 Orient around 4/19/2003 00:00 - 00:25 0.42 DRILL P PROD1 Drill from 12278-294' 2.5/3130/90L completing turn and midway into invert 00:25 - 00:35 0.17 DRILL P PROD1 Survey PVT 292 00:35 - 00:50 0.25 DRILL P PROD1 Wiper to window 00:50 - 02:55 2.08 DRILL P PROD1 POOH 02:55 - 04:00 1.08 DRILL P PROD1 LD drilling BHA 04:00 - 10:00 6.00 BOPSUR P PROD1 Test BOPE to 4000 psi as requested by AOGCC due to higher than expected formation pressure. Witness waived by AOGCC 10:00 - 10:45 0.75 DRILL N RREP PROD1 Changeout leaking skate cylinder on injector. 10:45 - 11 :00 0.25 DRILL P PROD1 Held PJSM & HA/HM for P/U lateral drilling BHA #6. 11 :00 - 12:00 1.00 DRILL P PROD1 M/U lateral BHA #6 with Sperry RES-MWD tools, 1.04 deg motor & new Hycalog 3-3/4 x 4-1/8" bicenter bit #5. 12:00 - 12:35 0.58 DRILL P PROD1 Initialize Resistivity tool. 12:35-13:15 0.67 DRILL N RREP PROD1 Changeout 4 broken bearing pins on injector. Grease & service injector. 13:15 -15:25 2.17 DRILL P PROD1 M/U injector & RIH with BHA#6. SHT orienter & MWD - OK. Continue RIH to 11813'. Correct normal-13' to 11800'. 15:25 - 15:45 0.33 DRILL P PROD1 Orient TF to 45L. SID pump & RIH thru window to 11865'. 15:45 - 16:40 0.92 DRILL P PROD1 Log down resistivity MAD pass from 11865' to TO (tagged @ 12296') with 45L TF, 2.5bpm/3000psi & 800fph. Correct CTD to 12294'. Log up 20' @ 48k, 60fph to verify GR repeatability. 16:40 - 16:45 0.08 DRILL P PROD1 Orient TF to 50L. PVT = 288bbls. 16:45 - 18:00 1.25 DRILL P PROD1 Drill to 12350' with +/-70L TF, 2.7/2.7bpm, 3300/3750psi & 45fph ave ROP. Wt stacking with ocassional motor stalling. 18:00-18:30 I 0.50 DRILL P PROD1 Orient & drill to 12370' with +/-50L TF, 2.7/2.7bpm, 3300/3750psi & 40fph ave ROP. Still stacking wt. Call for I Printed: 5/5/2003 1128:36 AM ) ) Pagë6of15 Operatiöns· Summary· Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 4/19/2003 4/20/2003 NK-62 NK-62 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/14/2003 Rig Release: 4/29/2003 Rig Number: Spud Date: 1/3/1998 End: 4/29/2003 From.;. To Hours Task Code NPT Phase Description·ofOperatiöns 18:00 - 18:30 0.50 DRILL P PROD1 lubetex. 18:30 -19:15 0.75 DRILL P PROD1 Drill from 12370' 2.4/2800/45L to 12395' and stacking 19:15 -19:35 0.33 DRILL P PROD1 Wiper to window prior to orient around 19:35 - 19:55 0.33 DRILL P PROD1 Orient 19:55 - 20:50 0.92 DRILL P PROD1 Drill ahead 35-45'/hr from 12395' stacking and stalling 2.7/3350/70L at 97 deg while continuing invert. Drill to 12430' 20:50 - 21:10 0.33 DRILL P PROD1 Orient around after seeing 99.74 deg 21:10 - 22:40 1.50 DRILL P PROD1 Drill from 12430' 2.6/3250/1 07L. Drill to 12492' and having trouble getting wt to bit 22:40 - 23:20 0.67 DRILL P PROD1 Wiper to window prior to orient around. Begin adding 60 bbls new mud w/ 8% L T, 8% FL in 20 bbl batches 23:20 - 00:00 0.67 DRILL P PROD1 Orient around 00:00 - 01 :35 1.58 DRILL P PROD1 Drill from 12492' 2.6/3250/130L Slide is better, but ROP is low 30-40'/hr. Start seeing shale on GR (45' behind bit). Drilled to 12535' (9244' TVD) at 97 deg and geo determines that we have gone thru the top of sand (quite a bit earlier than expected). It is later determined that we have not only gone thru the top of the BB2, but have also gone thru the DFS shale and are now in the GFSSB (or something like that) sand. . . 01 :35 - 02:05 0.50 DRILL P PROD1 Orient to drilllowside 02:05 - 03: 15 1.17 DRILL P PROD1 Drill from 12537' 2.6/3260/174L and ROP improving to 70'/hr. Drill to 12597' and now seeing sand on GR and showing 89 deg 03:15 - 03:35 0.33 DRILL P PROD1 Wiper to window prior to orient around 03:35 - 03:50 0.25 DRILL P PROD1 Log tie-in up from 11900', add 5.0' 03:50 - 04:20 0.50 DRILL P PROD1 RIH and tag TO at 12602'. Orient one click 04:20 - 04:40 0.33 DRILL P PROD1 Drill from 12602' 2.5/3200/148L Drill to 12623' 04:40 - 05:20 0.67 DRILL P PROD1 Orient to right side 05:20 - 05:55 0.58 DRILL P PROD1 Drill from 12623' 2.4/3140/160R Drill to 12650' 05:55 - 06:20 0.42 DRILL P PROD1 Orient around 06:20 - 07:00 0.67 DRILL P PROD1 Drill from 12650' to 12686' @ 2.5/3210/60-90R. Wt stacking. PVT = 319bbls. IA = 270psi, OA = 320psi. Not building angle @ 60R. 07:00 - 07: 15 0.25 DRILL P PROD1 Orient TF around to HS. 07:15 - 07:50 0.58 DRILL P PROD1 Drill to 12709' with 2L TF, 2.7/2.7bpm, 3250/3550psi & 35fph ave ROP. 07:50 - 08:00 0.17 DRILL P PROD1 Orient TF to 70R. 08:00 - 08:35 0.58 DRILL P PROD1 Drill to 12721' with 70R TF, 2.7/2.7bpm, 3450/4000psi & 28fph ave ROP. Stacking @ the base of DFS. 08:35 - 08:50 0.25 DRILL P PROD1 Short 100' wiper. 08:50 - 09:20 0.50 DRILL P PROD1 Drill to 12751' with 70R TF, 2.7/2.7bpm, 3450/3950psi & 60fph ave ROP. Drilling better since back into BB2. 09:20 - 10:05 0.75 DRILL P PROD1 Wiper trip clean to window. RBIH to 12,751' 10:05 - 10:15 0.17 DRILL P PROD1 Orient TF to 90R. 10:15-10:35 0.33 DRILL P PROD1 Drill to 12765' with 90-110R TF, 2.7/2.7bpm, 3450/3850psi & 45fph ave ROP. Need to drill LS to get out of the BB2/DFS interface. 10:35 - 10:45 0.17 DRILL P PROD1 Orient TF to 170L. 10:45 - 11 :50 1.08 DRILL P PROD1 Drill to 12772'. Short 100' wiper & drill on to 12788' with -ve wt, +/-175R TF, 2.7/2.7bpm, 3350/3750psi & 35fph ave ROP. 11:50-12:15 0.42 DRILL P PROD1 Orient TF around to 95R. 12:15-12:40 0.42 DRILL P PROD1 Drill to 12797' with +/-90R TF, 2.7/2.7bpm, 3450/3750psi & 30fph ave ROP. Not getting enough drop in inclination. Printed: 5/5/2003 11:28:36 AM ) ) Page·7öf 15 Oipérations SUl11maryRøport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-62 NK-62 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/14/2003 Rig Release: 4/29/2003 Rig Number: Spud Date: 1/3/1998 End: 4/29/2003 Date From-To Hours Task Code NPT Phase Description of Operations 4/20/2003 12:40 - 12:50 0.17 DRILL P PROD1 Orient TF to 160L. PVT = 310bbls. 12:50 - 13:17 0.45 DRILL P PROD1 Drill to 12815' with +/-160R TF, 2.7/2.7bpm, 3450/3800psi & 55fph ave ROP. 13:17 -13:40 0.38 DRILL P PROD1 Short 85' wiper, (length of the BHA) to agitate cuttings and improve weight transfer. 13:40 - 15:20 1.67 DRILL P PROD1 Drill to 12,830' with LS TF. Slow drilling with stacking and difficulty dropping angle below 89deg to get out of DFS siltstone. Pick up numerous times, craming weight to hold the toolface force the drop rate. Add 30bbls of new and 25bbls of a 60bbllubtex pill to the active system, (60bbls of 9.8ppg, 70kLSRV Flo-Pro w/ 8% L T, 8% FB & 6ppb KG) to help with WT transfer. 15:20 - 16:50 1.50 DRILL P PROD1 Drill DFS siltstone to 12,879 with LS TF, 2.6/2.6bpm, 3400/3800psi at 20fph avg ROP. Cannot hold a LS toolface to break through into the BB2 sand. Most likely bouncing off a hard Siderite streak at thè base of the DFS. Low angle of incidence, bi-center bit and 1.04deg motor angle are factors. Talk with town and decide to swap BHA. 16:50 - 19:20 2.50 DRILL P PROD1 POOH for BHA 19:20 - 20:00 0.67 DRILL P PROD1 LD drilling BHA. Notice well flowing and 5 bbl pit gain ~ 20:00 - 20:30 0.50 DRILL N DPRB PROD1 SI at swab, then line up to choke. Open SWab to 200 psi and rising. Cuss 'n discuss.. Download resistivity data. Repair injector traction cylinder 20:30 - 21 :30 1.00 DRILL N PROD1 275 psi WHP. LD drilling resistivity tool and MWD package using mousehole 21 :30 - 22:00 0.50 DRILL N PROD1 280 psi WHP Safety mtg re: circ kill ops 22:00 - 22:20 0.33 DRILL N PROD1 275 psi WHP SI swab, bleed off press. MU cement nozzle assy 22:20 - 00:00 1.67 DRILL N PROD1 RIH w/ BHA #7 circ 0.5/1240 holding 500 psi BP. Notify Slope AOGCC of influx 4/21/2003 00:00 - 00:50 0.83 DRILL N DPRB PROD1 Continue RIH circ 0.5/1400 holding 500 psi BP. RIH thru window, clean. RIH to TO, clean and tagged at 12885' CTD. PVT 332 PUH 45k 00:50 - 01 :25 0.58 DRILL N DPRB PROD1 POOH 30'/min while circ out influx 2.5/2650 w/ 500 psi BP. Divert returns to flowback tank when density at 9.7 ppg and becoming crude cut 01 :25 - 02:35 1.17 DRILL N DPRB PROD1 PUH thru window, clean and park at 11800'. Circ out influx (crude cut mud). CBU again 02:35 - 03:50 1.25 DRILL N DPRB PROD1 SO pump operations and SI at choke. Monitor WHP while wo KWM from MI mud plant. After 60 min WHP stabilized at 190 psi. Res press at 9360' TVD is 4960 psi (10.2 EMW) 03:50 - 05:10 1.33 DRILL N DPRB PROD1 RIH from 11800' while circ 10.8 ppg NaCI/Br 2.2/2200 to nozzle holding 500 psi BP and taking returns to flowback tank. RIH to TO. Displace OH to new mud while POOH 2.5/2360, (3%L T, 1.5%FL & 6ppb KG) 05:10 - 06:05 0.92 DRILL N DPRB PROD1 Park at 10000' and circ 2.5/2500 while look for clean returns and wait on second vac truck for volume to POOH 06:05 - 08:00 1.92 DRILL N DPRB PROD1 POOH w/ nozzle BHA. Will swap back to primary MHA & inspect/rebuild back-up because of high chloride mud environment. 08:00 - 08:15 0.25 DRILL P PROD1 PJSM prior to breaking nozzle & making drilling BHA. Discussed pit level monitoring, lifting, pinch points, make up torques & watching out for one another. Printed: 5/5/2003 11 :28:36 AM ) ) OpE:}rCltionsSlImmary Report Page 8 of15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-62 N K-62 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date · From-To Hours Task Code NPT Phase 4/21/2003 08:15 - 09:15 1.00 DRILL P PROD1 09:15 - 11 :30 2.25 DRILL P PROD1 11 :30 - 11 :45 0.25 DRILL P PROD1 11 :45 - 13:00 1.25 DRILL P PROD1 13:00 - 13:55 0.92 DRILL P PROD1 13:55 - 14:05 0.17 DRILL P PROD1 14:05 - 14:40 0.58 DRILL P PROD1 14:40 - 14:55 0.25 DRILL P PROD1 14:55 - 16:00 1.08 DRILL P PROD1 16:00 - 16:15 0.25 DRILL P PROD1 16:15 - 17:15 1.00 DRILL P PROD1 17:15 - 18:25 1.17 DRILL P PROD1 18:25 - 18:55 0.50 DRILL P PROD1 18:55 -19:30 0.58 DRILL P PROD1 19:30 - 20:00 0.50 DRILL N DPRB PROD1 20:00 - 20:45 0.75 DRILL N DPRB PROD1 20:45 - 22:35 1.83 DRILL P PROD1 22:35 - 23:25 0.83 DRILL P PROD1 23:25 - 00:00 0.58 DRILL P PROD1 4/22/2003 00:00 - 01 :25 1.42 DRILL P PROD1 01 :25 - 02:00 0.58 DRILL P PROD1 02:00 - 02:45 0.75 DRILL P PROD1 02:45 - 03:35 0.83 DRILL P PROD1 03:35 - 04:00 0.42 DRILL P PROD1 04:00 - 04:30 0.50 DRILL P PROD1 04:30 - 04:45 0.25 DRILL P PROD1 04:45 - 05:25 0.67 DRILL P PROD1 05:25 - 05:45 0.33 DRILL P PROD1 05:45 - 06:30 0.75 DRILL P PROD1 06:30 - 08:00 1.50 DRILL P PROD1 Start: 4/14/2003 Rig Release: 4/29/2003 Rig Number: Spud Date: 1/3/1998 End: 4/29/2003 Description of Operations Stand back injector. Lay down nozzle BHA. Pick up Re-built M09, same motor, new directional, same pulser, GR & orientator. New MHA. RIH wI lateral MWD BHA #8. Test pulser at 1040' and MWD I orientator at 3650'. OK. RIH to 11,850' PU to tie into RA tag at 11,850'. Make -14' correction RIH to TO at 12,879'. PU to GR log the interval, 12,860- 12,789 originally occupied by Res. Drilling, LS TF, 2.5 I 2.5bpm, 3800/4050ps. Plan is to drop inclination to <85deg and drill into the sand below. Drill to 12,926'. Inclination is 84.4deg. Orientate around to highside Drill fl 12,926' to 12,942', 2.5/4050/10-30L Inclination being held at 84deg. Orientate around to 90L Drill fl 12,942' to 12,989', 2.5/4100/85-98L Inclination building back above 85deg. At -9267' tvdss. Geo predicting re-entering the BB2 sand at -9270' tvdss Orientate around to 100L Drill fl 12,989' to 13,033', 2.5/4100/110L. Good indications of exiting the DFS at 13,000', (-9270' tvdss) - GR & drilling break. Calculated DFS dip angle is 1.4deg. Plan to land 5-7' below the DFS and hold inclination at 88.6deg in the next 50'. Wiper to window at 11,850' Drill from 13033' 2.3/3300/1 L Drill to 13071' (9275' TVD) and project 87 deg at bit Wiper to window PVT 248 Park at 11800' PVT 241 Circ 1.5/1.511950. Divert flow thru choke and zero press gauges Safety mtg re: breathing test SO pump, bleed off CTP and get stable PVT at 243 bbls Monitor well for flow for 45 min and none POOH for motor bend OOH. PVT 170. Change motor and bit. Stable FL @ 30' RIH wI BHA #9 (1.04 deg motor) Continue RIH wI BHA #9 RIH thru window, clean PVT 238. Precautionary ream to TO. Tag TO at 13088' and corr to 13071' 2.3/3400/59R PVT 246 Orient to left Drill from 13071' 2.3/3350/80L PVT 244 Drill to 13109' with slow penetration, stacking. Angle is in a slow drop from max 88.7 deg. GR started showing shale at 13080'. The dip must be more than expected, or the sand has pinched out Orient around to drill back down out of shale Drill from 13109' 2.3/3400/140L PVT 241 Drill to 13126' (9277' TVD) while stacking and drilling wI neg wt. Angle at bit is 86 deg Have trouble getting back to btm and starting to overpull. GR showing up to 150 api Wiper to window while circ up sample (Kingyak) PVT 240 Log tie-in up from 11890', no corr 2.3/3400/78L PVT 231 RIH to 13110' and stack wt. PUH 5k over PVT 236 Wiper to window, conditioning hole. Tie in to RA marker on WS Printed: 5/5/2003 1128:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) Page 90f 15 Operations Sumn'laryReport. NK-62 NK-62 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/14/2003 Rig Release: 4/29/2003 Rig Number: Spud Date: 1/3/1998 End: 4/29/2003 Date From ~To HoUrs Task Code NPT Phase Description of Operations 4/22/2003 06:30 - 08:00 1.50 DRILL P PROD1 at 11,850'. Park at 11,720' in the 7" liner. 08:00 - 15:00 7.00 DRILL N WAIT PROD1 Continue to monitor pit level for flow while waiting on the decision to run liner or sidetrack. If sidetrack, need to plug the holes in the DFS shale to isolate the upper GFSSB from the lower BB2 sands. 15:00 - 17:15 2.25 DRILL N WAIT PROD1 POOH with BHA #9. Overpull & pack-off upon pulling through the tailpipe nipple at 11,637'. Work pipe & pop through. 17:15-18:00 0.75 DRILL N PROD1 LD drilling BHA 18:00 - 19:20 1.33 STKOH X WAIT PROD1 WO WII WS assy 19:20 - 19:30 0.17 STKOH C PROD1 Safety mtg re: handle WS assy 19:30 - 20:20 0.83 STKOH C PROD1 Load WS assy into pipeshed. MU WS assy 20:20 - 22:15 1.92 STKOH C PROD1 RIH wI BHA #10 (Weatherford 3.5" OH whipstock) PVT 147 22: 15 - 22:20 0.08 STKOH C PROD1 Corr -15' (average of last two runs) at 11815' PVT 218 RIH thru window, clean. RIH in OH at 33'/min 22:20 - 22:40 0.33 STKOH X DPRB PROD1 Set down at 11920' (btm of tool). PU clean at 48k. Work to get past 5 times and steadily losing ground. Last set down at 11870'. PUH thru window, clean. Cuss 'n discuss. DLS is only 30 deg. A 2' high-GR shale is at 11903' 22:40 - 00:00 1.33 STKOH X PROD1 POOH circ down CT at reduced rate 0.8/1000 and pulling speed due to 3.5" 00 tool and acting like packed off. Mini overpulls at 11647', 9900', 7890' 4/23/2003 00:00 - 00:45 0.75 STKOH X DFAL PROD1 Continue POOH wI WS assy 00:45 - 01 :05 0.33 STKOH X DFAL PROD1 LD WS assy PVT 145 Slips were in open position (rubber retaining rings had parted and 2 of 4 set screws had sheared) and had clay and 1/2" DFS shale wedged behind them. Slip grooves were packed with clay. Assume slips caught on a ledge at first set down and opened which is the reason we lost ground on later attempts 01 :05 - 01 :45 0.67 STKOH X DFAL PROD1 MU drilling BHA 01 :45 - 03:50 2.08 STKOH X DFAL PROD1 RIH wI BHA #11 (1.04 deg motor, OS 49 bit) to clean out fill 03:50 - 04:15 0.42 STKOH X DFAL PROD1 Log up from 11900' 2.4/3500/135L PVT 216 Corr -10' 04:15 - 05:15 1.00 STKOH X DFAL PROD1 Ream high DLS area 11870-12100'. RIH 25'/min 2.413550/111 L-64L to 12100' wI no motor work. Orient to 108R and backream 25-30'/min to 11870', then ream 25-30'/min to 12100'. Get 3 clicks and repeat at 158R, then 143L. No motor work, competent formation 05:15 - 05:50 0.58 STKOH X DFAL PROD1 RIH from 12100' and precautionary ream (w/LS TF) to 13050', clean PVT 222 05:50 - 06:25 0.58 STKOH X DFAL PROD1 Get two clicks. Wiper OOH 35'/min 2.413400 06:25 - 06:40 0.25 STKOH X DFAL PROD1 Log tie-in up from 11880' 2.3/3430/146R, corr +3'. Flag CT at 11800' EOP PVT 212 06:40 - 08:30 1.83 STKOH X DFAL PROD1 POOH. No weight bobbles thru tailpipe. clean to surface. 08:30 - 08:45 0.25 STKOH X DFAL PROD1 LD drilling BHA. PVT 144 08:45 - 10:00 1.25 STKOH X DFAL PROD1 Waiting on replacement anchor assy for W'ford's OH WS to be checked & delivered. Incorrect placement of the brass shear screws in the lower shear screw groove resulted in the partial first run set. 10:00 -11:00 1.00 STKOH X DFAL PROD1 MU WS assy. Re-run only setting sleeve & diverter sub. Drop out circ sub & NRJ's on from new MHA. 11:00 -13:00 2.00 STKOH X DFAL PROD1 RIH wI BHA #12 (3.5" OH whipstock) to 11,920'. Corr -14ft at the window flag. 100fUmin in cased hole I 40fUmin in OH. 13:00 - 14:00 1.00 STKOH C PROD1 RIH to 12906' and sat down, (TOW = 12,890'). Make 8 attempts, picking up 20' @ RIH at 15-100'/min speed to break Printed: 5/5/2003 112836 AM ') ') Page 10 of 15 Operations Summary..RépO.rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-62 NK-62 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/14/2003 Rig Release: 4/29/2003 Rig Number: Spud Date: 1/3/1998 End: 4/29/2003 Date From -'To Hours Task Code NPT Phase Description ofOpèrations 4/23/2003 13:00 - 14:00 1.00 STKOH C PROD1 through and onto the desired 13,015' TOW setting depth. Talk with Town. PVT = 218 14:00 - 15:00 1.00 STKOH C PROD1 Pick up to 12,735', (TOW=12,720'). Drop 5/8" steel ball. Pump @ 2.4bpm/2690psi for 45bbls then cut back to 1.4bpm/1650psi. Ball on seat at 51 bbls. Pressure up to 4200psi to stroke rod and initiate set. At 3000psi pick up slightly for a +20klbs weight at set. See the coil pressure fall at shear off. Set 6klbs down to confirm set. Pick up setting assy clean out of WS. 15:00 - 17:15 2.25 STKOH C PROD1 POOH wi WS setting assy. 17:15 -18:00 0.75 STKOH C PROD1 LD WS setting BHA, WS set confirmed. MU drilling BHA. PVT=140 18:00 - 20:00 2.00 STKOH C PROD1 RIH wi BHA #13 (1.69 deg motor, old style M09 bit) to sidetrack higside-Ieft off of OH whipstock @ 12,720' 20:00 - 20:40 0.67 STKOH C PROD1 Log tie-in up from 11900' 2.3/3350/171 R PVT 207 Corr -17.5' 20:40 - 21:15 0.58 STKOH C PROD1 Precautionary ream to WS. Tag WS at min rate at 12721'. PUH 43k and chk TF at 10L. RIH slow and first motor worklstall at 12720.6'. PUH 43k PVT 212 21 :15 - 23:00 1.75 STKOH C PROD1 Begin time drilling from 12719.8' 0.1'/30 min after 3 stalls at 12720.2' 2.3/3360/1 OL 24.6k 23:00 - 00:00 1.00 STKOH C PROD1 12720.3' 4/24/2003 00:00 - 01 :30 1.50 STKOH C PROD1 Continue time drill at 12720.3' to get off OH WS. Slide is okay, but square shoulder on bit catches WS and stalls motor when injector brake is released too long (milliseconds). 'Two' pulls or not to pull. . . 01 :30 - 02:30 1.00 STKOH C PROD1 12720.5' 2.3/3300/10L PVT 197 Probably off, but two more stalls at this depth 02:30 - 03:30 1.00 STKOH C PROD1 12720.6' 2.3/3300/10L PVT 191 (bypass shaker screens due to mud loss-screens plugging due to Flovis additions) 03:30 - 03:45 0.25 STKOH C PROD1 12720.8' 2.5/3770/1 OL PVT 190 Stall when got greedy 03:45 - 04:35 0.83 STKOH C PROD1 12721.0' Ditto 04:35 - 04:55 0.33 STKOH C PROD1 12721.4' Stall Could only get back to 12721.0' and stall 2.5/3850/13L PVT 190 04:55 - 05:15 0.33 STKOH X DPRB PROD1 Wiper to window 05:15 - 07:10 1.92 STKOH X DPRB PROD1 Flag at 11800' EOP. POOH for bit and motor 07:10 - 08:00 0.83 STKOH X DPRB PROD1 LD drilling BHA. M09 bit badly balled up. Shale/siltstone wi aluminum cuttings packing the junk slots & 1 of 3 jets plugged w/ 2 large aluminum chunks. PVT = 115 08:00 - 10:30 2.50 STKOH X DPRB PROD1 Deliberate on what bit to use to sidetrack off of OH WS into the DFS siltstone. Wait while various bits are delivered to location. Since we have a stalling problem, a parabolic bit with small cutters is desired. Decide to PU a HC STR335 wi 6 blades, 8mm cutters & 4 x 12/32 jets. Will run on 1.37deg short radius motor for 22deg/1 OOft DLS. 10:30-11:00 0.50 STKOH X DPRB PROD1 MU drilling BHA 11 :00 - 13:25 2.42 STKOH X DPRB PROD1 RIH wi BHA #14 (1.37deg SR motor, rebuilt STR335 bit) to re-attempt a highside- left, sidetrack off of WS @ 12,721'. Tie into flag at 11,800. Corr -19'. PVT = 188 13:25 - 13:30 0.08 STKOH C PROD1 Stop at 12,690'. RIH and tag WS @ 12,719'. PU & orientate around for a HS TF. 13:30 - 14:10 0.67 STKOH C PROD1 Try to ease into milling at 12719.7, 0.1'/30min. Looked good initially at 2.4/3400/3600. 9 to 21 L reactive 2-3klbs down. Took 7 stalls in a row, PU each time & easing back down. Ease off Printed: 5/5/2003 11 :28:36 AM ') " Page 11 of 15 Operatlons Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-62 NK-62 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From -To Hours Task Code NPT Phase 4/24/2003 13:30-14:10 0.67 STKOH C 14:10 -15:35 1.42 STKOH C 15:35 - 15:45 0.17 STKOH C 15:45 - 16:30 0.75 STKOH C PROD1 PROD1 PROD1 PROD1 16:30 - 17:10 0.67 STKOH C 17:10 - 19:35 2.42 STKOH C 19:35 - 20:00 0.42 STKOH C 20:00-21:15 1.25 STKOH C 21 :15 - 22:25 1.17 STKOH C 22:25 - 00:00 1.58 STKOH C 4/25/2003 00:00 - 00:25 0.42 DRILL C 00:25 - 00:55 0.50 DRILL C 00:55 - 01 :20 0.42 DRILL C 01 :20 - 02:30 1.17 DRILL C PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 02:30 - 05:05 2.58 DRILL C PROD1 05:05 - 05:35 0.50 DRILL C PROD1 05:35 - 05:55 0.33 DRILL C PROD1 05:55 - 06:15 0.33 DRILL C PROD1 06: 15 - 06:20 0.08 DRILL C PROD1 06:20 - 06:35 0.25 DRILL C PROD1 06:35 - 07:10 0.58 DRILL C PROD1 07:10 - 07:50 0.67 DRILL C PROD1 07:50 - 08: 1 0 0.33 DRILL PROD1 08:10 - 08:20 0.17 DRILL C PROD1 08:20 - 08:50 0.50 DRILL C PROD1 08:50 - 09:20 0.50 DRILL C PROD1 09:20 - 10:50 1.50 DRILL C PROD1 10:50 - 11 :00 0.17 DRILL PROD1 11 :00 - 12:00 1.00 DRILL C PROD1 12:00-12:15 0.25 DRILL C PROD1 12:15 -12:20 0.08 DRILL C PROD1 12:20 - 12:50 0.50 DRILL C PROD1 12:50 -13:10 0.33 DRILL C PROD1 13:10 - 15:25 2.25 DRILL C PROD1 15:25 - 17:00 1.58 DRILL C PROD1 Start: 4/14/2003 Rig Release: 4/29/2003 Rig Number: Spud Date: 1/3/1998 End: 4/29/2003 Descri ption öf Operations the stacked wt & aim for 200psi of steady motor work. Appear to have milled off WS. 2.4/3400/3700, 24L, 2klbs down. Drilled 16' to 12,735 with 1stall. PU 10' to orient 1 click to HS. Drill ahead to 12,760' 2.4/3400/3800 20L built to 89.8deg. DLS only 15 v's 20 predicted, but are building faster & turn away from old wellbore. PVT = 182. Drill to 12791'. Projected Inc at bit = 96deg. POOH with sidetrack drilling BHA LD sidetrack BHA PVT 100 MU drilling BHA wi resistivity. Upload res tool Cut off 6' CT. Install new CTC. PT 40k, 3800 psi. Install new packoff RIH wi BHA #15 (1.04 deg motor, OS 49) Continue RIH wi BHA #15 Log tie-in up from 11920' 2.4/3620/75R PVT 171 Corr -7.5' RIH to 12715' Loglream down 1.2'/min from 12715' 2.3/3570/45L to catch resistivity data and ream by WS. Saw it at 12720.5' wi 500 psi motor work, but had stall at 12731.3'. Continue log in hole, clean Tag at TO at 12792' Get one click and drill 35-45'/hr 2.4/3720/86L maintaining 95 deg 47k,23k PVT 169 See 50 api sand by 12805'. Drill to 12910' and stacking wi minor overpulls Wiper to window PVT 160 15k overpull at 12813' RBIH Orient around from 120R to left side to go thru OH sidetrack area. Set down at 100L. Ream by at 4'/min at 45L and no motor work RIH to TO 2.3/3400 and plugged off 'out' MM PU & orient from 162R to left side Drill ahead to 12954', 2.4/3750/4000 75L. Stacking weight Attempt to improve wt transfer with 2 x wiper trips to just below the OH WS @ 12,720' Orient around to 60L Drill ahead to 12988', 2.4/3750/4000 75L Stacking wt. Make 200' wiper trip Drill ahead to 13020', 2.4/3750/4000 65L. Send 1 OObbls of new 10.8 Flo-Pro straight downhole, (8% L T, 8% FL & 6ppg KG) Wiper trip to the window while circulating the new mud around the bit. Orient around to the right in order to stay within the poly. Drill ahead to 13065', 2.4/3750/4000 70R. Inclination being held 97-98deg. Begin stacking weight again. Geo checks btm's up sample for HRZ - none present. Make a 200' wiper trip Attempt to drill ahead. Make 2', stack weight - no motor work. PVT=265 Wipe hole clean back to 12,800' Attempt to drill ahead, but just stack weight. POOH Lay down entire BHA. Download Res & MWD memory data. Printed: 5/5/2003 11 :28:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 4/25/2003 4/26/2003 ) ) Operati()I1~Sumr\nary Repo.rt Page 12of15 NK-62 NK-62 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/14/2003 Rig Release: 4/29/2003 Rig Number: Spud Date: 1/3/1998 End: 4/29/2003 From- To Hours Task Code NPT . Phase Descri ptiOn. of Operations 17:00 - 22:30 5.50 BOPSUR C PROD1 Function & pressure test BOPE. AOGCC test witness waived by Chuch Scheve. 22:30 - 23:15 0.75 DRILL C PROD1 Install Baker CTC (slip type). PT 40k, 3500 psi. PT inner reel valve 23:15 - 00:00 0.75 CEMT C COMP Load CT wiper dart. Circ to catcher w/ mud 2.5/2420 and hit at calc displ of 55.1 bbls. Retrieve dart. RD assy 00:00 - 00:50 0.83 DRILL C PROD1 MU MWD drilling BHA w/o res w/ Andergauge agitator tool. Use 14 jet in bleed sub 00:50 - 02:45 1.92 DRILL C PROD1 RIH w/ BHA #16 (1.04 deg motor), SHT (orientor too) PVT 189 02:45 - 03:10 0.42 DRILL C PROD1 Log tie-in up from 11900' 2.3/3800/22L PVT 254 Corr -13.5' 03:10 - 03:30 0.33 DRILL C PROD1 RIH 03:30 - 03:50 0.33 DRILL C PROD1 Orient from 116L to 48L to pass OH WS and ream by w/ no motor work 03:50 - 04:10 0.33 DRILL C PROD1 Log GR at 90'/hr from 13040' bit depth while ream to TO 2.3/3750/37R Tag TO at 13067' 04: 10 - 04:25 0.25 DRILL C PROD1 Orient 04:25 - 05:30 1.08 DRILL C PROD1 Drill from 13067' 2.3/3800/90R w/ 300 diff to 13127' GR is trending up from avg 60-70 api to 90 api. Wt transfer is good for avg incl of 98 deg 05:30 - 06:30 1.00 DRILL C PROD1 Wiper to circ up samples. PVT 259 It wasn't planned, but this is the exact depth of PB1 " RBIH 06:30 - 06:45 0.25 DRILL C PROD1 25' off of btm, orient around to 22R 06:45 - 07:10 0.42 DRILL C PROD1 Drill 20' more to 13146', (-9212') and circulate up a sample 07: 1 0 - 08:20 1.17 DRILL C PROD1 Wiper back @ 5ft/min while waiting on btms up sample 08:20 - 09: 15 0.92 DRILL C PROD1 Wait on decision from town to drill ahead or call TO. No evidence of HRZ. Appear to be drilling into rattier sands. Will TO here. 13,146'md, (-9212' tvdss) 09:15 - 09:50 0.58 DRILL P PROD1 Wiper to window. 09:50 - 10:00 0.17 DRILL P PROD1 Tie into RA tag at WS. Corr +3ft. 10:00 - 10:45 0.75 DRILL P PROD1 RIH to tag bottom. Official TD is 13,149'md 10:45 -13:15 2.50 DRILL P PROD1 POOH for liner. Flag CT at 11,600 EOP for running liner & 10,300' to identify window. 13:15 -14:50 1.58 DRILL P PROD1 Lay down drilling BHA 14:50 - 15:00 0.17 CASE P COMP Safety meeting proir to running liner. Discuss kick potential, liner tally, MU torque, handling safety 15:00 -16:15 1.25 CASE P COMP Make up 2-7/8" STL x 3-3/16" liner as per procedure. Stopped at x-over to fill liner with rig water. 16:15 -17:10 0.92 CASE P COMP Continue MU liner as per procedure 17:10 - 17:30 0.33 CASE P COMP MU BOT CTLRT, PU injector. MU BOT CTC. Pull test to 35klbs, Pressure test to 3500psi, MU CTC to top of CTLRT-DISC-XO 17:30 - 19:20 1.83 CASE P COMP RIH w/ liner string on CT 19:20 - 19:45 0.42 CASE P COMP See flag at 11850.6' (-16') did not corr 49k, 23k RIH thru window. One set down at 12785'. RIH to TD at 13157' CTD. Recip 40' at 55k and retag at 13157'. PUH to ball drop at 13133' 19:45 - 20:20 0.58 CASE P COMP Load 5/8" steel ball. Set liner at TO. Circ to seat w/ mud 1.6/2360, 2.6/3370, 0.8/1780 20:20 - 21 :05 0.75 CASE P COMP Ball seat sheared at 3800 psi. PUH 32k, released from liner. Circ mud 2.3/2880 w/ full returns while fin RU OS cementers PVT 243 Safety mtg re: cmtlbrine 21 :05 - 21:45 0.67 CEMT P COMP Swap to 10.8 NaCIIBr brine 2.4/2930 while cementers batch Printed 5/5/2003 1128:36 AM ') ) Page 13 of 15 Operations SurnmaryRøþort Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-62 NK-62 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/14/2003 Rig Release: 4/29/2003 Rig Number: Spud Date: 1/3/1998 End: 4/29/2003 Date From ..~ To Hours Task Code· NPT Phase Descri ptiOh . of Operations 4/26/2003 21 :05 - 21 :45 0.67 CEMT P COMP up. Fin pump 100 bbls wI full returns. Cmt to wt at 2130 hrs 21:45 - 22:15 0.50 CEMT P COMP PT OS @ 3500 psi. Load CT w/19 bbls 15.8 ppg 'G' cement wI expansivellatex properties 1.9/2200 22:15 - 23:00 0.75 CEMT P COMP Launch wiper dart w/1 000 psi and check. Displace wI mud 2.4/2500, 2.8/3220 wI full returns. Slow rate to 1.5 bpm, but did not see press increase when wiper dart should have latched LWP. Displace calc liner volume of 9.3 bbls to latch collar (past known 55.1 bbls CT volume) and did not pressure up. SO pump. Chk floats, ok. PUH 46k 20' which seems heavy, and can't pump or will over displace. RBIH 3 times worrying we still have liner PVT 301 CIP 2300 hrs, 4:20 TT 23:00 - 00:00 1.00 CEMT P COMP POOH at normal speed at 44k wI no turbo overpulls, so must have left it on btm. Circ used mud wI 0.5 bpm returns while POOH to minimize ECD's and to mix mud wI brine 4/27/2003 00:00 - 01 :05 1.08 CEMT P COMP While POOH at 7300', mud pump tripped at 500 psi over circ press. Assume dart is in CTLRT. Fill from BS while POOH. Based on 120.4 bbls pumped when tripped, this would have put wiper dart at surface during displacement (55.1 CT vol + 9.34 liner vol + 55.1 CT vol=119.5 bbls). Assume dart hung up in surface plumbing and was launched right after starting to move CT when POOH-pretty straight fluid path for this reel tho. . . 01 :05 - 02:00 0.92 CEMT P COMP LD CTLRT. PVT 234 Recover wiper dart, LWP and ball. Wiper dart fins had fluid wear. Load out tools 02:00 - 03:00 1.00 EVAL P COMP Load CNL tools to floor. RU to run CSH 03:00 - 03: 15 0.25 EVAL P COMP Safety mtg re: source/CSH 03:15 - 05:25 2.17 EVAL P COMP MU 2.30" 0331,2.125" motor, CNL carrier, MHA MU 50 new CSH singles and drift to 1.18" 05:25 - 06:55 1.50 EVAL P COMP RIH wI BHA #18 to 11,500' 06:55 - 07:55 1.00 EVAL P COMP Log down @ 30ftlmin wI mem CNL wI 1420psi/0.5bpm pump rate. Tag at 13,124' CTD 07:55 - 08:20 0.42 EVAL P COMP Log up @ 60ftlmin wI 750psi/0.5bpm to 11,500' 08:20 - 09:20 1.00 EVAL P COMP RIH at 70fph, Drop 5/8" ball to open circ sub. SWS discourage pumping @ 1.5bpm for anymore than 5min to prevent tool damage. Chase with a 6.5bbl viscosified 10.8 NaCl/Br perf pill. Circulate to bit @ 2600psi/1.4bpm. 09:20 - 09:40 0.33 EVAL P COMP 5/8" ball on seat and circ sub shears out @ 3800psi. Lay in perf pill 1: 1 POOH at 60'/min 09:40 - 10:15 0.58 EVAL P COMP At 11,500' pump rate 2200psi/2bpm to drive out contaminate cmt. Worst of it diverted off the screens to the green tank. 10:15 -11:25 1.17 EVAL P COMP POOH with SWS memory log 11 :25 - 13:35 2.17 EVAL P COMP LD 14 jts of CSH. Stand remaining 36 jts back as doubles. 13:35 - 13:50 0.25 EVAL P COMP PJSM prior to bringing the RA source in the CNL tool to surface. All non essential personel to be off the floor until source is in transportation pod. 13:50 - 14:05 0.25 EVAL P COMP LD SWS mem tool and cleanout BHA. 14:05 - 17:40 3.58 EVAL P COMP Wait on cement comp strength to reach 2kpsi. Bring SWS perf guns into the pipe shed. 17:40 - 18:00 0.33 EVAL P COMP Liner lap to 2kpsi failed with 10.8 ppg fluid. Built to 1900psi wI 23spm (0.5 bpm) pump rate before sudden break down. At pump rate 1000psi being maintained. 18:00 - 19:45 1.75 EVAL N DFAL COMP Discuss wI asset. WO BOT seal assy to test liner lap 19:45 - 20:35 0.83 EVAL N COMP Load seal assy into pipeshed. MU BHA 20:35 - 22:30 1.92 EVAL N COMP RIH wI BHA #19 Printed: 51512003 11 :28:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ') ) Page 14of15 Operations SummaryR~port NK-62 NK-62 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/14/2003 Rig Release: 4/29/2003 Rig Number: Spud Date: 1/3/1998 End: 4/29/2003 Date· From -To Houts Task Code NPT ' Phase Description of Operations 4/27/2003 22:30 - 23:15 0.75 EVAL N COMP Pump at min rate and see seals sting in and press incr on CT at 11641' CTD. Stack 10k on no-go. PVT 241 Initial press WHP 0, CTP 670, IA -20. Pressure BS to 2000 psi wI 0.8 bbls and stabilized at 1855 psi after SI pump valves. After 5 min WHP had bled to 1810 psi while CTP bled to 340 psi. No change to IA. Bleed off all press to zero. Press CT (and liner) to 2000 psi wI 0.6 bbls and broke down at 1900 psi-SO pump. WHP 0, IA -20. CTP bled to 900 psi in 1 min Repressure BS to 2500 psi wI 0.8 bbls. SI at 2310 psi wI 800 psi CTP. After 5 min WHP 2210 and CTP 355. After 10 min WHP 2160 psi and CTP 33. After 15 min WHP 2160 and CTP 30. No change to IA and verify on vac Determine liner lap is good, assume wet shoe on liner. Used 10.8 ppg fluid during all pressure tests 23: 15 - 00:00 0.75 EVAL N COMP Unsting 52k. PVT 241 POOH 45k 4/28/2003 00:00 - 01 :20 1.33 EVAL N DFAL COMP Continue POOH wI sealassy 01 :20 - 01 :35 0.25 EVAL N COMP LD seal assy 01 :35 - 01 :50 0.25 PERF P COMP RU to run perf guns 01 :50 - 02:05 0.25 PERF P COMP Safety mtg re: perf guns/CSH 02:05 - 03:10 1.08 PERF P COMP MU 5 perf guns, firing head, MHA PU 10 CSH singles Kick drill, discuss MU 18 stds CSH, MHA 03:10 - 05:25 2.25 PERF P COMP RIH wI BHA #20 05:25 - 06:15 0.83 PERF P COMP Tag PBD at 13138' CTD and verify twice. Corr to 13113'. PUH 52k and park at perf depth. Pump 10 bbls fresh 10.8 ppg hi-vis Flo Pro mud 1.5/2000. PUH to ball drop. Load 5/8" aluminum ball. Displace with 4 bbls fresh mud while RIH to set depth. Displace ball to seat 2.2/3000 PVT 228. Red rate at 48 bbls 1.1/1650 (higher rate than normal due to 98 deg and checks). At 53 bbls, lost 300 psi CTP and gained 3k wt. Also, returns decreased to 0.5 bpm. Assume guns fired. Pump until calc displ and no further press incr. Lost 1 bbl-PVT 227 06:15 - 08:30 2.25 PERF P COMP POH wI perf guns. Flag at 11000' EOP. Fill from BS 08:30 - 10:30 2.00 PERF P COMP LD 10 CSH joints. Break for safety meeting on spent perf gun handling. Verify guns have fired. PERF INTERVAL 12970 - 13060 (90' total) LD the 5 gun joints. 10:30 - 11 :55 1.42 PERF P COMP MU 23 perf guns, firing head, MHA. MU 18stds CSH, (torque checked two unbroken joints since we have logged and perforated with the string) & MHA. 11:55-13:30 1.58 PERF P COMP RIH wI BHA #21 13:55 - 14:20 0.42 PERF P COMP Tie into EOP flag @ 11,000' CTD. Corr = -19'. RIH to 12602'. Pump 11 bbls fresh 10.8 ppg hi-vis Flo Pro mud 1.4/1640. PU to 12,579' w/47klbs and park at perf depth. Load 5/8" aluminum ball. Displace with remaining 18bbls of fresh mud & RIH to set depth. Displace ball to seat 2.4/2900. Red rate at 45 bbls 0.6/1150. At 53.6 bbls, ball on seat. Watch P build to 3800psi & the guns go with a good coil jolt at surface lost 250 psi CTP and gained 3k wt. 14:20 - 16:45 2.42 PERF P COMP POH wI perf guns, displacing 18bbl pill from coil, 0.9/1000. Printed 5/5/2003 11 :28:36 AM ') ') Page 15 of15 Operations SumrnaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-62 NK-62 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/14/2003 Rig Release: 4/29/2003 Rig Number: Spud Date: 1/3/1998 End: 4/29/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/28/2003 14:20 - 16:45 2.42 PERF P COMP PVT = 160 16:45 - 17:45 1.00 PERF P COMP LD the 36 jts of CSH. 17:45 - 18:30 0.75 PERF P COMP PJSM with the oncoming crew on the hazards associated with and the handling of spent perf guns. 18:30 - 19:45 1.25 PERF P COMP LD the 23 perf gun joints. All guns fired. PERF INTERVALS 12050 - 12310 : 12330 - 12450 (380' total) Load out guns. 19:45-20:15 0.50 STIM P COMP MU sidejet nozzle assy. Stab onto well. PT packoff against closed swab to 2500 psi 20:15 - 22:15 2.00 STIM P COMP RIH w/ BHA #22. Jet stack. Jet tubing while RIH 2.2/1925. MIRU LRS and vac trucks 22: 15 - 22:25 0.17 STIM P COMP Tag TOL at 11642' CTD. PUH 50k and park. Swap to circ thru choke and zero press sensors. Pump 10 bbl hi vis pill 22:25 - 22:40 0.25 STIM P COMP Safety mtg re: hi press/simops 22:40 - 23:59 1.32 STIM P COMP Start 76 deg F, 6.88 ppg diesel down CT. 2.5/3670 when diesel at noz. POOH using pressure schedule and displacing wellbore to diesel from TOL 23:59 - 00:00 0.02 RIGD P POST DIMS quirk for cost tracking 4/29/2003 00:00 - 01 :20 1.33 STIM P COMP POOH from 7300' displacing diesel in CT w/ FW w/ well SI at choke. Well pressure stable at 1500 psi 01 :20 - 01 :30 0.17 RIGD P COMP SI master/swab (24). Bleed off press. LD nozzle BHA. MU nozzle for pumping N2 01 :30 - 02:10 0.67 RIGD P POST RU OS N2 pumper, vac tanks, load misc equip on trailers while WO DSM 02: 10 - 03:30 1.33 RIGD P POST Load DSM hi-press lub and tools to floor. Safety mtg re: hi press/spills. Set 4" BPV w/1410 psi WHP. Secure well. RDMO DSM 03:30 - 03:45 0.25 RIGD P POST Safety mtg re: N2 03:45 - 05:00 1.25 RIGD P POST Cool down OS. PT 3500 psi. Blow down CT w/ N2. Bleed off press 05:00 - 06:00 1.00 RIGD P POST Cut off CTC. Unstab CT. Remove gooseneck 06:00 - 07:30 1.50 RIGD P POST Rig released at 0600 hrs 4/29/2003 Wind 17-25 mph Continue RD. Set injector in box 07:30 - 08:30 1.00 RIGD P POST NO BOPE 08:30 - 09:00 0.50 RIGD P POST Have DSO removed fusable cap from SSV. Verify that adjacent wells are shut in. 09:00 - 11 :00 2.00 RIGD P POST Continue preparations to back off well. Lift rig and back off 30ft from well. 11 :00 - 18:00 7.00 RIGD N WAIT POST Wait on Weather to lower wind walls, etc. Wind at 20-35 mph. 18:00 - 22:00 4.00 RIGD P POST Lay down wind walls and mast. 22:00 - 22:30 0.50 RIGD P POST Pre-rig move safety meeting with all needed personnel. 22:30 - 00:00 1.50 RIGD P POST Move Nord 1 CTD rig to H-27A. 34 mile rig move. No Problems. Printed: 5/5/2003 11 :28 36 AM ) ) Q03-(J!7 29-Apr-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well NK-62A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 12,711.93' MD Window / Kickoff Survey: 12,720.00' MD (if applicable) Projected Survey: 13,149.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) R' E·· . C' t-l \ ¡ ---- ''").-' ,'"7.. ·..i t:" ~·i t.:J Uf~ v 1 3 ':\/", ¡VI}, ,\. ... /~,~~ ~t1h ;:~ ~rf 3 ~~; ::_~: ~='. ,'...~~,;.;'~ ~:.(!¡<~.~,+:: n Sperry-Sun Drilling Services North Slope Alaska BPXA NIAKUK NK-62A ~~-.; Job No. AKMW0002398939, Surveyed: 26 April, 2003 Survey Report 28 April, 2003 Your Ref: API 500292285201 Surface Coordinates: 5979932.36 N, 721677.01 E (70020' 50.8088" N, 148012' 01.0091" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 -"c Surface Coordinates relative to Project H Reference: 979932.36 N, 221677.01 E (Grid) Surface Coordinates relative to Structure: 5566.05 S, 5536.51 E (True) Kelly Bushing: 59. 80ft above Mean Sea Level Elevation relative to Project V Reference: 59.80ft Elevation relative to Structure: 59. 80ft Sr=""''''Y-SUI! 1:i'RILLll\fG .. SERVices A Halliburton Company Survey Ref: svy4012 Sperry-Sun Drilling Services Survey Report for NIAKUK - NK-62A Your Ref: API 500292285201 Job No. AKMW0002398939, Surveyed: 26 April, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) 12711.93 86.430 259.830 9252.03 9311.83 5403.22 N 2207.17 E 5985398.50 N 723723.40 E -2669.69 Tie On Point 12720.00 87.240 260.400 9252.47 9312.27 5401.84 N 2199.23 E 5985396.89 N 723715.50 E 12.267 -2661.66 Window Point 12750.65 91.100 260.710 9252.91 9312.71 5396.81 N 2169.01 E 5985390.97 N 723685.44 E 12.634 -2631.11 12782.67 95.240 258.070 9251 .14 9310.94 5390.93 N 2137.59 E 5985384.16 N 723654.21 E 15.327 -2599.31 12812.69 94.980 254.890 9248.47 9308.27 5383.94 N 2108.52 E 5985376.31 N 723625.36 E 10.586 -2569.74 12844.27 93.830 249.260 9246.04 9305.84 5374.25 N 2078.58 E 5985365.74 N 723595.72 E .~ 18.144 -2539.06 12874.72 94.010 246.260 9243.96 9303.76 5362.75 N 2050.46 E 5985353.42 N 723567.95 E 9.847 -2510.05 12908.37 95.570 243.370 9241.15 9300.95 5348.49 N 2020.12 E 5985338.26 N 723538.05 E 9.733 -2478.58 12939.39 95.330 237.100 9238.20 9298.00 5333.16 N 1993.33 E 5985322.15 N 723511.72 E 20.136 -2450.56 12967.02 95.150 230.220 9235.67 9295.47 5316.87 N 1971.18 E 5985305.21 N 723490.06 E 24.805 -2427.07 12999.79 95.860 223.880 9232.53 9292.33 5294.66 N 1947.32 E 5985282.30 N 723466.87 E 19.379 -2401.36 13033.52 97.270 228.820 9228.67 9288.47 5271.53 N 1923.08 E 5985258.47 N 723443.33 E 15.138 -2375.21 13070.07 99.910 232.340 9223.21 9283.01 5248.59 N 1895.17 E 5985234.71 N 723416.11 E 11.951 -2345.40 13102.37 98.330 235.340 9218.09 9277.89 5229.78 N 1869.42 E 5985215.14 N 723390.93 E 10.393 -2318.12 13120.96 98.060 237.980 9215.44 9275.24 5219.66N 1854.05 E 5985204.58 N 723375.86 E 14.131 -2301.92 13149.00 98.060 237.980 9211.51 9271.31 5204.94 N 1830.51 E 5985189.17 N 723352.77 E 0.000 -2277.19 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 265.000° (True). .~ Magnetic Declination at Surface is 26.171 0(16-Apr-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 13149.00ft., The Bottom Hole Displacement is 5517.45ft., in the Direction of 19.376° (True). 28 April, 2003 - 13:40 Page2of3 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services SŒ~yR~orlrorNMKUK-N~~A Your Ref: API 500292285201 Job No. AKMW0002398939, Surveyed: 26 April, 2003 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 12711.93 12720.00 13149.00 9311.83 9312.27 9271.31 5403.22 N 5401.84 N 5204.94 N 2207.17 E 2199.23 E 1830.51 E Tie On Point Window Point Projected Survey ~ Survey tool program for NK-62A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 11800.00 0.00 11800.00 9273.62 13149.00 9273.62 BP High Accuracy Gyro (NK-62) 9271.31 MWD Magnetic (NK-62APB1) ~ 28 April, 2003 - 13:40 Page 3 of 3 DrillQuest 3.03.02.005 ) ) 29-Apr-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well NK-62APB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 11,800.00 I MD Window / Kickoff Survey: 11,840.00 I MD (if applicable) Projected Survey: 13,126.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED MAY 13 2003 Alaska OJ·) & Gas Cons. Commission AnchOf!Qe a03-(}/7 Sperry-Sun Drilling Services North Slope Alaska BPXA NIAKUK NK-62APB1 ~...... Job No. AKMW0002398939, Surveyed: 22 April, 2003 Survey Report 28 April, 2003 Your Ref: API 500292285270 Surface Coordinates: 5979932.36 N, 721677.01 E (70020' 50.8088" N, 148012' 01.0091" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 --- Surface Coordinates relative to Project H Reference: 979932.36 N, 221677.01 E (Grid) Surface Coordinates relative to Structure: 5566.05 S, 5536.51 E (True) Kelly Bushing: 59. 80ft above Mean Sea Level Elevation relative to Project V Reference: 59. 80ft Elevation relative to Structure: 59. 80ft srl:tl'''''Y-SUI! DRIL..L-ING SERVices A Halliburton Company Survey Ref: svy4011 Sperry-Sun Drilling Services Survey Report for NIAKUK - NK-62APB1 Your Ref: API 500292285270 Job No. AKMW0002398939, Surveyed: 22 April, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11800.00 48.840 27.460 9213.82 9273.62 5083.30 N 2720.86 E 5985093.91 N 724246.33 E -3153.55 Tie On Point MWD Magnetic 11840.00 48.970 27.310 9240.11 9299.91 5110.07 N 2734.73 E 5985121.08 N 724259.40 E 0.431 -3169.69 Window Point 11871.62 53.480 24.490 9259.91 9319.71 5132.24 N 2745.47 E 5985143.56 N 724269.48 E 15.865 -3182.33 11912.15 65.210 21.500 9280.54 9340.34 5164.30 N 2759.02 E 5985176.00 N 724282.07 E 29.624 -3198.62 11940.00 72.690 17.010 9290.54 9350.34 5188.82 N 2767.56 E 5985200.76 N 724289.88 E 30.778 -3209.26 .~ 11973.92 88.550 16.480 9296.05 9355.85 5220.76 N 2777.16 E 5985232.98 N 724298.54 E 46.782 -3221.62 12002.23 92.160 2.210 9295.88 9355.68 5248.62 N 2781.75 E 5985260.96 N 724302.30 E 51.985 -3228.61 12042.33 93.570 353.930 9293.87 9353.67 5288.61 N 2780.40 E 5985300.90 N 724299.77 E 20.920 -3230.76 12078.31 91.450 338.950 9292.28 9352.08 5323.45 N 2772.00 E 5985335.47 N 724290.34 E 42.007 -3225.42 12110.81 91.280 327.320 9291.51 9351.31 5352.39 N 2757.34 E 5985363.96 N 724274.83 E 35.778 -3213.34 12143.98 97.090 323.090 9289.09 9348.89 5379.54 N 2738.48 E 5985390.54 N 724255.17 E 21.643 -3196.91 12174.06 96.040 315.340 9285.64 9345.44 5402.14 N 2718.97 E 5985412.56 N 724235.01 E 25.832 -3179.45 12204.01 92.420 306.000 9283.43 9343.23 5421.58 N 2696.34 E 5985431.32 N 724211.81 E 33.361 -3158.60 12235.08 91.190 295.250 9282.45 9342.25 5437.37 N 2669.66 E 5985446.32 N 724184.67 E 34.807 -3133.40 12268.06 95.510 288.200 9280.52 9340.32 5449.56 N 2639.10 E 5985457.59 N 724153.77 E 25.035 -3104.02 12297.71 97.440 281.680 9277.17 9336.97 5457.15 N 2610.65 E 5985464.34 N 724125.11 E 22.797 -3076.34 12327.86 96.740 277.450 9273.45 9333.25 5462.12 N 2581.16 E 5985468.43 N 724095.48 E 14.115 -3047.39 12358.81 95.950 272.520 9270.03 9329.83 5464.79 N 2550.52 E 5985470.20 N 724064.78 E 16.036 -3017. 11 12388.25 98.940 270.400 9266.21 9326.01 5465.53 N 2521.35 E 5985470.08 N 724035.59 E 12.415 -2988.10 12419.53 100.090 266.170 9261.04 9320.84 5464.61 N 2490.52 E 5985468.25 N 724004.81 E 13.834 -2957.31 12455.68 99.300 264.590 9254.95 9314.75 5461.74 N 2455.00 E 5985464.33 N 723969.39 E 4.831 -2921.68 12486.61 98.590 260.000 9250.14 9309.94 5457.65 N 2424.73 E 5985459.34 N 723939.26 E 14.838 -2891.17 --- 12519.28 96.480 258.240 9245.85 9305.65 5451.53 N 2392.93 E 5985452.29 N 723907.65 E 8.380 -2858.96 12551.66 93.390 255.780 9243.07 9302.87 5444.28 N 2361.50 E 5985444.11 N 723876.45 E 12.180 -2827.02 12581.78 90.660 253.660 9242.00 9301.80 5436.35 N 2332.47 E 5985435.32 N 723847.66 E 11.473 -2797.40 12616.25 85.990 252.780 9243.01 9302.81 5426.41 N 2299.49 E 5985424.41 N 723814.99 E 13.786 -2763.68 12647.83 83.700 254.720 9245.85 9305.65 5417.60 N 2269.30 E 5985414.72 N 723785.07 E 9.487 -2732.84 12679.96 83.880 256.660 9249.32 9309.12 5409.71 N 2238.35 E 5985405.91 N 723754.37 E 6.029 -2701.32 12711.93 86.430 259.830 9252.03 9311.83 5403.22 N 2207.17 E 5985398.50 N 723723.40 E 12.697 -2669.69 12741.71 89.430 261.940 9253.10 9312.90 5398.51 N 2177.79 E 5985392.92 N 723694.17 E 12.313 -2640.01 28 April, 2003 - 13:47 Page2of4 Dril/Quest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for NIAKUK - NK-62APB1 Your Ref: API 500292285270 Job No. AKMW0002398939, Surveyed: 22 April, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (tt) (tt) (tt) (tt) (tt) (tt) (tt) e/10ott) 12773.23 87.750 264.940 9253.88 9313.68 5394.91 N 2146.49 E 5985388.40 N 723662.99 E 10.906 -2608.52 12808.73 89.440 267.270 9254.75 9314.55 5392.50 N 2111.09 E 5985384.94 N 723627.67 E 8.106 -2573.04 12838.78 87.750 267.930 9255.48 9315.28 5391.24 N 2081.07 E 5985382.80 N 723597.71 E 6.037 -2543.03 12873.87 88.900 266.520 9256.51 9316.31 5389.54 N 2046.04 E 5985380.06 N 723562.74 E 5.184 -2507.98 12905.37 84.410 265.110 9258.35 9318.15 5387.25 N 2014.69 E 5985376.84 N 723531.47 E 14.938 -2476.55 --- 12934.87 82.560 267.050 9261.69 9321.49 5385.25 N 1985.45 E 5985373.98 N 723502.30 E 9.056 -2447.25 12967.89 84.410 261.770 9265.44 9325.24 5382.05 N 1952.81 E 5985369.81 N 723469.78 E 16.845 -2414.46 12998.46 84.140 257.360 9268.49 9328.29 5376.54 N 1922.90 E 5985363.42 N 723440.05 E 14.381 -2384.18 13028.27 83.080 253.130 9271.81 9331.61 5369.00 N 1894.26 E 5985355.04 N 723411.64 E 14.543 -2354.99 13059.49 87.400 251.190 9274.40 9334.20 5359.47 N 1864.66 E 5985344.64 N 723382.33 E 15.159 -2324.67 13090.59 87.750 249.960 9275.72 9335.52 5349.14 N 1835.35 E 5985333.44 N 723353.34 E 4.109 -2294.58 13126.00 87.750 249.960 9277.11 9336.91 5337.01 N 1802.11 E 5985320.34 N 723320.48 E 0.000 -2260.41 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 265.000° (True). Magnetic Declination at Surface is 26.171 0(16-Apr-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 13126.00ft., The Bottom Hole Displacement is 5633.05ft., in the Direction of 18.658° (True). --- 28 April, 2003 - 13:47 Page 3 of 4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for NIAKUK - NK-62APB1 Your Ref: API 500292285270 Job No. AKMW0002398939, Surveyed: 22 April, 2003 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11800.00 11840.00 13126.00 9273.62 9299.91 9336.91 5083.30 N 5110.07N 5337.01 N 2720.86 E 2734.73 E 1802.11 E Tie On Point Window Point Projected Survey .~ Survey tool program for NK-62APB1 Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 11800.00 0.00 11800.00 9273.62 13126.00 9273.62 BP High Accuracy Gyro (NK-62) 9336.91 MWD Magnetic (NK-62APB1) ~ 28 April, 2003 - 13:47 Page 4 of 4 DrillQuest 3.03.02.005 ~~ffi[O"-;J[ Q!. ., [¡~L .~ ~b \~_'" .J 1 fÆ ~~fÆ ~ ~«!Æ ) l AI,ASKA. OIL AND GAS CONSERVATION CO.MMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. -,nt AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara CT Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Unit NK.-62A BP Exploration (Alaska) Inc. Pennit No: 203-047 Surface Location: 1394' NSL, 884' WEL, SEC. 36, T12N, RISE, UM Bottomhole Location: 1014' NSL, 295' WEL, SEC. 30, TI2N, RISE, UM Dear Mr. Kara: Enclosed is the approved application for pennit to redrill the above development well. This pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law frOln other govemn1ental agencies, and' does not authorize conducting drilling operations until all other required pern1its and approvals have been issued. In addition, the Con1n1ission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Adlninistrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Adluil1istrative Code, or a Con1111ission order, or the tenns and conditions of this pem1it may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the COlnmission to witness any required test. Contact the COlnmission's North Slope petrolemn field inspector at 659-3607 (pager). Sincerely, ~~~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this_ day of March, 2003 cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. VJGA-'51z-4 ¡-¿IYC) ~ 1 a. Type of work 0 Drill II Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location.of well at surface x = 721677, Y = 5979932 1394' NSL, 884' WEL, SEC. 36, T12N, R15E, UM At top of productive interval x = 724239, Y = 5985079 1182' NSL, 1830' EWL, SEC. 30, T12N, R16E, UM At total depth x = 722119, Y = 5984847 1014' NSL, 295' WEL, SEC. 30, T12N, R15E, UM J' STATE OF ALASKA ) ALASKf-. '. L AND GAS CONSERVATION COMfvllciSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 59.8' Niakuk Oil Pool 6. Property Designation ADL 034630 7. Unit or Property Name Niakuk 8. Well Number / NK-62A 9. Approximate spud date 04/10/03 / Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 14350' MD / 9285' TVDss o 17. Anticipated pressure {S~"20 AAC 25.035 (e) (2)} 95 Maximum surface 2485 psig, Attotal depth (TVD) 9314' 13410 psig Setting Depth Top Bottom Quantity of Cement LenQth MD TVD MD TVD (include staae data) 2730' 11620' 9156' 14350' 9285' 147 sx Class 'G' -- 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 12. Distance to nearest property line 13. Distance to nearest well /. ADL 034635,295' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 11840' MD Maximum Hole Angle 18. casing;~~gram Specifications Hole Casina Weight Grade CouDlina 3-3/4" 3-3116" x 2-7/8" 6.2# / 6.16# L-80 TCII / ST-L 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 12206 feet 9542 feet 12093 feet 9465 feet Length Plugs (measured) Junk (measured) Fish: Spinner Blades at about 12087' (07/02) Size Cemented MD TVD Structural Conductor Surface Intermediate Production Liner 116' 5469' 20" 9-5/8" 260 sx Arcticset (Approx.) 2270 sx PF 'E', 440 sx 'G', 50 sx PF 'c' 116' 5510' 116' 5188' 12152' 7" 400 sx Class 'G' F''rI t. ",,. i('-~ r,r'''~ ~ ~ D ,," ¡'\"" /. fi,,'"''' I'.\, ~j ,,,:0_ \: ,~,t ."..,....,..,~. ,", Î'J· t¡ tv' ;.:' ' ~ \~'-'. ':.',..,::or~ ': '¥..),~.Dr.'UI ~~ ,,oM r.~m8 9531' M)~R 2 4 2003 Perforation depth: measured 11788' - 11818', 11860' - 11960' true vertical 9266' - 9285', 9313' - 9378' n."' ('.""""''''.':~iO'· ..I\'I'~"'." """:1 r. '.. '.''', (}'':''S,. ~\;~¡;.¡;J,)I I M ';~~'.'; ~¡";'It. \. :. ,~", 1'Ì: ': ~. ~ '.... ~:;.}8 20. Attachments II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report II 20 AAC 25.050 Requirements Contact Engineer Name/Number: Dan Kara, 564-5667 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify tha~.the.for~g*.regOi I~"tru and. co. .r.rect. t..o, ..th. e.. b..e. .st .O.f m.. ..Y..k,n,..~....~.., I.ed. ....g..e.... . J ) Signed Dan Kara (f..~.;. . ... ... }itle ~T ~~lIlng ~~gl~~:r. ... ..... ... Date 3{21 0] , '.' ., ',.' '",:,;,<,Q')~bsSj~~lJ",::Q~¥;~i;::,:,;,í~5·:::!:::~:_:,':::,,::'\' Permit Number API Number OAJ2Pr9~a!p}15l See cover letter ?-o .? - CJ 9 ? 50- 029-22852-01 5( -Vf/ ' for other requirements Conditions of Approval: Samples Required 0 Yes 181 No Mud Log Required 0 Yes N No Hydrogen Sulfide Measures IS Yes 0 N.o Directional Survey Required S Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: \-E..~t "B"?E f-o ~ÇOO 1) ~{ . Approved By ¡¿~~ ~L. ~ còmmiSSionÃ Form 10-401 Rev." 1~~1~5 / ". 0 ~ (j" N _ by order of the commissi.on Date OS/2-Ff<:>-s Submit In Triplicate ) ) BP Niakuk NK-62A CTD Sidetrack Summary of Operations: Phase 1: Prep work 1. Integrity testing 2. Caliper logging 3. Mechanical whipstock installation 4. Possibly cement squeeze existing perfs (CTD rig may do this step) /' Phase 2: Mill window, Drill and Complete sidetrack: Planned for April 10, 2003. CTD will be used to mill the window at 11840' MD (9300'TVD) from a mechanical whipstock, then drill and complete the directional hole as per attached plan. Maximum hole angle will be 95 degrees. Mud Program: · Phase 1: Seawater · Phase 2: Mill with seawater/biozan, drill with Flo-Pro (8.6 - 8.7 ppg) /'" Disposal: · All drilling and completion fluids and all other Class n wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: The production liner will be a 3-3/16" TCn 6.2# L-80 from the top of liner at 11,620' MD (9156' TVD) to 13,000' MD (9288' TVD}~sed over to 2 7/8" STL to TD at 14,350' MD (9345' TVD). The liner will be cemented With~~ to bring cement up to top of liner. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. /' · The annular pre venter will be tested to 400 psi and 2500 psi. / Directional · See attached directional plan. Max. planned hole angle is -95 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · MWD Gamma Ray and resistivity will be run in the open hole section. Hazards / · No H2S gas production. · Possibility of encountering original pressure (4543 psi) in the lateral is low; no geologic discontinuity expected. · No faults are mapped in the planned direction. Lost circulation is considered low. · Nearest close approach is just outside the window, -100' to NK-05. Minor risk. Reservoir Pressure Res. press. is estimated to be 3410 psi at 9314'TVD (7.0 ppg EMW). Max. surface pressure with gas (0.1 psi/ft) to surface is 2485 psi/There is a potential 900 psi difference between the GFSSB-ESB interval and the targeted interval, CMFS/BB2. However, the higher pressure GFSSB-ESB interval will be isolated with squeeze cemented. TREE = 4-1/16"-5MCIW WELLHEA D = 11" 5M FMC GEN 5 ÃëTUÃ'fõ¡:r;""mww,,,,,,,,,^,,,,,w""SAKffi "Ki~3':"""ÊC'Ë\i"";"""""" ,','."",' '.'w.'ow,',','"'.'.w,",','."".'.'.,,, .'.' """""""""'5'9"~"ã';' 'äF'~"'ËCË\i,^;;,,,,w"^^"""N"W',^"""""""23:7'5"ì KÕp';^^"w,w,w" .w·.·..·. ..... ·········"·'3'70'0' "rvìã'xA·ñgle·;;··..·..·················,·····S·1··'@"'6'45oï ··Datum··Mb··;;'·w~"''''''''-"-"'''^_'''._WNM'1·1'T73; õãtum'íVÖ;;;"" ..... ... ....... ... . 88'OÖ;'55 ) NK-62 ') SAFETY NOTES: 2098' 1-1 4-1/2" SLVN, HES HXO, ID = 3.813" I «8 9-5/8" CSG, 40#, L-80, 10 = 8.835" 1-1 5510' r-JI ~ GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LA TCH PORT DATE L 5 3238 3176 3 CA-KBG-2-LS DMY BL 0 08/11/02 4 4001 3928 16 CA-KBG-2-LS DOME BL 16 08/11/02 3 7423 6362 50 CA-KBG-2-LS DOME BL 16 08/11/02 2 9922 7975 48 CA-KBG-2-LS SO BL 24 08/11/02 1 11430 8979 48 CA-KBG-2-LS DMY BL 0 08/11/02 Minimum ID = 3.725" @ 11637' t J 6003' l-i 4-1/2" HES X NIP, 10 = 3.813" 1 4-1/2" HES XN NIPPLE 11540' l-i 4-1/2" HES X NIP, ID = 3.813" 1 :8: Z'-I 11551' 1-1 7" x 4-1/2" BAKER S-3 PKR, ID = 3.813" DA TE REV BY COMMENTS 08/11/02 RL/KAK GLV C/O I. 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" 1-1 11647' 1 ÆRFORA TION SUMMARY REF LOG: SWS US IT ON 01/28/98 ANGLE AT TOP ÆRF: 49 @ 11860' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 11788 - 11818 0 01/20/02 2-3/4" 6 11860 - 11960 0 02/14/98 1 PBìD 1-1 12093' 7" CSG, 26#, L-80, 10 = 6.276" 1-1 12190' DATE 02/13/98 02/27/01 1 0/04/01 01/21/02 07/25/02 REV BY COMMENTS ORIG COMPlETION, (POOL 7) FINAL CORRECTIONS ADD ÆRFS FISH SIS-LG RNfTP ONS/tlh TMN/KK I 1 11616' 1-1 4-1/2" HES X NIP, ID = 3.813" 1 I I 11637' 1-1 4-1/2" HES XN NIP, ID = 3.725" I I- 11647' 1-1 4-1/2"TUBINGTAILWLEG, 10=4.00" I 11654' 1-1 ELMD TT LOGGED 02/14/98 1 b 11740' 1-1 MARKER JOINT (ELMD) 11760' 1-1 MARKER JOINT (ELMD) I I' ~ I 12087' 1- FISH - (2) 3-1/2" SPINNER BLADES FROM PPROF (07/25/02) NIA KUK UNIT WELL: NK-62 ÆRMIT No: 197-2560 API No: 50-029-22852-00 SEC 36, T12N, R15E, 2873.59 FEL 3814.92 FNL BP Exploration (Alaska) I TREE = WELLHEAD = AciÚÄfÔR;·· KB. ELEV = ."""""'"'''''''''''''''''''''''",,',,''''''''''''' BF. ELEV = KOP= MaxAngl~ = Datum MD = DatumiVD = 4-1/16" -5M eM! 11" 5M FMC GEN 5 BAKER 59.8' 23.75' 3700' 51 (g) ~4~O' 11173' 8800' SS ") / NK-62A ) SA FETY NOTES: Proposed CTD Sidetrack 2098' 1-1 4-1/2" SLVN, HES HXO, 10 = 3.813" 1 - 9-5/8" CSG, 40#, L-80, 10 = 8.835" l-i 5510' ~ ~ GAS LIFT MANDRELS ST MD iVD DEV lYPE VLV LA TCH PORT DATE L 5 3238 3176 3 CA-KBG-2-LS DMY BL 0 08/11/02 4 4001 3928 16 CA-KBG-2-LS DOME BL 16 08/11/02 3 7423 6362 50 CA-KBG-2-LS DOME BL 16 08/11/02 2 9922 7975 48 CA-KBG-2-LS SO BL 24 08/11/02 1 11430 8979 48 CA-KBG-2-LS DMY BL 0 08/11/02 Minimum ID = 3.725" @ 11637' 4·1/2" HES XN NIPPLE t J 6003' 1-1 4-1/2" HES X NIP, 10 = 3.813" I 11540' 1-1 4-1/2"HESXNIP, 10=3.813" I 11551' 1-1 7" x 4-1/2" BAKER S-3 A<R, 10:: 3.813" 8 ~ I I 11616' l-i 4-1/2" HES X NIP, 10 = 3.813" I 11620' I-iTop of 3-3/16" Liner 11630' -3-1/2"XNIP, 10::2.813" 1 11637' - 4-1/2" HES XN NIP, 10:: 3.725" 1 I Top of cement-1 11620' I I PBTD 1-1 12093' 11647' 1-1 4-1/2"TUBINGTAILWLEG,ID::4.00" 1 11654' l-i ELMO 11 LOGGED 02/14/98 I I 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, 10:: 3.958" l-i 11647' 1 ANGLE AT TOP PERF: 49 @ 11860' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 11788 - 11818 isolated proposed 2-3/4" 6 11860 - 11960 isolated proposed 11740' 1-1 MARKER JOINT (ELMO) I 11760' 1-1 MARKER JOINT (ELMO) 1 I / 3-3/16" X 2-7/8" cmt'ed and 11840' 1-1 Mechanical Whipstock 12087' 1- FISH - (2) 3-1/2" SPINNER BLADES FROM PPROF (07/25/02) 7" CSG, 26#, L-80, 10 = 6.276" I~ 12190' REV BY COMMENTS ORIG COMPLETION, (POOL 7) FINAL CORRECTIONS ADD ÆRFS FISH DA TE REV BY COMMENTS 08/11/02 RUKAK GLV C/O NIA KUK UNIT W8...L: NK-62 PERMIT No: 197-2560 API No: 50-029-22852-00 SEe 36, T12N, R15E, 2873.59 F8... 3814.92 FNL BP Exploration (Alaska) DATE 02/13/98 02/27/01 10/04/01 01/21/02 07/25/02 SIS-LG RNITP CWS/tlh TMN/KK Plan: Plan #8 (NK-62lPlan#8 NK-62A) Created By: Brij Patnis Date: 3120/2003 (907) 267-6613 brij.potnis@inteq.com (907) 267-6600 Information: Direct: E-mail INTEQ Contac Azimuths to True North Magnetic North: 26.17° Magnetic Field Strength: 57567nT Dip Angle: 80.91° Date: 3/20/2003 Model: BGGM2002 T AM ¿ LEGEND ~~i~ m~i~¡ Plan#8 NK-62A Plan #8 .~. BAKER HUGIIIS ObP ~/ Hughes Bake ~- : ¡ I :, I ~ i I 14'00 1600 1700 1800 1900 West(-)/East(+) [100ft/in] lNTEQ 55 - .5 5400 _ æ - 8 5300 "I"" _ ....5200 _ - + - ::ë5100 _ 1:: = o 5000 _ ~ - "':""4900 _ - - ,e __ '5 480~ o - en 4700 = 4600 4400 4300 4200 4500 BP Amoco WELL PATH DETAILS P...... NK..2A 5002122.5201 p.,.nt Wellpalh: NK..2 Tie Oft MO: 11100.00 1UI' 44 , 62 1212111887 13:00 II .!HIIt lief. Datu"" V.aec:Uon ~~!; ~~= ::::tt.ø AIogI. 2'5.00' 0.00 0.00 0.00 REFERENCE INFORMATION Co-ordinale ~¡ Reference: Well Centre: NK-62. True North v~ (V~ ~:¡:~: ~~~ ~o8J.gao!J~)1 MeaSll'OO Depth Reference: 44: 62 1 ~/2811997 13:00 59.90 CaicUalioo Method: MinimLm CMvature IECTION HTAlLa he ... '00 A" TVO +N'.a +!/... OLe. TFace va.c Yu.. .. 11HO.OO 41..... 21.41 I2U.72 5013.4. 2721.04 O.DO 0.00 -3153.74 2 11NO.GO ....., 27.31 8240.01 IU10.21 27...... 0.42 311.80 """.at: 3 11110.00 10.2.1 H.15 1212.17 11U." ~ifl~ v!: ~:~ :Îfíi:ii 4 11.....08 10-00 SS3.08 185.31 S2SI." So 12064.08 '3.72 SU.21 8291.'3 6322.80 e 127201.08 ".38 au.23 e24S.0S 6S71AS 2122.22 12.00 272M ~2.5I2..2I 7 12'71.01 13~12 254'" 1235.15 1307.'1 1112.00 12.00 18.00 ~2437.o5 a 130t5.00 13." 238.02 1227.01 5214.11 1117.12 12~OO 271.00 ~230I.I' . 13255.00 ".07 2Ø.32 1227'" Itl2..48 11S1A' 12.00 105.00 ~207U1 10 1U80.00 18.10 231.27 fl,U.51 SUI.M 141.... 12.00 270.00 ~18S'.11 11 13130.00 ....7 118.32 0257.01 1O...aa ttl1AS 12.00 10.00 ~1et7.0I 12 13'80.00 ".se 218.2' 121'.11 "'.07 84'''' 12.00 210.00 ~1S7"54 13 '.230.00 11.73 zel.11 nao..... 48".2. 7Oe.13 ~~:: 21-::::: :~~~~-: 14 14350.00 17.&0 2$4.10 8285.35 ,"".80 587M ANNOTATION' TARGET DETALS TVD MD Annotation """. 1VO +""-5 "EJ-Yt~ 1213.72 11100.00 TIP ~~~~~_1 9"22~:~ :~::~~ I~~~ ~ 1240.01 11140.00 KOP h1<-6-2A Ta.t g,2-&OOO 51f0.22 2134.49 Pon 1252.87 11....00 3 h1<-62A T!." ~77.00 4923_77 7$5_03 POItII 1215.31 111".01 4 ~QA Ta2 ~_OO S~5~ 2756_21 Port Izt1.n 12014.01 5 1245.05 12724.01 . 1235." 12'71.01 7 1227.01 13015.00 . .227." 13255.00 . 1242.11 13410.00 10 1257.01 13730.00 11 1211.71 13110.00 12 12'0.84 14230.00 13 flIUI:"1!I 1.1.'t¡5ð.ðð TD 8200--= 8300 8400 8500 9600 (NK-05: -3600 -3500 -3400 -3300 -3200 -3100 -3000 -2900 -2800 -2700 -2600 -2500 -2400 -2300 -2200 -2100 -2000 -1900 -1800 -1 700 -1600 -1500-1400 -1300 -1200 -11 00 -1 000 Vertical Section at 265.00° [100ft/in] ~' 2400 ----¡-------- ¡ I ' , I Planf#8 NK-6~1 J1Q],--------:-~ ~---==---=-illJ-=~--rm=~1 ]::IQJ' [ --=- ~ /..~ --~I I : A: I ¡;. ! INK-62A':s4 i ! _ !_ i_ : -I i -=~-= . -c-i.cc_ ¡ j ___~___...L. ~- i I . NK-62 (NK·62 I - c- -- 8600- æ = 8 8700 "I"" .... 8800--- ,e- ... t8900 Q _ 9000 CIS u 1: 9100 CÞ > 9200 CÞ 2 9300- ... 9400 9500- 200 11:24 AM 100 o 3/20/2003 -400 -500 -600 -700 -800 -900 - NK-Q 9700 ObP ') ') ...1 ___GIllS iÑiiÈQ BP Baker Hughes INTEQ Planning Report ,..~. .".~_._".._....w.___..__.._._..__.._"".,......,_...._._.~___.,._~,,,~_,_,,,",._._,,_._,......._.~....,,,__."._.__._.._.._~...._,._.~_.._____,.,_._..,..-..._.,.___.__,.._.______,,_,_~_._.._.....__..___..._.,-------,....,_,____:..____..,___.__.__._,.....~........._.______..._____..____,,___,_____....__._.___,._"_.__.,_____.__.,~_----"_-"_'"__.... Company: Field: Site: Well: Wellpath: BP Amoco Niakuk NKMainPad NK-62 Plan#8NK-62A .. ,_ __"... _..',_~.___ ,....:,_..;.._...,'_J..'_,..,~. _~ ~_~_.. ;Date:~/2d/2003. ........... ......... Time: 11:25:63........ .... ...... Pag~:' Co~rdinate(NJj:)Ø-~ferençe: Well:. NK-.62.·; True NÒ¡1h Y~rti~al('fVD)R~(er~l1ce: SY~~~rn:Me~nSeaJ,.evel ....... . S~tiol1(YS)Reference: '.. Well (0,OON,O.OOE,265.QOAzi) ...._ ....~~~~r.,£~~~~~~!~~~~~~?~~~~,____...~!:~!~_~.~.2~~~~~~~...._....____ ... J?~.=..... ~!~~Ie. "' .',,_, ~''':L~' _ ~~ ..__..~...,,_. ~ _..~.._ _... ..._._:._ ,',~';', ,.,.,~.":'_ --.'.-..."., -." -.........".-- ._.." __ u__ _ _. .... _.~ . _ -... -- -. - ~_.....~- .._,__,"__.._..,,_..... ....._,_._..., _ _.."'........._.._...'_..__...___._..._... """_.__,____,,,,,_ _...__.__ .~_,..._."_"'_,_"L._'h'_ ,,_ _..____....._ .. ."_"'___'.'_'~'_'__~' .,...._,.."'._..~,___'"" ._~..__._.. Field: Niakuk North Slope UNITED STATES Map System :US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 .-.,..".-----".--.,-,..".".-.----.. .---,.-.-.-..-.-...... --'.- .-. -,.--...----.-...... ~ ... _.._._-,-~....~,-----,..._.....-. - -...........---.-.-.,-....,., ". ..." ,,-. --'..~,_..-.. ".'''---''- -. _..---- Site: NK Main Pad TR-12-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft ."-~' -,-'.....,..,._._-~-_...~-_.-.._-_._- 5981257.79 ft Latitude: 714553.26 ft Longitude: North Reference: Grid Convergence: . __··_.'·,.·__""_.._,·_'.",~_h.....,__'...,.,__,_. _. .,_.__,.,....,~..__..__ ,. ._.._ 70 21 5.879 N 148 15 27.984 W True 1.64 deg _ _" __..........__ .___... - _.n. .." .__~,____...~.._,._, ._. .. . -- .. -....,,-.-. ....-,.. -.~'.'-,-,.,,-,- -... -------.-- -_..,...-..-..."-._.,-~...,.._----_._--.--,-_._._.-.-_-_.-"'--'---"""-'-"---'--'--- . --,..._..,--,--_.,._-,_...,.-.",,,-,,~. ....--..."..",-........--.. ....-....--.-...-...-..- Well: NK-62 Slot Name: NK-62 Well Position: +N/-S -1528.94 ft Northing: 5979932.36 ft Latitude: +E/-W 7083.21 ft Easting: 721677.01 ft Longitude: Position Uncertainty: 0.00 ft 62 70 20 50.809 N 148 12 1.009 W -' - - .., -,,_",__. - ,-.-_,____._ _'_.._.."__.'_..'_'."'_."_ "·".w_,..,, ___.... _,,__ .,,_._..... . ..._..,........_n__.____._ ._._ . ... _. _. ._,..___,_,..._._...,_"._._~".".,._""___....~~ ,..,,__._,__.___,._.. __...._"n ,..._ ~". __."_..__,...,...,_._...·..M.._.,._ .,. Well path: Plan#8 NK-62A 500292285201 Current Datum: 44: 6212/28/199713:00 Magnetic Data: 3/20/2003 Field Strength: 57567 nT Vertical Section: Depth From (TVD) ft 0.00 Targets Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/- W ft 0.00 NK-62 11800.00 ft Mean Sea Level 26.17 deg 80.91 deg Direction Height 59.90 ft +N/-S ft 0.00 265.00 ... .. . ,. ..'. ~... "'''M''_ .,.. ..""_,,....._ ".....'"'.~_.... '_'__,e"_,. ___.~_....~_... . ~,.. _~.__,__,___._...~~__...,.._.u,'. "'. "."_".,,0 ....,. ,_,_.. ..~-,~.. _".. _ ..._, ,-__.. __ _..._..,...,~'" ",,_,..._.... nM,,_._ ..'"_ ,.'.~_~'."."_.. ,. ..____ . ,. _M._.~'.,,,"' ... M~,.'''_"..,."._ ..._ _" .._~, "·~""_m".~_ ...,. ~ ".-" _ .~....,._ .,....~ _._'-'- ':'" '"'r'.~"-:"-" '~. ". ..__._. Map, ".Map ¡..... <-.¡Lat¡tud~¡...,--->· <~-:--.)l;ongitudê.-':'> . Northi~gEa~til1~' Deg Min' .Sè¢DegMbr· . See .. ·,ft .... ....... .·ft.i' i ¡ '. '.. . .......:. .. ''',.. ~,.....~~,_.._..,..:..__..........._ __,~.....;..._._~_,.........~......_..........~~M_...,.'___. ...~. .,_.. '"',.".~, "....,."~...,,..'_. '." ,. _",.. ..._".........:...~_.;_,~:..I. .:......J_'.,,~_~ ._._.,...~...,,__,__ _._,.._.U".~.., .~. .._ 5984692.01 722160.03 70 21 37.460 N 148 11 42.775 W 5984692.01 722160.03 70 21 37.460 N 148 11 42.775 W 5984957.02 723022.03 70 21 39.813 N 148 11 17.350 W 5985291.02 723831.03 70 21 42.860 N 148 1053.413 W 5985573.02 723721.03 70 21 45.664 N 148 10 56.382 W 5985245.01 722915.03 70 21 42.676 N 148 11 20.227 W 5985000.02 722080.03 70 21 40.512 N 148 11 44.846 W Name Description Dip. Dir. - .. ,.~..".~".~".'", ..-.',.. ~.,.. NK-62A Polygon8.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 ·Polygon 6 '(VO +N/"S +E/-W·· .ft . . ,'ft ft ,.·....'....."~,...",w, ..,._ .'u~ __,~~_,',"_"."...",_...,,_~ _...._..,._........._,'-_, ....~_._. '"..._..."~.....,'".... .. .,. 0.00 4743.49 623.62 0.00 4743.49 623.62 0.00 4982.89 1493.12 0.00 5292.83 2311.68 0.00 5577.97 2210.07 0.00 5273.94 1394.68 0.00 5053.74 552.76 NK-62A T8.3 9223.00 5207.13 1758.89 5985189.01 723281.03 70 21 42.018 N 148 11 9.578 W NK-62A T8.1 9240.00 5110.22 2734.49 5985121.00 724259.04 70 21 41.062 N 148 1041.051 W NK-62A T8.4 9277.00 4923.77 786.03 5984877.01 722317.03 70 21 39.233 N 148 11 38.026 W NK-62A T8.2 9295.00 5235.64 2756.21 5985247.00 724277.04 70 21 42.296 N 148 10 40.415 W Annotation MD ft 11800.00 11840.00 11860.00 11984.06 12084.06 . 12724.06 12879.06 13015.00 13255.00 13480.00 . 13730.00 TVD ft 9213.72 9240.01 9252.97 9295.31 9291.93 9245.05 9235.65 9227.08 9227.66 9242.51 9257.09 -.-.----. -.. ,.,--.-.- -.....- . -..,,--.,--.._". . _.M·.. .__..__._ _ __ -..- ..,..---.,--- ..-. .._ ...~. _ .___M______. ._.__....._ .~______.._._.'""._._.____.._.___ TIP KOP 3 4 5 6 7 8 9 10 11 ) ) _ .,.Ii, , , .., ii, '., I _..:s 1N'l'EQ bp BP Baker Hughes INTEQ Planning Report _..~ __, _........ ,_." ..,.." ''''''_~.''_''',,~._.....' - _"'.0_"'- .".__._....."...,..._.. . ~.".. ..._~ "......._..,., ,......._.__.... .~___,~.._._._._" __'....___. ....'....___ .... ...:....__.".,.,......,_..... .,.__.._.."__"_.._._._,,._._.._.,,_,__."~_.,, ._".._.'._'''...,_...._._.."..._....._.._" ..._ _" "_,, __....._.._........_.._'._..__.. Company: BP Amoco Field: Niakuk Site: NK Main Pad Well: NK-62 .' ~~~I~,at~:." ~I~~~~. .~~~~~~ ,. ',.'....., _ '..,..". .....,.._.... Annotation Date:. " 3/201~003;, >,,' " ,Tim~: \ 11:25:53 ,Page: 2 Cø~rdinate(NE)Reference: Well: NK~62, True .North Vertical(TVQ>R.eferel1ce: Sys~elT¡: Me~n,Sea Level Section'(VS) Reference: , ',' Well (0.00N,O.QOE,265.00Aii) ._ ".",,,,.,,..,',,-., ... __......._.c., _.. ._'.' ."..~~~~~S.~~~~~~t.!~~.~~tl1~~,:c.:.';"_ ..~:~,~i!!,.~~ ~~0.'~t~~~ .'..'.,.....,. .",.__~~:,... ".9~~~I:__ 13980.00 14230.00 14350.00 9269.71 9280.64 9285.35 12 13 TO Plan: Plan #8 Identical to Lamar's Plan #8 Principal: Yes Date Composed: Version: Tied-to: 3/20/2003 3 From: Definitive Path ,.- .,..._, .".- ....-.----.--......"-...-,, __ __. __, ,.._.,..___...,._ .."..n.__......··___,,_..__... ._.... ___... _n._... Plan Section Information MD lncl Azim TVD +N/-S ft deg deg ft ft . .",-" .'"'' -,..~.., ,~., ,_..".'-....~. ,'.. .... ..,,~ . ," ....J ".'", ."., "~.,._....,..,,.~.,,_.,.~.... '."... .~:." "...".~....:~ ........"1,,.. ....... J. ....:"." 11800.00 48.84 27.46 9213.72 5083.49 11840.00 48.97 27.31 9240.01 5110.26 11860.00 50.25 25.65 9252.97 5123.89 11984.06 90.00 353.06 9295.31 5235.53 12084.06 93.72 313.21 9291.93 5322.90 12724.06 93.38 236.23 9245.05 5371.45 12879.06 93.52 254.86 9235.65 5307.69 13015.00 93.66 238.52 9227.08 5254.19 13255.00 86.07 266.32 9227.66 5182.46 13480.00 86.50 239.27 9242.51 5116.66 13730.00 86.97 269.32 9257.09 5049.88 13980.00 87.38 239.28 9269.71 4983.07 14230.00 87.73 269.31 9280.64 4916.24 14350.00 87.80 254.90 9285.35 4899.80 Survey MD Incl Aiim SSTVD N/S ft deg deg ft ft ....'...'. ........-..".-. .. ,,,...~. ,...~....,~,..:'. .~..,.'.,-,.:,;",-~,...._~.,.. 11800.00 48.84 27.46 9213.72 5083.49 11814.11 48.89 27.40 9223.00 5092.92 11825.00 48.92 27.36 9230.16 5100.21 11839.98 48.97 27.31 9240.00 5110.24 11840.00 48.97 27.31 9240.01 5110.26 ..".." ""'I'~" """:. ,."..., :":,T'''' ';,;.''''-'' "...".. "... "'....,"'-, ",.,."". ".,,- ."-""...,,. ,., . +E/-W DLS. Build Turn TFO Target ,':".._.,...c. ...~,.."",:,.;_..,..~.~.~~_~,~?!t...d.,~~H,~2~.~7.~{JP?.~....,.,.~:~_...... "...~...._..._.... 2721.04 0.00 0.00 0.00 0.00 2734.90 0.42 0.31 -0.36 318.60 2741.69 9.00 6.42 -8.28 315.00 2755.74 40.00 32.04 -26.27 315.00 2711.52 40.00 3.72 -39.86 275.80 2122.22 12.00 -0.05 -12.03 272.60 1982.00 12.00 0.09 12.02 89.00 1857.82 12.00 0.10 -12.02 271.00 1631.43 12.00 -3.16 11.58 105.00 1418.96 12.00 0.19 -12.02 270.00 1181.45 12.00 0.19 12.02 90.00 943.83 12.00 0.16 -12.01 270.00 706.13 12.00 0.14 12.01 90.00 587.68 12.00 0.06 -12.01 270.00 , ........_"',L.,.'""._....".,_... __,_. __m . _._ _n .__._.__..___..__.___.. .~."..~,._.,.._. .,...,..'. -,_.,.," .-...""...".p,.....'"".-"".-'..-." ,,,-....,,,-~-'..' ... ....."'._,.,,,-,._,,,''"''.-.., ._...~.".,"~" .,,,-.,"-'"....,.,'~,.,,"." '. EIW MapN MapE VS DLS TFO· Tool ft ft ft ft deg/100ft, deg . -,,,~~_.. . "...' ... .'... .'..'" ~,,,_... ,~." ~'., ". .....~'....',.~.._~~".....¡, ',... -,.~'....~.., ~._.,_,.~... .,..;, ."'''."''" .",~.~",.... .....~ ..,_.,:".~.",J ',,,. .._..:. __ ...:...... ,,_ .~ "..~,.;;.......". ~"""".,. _. , _... ". _...: . ... -'~.' ~ "~,,,, ,..~ "....~ ".~" , .-.... .'........~,. _... ""-" ..- 2721.04 5985093.88 724246.38 -3153.74 0.00 0.00 TIP 2725.93 5985103.45 724250.99 -3159.44 0.42 318.60 NK-62A - 2729.71 5985110.85 724254.55 -3163.83 0.42 318.63 MWD 2734.90 5985121.04 724259.44 -3169.88 0.42 318.66 NK-62A - 2734.90 5985121.05 724259.44 -3169.88 0.42 318.69 KOP 11850.00 49.61 26.47 9246.53 5117.02 2738.33 5985127.91 724262.67 -3173.89 9.00 315.00 MWD 11860.00 50.25 25.65 9252.97 5123.89 2741.69 5985134.88 724265.83 -3177.84 9.00 315.54 3 11875.00 54.62 20.45 9262.12 5134.83 2746.33 5985145.95 724270.14 -3183.41 40.00 315.00 MWD 11900.00 62.31 12.94 9275.20 5155.22 2752.39 5985166.51 724275.59 -3191.22 40.00 318.17 MWD 11903.96 63.56 11.85 9277.00 5158.66 2753.14 5985169.97 724276.24 -3192.27 40.00 322.12 NK-62A - 11925.00 70.35 6.44 9285.24 5177.76 2756.19 5985189.15 724278.73 -3196.98 40.00 322.61 MWD 11950.00 78.60 0.57 9291.93 5201.77 2757.64 5985213.19 724279.46 -3200.51 40.00 324.74 MWD 11975.00 86.96 355.03 9295.07 5226.52 2756.68 5985237.90 724277.77 -3201.71 40.00 326.31 MWD 11984.06 90.00 353.06 9295.31 5235.53 2755.74 5985246.88 724276.56 -3201.56 40.00 327.01 4 12000.00 90.64 346.72 9295.22 5251.21 2752.94 5985262.4 7 724273.30 -3200.14 40.00 275.80 MWD 12025.00 91.63 336.76 9294.73 5274.92 2745.12 5985285.93 724264.79 -3194.41 40.00 275.76 MWD 12050.00 92.57 326.80 9293.81 5296.90 2733.32 5985307.56 724252.34 -3184.58 40.00 275.57 MWD 12075.00 93.44 316.83 9292.49 5316.50 2717.91 5985326.69 724236.36 -3170.93 40.00 275.20 MWD 12084.06 93.72 313.21 9291.93 5322.90 2711.52 5985332.90 724229.78 -3165.12 40.00 274.68 5 12100.00 93.81 311.29 9290.88 5333.59 2699.74 5985343.24 724217.70 -3154.32 12.00 272.60 MWD 12125.00 93.93 308.29 9289.19 5349.55 2680.58 5985358.62 724198.07 -3136.62 12.00 272.47 MWD 12150.00 94.05 305.28 9287.45 5364.48 2660.61 5985372.96 724177.67 -3118.03 12.00 272.27 MWD 12175.00 94.15 302.28 9285.66 5378.35 2639.88 5985386.20 724156.54 -3098.59 12.00 272.06 MWD 12200.00 94.24 299.27 9283.83 5391.10 2618.46 5985398.31 724134.75 -3078.36 12.00 271.85 MWD 12225.00 94.32 296.26 9281.97 5402.71 2596.41 5985409.27 724112.36 -3057.40 12.00 271.63 MWD 12250.00 94.39 293.25 9280.07 5413.15 2573.77 5985419.03 724089.43 -3035.76 12.00 271 .40 MWD 12275.00 94.44 290.24 9278.15 5422.39 2550.62 5985427.58 724066.02 -3013.51 12.00 271.17 MWD 12300.00 94.49 287.24 9276.20 5430.39 2527.02 5985434.88 724042.20 -2990.70 12.00 270.94 MWD bp .." "~. .,.. ".,--,- ,..... P'" - Company: BPAmoco Field: Niakuk Site: NK Main Pad Well: NK:·62 Wellpath: Plan#8 NK-62A Survey .-.-, .....,_..,,-_.,,_.._,~, .... ) ) BP Baker Hughes INTEQ Planning Report .'. 'n '__",".." ~_._.._. ...,,_ ..,.__,._..~ ,.. ."._."._.,_......_._ .-- ._,.~.- .-.--~.-,~ ,.....".-.----...---..--,.-. "-"--'-"-'--- '-"---'" "'-',-"---~ .--..-.. ." ,+ ~-~- ,.__.,.__.'~ - -' ._-"_._-.._'.,..----""-,._._._.._-~'-_.~._;-----'---.,.,-- ----_._-.---.-.- ..._--;'"-:-"._- MD Inci ft deg ,..-.,,- '~'-""'''''',,,...,,.._",, ---.. 12325.00 94.52 12350.00 94.54 12375.00 12400.00 12425.00 12450.00 12475.00 12500.00 12525.00 12550.00 12575.00 12600.00 12625.00 12650.00 12675.00 12700.00 12724.06 12725.00 12750.00 12775.00 12800.00 12825.00 12850.00 12875.00 12879.06 12900.00 12925.00 12950.00 12975.00 13000.00 13015.00 13025.00 13050.00 13075.00 13100.00 13125.00 13150.00 13175.00 13200.00 13225.00 13250.00 13255.00 13275.00 13300.00 13325.00 13350.00 13375.00 13400.00 13425.00 13450.00 13475.00 13480.00 94.54 94.53 94.52 94.48 94.44 94.39 94.32 94.24 94.15 94.04 93.93 93.81 93.67 93.53 93.38 93.38 93.43 93.46 93.49 93.51 93.52 93.52 93.52 93.56 93.60 93.63 93.65 93.66 93.66 93.35 92.56 91.77 90.98 90.18 89.38 88.59 87.79 87.01 86.23 86.07 86.07 86.09 86.11 86.15 86.19 86.25 86.32 86.39 86.48 86.50 Azim deg _,.".~,". _'0."_."" .'" .."_",,, 284.23 281.22 278.21 275.20 272.19 269.18 266.17 263.16 260.16 257.15 254.14 251 .14 248.13 245.13 242.12 239.12 236.23 236.34 239.35 242.35 245.36 248.37 251.37 254.38 254.86 252.35 249.34 246.34 243.33 240.32 238.52 239.68 242.58 245.48 248.37 251.26 254.15 257.05 259.94 262.84 265.74 266.32 263.92 260.91 257.90 254.90 251.89 248.89 245.88 242.87 239.87 239.27 .. ... .,,~ ,_....._. .....~.... "'0"".' "_'~"""._'_""_____'_'" ,'"'~.. .~..._..M_'._'__""n_"'___'_"_'~"'._.'"o,'_'V'~~"_'''' __.,__, "0 _..____c_ .._.~.__... SSTVD N/S ft ft .,."'" ."~..~,~,.._..,,.' ..,....'. "'"~ .,... ...._,~ 9274.24 5437.15 9272.26 5442.64 9270.29 9268.31 9266.33 9264.37 9262.43 9260.50 9258.60 9256.74 9254.91 9253.13 9251.39 9249.70 9248.07 9246.50 9245.05 9245.00 9243.51 9242.01 9240.49 9238.97 9237.43 9235.90 9235.65 9234.35 9232.79 9231.22 9229.63 9228.04 9227.08 9226.47 9225.18 9224.23 9223.63 9223.38 9223.48 9223.92 9224.71 9225.85 9227.32 9227.66 9229.03 9230.74 9232.44 9234.12 9235.79 9237.44 9239.06 9240.65 9242.20 9242.51 5446.84 5449.75 5451.36 5451.65 5450.64 5448.33 5444.71 5439.80 5433.62 5426.18 5417.50 5407.61 5396.53 5384.29 5371.45 5370.93 5357.65 5345.50 5334.50 5324.70 5316.11 5308.76 5307.69 5301.79 5293.60 5284.19 5273.59 5261.81 5254.19 5249.07 5237.02 5226.08 5216.28 5207.66 5200.23 5194.01 5189.03 5185.29 5182.81 5182.46 5180.77 5177.48 5172.89 5167.03 5159.90 5151.53 5141.93 5131.15 5119.19 5116.66 ...1 BAK" IIUGIIU iÑifËQ -"., -....--..-.....".... ..'-"'--'" ,~~._- ...-.-, --" ·r·_··_'··U"_'"....~_.""._.._. Date: .3/20/2003 . .Thne:J1 :25:53 .Page: 3 C0rOrdinùt~(NE) Refer.m~e: Well: NK-62,Troe North Vertical (TVl) Re.ferel1ce: System: Mean Sea Level ~~;;~._~~~~7.~!;~~;!~~~.~_..._...._;!;lil~~~~~~~~~~~_~~.'~,~~~:._ ..9r.~~1~.. .. .........1 ._-~.._.__._..-.'--_....,..._, _."------,----.,'_..--'--~_._--"-.._~~_. ..- --_...'-~~._,.. -- ~._.--_. EIW ft 2503.04 2478.73 MapN MapE VS ft ft ft ." .._", "4'__"'~"'.' ,_.,_."...,", ..~....._,_.,_""."..__. "._.,.~_,__, ,..... ..~".,........,.... ..,.,..,..,. ~ ..._, 'V'''''~'' "....... ."._ 5985440.93 724018.02 -2967.39 5985445.69 723993.56 -2943.65 2454.17 2429.42 2404.55 2379.63 2354.73 2329.92 2305.26 2280.82 2256.66 2232.87 2209.49 2186.60 2164.25 2142.51 2122.22 2121.44 2100.31 2078.52 2056.12 2033.18 2009.75 1985.91 1982.00 1961.95 1938.38 1915.28 1892.70 1870.71 1857.82 1849.26 1827.40 1804.94 1781.95 1758.49 1734.62 1710.41 1685.93 1661.24 1636.41 1631.43 1611.55 1586.83 1562.32 1538.08 1514.18 1490.68 1467.65 1445.16 1423.26 1418.96 5985449.17 5985451.34 5985452.21 5985451.77 5985450.03 5985446.98 5985442.63 5985437.01 5985430.12 5985421.98 5985412.61 5985402.04 5985390.31 5985377.43 5985364.00 5985363.45 5985349.55 5985336.76 5985325.11 5985314.63 5985305.36 5985297.31 5985296.12 5985289.63 5985280.75 5985270.66 5985259.39 5985246.97 5985238.98 5985233.60 5985220.91 5985209.31 5985198.84 5985189.52 5985181.39 5985174.46 5985168.76 5985164.29 5985161.08 5985160.59 5985158.30 5985154.28 5985148.97 5985142.39 5985134.56 5985125.50 5985115.23 5985103.78 5985091.19 5985088.53 723968.89 723944.07 723919.16 723894.25 723869.39 723844.66 723820.11 723795.83 723771.87 723748.31 723725.20 723702.61 723680.60 723659.23 723639.33 723638.56 723617.84 723596.42 723574.36 723551.71 723528.55 723504.94 723501.06 723481.20 723457.89 723435.07 723412.82 723391.19 723378.53 723370.12 723348.63 723326.50 723303.81 723280.62 723256.98 723232.97 723208.65 723184.08 723159.34 723154.37 723134.55 723109.94 723085.57 723061.52 723037.84 723014.60 722991.87 722969.71 722948.17 722943.95 -2919.55 -2895.15 -2870.52 -2845.72 -2820.83 -2795.90 -2771.02 -2746.25 -2721.65 -2697.29 -2673.25 -2649.58 -2626.35 -2603.63 -2582.29 -2581.47 -2559.27 -2536.50 -2513.23 -2489.52 -2465.43 -2441.04 -2437.05 -2416.57 -2392.38 -2368.54 -2345.12 -2322.19 -2308.69 -2299.71 -2276.88 -2253.55 -2229.80 -2205.67 -2181.25 -2156.59 -2131.77 -2106.85 -2081.89 -2076.91 -2056.95 -2032.04 -2007.22 -1982.56 -1958.13 -1933.99 -1910.22 -1886.87 -1864.01 -1859.51 DLS deg/100ft 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 TFO Tool de~i 270.71 MWD 270.47 MWD 270.23 MWD 270.00 MWD 269.76 MWD 269.52 MWD 269.28 MWD 269.05 MWD 268.82 MWD 268.59 MWD 268.37 MWD 268.15 MWD 267.93 MWD 267.72 MWD 267.52 MWD 267.32 MWD 267.14 6 89.00 MWD 89.01 MWD 89.19 MWD 89.37 MWD 89.55 MWD 89.73 MWD 89.92 MWD 90.10 7 271.00 MWD 270.84 MWD 270.66 MWD 270.47 MWD 270.28 MWD 270.09 8 105.00 MWD 105.07 MWD 105.22 MWD 105.33 MWD 105.40 MWD 105.43 MWD 105.42 MWD 105.37 MWD 105.27 MWD 105.14 MWD 104.97 9 270.00 MWD 270.16 MWD 270.37 MWD 270.57 MWD 270.78 MWD 270.98 MWD 271.18 MWD 271.37 MWD 271.56 MWD 271.75 10 bp ....u.·..._...~..._,_..__"... Company: BP Amoco Field: Niakuk Site: NK Main Pad Well: NK"62 ~e.II.~~~~~_. Plan~~.~~.,~2A Survey ) ') BP Baker Hughes INTEQ Planning Report , -." ,".~"."..""".",,--,.~ ",.""._",~_,."._. __,_,...,.._..,_"._..·"._.__._,w,....~ '__'n~.,_,~..__ .__....._..w_.._·.._.___.....w.~._,....,.____"......__,_.._.__________....~_..,_._~_."._.__. ______~. .__,h____._._.___~____ _..___.._ ._....___~., ""._._ -- ._-_.._.__.".._~_.._.._- .··._··..·w., ._'.. ....._.. ...~.~., ... .._,_..w...........".,._ -"-"''''-7"''-' ._...~..._~'. ".,-,...."_..,,..':'"~,._-:...,~' .-..-- "", ,-. ,"- '"--''' """-~-_.'. -.- ..-....--....... ,p,,-..., ".,- ..-,..-.. .._--"..".~. . -~-':.. .~,. M.D ft 13500.00 13525.00 13550.00 13575.00 13600.00 13625.00 13650.00 13675.00 13700.00 13725.00 13730.00 13750.00 13775.00 13800.00 13825.00 13850.00 13875.00 13900.00 13925.00 13950.00 13975.00 13980.00 14000.00 14025.00 14050.00 14075.00 14100.00 14125.00 14150.00 14175.00 14200.00 14225.00 14230.00 14250.00 14275.00 14300.00 14325.00 14350.00 Incl deg ".. ~._... "'_h','''''~'~ "."._.., 86.50 86.52 86.54 86.57 86.61 86.66 86.72 86.79 86.87 86.95 86.97 86.97 86.98 87.00 87.03 87.06 87.11 87.16 87.22 87.29 87.36 87.38 87.38 87.39 87.40 87.43 87.46 87.50 87.54 87.59 87.65 87.71 87.73 87.73 87.74 87.75 87.77 87.80 Àzim deg 241.67 244.68 247.68 250.69 253.69 256.70 259.70 262.71 265.71 268.71 269.32 266.91 263.91 260.90 257.90 254.90 251.89 248.89 245.89 242.88 239.88 239.28 241.68 244.69 247.69 250.69 253.70 256.70 259.70 262.70 265.70 268.71 269.31 266.90 263.90 260.90 257.90 254.90 SSTVl) ft 9243.73 9245.25 9246.77 9248.27 9249.76 9251.23 9252.67 9254.09 9255.47 9256.82 9257.09 9258.14 9259.46 9260.77 9262.07 9263.36 9264.63 9265.88 9267.11 9268.31 9269.48 9269.71 9270.62 9271.76 9272.90 9274.03 9275.14 9276.25 9277.33 9278.39 9279.43 9280.44 9280.64 9281.43 9282.42 9283.40 9284.38 9285.35 _._1 BAa* ....... INrEQ Date: .... 3/20/2003 . . Time: 11 :25:53 Page: 4 Co~r~inate(NE) R~feren~~: Well: .NK-62. True North Vertical (TV») Rererence: System: Mean Se~ Level Section (VS)Referrence: Well (0.00N.O.00E,265.00Azi) ...~.~,~~!~._~.~~~_~~.~~O.~_~!_!~.~.~.:_...._"...."~.~!T_~r.:n.. ~~r'~.t~~EI...__.. ...__:c_;.~,~:_,. .g~~.~I:_.. ._ .....__.,." __h"'"__' .,,~_w...w~.·,.. _..__. ..~.."..,.~."., ,"'",..__~ ._..~.......~,_.~". ,.,._" ~,.._~_._" ._'.__~,,,.........."'_.,,'...' ,_~,,~.. "',__. ..__... _,. ._.~._ ......."u._.."........_..,. _ ___._,..._..w. "... ..~, ..." ...".,__..._,...__ .~___,._. ._,__. .... ". N/S ft 5106.83 5095.57 5085.49 5076.62 5068.99 5062.62 5057.52 5053.70 5051.18 5049.97 5049.88 5049.23 5047.23 5043.93 5039.34 5033.4 7 5026.33 5017.95 5008.35 4997.56 4985.60 4983.07 4973.23 4961.96 4951.88 4943.01 4935.37 4928.99 4923.88 4920.06 4917.54 4916.32 4916.24 4915.58 4913.58 E/W MapN MapE ft ft ft .·."_'._""L_".·'..._.~~,,.,..........~,,_~_, ,.I_"_,~"."._..__ ..~ _., ,.,.....~.'..,'_,w"_,._,_'.,,.,',..~.... ..__",_-,.._ 1401.59 5985078.19 722926.88 1379.33 5985066.27 722904.95 1356.50 5985055.53 722882.44 1333.18 5985045.98 722859.39 1309.42 5985037.65 722835.87 1285.29 1260.86 1236.20 1211.37 1186.44 1181.45 1161.49 1136.60 1111.86 1087.32 1063.06 1039.13 1015.62 992.57 970.05 948.14 943.83 926.44 904.16 881.31 857.97 834.19 810.05 785.60 760.92 736.08 711.13 706.13 686.16 661.26 4910.27 636.51 4905.68 611.95 4899.80 587.68 ._u_. _.._ ._,__~._______.__".o_ 5985030.56 5985024.74 5985020.19 5985016.94 5985014.99 5985014.76 5985013.51 5985010.78 5985006.75 5985001.43 5984994.85 5984987.01 5984977.94 5984967.66 5984956.21 5984943.61 5984940.95 5984930.60 5984918.68 5984907.93 5984898.37 5984890.03 5984882.94 5984877.11 5984872.56 5984869.31 5984867.35 5984867.12 5984865.87 5984863.13 5984859.10 5984853.78 5984847.19 722811.94 722787.68 722763.14 722738.39 722713.51 722708.52 722688.59 722663.78 722639.15 722614.76 722590.68 722566.98 722543.72 722520.97 722498.78 722477.23 722473.00 722455.91 722433.97 722411.43 722388.36 722364.82 722340.88 722316.60 722292.04 722267.28 722242.38 722237.39 722217.45 722192.62 722167.97 722143.57 722119.48 VS ft -1841.35 -1818.18 -1794.57 -1770.56 -1746.23 -1721.64 -1696.86 -1671.96 -1647.00 -1622.06 -1617.08 -1597.14 -1572.17 -1547.24 -1522.39 .,1497.71 -1473.25 -1449.10 -1425.30 -1401.93 -1379.05 -1374.54 -1356.36 -1333.18 -1309.54 -1285.52 -1261.17 -1236.56 -1211.76 -1186.84 -1161.87 -1136.91 -1131.92 -1111.97 -1086.99 -1062.04 -1037.18 -1012.49 DLS degltOOft 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 TFO Tool deg .".,.. 0'_" .~.,,",_'.~_M.',...._...·. ..._,.,..,......" u_" ._."'.. _ 90.00 MWD 89.85 MWD 89.67 MWD 89.49 MWD 89.31 MWD 89.13 MWD 88.95 MWD 88.78 MWD 88.61 MWD 88.44 MWD 88.28 11 270.00 MWD 270.13 MWD 270.29 MWD 270.44 MWD 270.60 MWD 270.75 MWD 270.91 MWD 271.06 MWD 271.20 MWD 271.35 MWD 271.49 12 90.00 MWD 89.89 MWD 89.75 MWD 89.62 MWD 89.48 MWD 89.35 MWD 89.21 MWD 89.08 MWD 88.96 MWD 88.83 MWD 88.71 13 270.00 MWD 270.10 MWD 270.21 MWD 270.33 MWD 270.45 TO! ) ~ BOP-Tree ') Well . Rig Floor Lubricator 10 = 6.375" with 6" Otis Unions /" 171/16" 5000 psi BOP's. 10 = 7.06" I 1/16" 5000 psi, RX-46 I 13" 5000 psi 11/4 Turn L T Valve I I ~ /' . I ~ 1/16" 5000 psi ,RX-24 I /' 7 1/16" 5000 psi (RX-46) or 4 1/16" 5000 psi (RX-39) /' Swab Valve I SSV I Master Valve I Base Flanqe I Page 1 ....---> p055028 DATE 3/12/2003 ~: CHECK NO, 055028 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 3/12/2003 INV# CK030603A PERMIT TO DRILL H 1\\ 1/ , (p rJ f+- ! v'\\ '-~, >,' N.'" O......ì¡ f¡'--~.'.' .~'. p"'-!.~, ~D f,,¡ ~,,"""- i 'bú i, ~(#: ~. .(~ 'L~-m "'1_'__;' ~~ i.~ ~-\:' ...-:'!-"- MAi" ~~ 1.1· ?U\J,' . 1< ¡\I~d~:i ~]I & '!:;~. Ci~:i¡i¡;~'s3iorl A~C.i.'.~¿;~ THE AlTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ PAY: No.P 055028 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT ."--"" ****J\'1"*$1 00.00******* TOTHE ORDER OF: . - . . NQTVALlrj~~~f..~?O nA.:f\i-=,. .. "'\ '.. " '" ";~ :::'.:~:'::: :':";:.:.: ,,::::~: :;:"::::~~~3'~':::;''';'?':~~:;'~:::; ::~,~:}~\\:.::. .' ". .If,.'~ ~.,.. .." ....., \..... ...... ·.N.' ...... i" ~':\';::',>~p~~. .."..::....; ';": :.:" ;~~_~"\: . . . ff ...' . ..... , .. ." . '. ... ." .. \ ~>: :(,::{::~':\:i".~~.:}~:C·\~ :~::'i\~:\~:~'>:~ :~~\: ~..:,¡ ~;~ 11105 50 28111 !i:O ~ ~ 20 ~81151: 0 ~ 278'1 bill 1~ ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME l'¡1u .203 "'ð~7 PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API num ber last two (2) digits are between 60-69) AJR.-C,2A "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production .should continue to be reported as a function· of the original API number stated above. BOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07110/02 ajody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to tbe spacing . exception that may occur. All dry ditcb sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. II? U v,~J</~ /ððl WELL PERMIT CHECKLIST COMPANY lli ¡; X WELL NAME ~ k - E-:2.. A PROGRAM: Exp _ Dev 1 Redrll ~ Re-Enter _ Serv _ Wellbore seg _ FIELD & POOL G9d/7It¡' INITCLASS .l)c-V /-ð// GEOLAREA ~1r;) UNIT# /1t:Çe> ON/OFFSHORE~ ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . ry N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N ~ ~ J_ > ) 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 1)('(. ~ ð3 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . ::t) N (Service Well Only) 13. Well located wlin area & strata authorized by injection order#_ '!. Y, N ,,'1, (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .. .y N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . -¥--N- 16. Surface casing protects all known USDWs. . . . . . . . . . -¥-N- Ai/'A- 17. CMT vol adequate to circulate on conductor & surf csg. . . . '-¥--N-' '" 18. CMT v~1 adéquate to tie-in long s~ring t~ surf csg. . . . . . . . '~ N 19. CMT will cover all known productive hOrizons. . . . . . . . . . ~' N 20. Casing designs adequate for C, T, B & permafrost. . . . . . . @ N 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . OC N C/T D lÁ.. 22. If a re-drill, has a 10-403 for abandonment been approved. .. -* 'J.-. N 23. Adequate wellbore separation proposed.. . . . . . . . . . . . (y) N 24. If diverter required, does it meet regulations. . . . . . . .. . ~I\L/~ \J 25. Drilling fluid program schematic & equip list adequate. . . . . œ N IU Q,A/ rJ111J (S·7 P p~ . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . ~ N P 27. BOPE press rating appropriate; test to 3':;00 psig. " N ms 2 c/--8S P(/· 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 29. Work will occur without operation shutdown. . . . . . . . . . . ; ~ 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y @' 31. Mechanical condition of wells within AOR verified. . . . . . . . -¥-N-N/Æ- 32. Permit can be issued wlo hydrogen sulfide measures. . . . . Y @ 33. Data presented on potential overpressure zones. . . . . . .. ){ 34. Seismic analysis of shallow gas zones. . . . . . . .. .. .. .. .. .. YY~ /U ~ A . 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . 36. Contact namelphone for weekly progress reports. GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING RP~ APPR DATE APPR DATE \ijG.A- 3í7A/O"$ (Service Well Only) GEOLOGY APPR DATE ~J 3~_q/0 ,. (Exploratory Only) Rev: 2/25/03 \well_perm it_checklist UIC ENGINEER COMMISSIONER: Comments/Instructions: TM JH JR SP RR o~\~ DS 0 :f e.1° -:'! SFD_ ""'" MW WA ') ) Welll--!ístory File APPENDIX Information of detailed nature that is not particulady germane to the Well Pennilting Process but is part of the tlistory file. To irTlprove the readability of the Well History file and to sim,plify finding information, infomlation of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. ) ) ~03-- 0<:4'1 \ l <3 ?:J.'1 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Jun 13 10:50:30 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/13 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. . . . . . . . . . . . . . . . . . . . .03/06/13 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 Niakuk MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA NK-62A 500292285201 BP Exploration (Alaska) Inc. Sperry Sun 13-JUN-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 K-MW-2398939 B. JAHN J. EGBEJIMBA MWD RUN 2 K-MW-2398939 B. JAHN J. EGBEJIMBA MWD RUN 3 K-MW-2398939 B. JAHN J. EGBEJIMBA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 K-MW-2398939 B. JAHN J. EGBEJIMBA MWD RUN 9 K-MW-2398939 S. LATZ A. SHERWOOD MWD RUN 10 K-MW-2398939 S. LATZ A. SHERWOOD JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 11 K-MW-2398939 S. LATZ A. SHERWOOD # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 36 12N 15E 1394 884 59.80 .00 .00 # WELL CASING RECORD 1ST STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.125 4.500 11647.0 ) ) 2ND STRING 3RD STRING PRODUCTION STRING 4.125 4.125 4.500 4.500 11647.0 11647.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH SUBSEA (TVDSS). 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK IN THE NK-62 WELLBORE. THE TOP OF THE WHIPSTOCK WAS SET AT ABOUT 11840' MD / 9240' TVDSS. 4. MWD RUNS 1 - 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. UPHOLE TIE-IN DATA (SGRC) ARE INCLUDED WITH RUN 1 DATA. 5. MWD RUN 4 COMPRISED DIRECTIONAL WITH DGR¡ AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RESISTIVITY DATA OVER THE INTERVAL (SENSOR DEPTHS) 11833'MD TO 12262'MD WERE ACQUIRED DURING A MEASUREMENT AFTER DRILLING (MAD) PASS PRIOR TO MWD RUN 4. NO SEPARATE MAD PASS DATA ARE PRESENTED. RESITIVITY DATA GATHERED ON THE MAD PASS ARE INCLUDED WITH RUN 3 DATA. 6. MWD RUN 9 COMPRISED DIRECTIONAL WITH DGR. NK-62A KICKED OFF FROM THE NK-62A PB1 WELLBORE IN AN OPEN HOLE SIDETRACK AT 12720' MD / 9252' TVDSS. THE NK-62A PB1 DATA ARE PRESENTED ELSEWHERE. 7. MWD RUN 10 COMPRISED DIRECTIONAL WITH DGR¡ EWR4. RESISTIVITY DATA OVER THE INTERVAL (SENSOR DEPTHS) 12683'MD TO 12759'MD WERE ACQUIRED DURING A MAD PASS PRIOR TO MWD RUN 10. NO SEPARATE MAD PASS DATA ARE PRESENTED. RESITIVITY DATA GATHERED ON THE MAD PASS ARE INCLUDED WITH RUN 9 DATA. 8. MWD RUN 11 COMPRISED DIRECTIONAL WITH DGR. 9. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN NK-62A ON 27 APRIL 2003. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY DEWAYNE SCHNORR ON 11 JUNE 2003. 10. MWD RUNS 1 - 4 AND 9 - 10 REPRESENT WELL NK-62A WITH API#: 50-029-22852-01. THIS WELL REACHED A TOTAL DEPTH (TO) OF 13149' MD / 9211' TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. 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...... .03/06/13 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM 1 and clipped curves¡ all bit runs merged. .5000 START DEPTH 11722.5 11833.5 11833.5 11833.5 STOP DEPTH 13124.0 13036.5 13036.5 13036.5 RPS RPX ROP $ ) ) 11833.5 11833.5 11865.5 13036.5 13036.5 13150.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 11722.5 11731.0 11740.0 11747.0 11752.0 11758.5 11770.0 11780.5 11784.0 11790.5 11797.5 11840.5 11861.5 11866.0 11876.5 11880.5 11894.5 11898.0 11909.5 11911.5 11916.0 11921. 5 11925.5 11933.5 11949.5 11956.5 11963.5 11981.5 11990.0 12005.5 12036.0 12055.0 12068.5 12076.0 12134.5 12170.0 12197.5 12245.5 12260.5 12270.5 12312.0 12353.0 12359.5 12368.5 12379.0 12388.5 12455.0 12465.0 12467.0 12469.0 12487.0 12499.5 12501. 5 12514.5 12517.0 12539.0 12542.0 12550.0 12551. 5 12559.5 12568.5 12570.0 12580.5 12582.0 12587.0 12653.0 12663.0 GR 11724.0 11733.0 11741.5 11746.0 11753.0 11757.0 11 767.0 11779.0 11781.0 11789.5 11796.0 11841.0 11861.5 11865.0 11876.5 11881.0 11893.0 11896.0 11905.5 11908.0 11913.5 11918.0 11921.0 11929.5 11946.0 11952.0 11959.5 11978.0 11986.5 12000.0 12030.5 12051.5 12064.5 12073.0 12132.0 12167.5 12194.5 12240.0 12255.5 12264.5 12310.0 12350.0 12355.5 12366.0 12377.5 12386.5 12452.0 12460.5 12462.0 12463.5 12481.5 12494.0 12495.5 12510.5 12512.0 12536.5 12541.0 12547.5 12549.0 12557.0 12566.0 12567.0 12579.0 12580.0 12584.0 12649.5 12660.0 ) ') 12684.5 12686.5 12691.5 12707.0 12711.0 12731.0 12773.5 12779.5 12781.0 12810.5 12830.0 12859.0 12889.0 12909.5 12963.5 13034.0 13055.0 13087.5 13150.5 $ 12681. 0 12683.0 12688.5 12704.5 12708.5 12728.5 12769.5 12776.0 12777.5 12807.0 12826.0 12855.0 12883.5 12905.5 12960.0 13032.0 13053.0 13085.5 13148.5 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD $ BIT RUN NO MERGE TOP MERGE BASE 1 11724.0 11932.0 2 11906.5 12014.0 3 11833.5 12293.5 4 12248.0 12720.5 9 12683.5 12791. 0 10 12745.5 13065.0 11 13022.5 13148.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction.. ............. ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11722.5 13150.5 12436.5 2857 11722.5 13150.5 ROP MWD FT/H 0.25 2031.5 57.6364 2571 11865.5 13150.5 GR MWD API 38.93 208.19 80.5694 2736 11722.5 13124 RPX MWD OHMM 0.15 2000 27.945 2407 11833.5 13036.5 RPS MWD OHMM 0.19 2000 15.3707 2407 11833.5 13036.5 RPM MWD OHMM 0.35 2000 14.3988 2407 11833.5 13036.5 RPD MWD OHMM 0.06 2000 19.3229 2407 11833.5 13036.5 FET MWD HOUR 0.48 56 13.6293 2407 11833.5 13036.5 First Reading For Entire File......... .11722.5 Last Reading For Entire File.......... .13150.5 File Trailer ) Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/13 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..... ..03/06/13 Maximum Physical Record..65535 File Type................ LO Previous File Name..... ..STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 ) header data for each bit run in separate files. 1 .5000 START DEPTH 11724.0 11864.5 STOP DEPTH 11906.0 11932.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # 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 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # 17-APR-03 Insite 4.3 Memory 11932.0 11730.0 11932.0 48.8 65.2 TOOL NUMBER 82758 4.125 11647.0 Flo Pro 8.70 60.0 9.0 23000 6.4 .000 .000 .000 .000 .0 148.5 .0 .0 ) 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 .1IN Max frames per record........ ... ..Undefined Absent value................. .... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 Name Service Unit DEPT FT ROP MWD010 FT/H GR MWD010 API Min 11724 0.33 39.98 Max 11932 96.85 208.19 Mean 11828 31. 5985 103.964 First Reading For Entire File...... ... .11724 Last Reading For Entire File....... ... .11932 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/13 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...... .03/06/13 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 Nsam 417 136 293 ) First Reading 11724 11864.5 11724 Last Reading 11932 11932 11906 header data for each bit run in separate files. 2 .5000 START DEPTH 11906.5 11932.5 STOP DEPTH 11987.0 12014.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: 18-APR-03 Insite ) 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: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # 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 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value... .................. .-999 Depth Units.......... . . . . . . . . . . . . . Datum Specification Block sub-type...O 4.3 Memory 12014.0 11932.0 12014.0 72.7 88.6 TOOL NUMBER 82758 4.125 11647.0 Flo Pro 8.80 60.0 9.0 23000 6.4 .000 .000 .000 .000 Name Service Order DEPT ROP MWD020 GR MWD020 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 ) .0 148.5 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11906.5 12014 11960.3 216 11906.5 12014 ROP MWD020 FT/H 0.25 131.48 62.9691 164 11932.5 12014 GR MWD020 API 42.72 94.29 65.1916 162 11906.5 11987 First Reading For Entire File......... .11906.5 Last Reading For Entire File........ ...12014 File Trailer Service name......... ... .STSLIB.003 Service Sub Level Name... ) version Number... .... ....1.0.0 Date of Generation.. .....03/06/13 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...... .03/06/13 Maximum Physical Record. .65535 File Type............ ....LO Previous File Name... ....STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 4 ) header data for each bit run in separate files. 3 .5000 START DEPTH 11833.5 11833.5 11833.5 11833.5 11833.5 11987.5 12014.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 12263.0 12261. 5 12261.5 12261.5 12261.5 12266.0 12293.5 TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # 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-APR-03 Insite 4.3 Memory 12293.0 12014.0 12293.0 91.2 97.1 TOOL NUMBER 82758 144955 4.125 11647.0 Flo Pro 9.80 20.0 9.0 160000 6.2 .000 .000 .000 .000 .0 163.0 .0 .0 ) ) 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 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11833.5 12293.5 12063.5 921 11833.5 12293.5 ROP MWD030 FT/H 0.53 235.94 58.6988 559 12014.5 12293.5 GR MWD030 API 40.82 81.01 66.2728 558 11987.5 12266 RPX MWD030 OHMM 0.15 2000 62.918 857 11833.5 12261. 5 RPS MWD030 OHMM 0.19 2000 25.8917 857 11833.5 12261. 5 RPM MWD030 OHMM 0.16 2000 21. 3787 857 11833.5 12261.5 RPD MWD030 OHMM 0.06 2000 33.0607 857 11833.5 12261. 5 FET MWD030 HOUR 17.14 56 32.7756 860 11833.5 12263 First Reading For Entire File.. ....... .11833.5 Last Reading For Entire File... ...... ..12293.5 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/13 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/13 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Corrunent Record FILE HEADER FILE NUMBER: 5 RAW MWD ) ) header data for each bit run in separate files. 4 .5000 Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX FET RPD RPM RPS ROP $ START DEPTH 12248.0 12262.0 12262.0 12262.0 12262.0 12262.0 12294.0 STOP DEPTH 12720.0 12720.5 12720.5 12720.5 12720.5 12720.5 12720.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # 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 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.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing... ............ ..... .60 .1IN Max frames per record............ .Undefined Ab s en t val u e . . . . . . . . . . . . . . . . . . . . . . - 9 9 9 Depth Units....................... Datum Specification Block sub-type...O 20-APR-03 Insite 4.3 Memory 12720.0 12293.0 12720.0 83.7 100.1 TOOL NUMBER 93091 144955 4.125 11647.0 Flo Pro 9.80 20.0 8.5 155000 7.6 .060 .030 .090 .080 68.0 155.9 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel ) ) DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12248 12720.5 12484.3 946 12248 12720.5 ROP MWD040 FT/H 2.05 240.93 51.7845 853 12294 12720 GR MWD040 API 41.36 139.77 88.6354 945 12248 12720 RPX MWD040 OHMM 1. 36 343.57 9.17329 918 12262 12720.5 RPS MWD040 OHMM 1. 89 42.93 9.34532 918 12262 12720.5 RPM MWD040 OHMM 2.5 34.96 10.1199 918 12262 12720.5 RPD MWD040 OHMM 4.61 26.61 11. 0953 918 12262 12720.5 FET MWD040 HOUR 0.58 17.62 2.36712 918 12262 12720.5 First Reading For Entire File.. ....... .12248 Last Reading For Entire File... ....... .12720.5 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation.. .... .03/06/13 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/06/13 Maximum Physical Record..65535 File Type.... .......... ..LO Previous File Name... ....STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPX RPS RPD RPM GR ROP $ 6 header data for each bit run in separate files. 9 .5000 START DEPTH 12683.5 12683.5 12683.5 12683.5 12683.5 12692.5 12720.5 STOP DEPTH 12759.0 12759.0 12759.0 12759.0 12759.0 12765.0 12791.0 # 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): 24-APR-03 Insite 4.3 Memory 12791. 0 12720.0 ) BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # 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 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.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point......... .... .Undefined Frame Spacing................ .... .60 .1IN Max frames per record... ......... .Undefined Absent value..................... .-999 Depth Units.. . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 ') 12791. 0 87.2 91.1 TOOL NUMBER 82758 144955 3.750 11647.0 Flo Pro 10.80 65.0 8.5 182000 4.8 .000 .000 .000 .000 .0 159.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD090 FT/H 4 1 68 4 2 GR MWD090 API 4 1 68 8 3 RPX MWD090 OHMM 4 1 68 12 4 RPS MWD090 OHMM 4 1 68 16 5 RPM MWD090 OHMM 4 1 68 20 6 RPD MWD090 OHMM 4 1 68 24 7 FET MWD090 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12683.5 127 91 12737.3 216 12683.5 12791 ROP MWD090 FT/H 0.76 58.45 31.2018 142 12720.5 12791 GR MWD090 API 78.78 135.06 109.1 146 12692.5 12765 RPX MWD090 OHMM 3.4 48.73 7.70572 152 12683.5 12759 RPS MWD090 OHMM 5.77 62.62 8.93408 152 12683.5 12759 RPM MWD090 OHMM 6.22 58.01 9.35072 152 12683.5 12759 RPD MWD090 OHMM 7.46 26.26 9.46599 152 12683.5 12759 FET MWD090 HOUR 10.14 114.49 61.5953 152 12683.5 12759 ') ') First Reading For Entire File......... .12683.5 Last Reading For Entire File.......... .12791 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation... ... .03/06/13 Maximum Physical Record. .65535 File Type............ ... .LO Next File Name......... ..STSLIB.007 Physical EOF File Header Service name......... ... .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .... .03/06/13 Maximum Physical Record. .65535 File Type..... .......... .LO Previous File Name..... ..STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 7 header data for each bit run in separate files. 10 .5000 START DEPTH 12745.5 12759.5 12759.5 12759.5 12759.5 12759.5 12791. 5 STOP DEPTH 13022.0 13034.5 13034.5 13034.5 13034.5 13034.5 13065.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 25-APR-03 Insite 4.3 Memory 13065.0 12791. 0 13065.0 93.8 97.3 # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RES IS. 4 TOOL NUMBER 93091 144955 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.125 11647.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): Flo Pro 10.80 55.0 9.0 182000 4.8 ') ') RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .120 .050 .140 .170 68.0 162.0 68.0 68.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction...... ......... ..Down Optical log depth units.... ..... ..Feet Data Reference Point.... ... ...... .Undefined Frame Spacing... ........... ...... .60 .1IN Max frames per record............ .Undefined Absent value.... ..... ............ .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD100 FT/H 4 1 68 4 2 GR MWD100 API 4 1 68 8 3 RPX MWD100 OHMM 4 1 68 12 4 RPS MWD100 OHMM 4 1 68 16 5 RPM MWD100 OHMM 4 1 68 20 6 RPD MWD100 OHMM 4 1 68 24 7 FET MWD100 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12745.5 13065 12905.3 640 12745.5 13065 ROP MWD100 FT/H 1.1 475.65 64.5245 548 12791. 5 13065 GR MWD100 API 38.93 138.67 68.5098 554 12745.5 13022 RPX MWD100 OHMM 1. 52 1437.27 11. 9106 551 12759.5 13034.5 RPS MWD100 OHMM 2.7 44.4 9.33811 551 12759.5 13034.5 RPM MWD100 OHMM 3.29 62.39 11. 3538 551 12759.5 13034.5 RPD MWD100 OHMM 4.12 57.77 13.066 551 12759.5 13034.5 FET MWD100 HOUR 0.48 10.14 2.22423 551 12759.5 13034.5 First Reading For Entire File......... .12745.5 Last Reading For Entire File.......... .13065 File Trailer Service name............ .STSLIB.007 Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation... ... .03/06/13 Maximum Physical Record. .65535 File Type............ ... .LO Next File Name.. ........ .STSLIB.008 Physical EOF File Header Service name.... ........ .STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .03/06/13 Maximum Physical Record. .65535 ) File Type................ LO Previous File Name...... .STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 8 ) header data for each bit run in separate files. 11 .5000 START DEPTH 13022.5 13065.5 STOP DEPTH 13122.0 13148.5 # 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: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # 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 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units...... .... .Feet Data Reference Point.... ........ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O 26-APR-03 Insite 4.3 Memory 13149.0 13065.0 13149.0 98.1 99.9 TOOL NUMBER 82758 4.125 11647.0 Flo Pro 10.80 65.0 9.0 182000 4.8 .000 .000 .000 .000 .0 162.0 .0 .0 ) ') Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 11 0 FT/H 4 1 68 4 2 GR MWD11 0 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13022.5 13148.5 13085.5 253 13022.5 13148.5 ROP MWD 11 0 FT/H 9.58 2031. 5 103.446 167 13065.5 13148.5 GR MWD 11 0 API 56.36 122.52 83.9668 200 13022.5 13122 First Reading For Entire File. ........ .13022.5 Last Reading For Entire File.. ....... ..13148.5 File Trailer Service name............ .STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/13 Maximum Physical Record. .65535 File Type............... .LO Next File Name. ......... .STSLIB.009 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/13 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/13 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... ........ ....UNKNOWN Continuation Number... ...01 Next Reel Name........ ...UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ) lo~-D4-l \ ) ?33 ~ Sperry-Sun Drilling Services LIS Scan utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Jun 13 10:54:43 2003 Reel Header Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/13 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. . . . . . . . . . . . . . . . . . . . .03/06/13 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 Niakuk MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA NK-62Apbl 500292285270 BP Exploration (Alaska) Inc. Sperry Sun 13-JUN-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 K-MW-2398939 B. JAHN J. EGBEJIMBA MWD RUN 2 K-MW-2398939 B. JAHN J. EGBEJIMBA MWD RUN 3 K-MW-2398939 B. JAHN J. EGBEJIMBA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 K-MW-2398939 B. JAHN J. EGBEJIMBA MWD RUN 5 K-MW-2398939 B. JAHN A. SHERWOOD MWD RUN 6 K-MW-2398939 B. JAHN A. SHERWOOD # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 36 12N 15E 1394 884 59.80 .00 .00 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 4.125 4.125 4.125 CASING SIZE (IN) 4.500 4.500 4.500 DRILLERS DEPTH (FT) 11647.0 11647.0 11647.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE ) ) MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH SUBSEA (TVDSS). 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK IN THE NK-62 WELLBORE. THE TOP OF THE WHIPSTOCK WAS SET AT ABOUT 11840' MD / 9240' TVDSS. 4. MWD RUNS 1 - 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. UPHOLE TIE-IN DATA (SGRC) ARE INCLUDED WITH RUN 1 DATA. 5. MWD RUN 4 COMPRISED DIRECTIONAL WITH DGR; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RESISTIVITY DATA OVER THE INTERVAL (SENSOR DEPTHS) 11833'MD TO 12262'MD WERE ACQUIRED DURING A MEASUREMENT AFTER DRILLING (MAD) PASS PRIOR TO MWD RUN 4. NO SEPARATE MAD PASS DATA ARE PRESENTED. RESITIVITY DATA GATHERED ON THE MAD PASS ARE INCLUDED WITH RUN 3 DATA. 6. MWD RUNS 5 - 6 COMPRISED DIRECTIONAL WITH DGR. NK-62A KICKED OFF FROM THE NK-62A PB1 WELLBORE IN AN OPEN HOLE SIDETRACK AT 12720' MD / 9252' TVDSS. THE NK-62A DATA ARE PRESENTED ELSEWHERE. 7. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN IN NK-62A ON 27 APRIL 2003. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE PDC LOG DATA WERE PROVIDED BY DEWAYNE SCHNORR ON 11 JUNE 2003. 8. MWD RUNS 1 - 6 REPRESENT WELL NK-62A PB1 WITH API#: 50-029-22852-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13126' MD / 9277' TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. 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...... .03/06/13 Maximum Physical Record. .65535 File Type........ ...... ..LO Previous File Name..... ..STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX FET ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 11722.5 11833.5 11833.5 11833.5 11833.5 11833.5 11865.5 STOP DEPTH 13099.5 12848.5 12848.5 12848.5 12848.5 12848.5 13126.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 11722.5 11731.0 11740.0 11747.0 GR 11724.0 11733.0 11741.5 11746.0 11752.0 11758.5 11770.0 11780.5 11784.0 11790.5 11797.5 11840.5 11861. 5 11866.0 11876.5 11880.5 11894.5 11898.0 11909.5 11911.5 11916.0 11921.5 11925.5 11933.5 11949.5 11956.5 11963.5 11981.5 11990.0 12005.5 12036.0 12038.5 12055.0 12068.5 12076.0 12134.5 12170.0 12197.5 12245.5 12260.5 12270.5 12312.0 12353.0 12359.5 12368.5 12379.0 12388.5 12455.0 12465.0 12467.0 12469.0 12487.0 12499.5 12501. 5 12514.5 12517.0 12539.0 12542.0 12550.0 12551.5 12559.5 12568.5 12570.0 12580.5 12582.0 12587.0 12653.0 12663.0 12684.5 12686.5 12691.5 12698.0 12707.0 12711. 0 12715.5 12718.5 13126.5 $ # MERGED DATA SOURCE ) ) 11753.0 11757.0 11 767.0 11779.0 11781.0 11789.5 11796.0 11841.0 11861.5 11865.0 11876.5 11881.0 11893.0 11896.0 11905.5 11908.0 11913.5 11918.0 11921.0 11929.5 11946.0 11952.0 11959.5 11978.0 11986.5 12000.0 12030.5 12032.5 12051. 5 12064.5 12073.0 12132.0 12167.5 12194.5 12240.0 12255.5 12264.5 12310.0 12350.0 12355.5 12366.0 12377.5 12386.5 12452.0 12460.5 12462.0 12463.5 12481. 5 12494.0 12495.5 12510.5 12512.0 12536.5 12541. 0 12547.5 12549.0 12557.0 12566.0 12567.0 12579.0 12580.0 12584.0 12649.5 12660.0 12681.0 12683.0 12688.5 12695.0 12704.5 12708.5 12713.5 12717.0 13125.0 ) ) PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 11724.0 11932.0 MWD 2 11906.5 12014.0 MWD 3 11833.5 12293.5 MWD 4 12244.0 12879.5 MWD 5 12835.0 13070.5 MWD 6 13043.0 13125.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type............. .....0 Data Specification Block Type.....O Logging Direction........... .... ..Down Optical log depth units......... ..Feet Data Reference Point............ ..Undefined Frame Spacing................... ..60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units..................... . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11722.5 13126.5 12424.5 2809 11722.5 13126.5 ROP MWD FT/H 0.25 295.47 53.8607 2523 11865.5 13126.5 GR MWD API 39.98 208.19 88.1517 2687 11722.5 13099.5 RPX MWD OHMM 0.15 2000 30.6287 2031 11833.5 12848.5 RPS MWD OHMM 0.19 2000 16.4617 2031 11833.5 12848.5 RPM MWD OHMM 0.35 2000 14.8358 2031 11833.5 12848.5 RPD MWD OHMM 0.06 2000 20.2049 2031 11833.5 12848.5 FET MWD HOUR 0.58 56 15.3588 2031 11833.5 12848.5 First Reading For Entire File........ ..11722.5 Last Reading For Entire File.......... .13126.5 File Trailer Service name......... ....STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/13 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...... .03/06/13 Maximum Physical Record. .65535 File Type............... .LO Previous File Name... ... .STSLIB.001 Comment Record FILE HEADER ) FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 ) header data for each bit run in separate files. 1 .5000 START DEPTH 11724.0 11864.5 STOP DEPTH 11906.0 11932.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # 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 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. ...... .... ..... .Down Optical log depth units.......... .Feet Data Reference Point....... ...... .Undefined Frame Spacing... ......... ........ .60 .1IN Max frames per record... ......... .Undefined Absent value. ......... ........... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 17-APR-03 Insite 4.3 Memory 11932.0 11730.0 11932.0 48.8 65.2 TOOL NUMBER 82758 4.125 11647.0 Flo Pro 8.70 60.0 9.0 23000 6.4 .000 .000 .000 .000 .0 148.5 .0 .0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 ') Name Service Unit DEPT FT ROP MWDOI0 FT/H GR MWDOI0 API Min 11724 0.33 39.98 Max 11932 96.85 208.19 First Reading For Entire File.. .... ....11724 Last Reading For Entire File.......... .11932 File Trailer Service name........ .... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .... .03/06/13 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..... ..03/06/13 Maximum Physical Record. .65535 File Type............... .LO Previous File Name..... ..STSLIB.002 Corrunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 Mean 11828 31.5985 103.964 Nsam 417 136 293 ) First Reading 11724 11864.5 11724 Last Reading 11932 11932 11906 header data for each bit run in separate files. 2 .5000 START DEPTH 11906.5 11932.5 STOP DEPTH 11987.0 12014.0 # 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: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # 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): 18-APR-03 Insite 4.3 Memory 12014.0 11932.0 12014.0 72.7 88.6 TOOL NUMBER 82758 4.125 11647.0 Flo Pro 8.80 60.0 ) 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 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type. ..0 Name Service Order DEPT ROP MWD020 GR MWD020 9.0 23000 6.4 .000 .000 .000 .000 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API Min 11906.5 0.25 42.72 Max 12014 131. 48 94.29 First Reading For Entire File......... .11906.5 Last Reading For Entire File.......... .12014 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/13 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...... .03/06/13 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FI LE HEADER FILE NUMBER: 4 RAW MWD Mean 11960.3 62.9691 65.1916 Nsam 216 164 162 ') .0 148.5 .0 .0 First Reading 11906.5 11932.5 11906.5 Last Reading 12014 12014 11987 ) Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM RPD RPS FET RPX GR ROP $ ) header data for each bit run in separate files. 3 .5000 START DEPTH 11833.5 11833.5 11833.5 11833.5 11833.5 11987.5 12014.5 STOP DEPTH 12261.5 12261. 5 12261.5 12263.0 12261. 5 12266.0 12293.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # 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 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point....... .... ...Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value................... ...-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 19-APR-03 Insite 4.3 Memory 12293.0 12014.0 12293.0 91. 2 97.1 TOOL NUMBER 82758 144955 4.125 11647.0 Flo Pro 9.80 20.0 9.0 160000 6.2 .000 .000 .000 .000 .0 163.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel ) ') DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11833.5 12293.5 12063.5 921 11833.5 12293.5 ROP MWD030 FT/H 0.53 235.94 58.6988 559 12014.5 12293.5 GR MWD030 API 40.82 81.01 66.2728 558 11987.5 12266 RPX MWD030 OHMM 0.15 2000 62.918 857 11833.5 12261. 5 RPS MWD030 OHMM 0.19 2000 25.8917 857 11833.5 12261. 5 RPM MWD030 OHMM 0.16 2000 21. 3787 857 11833.5 12261. 5 RPD MWD030 OHMM 0.06 2000 33.0607 857 11833.5 12261. 5 FET MWD030 HOUR 17.14 56 32.7756 860 11833.5 12263 First Reading For Entire File. ..... ....11833.5 Last Reading For Entire File....... ....12293.5 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/13 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name......... ... .STSLIB.005 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation.. .... .03/06/13 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name..... ..STSLIB.004 Comment Record FI LE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE Rap GR FET RPD RPM RPS RPX $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 12244.0 12248.0 12262.0 12262.0 12262.0 12262.0 12262.0 STOP DEPTH 12879.5 12834.5 12847.0 12847.0 12847.0 12847.0 12847.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): 20-APR-03 Insite 4.3 Memory 12879.0 12293.0 ) BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # 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 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 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units... . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 12879.0 83.7 100.1 TOOL NUMBER 93091 144955 4.125 11647.0 Flo Pro 9.80 20.0 8.5 155000 7.6 .060 .030 .090 .080 68.0 155.9 68.0 68.0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12244 12879.5 12561. 8 1272 12244 12879.5 ROP MWD040 FT/H 2.05 240.93 50.1127 1272 12244 12879.5 GR MWD040 API 41.36 139.77 92.9848 1174 12248 12834.5 RPX MWD040 OHMM 1. 36 343.57 9.03926 1171 12262 12847 RPS MWD040 OHMM 1. 89 42.93 9.23047 1171 12262 12847 RPM MWD040 OHMM 2.5 48.53 9.97907 1171 12262 12847 RPD MWD040 OHMM 4.61 26.61 10.7527 1171 12262 12847 FET MWD040 HOUR 0.58 17.62 2.24161 1171 12262 12847 ) First Reading For Entire File......... .12244 Last Reading For Entire File.......... .12879.5 File Trailer Service name........... ..STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/13 Maximum Physical Record. .65535 File Type..... ...... .... .LO Next File Name....... ... .STSLIB.006 Physical EOF File Header Service name........... ..STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/13 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 6 ) header data for each bit run in separate files. 5 .5000 START DEPTH 12835.0 12880.0 STOP DEPTH 13043.5 13070.5 # 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: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (8): 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: # 21-APR-03 Insite 4.3 Memory 13071. 0 12879.0 13071. 0 82.6 88.9 TOOL NUMBER 82758 3.750 11647.0 Flo Pro 10.80 70.0 8.5 192000 4.9 .000 .000 .000 .000 .0 159.0 .0 .0 ') 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.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing........ ............ .60 .1IN Max frames per record............ .Undefined Absent value..... ................ .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD050 GR MWD050 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 Name Service Unit DEPT FT ROP MWD050 FT/H GR MWD050 API Min 12835 5.89 59.09 Max 13070.5 295.47 139.63 Mean 12952.8 66.298 97.6195 First Reading For Entire File......... .12835 Last Reading For Entire File.......... .13070.5 File Trailer Service name..... ....... .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/13 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.007 Physical EOF File Header Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/13 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.006 Corrunent Record FILE HEADER FI LE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 7 Nsam 472 382 418 ') First Reading 12835 12880 12835 Last Reading 13070.5 13070.5 13043.5 header data for each bit run in separate files. 6 .5000 START DEPTH 13043.0 13071.0 STOP DEPTH 13098.0 13125.0 ) # 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: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # 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 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 .1IN Max frames per record............ .Undefined Absent value.................... ..-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD060 GR MWD060 22-APR-03 Insite 4.3 Memory 13126.0 13071. 0 13126.0 87.8 87.8 TOOL NUMBER 82758 3.750 11647.0 Flo Pro 10.80 65.0 8.5 155000 4.9 .000 .000 .000 .000 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 Name Service Unit DEPT FT ROP MWD060 FTIH GR MWD060 API Min 13043 0.42 60.44 Max 13125 69.31 160.23 First Reading For Entire File......... .13043 Last Reading For Entire File........ ...13125 Mean 13084 36.9196 94.7747 Nsam 165 109 111 ) .0 167.0 .0 .0 First Reading 13043 13071 13043 Last Reading 13125 13125 13098 ) ') File Trailer Service name.......... ...STSLIB.007 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.. .... .03/06/13 Maximum Physical Record..65535 File Type.............. ..LO Next File Name......... ..STSLIB.008 Physical EOF Tape Trailer Service name.... ..... ....LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/13 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name........... .... . UNKNOWN Continuation Number.. ....01 Next Tape Name......... ..UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/13 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number.... ..01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File