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Home My WebLink About201-123Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:201-123 6.50-029-23028-00-00 PRUDHOE BAY, BOREALIS OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 9020 8893 7064 None None None None Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 93 20" 27 - 120 27 - 120 1490 470 Surface 2793 7-5/8" 26 - 2819 26 - 2560 6890 4790 Intermediate Production 8968 5-1/2" x 3-1/2" 24 - 8992 24 - 7159 7000, 10160 4990, 10530 Perforation Depth: Measured depth: 8467 - 8521 feet True vertical depth:6649 - 6702 feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# L-80 22 - 8315 22 - 6500 Packers and SSSV (type, measured and true vertical depth) No Packer Liner 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 3771079458348 4814820 521 13799 13 1149 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Brodie Wages david.wages@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:(907)564-5006 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured7186 Sundry Number or N/A if C.O. Exempt: N/A No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Install GLM Patch Operations shutdown Change Approved Program 5 n/a Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028241 & 028239 PBU L-110 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:12 pm, Oct 13, 2020 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.10.13 12:30:53 - 08'00' Stan Golis DSR-10/15/2020 SFD 10/15/2020 MGR13OCT2020 RBDMS HEW 11/13/2020 ACTIVITY DATE SUMMARY 9/15/2020 T/I/O=275/262/280. Attempt MIT-T but IA tracked while pressuring TBG. Pumped 2 bbls crude down tbg, IA tracked tubing indicating swell packing dglv in sta#4 failed. Stopped increasing pressure at 1200 psi and bleed down to starting pressures. Final WHP's 282/284/280 9/26/2020 ...WELL S/I ON ARRIVAL... (patch-tbg). SET 3-1/2" WHIDDON CATCHER SUB ON PX @ 8,387' MD. PULLED ST #3 INT-DGLV @ 6,969' MD. MADE 3 ATTEMPTS TO PULL ST #4 @ 4,259' MD. ...JOB CONTINUED ON 9/27/20 WSR... 9/27/2020 ...JOB CONTINUED FROM 9/26/20 WSR... (patch tbg-integrity) PULLED ST #4 INT-OIL SWELL @ 4,259' MD. (picture of swell packing in well pictures folder) SET ST #3 INT-OGLV (22/64") @ 6,969' MD. PULLED EMPTY WHIDDON CATCHER @ 8,360' SLM. PULLED P-PRONG FROM PX PLUG @ 8,387' MD. ***CONTINUE JOB ON 9/28/20 WSR*** 9/28/2020 ...JOB CONTINUED FROM 9/27/20 WSR... (patch tbg-integrity). PULLED 3-1/2" PX PLUG BODY @ 8,376' MD. SET FOUR TRIP 3-1/2" POGLM ACROSS ST #4. LOWER ELEMENT at 4,267' MD. UPPER ELEMENT AT 4,242' MD. BK-LGLV (16/64", 1588#) LOADED INSIDE 2-3/8" IN SITU GLM. ***JOB COMPLETE.*** WELL LEFT S/I ON DEPARTURE 10/1/2020 T/I/O = 1220/670/380. Temp = 92°. TIFL (UE). AL open @ CV. IA FL @ 200' (3 bbls). Stacked well out to 1560/660/380. Bled IAP to L-205 production to 320 psi in 30 min. IA FL unchanged. Monitored for 1 hr. IAP decreased 10 psi, IA FL unchanged. Released to Ops. Final WHPs = 1590/310/360. SV = C. WV, SSV, MV = O. IA, OA = OTG. 23:00 Daily Report of Well Operations PBU L-110 Imam_. Project Well History File Covel, age 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. _~ ~ J._- ]_~_"~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: ~ Diskettes, No. I [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: NOTES: [] Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~WINDY Scanning Preparation BY: Production Scanning Stage I PAGE COUNT FROM scANNED F~LE: ...... ~!. PAGE COU.T,,ATC.ES .UMBER ~N SCA..~NG PREP^RATiON' "~' YES BY: BEVERL~INCENT SHERYL MARIA WINDY Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~ YES (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO ReScanned (indh/idual p;~g.,~, I:~pecial ,,tte, t~tiot~] ,.~c¢~.tm#fg ct~mph~ed) RESCANNEDBT; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE; Is~ Quality Checked 1211 O/02Rev3NOTScanned.wpd r riA 7 t G #° z SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 ` B PHONE (907) 279 -1433 FAX (907) 276-7542 Terrie Hubble I I f Drilling Technologist �� BP Exploration (Alaska), Inc. P.O. Box 196612 4 I Anchorage, AK 99519 -6612 ao Re: Prudhoe Bay Field, Polaris Oil Pool, PBU L -110 Y > Sundry Number: 312 -262 Dear Ms. Hubble: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy ' . Foerster Chair DATED this day of July, 2012. Encl. `�+E %VE STATE OF ALASKA • , AL KA OIL AND GAS CONSERVATION COMMISSION �� 17 2012 APPLICATION FOR SUNDRY APPROVAL ,) 2 �,c 20 AAC 25.280 AO 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ® Other Correct RKB to 77.1' ' 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 201 - 123 3. Address: 6. API Number: ®D evelopment ❑ ❑ Service ❑ Stratigraphic P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 23028 -00-00 ` 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU L -110 ' Spacing Exception Required? ❑ Yes 0 No 9. Property Designation: 10. Field / Pool(s): ADL 028239 & 028241 • Prudhoe Bay / Borealis • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9020' 7186' ' _ 8893' 7064' None None Casing Length Size MD TVD Burst Collapse Structural _ Conductor 93' 20" 117' 117' 1490 470 Surface 2793' 7 -5/8" 2819' 2560' 6890 4790 Intermediate Production 8968' 5 - 1/2" x 3 - 1/2" 8992' 7159' 7000 4990 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8467' - 8521' 6649' - 6702' 3 - 1/2 ", 9.2# L - 80 8315' Packers and SSSV Type: None Packers and SSSV None . MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: . ® Description Summary of Proposal ❑ B Sketch ❑ Detailed Operations Program ❑ Exploratory ® Development ❑ Service ❑ Str 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David G. Dempsey, 564 -4280 Printed Name Terrie Hubble Title Drilling Technologist Prepared By Name /Number: Signature ° EL e Phone 564 - 4628 Date °'11? ILOIZ... T Hubble, 564 -4628 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness � 2 .Z �� Sundry Number: ❑ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: Subsequent Form Required: APPROVED BY 7 Approved By: Revised ( 7 4 r J j COMMISSIONER THE COMMISSION Date / - ��- 2010 a.V Jr- OR1G1NIAL Submit In Duplicat /7 ./ , 0 74/4 (1:' by ‚ 4 David G. Dempsey •�0 Technologist New Wells Delivery Team BP Exploration (Alaska) Inc. Direct: (907) 564 -4280 900 East Benson Boulevard David.Dem se 1 @b com P.O. Box 1, Alaska y p• Anchorage, Alaska 99519 -6612 (907) 561-5111 July 12, 2012 Alaska Oil & Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 Reference: API # 50- 029 - 23028 -00 -00 Permit # 201 -123 Mr. Guy Schwartz: I am writing to report a change in the official RKB for L -110 from 71.7' to 77.1'. Although the official records report 71.7', BP has determined it was originally recorded incorrectly. I have researched this problem and have, with consensus, reached the conclusion that the original RKB was in fact 77.1. i/ In comparing the RKB to the RKB of wells drilled at the same time with Nabors 9ES in the same vicinity, 71.7' is 4.5' to 5' lower than the RKB of the other four wells. As you can see by the chart below, with L -110 corrected to 77.1' RKB, that it more closely aligns with the neighboring wells drilled by the same rig in the same general time frame. Calculated SW_Name Original Well Original RKB Distance RKB Original Base Ground Level Spud Date (msl) to BF (ft) Flange (msl) Elevation (msl) L -116 07/02/2001 76.7' 24.20' 52.50' 48.2' L -110 07/16/2001 77.1' 24.20' 52.90' 48.2' L -114 08/04/2001 76.3' 24.20' 52.10' 47.8' L -111 02/21/2002 76.2' 24.38' 51.82' 48' L -109 05/30/202 76.4' 24.94' 51.46' 47.9' The Well Site Geologist' End -of -Well Report, which is written on the rig at the time of drilling, reports an RKB of 77.1' as does the welibore schematic. It is our opionion that this evidence justifies changing the RKB to 77.1'. Thank you very much for your assistance in this matter. Sincerely, David G. Dempsey Distribution Well Files — Joe Lastufka PDC / Partner Distribution Chris Tzvetcoff N/S Wells Tech il■ TREF =. 3-1(8" CM/ 0 . WELL = FMC SAFETY NOTES: ACTUATOR = BAKER L- 1 1 0 I KB. ELEV = 77.10 BF, ELEV = 52.9' KOP = 1000' Max Angle = 52' @ 4634'‘ —I 1015 I-17-5/8" TAM PORT COLLAR 1 Datum MD = 8490 Datum TVD = 6600' SS rail 2310 H3-1/2' HES XDB BVN, ID = 2.75" 1 17-5/8" CSG, 29.79, L-80, ID = 6.875" I 2819' 1 GAS LIFT MANDRELS !Minimum ID = 2.75" @ 2310' ST IVI) ND DEV TYPE VLV LATCH FORT DATE 3-1/2" HES SSSVN 4 4259 3510 49 KBG-2 DOME BTM 16 09/06/10 3 6969 5298 39 KBG-2 SO BTM 20 09/06/10 2 8107 6296 13 KBG-2 WY BTM 0 08/02/01 1 8226 6412 12 KBG-2 DAY BTM 0 08/02/01 I 1 1 I 8251' 1-13-1/2" HES X NIP, ID = 2.7F i:I/FCSG, 15.5#, L-80, BTC, ID = 4.950" H 8302' 13-1/7 TBG, 9.2#, L-80, IBT-M, .0087 bpf, ID = 2.992" H 8303' 1 h 1 13304' IHTOP OF BKR PBR, ID = 4.00" I5-1/2' IT CSGXO, ID= 23 I–I 8315' 1— 8315' H3-1/2" BKR SEAL ASSY, ID = 3.00 I 1 I 8388' 1–i 3-1/2" HES X NIP, ID = 2.75" I PERFORATION SUMMARY 1 n1313 3-1/2" HES X NIP, ID = 2.75" I REF LOG: ANGLE AT TOP PUT; 12° @ 846T I 8428' H20 PUP JT W / RA TAG I Note: Refer to Production DB for historical perf data SIZE ' SFf , INTERVAL ' Cion/Sqz - DATE 2-1/2" 6 8467 - 8521 0 09/15/01 _ a i 8821' H10' PUP JT W/ RA TAG I PBTD 8893' . 1 ***** ••••• 1.•••• Att•Al 13-1/2" CSG, 9.2#, L-80, NSCT, ID = 2.992" H 8992' I DATE REV BY CONVENTS 1 DATE REV BY COMMENTS BOREALIS UNfT 08/02101 9ES ORIGINAL COMPLETION 09/23/10 CJN/PJC GLV C/0 (09/06/10) WELL: L-110 09/15/01 JLWKK PERFS FERMT Kb: '01 1230 12130/02 DAC/KK GLV CORRECTIONS API No: 50-029-23028-00 04/08/03 DRS/TP WD/MD CORRECTIONS SEC 34, Ti 2N R11E 2365' NSL & 3772' WEL 11/06/09 BSE/SV GLV C/0/11/D CORR (10/31/09) 05/31/10 GF/PJC GLV C/0 (0506/10) BP Exploration (Alaska) i _ OPERABLE: Producer L-110 (PTD #11230) Tubing Integrity Confirmed • Page 1 of 2 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Saturday, May 08, 2010 2:09 PM ` `~~ ~Iizi,o To: Regg, James B (DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); AK, OPS GC2 OSM; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, OPS GC2 Facility OTL; AK, OPS GG2 Wellpad Lead; AK, RES GPB West Production Optimization Engineer; AK, RES GPB East Production Optimization Engineer; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; Daniel, Ryan Cc: AK, D&C Well Integrity Coordinator; Oakley, Ray (PRA); Quy, Tiffany; Janowski, Carrie; Holt, Ryan P (ASRC) Subject: OPERABLE: Producer L-110 (PTD #2011230) Tubing Integrity Confirmed Attachments: L-110 TIO Plot 04-23-10.doc; L-110.pdf .~ All, Producer L-110 (PTD #2011230) passed aMIT-IA to 3000 psi on 5/7/10 confirming tubing integrity after replacingthe OGLV. The well has been classified as O~rahle. ~~ Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 ~~~~-~~~, ~~~ ~~`:. ' ~~`.~' ~~';! From: NSU, ADW Well Integrity Engineer Sent: Saturday, April 24, 2010 7:32 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA) <guy.schwartz@alaska.gov>'; 'Maunder, Thomas E (DOA)'; NSU, ADW Well Integrity Engineer; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers; Rossberg, R Steven; Engel, Harry R Cc: NSU, ADW Well Integrity Engineer; Oakley, Ray (PRA); Quy, Tiffany Subject: UNDER EVALUATION: L-110 (PTD #2011230) for Sustained Casing Pressure on the IA All, Producer L-110 (PTD #2011230) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing/IA/OA equal to 380/2020/240 psi on 04/21/10. A subsequent TIFL failed on 04/24/10 confirming TxIA communication. The well has been reclassified as Under Evaluation. The plan forward is as follows: 1. DHD: TIFL -Failed 2. Slickline: Set DGLV 3. Pumping: MIT-IA to 3000 psi A TIO Plot and wellbore schematic have been included for your reference. «L-110 TI0 Plot 04-23-10.doc» «L-110.pdf» 5/12/2010 OPERABLE: Producer L-110 (PTD #11230) Tubing Integrity Confirmed • Page 2 of 2 Please call with any questions or concerns. Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 5/12/2010 PBU L-110 PTD 2011230 5/8/2010 TIO Pressures Plot Well: L-110 • _._ TREE = 3-183'9 tt~Jl CNY WELLHEAD= FMC ACTUATOR= KB. ELEV - BAKER 77.10' BF. ELEV = 54.82' KOP = 1000" Max Angle = 52 @4634' Datum MD = 8490' Datum TV D = 6600' SS 7-5/8" CSG, 29.7#, L-80, ID = 6.875" ~ L-110 1015' I--17-518" TAM PORT COLLAR 2310' I-13-112" HES XDB BV N, ID = 2.75" i Minimum ID = 2.?5" @ 2310' 3-1/2" HES SSSVN GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 4259 3510 49 KBG-2 SO BTM 20 10/31/09 3 6969 5298 39 KBG-2 DMY BTM 0 10!31/09 2 8107 6296 13 KBG-2 DMY BTM 0 08!02/01 1 8226 6412 12 KBG-2 DMY BTM 0 08/02101 3-112" HES X NIP, ID = 2.75" 5-112" CSG, 15.5#, L-80, BTC, ID = 4.950" 3-1/2" TBG, 9.2#, L-80, IBT-M, .0087 bpf, ID = 2.992" 5-1/2" X 3-112" CSG XO, ID = 2.968" PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 12° @ 8467' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2-1/2" 6 8467 - 8521 O 09/15101 PBTD 3-1/2" CSG, 9.2#, L-80, NSCT, ID = 2.992" DATE REV BY COMMENTS DATE REV BY COMMENTS 08/02/01 CH/KAK ORIGINAL COMPLETION 09!15/01 JLM/KK PERFS 12/30102 DAC/KK GLV CORRECTIONS 04108/03 DRS/TP TVD/MD CORRECTIONS 11/06!09 BSE/SV GLV C/O/TVDCORR{10!31!09} BOREALIS UNIT WELL: L-110 PERMfT No: ®2011230 API No: 50-029-23028-00 SEC 34, T12N; R11 E 2365' NSL & 3772' WEL BP Exploration {Alaska) $304' -~ TOP OF BKR PBR, ID = 4.00" 8315' 3-1/2" BKR SEAL ASSY, ID = 3.00" 83$8' 3-1/2" HES X NIP, ID = 2.75" 8387' 3-112" HES X NIP, ID = 2.75" $428' ~ 20' PUP JT W ! RA TAG 10' PUP JT W t RA TAG UNDER EVALUATION: L-110 (PTD~011230) for Sustained Casing Pressur~n the IA Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~ ¢~?~~«y Sent: Saturday, April 24, 2010 7:32 PM G To: Regg, James B (DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); NSU, ADW Well Integrity Engineer; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers; Rossberg, R Steven; Engel, Harry R Cc: NSU, ADW Well Integrity Engineer; Oakley, Ray (PRA); Quy, Tiffany Subject: UNDER EVALUATION: L-110 (PTD #2011230) for Sustained Casing Pressure on the IA Attachments: L-110 TIO Plot 04-23-10.doc; L-110.pdf All, Producer L-110 (PTD #2011230) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing/IA/OA equal to 380/2020/240 psi on 04/21/10. A subsequent TIFL failed on~4/~4/10 confirming TxIA communication. The well has been reclassified as Under Evaluation. The plan forward is as follows: 1. DHD: TIFL -Failed 2. Slickline: Set DGLV 3. Pumping: MIT-IA to 3000 psi A TIO Plot and wellbore schematic have been included for your reference. ,, «L-110 TIO Plot 04-23-10.doc» «L-110.pdf» Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 '. `F^` tt~, „ ~. 9 ,! ,~ ~~, ~" M; ~~ ~ ~. 4/29/2010 PBU L-110 PTD 2011230 4/24/2010 TIO Pressures Plot 4.000 3,D00 2 A00 1,000 Well: L-110 01130110 02113/10 02127110 03113110 03127110 04110110 04124110 ~ Tbg --~- IA -~ OA ODA OOOA On • • TREE = 3-1 ffi'1 Ct1~I CIW 'WELLHEAD = FMC ACTUATOR= BAKER KB. ELEV - ......77.10" BF. ELEV = 54.82' '~KOP - 1000' Max Angle = 52 @ 4634' Datum MD = 8490' Datum TV D = 6600' SS 7-5/8" CSG, 29.7#, L-80, ID = 6.875" Minimum ID = 2.75" @ 2310' 3-1/2" HES SSSVN 5-112" CSG, 15.5#, L-80, BTC, ID = 4.950" 3-112" TBG, 9.2#, L-80, IBT-M, .0087 bpf, ID = 2.992" 5-1/2'° X 3-112" CSG XO, ID = 2.968" PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 12° @ 8467' Note: Refer to Production DB far historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2-1/2" 6 8467 - 8521 O 09/15!01 PBTD 3-1/2" CSG, 9.2#, L-80, NSCT, ID = 2.992" L-110 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 4259 3510 49 KBG-2 SO BTM 20 10!31!09 3 6969 5298 39 KBG-2 DMY BTM 0 10/31!09 2 8107 6296 13 KBG-2 DMY BTM 0 08!02/01 1 8226 6412 12 KBG-2 DMY BTM 0 08102!01 1®15' ~°j7-5/8" TAM PORT COLLAR 2310' 3-1/2" HES XDB BV N, ID = 2.75" 8251 -~3-112" HES X NIP, ID = 2.75" 8304 TOP OF BKR PBR, ID = 4.00" ~~ 8315' 3-112" BKR SEAL ASSY, ID = 3.00" 8366' 3-112" HES X NIP, ID = 2.75" -8387' - 3-1/2" HES X NIP, ID = 2.75" -~ 8428' -I 20' PUP JT W ! RA TA G 10' PUPJT W / RA TAG DATE REV BY COMMENTS DATE REV BY COMMENTS 08!02101 CHtKAK ORIGINAL COMPLETION 09115/01 JLMIKK PERFS 12/30/02 DAGKK GLV CORRECTIONS 04/08/03 DRS/TP TVDJMD CORRECTIONS 11/06(09 BSEISV GLV CIOITVD CORK (10/31(09) BOREALIS UNIT WELL: L-110 PERMIT No: 2011230 API Na: 50-029-23028-00 SEC 34, T12N; R11 E 2365' NSL & 3772' WEL 8P Exploration (Alaska) OPERABLE: Producer L-110 (PTD #11230) Tubing integrity confirmed • Page 1~€'~ b-~-n+~ Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comj ~e/G ~(~.~ ~ ~ Sent: Saturday, April 10, 2010 1:22 PM -( f To: Regg, James B (DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers; Rossberg, R Steven; Engel, Harry R Cc: Oakley, Ray (PRA); Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer Subject: OPERABLE: Producer L-110 (PTD #2011230) Tubing integrity confirmed All, Producer L-110 (PTD #2011230) passed a re-TIFL on 4110/10 confirming tubing integrity. The original TIFL was thought to have failed due to debris in the check of the gas lift valve so a re-TIFL was attempted. The well has been reclassified as Operable. Please let us know if you have any questions. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907} 659-5102 Pager: (907} 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, April 04, 2010 7:50 AM R ~ ~~ ~'~ ad's ~~~~ P r~ To: 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA) <guy.schwartz@alaska.gov>'; 'Maunder, Thomas E (DOA)'; NSU, ADW Well Integrity Engineer; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers; Rossberg, R Steven; Engel, Harry R Cc: Oakley, Ray (PRA); Janowski, Carrie; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: L-110 (PTD #2011230) for Sustained Casing Pressure on the IA AI I, Producer L-110 (PTD #2011230) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing/IA/OA equal to 760/2020/200 psi on 03/31/10. A subsequent TIFL failed on 04/04/10 confirming TxIA communication. The well has been reclassified as Under Evaluation. The plan forward is as follows: 1. DHD: TIFL -Failed 2. Slickline: Set DGLV 3. Pumping: MIT-IA to 3000 psi A TIO Plot and wellbore schematic have been included for your reference. « File: L-110 TIO Plot 04-04-10.doc » Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator 4/12/2010 UNDER EVALUATION: L-110 (PT~2011230) for Sustained Casing Pressu~on the IA Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunday, April 04, 2010 7:50 AM " ~~~ ~~'~~ ~~' To: Regg, James B (DOA); Schwartz, Guy L (DOA); Maunder, Thomas E (DOA); NSU, ADW Well Integrity Engineer; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers; Rossberg, R Steven; Engel, Harry R Cc: Oakley, Ray (PRA); Janowski, Carrie; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: L-110 (PTD #2011230) for Sustained Casing Pressure on the IA Attachments: L-110 TIO Plot 04-04-10.doc; L-110.pdf All, ,/ Producer L-110 (PTD #2011230) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing/IA/OA equal to 760/2020/200 psi on 03/31/10. A subsequent TIFL fade on /04/10 confirming TxIA communication. The well has been reclassified as Under Evaluation. The plan forward is as follows: 1. DHD: TIFL -Failed 2. Slickline: Set DGLV 3. Pumping: MIT-IA to 3000 psi A TIO Plot and wellbore schematic have been included for your reference. «L-110 TIO Plot 04-04-10.doc» «L-110.pdf» Thank you, ~~~... Toxin Roschinger (alt. Anna Dube) ~"` ~~ ~~~ ~ ~ %'~1 Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 4/5/2010 PBU L-110 PTD 2011230 4-4-10 TIO Pressures Plot 4Ve1L- L-110 • TREE = 3-1 ffi'1 t$VI CM! WELLHEAD = FMC ACTUATOR = BAKER KB. ELEV = 77.10' BF. ELEV.- 54.82' KOP = 1000' Max Angle = 52 @ 4634' Datum MD = 8490' Datum TV D = 6600' SS 7-5/8" GSG, 29.7#, L-80, ID = 6.875" ~ L-110 1015' ~'-I7-5/8" TAM PORT COLLAR Minimum ID = 2.75" @ 2310" 3-112" HES SSSVN 5-112" CSG, 15.5#, L-80, BTG ID = 4.950" 8302' - 3-112" TBG, 9.2#, L-80, IBT-M, .0087 bpf, ID = 2.992" 8303' 5-1/2" X 3-1/2" CSG XO, ID = 2.968" 8315' - PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 12° @ 8467` Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 8467 - 8521 O 09/15(01 PBTD 3-1/2" CSG, 9.2#, L-80, NSCT, ID = 2.992" ~ 3-1 /2" HES XDB BV N, ID = 2.75" ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 4259 3510 49 KBG-2 SO BTM 20 10131!09 3 6969 5298 39 KBG-2 DMY BTM 0 10131!09 2 8107 6296 13 KBG-2 DMY BTM 0 08/02/01 1 8226 6412 12 KBG-2 DMY BTM 0 08!02/01 ---i_8251' -~3-112" HE5 X NIP, ID = 2.75" -~-~ , $304' TOP OF BKR PBR, ID = 4.00" 8315' 3-112" BKR SEAL ASSY, ID = 3.00" -' 836$' 3-112" HES X NIP, ID = 2.75" -~ 8387' - 3-1/2" HES X NIP, ID = 2.75" _r 8428' 20' PUP JT W ! RA TAG $$21' ~--~ 10' PUP JT W / RA 7AG DATE REV BY COMMENTS DATE REV BY COMMENTS 08/02/01 CH(KAK ORIGINAL COMPLEf10N 09115!01 JLMlKK PERFS 12/30!02 DAC/KK GLV CORRECTIONS 04(08(03 DRS/TP TV D/MD CORRECTIONS 11/06/09 BSE/SV GLV C/O/TVD CORR (10!31/09) BOREALIS UNIT WELL: L-110 PERMiT Na: y2011230 API No: 50-029-23028-00 SEC 34, T12N; R11 E 2365' NSL & 3772' WEL BP Exploration (Alaska) • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 ~;'~~s~~~~:i., ',r' ;' ~ `vr ~~~~~ ~: a~ ~~~_. • bp ~~ ~~~~L~d' Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, 0 C T 0~ 2009 ~Ilaska ~ii ~ Gas Cons. Gommissior~ Anchorage ~~ ~ ., ~ ~.,3 ~`~~~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad 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, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ . BP Exploration (Alaska ) Inc. Surtace Casing by Conductor Mnulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10~04) Date L pad 8/13/2009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ seala~t date ft bbls ft na al L-Ot 2010720 50029230110000 NA 6 NA 61.2 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 6.2 NA 57.8 6/29/2009 L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L•102 2020360 50029230710000 37' NA Need To Job? NA L-103 2021390 50029231010000 NA 1.6 NA 102 6/26/2009 1-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 3162 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 1-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 ~-116 201 t 160 50029230250000 NA 5 NA 54.4 6/28/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121A 2030390 50029231380100 NA 22 NA 25.5 6127/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 50029231970000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L402 2041960 50029232290000 NA 2 NA 17 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA 1 NA 12.75 111012009 L-210 2031990 50029231870000 NA 3.25 NA 31.4 5/5/2009 ~-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6I25/2009 L-214A 2060270 50029232580100 NA 0.25 NA 10.2 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late bbckin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 50029233760000 surface NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 1-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marlœr.doc %z - ~o o o o 8 o o o o~ o o o o o o~ o~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C) CZ) C) O~ CZ) (N LO O~ C) CZ) .. 0 o o o~ o o ~) z UJ 0 Z uJ o ~ z 0 ;o z -- z 0 z 0 0 ,. o >~ z C) 0 ..Q 0 C](b C7', o z 0 m ~. ca 0 o o 0 Z H- UJ Z Z Z __0 '-- (A STATE OF ALASKA L ..... ALASK ~JIL AND GAS CONSERVATION COM ,,,.4SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 12127101, Put on Line 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-123 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23028-00 4. Location of well at surface'~"~'~~:~'~ 9. Unit or Lease Name 2365' NSL, 3772' WEL, SEC. 34, T12N, El 1 E, UM !_¥~_,' ! Prudhoe Bay Unit At top of productive interval 2031' SNL, 5179' WEL, SEC. 03, T11N, R11E, UM!~i' 10. Well Number At total depth 2156' SNL, 5215' WEL, SEC. 03, T11N, R11E, UM ..':: ;,~. .. ~.~~,,,.,~ L-110 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Borealis Pool KBE = 71.70' ADL 028241 (Undefined) '12. Date Spudded 7-16-2001 113' Date T'D' Reached 114' Date COmp'' Susp'' or Aband'7.27-2001 9-15-2001 115' Water depth' if offshore N/A MSL 116' NO' of C°mpletions One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set121. Thickness of Permafrost 9020 7186 FTI 8819 6992 FT []Yes [] No (Nipple) 2310' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run Gyro, MWD, LWD, GE, RES 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 24' 117' 30" 260 sx Arctic Set (Approx.) 7-5/8" 29.7# L-80 27' 2820' 9-7/8" 329 sx Arcticset Lite, 206 sx Class 'G' 5-1/2"x 3-1/2" 15.5# / 9.2# L-S0 24' 8992' 6-3/4" 256 sx LiteCrete 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 SPF ~ 3-1/2", 9.2#, L-80 8315' 8304' MD TVD MD TVD 8467,. 8521, 6649'. 6702, 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ' , , , , , ,,,, , ,,, , ,,, , , DEPTH INTERVAL (M,D) AMOUNT &, KIND OF MATERIAL USED 8467' - 8521' Fractured with 225807 #'s of 16 / 20 ' " Carb0Li'te b~'hind' pipe. , , , , , ,, ,,, 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) November 8, 2001 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO 11/13/2001 4 TEST PERIOD 3803 1422 0 75I 374 ~Iow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORE) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED DEC 8 ?OOt'-' ~i~ei~ Clil,~, ('-,,~CdllS. Commission ,,, Form 10-407 Rev. 07-01-80 AliCh~bmit In Duplicate J ,N 2 3 2002 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. ., Schrader Bluff N 5137' 4078' Schrader Bluff O 5381' 4239' Base Schrader / Top Colville 5950' 4606' Mudstone CM 1 7418' 5664' THRZ 8087' 6277' TKLB 8286' 6471' Top Kuparuk C 8465' 6647' LCU / Top Kuparuk B 8630' 6808' Top of Kuparuk A 8775' 6949' Base Kuparuk / Top Miluveach 8850' 7021' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Post Rig Summary, Leak Off Integrity Test Summary 32. I hereby certify that the fore. goings,,,,._ is true and correct to the best of my knowledge )-- ~"~'/~ Signed TerrieHubble,~.~v~~~._ Title TechnicalAssistant Date 0/ L-110 201-123 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 l: .g WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ,[~Oil [] Gas [] Suspended [] Abandoned [] Service TSUSP 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 201-123 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23028-00 4. Location of well at surface , ............................... ~ 9. Unit or Lease Name 2365' NSL, 3772' WEL, SEC. 34, T12N, R11E, UM '" ,:;~.,l'..':?i_~:,r_;!,~ 'i~.~.~.a~,,[~ Prudhoe Bay Unit At top of productive interval 2031 SNL, 5179' WEL, SEC. 03, T11N, R11E, UM ' - ...... :/- -: ....... i~ " 10. Well Number At total depth 2156' SNL, 5215' WEL, SEC. 03, T11N, R11E, UM ~ ............. .~.~. : .--,.,...--.,,.--~.-..'~1 L-110 iii.., .1~1 :5. Elevation in feet (indicate KB, DF, etc.) 6. Lease D(~signation and Serial No. 11. Field and Pool Prudhoe Bay Field / Borealis Pool KBE = 71.70' ADL 028241 (Undefined) 12. Date Spudded7.16-2001 113' Date T'D' Reached 114' Date C°mp'' Susp'' °r Aband'7.27-2001 9-15-2001 115' water depth' if °ffsh°reN/A MSL 116' N°' °, C°mpleti°noOne 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)119. Directional Survey 1 20. Depth where SSSV setl 21. Thickness of Permafrost 9020 7186 FTI 8819 6992 FT []Yes [] No (Nipple) 2310' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run Gyro, MWD, LWD, G R, RES 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 24' 117' 30" 260 sx Arctic Set (Approx.) 7-5/8" 29.7# L-80 27' 2820' 9-7/8" 329 sx Arcticset Lite, 206 sx Class 'G' 5-1/2"x3-1/2,, 15.5#/9.2# L-80 24' 8992' 6-3/4" 256 sx LiteCrete , 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 SPF 3-1/2", 9.2#, L-80 8315' 8304' MD TVD MD TVD , 8467' - 8521' 6649' - 6702' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8467' - 8521' Fractured with 225807 #'s of 16 / 20 CarboLite behind pipe. 27. PRODUCTION TEST Date First P~oduction Method of Operation (Flowing, gas I'ift, etc.) " Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-Hour RATE .28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED 0c'r 0 Alaska 0il & Gas Cons. Commissi0r~ Form 10-407 Rev. 07-01-80 OR16tf'x!/ ,L Ar~Cll°ragesubmit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Schrader Bluff N 5137' 4078' Schrader Bluff O 5381' 4239' Base Schrader / Top Colville 5950' 4606' Mudstone CMl 7418' 5664' THRZ 8087' 6277' TKLB 8286' 6471' Top Kuparuk C 8465' 6647' LCU / Top Kuparuk B 8630' 6808' Top of Kuparuk A 8775' 6949' RECEIVED Base Kuparuk/Top Uiluveach 8850' 7021' OCT 0 zJ: ZOO1 Alaska 0il & Gas Co~s. Commissio~ Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Post Rig Summary, Leak Off Integrity Test Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~,~ ~ Title Technical Assistant Date L-110 201-123 Prepared By Name/Number: Sondra Stewrnan, 564-4750 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ', BP EXPLORATION Page I of 6 Operations Summar Report Legal Well Name: L-110 Common Well Name: L-110 Spud Date: 7/15/2001 Event Name: DRILL+COMPLETE Start: 7/15/2001 End: 8/2/2001 Contractor Name: NABORS Rig Release: Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/16/2001 04:00 - 09:00 5.00 MOB PRE MIRU on L-110, make all elect / plumbing connections. 09:00 - 13:00 4.00 RIGU PRE Prepare spud mud while nipple up diver[er / drip pan. 13:00 - 15:00 2.00 DRILL SURF PU 4" hwdp, jars, DCs, stand back in mast. 15:00 - 15:30 0.50 DRILL SURF PJSM, pre-spud meeting all personnel. 15:30 - 18:00 2.50 DRILL SURF Rih bha #1, Flush Conductor, tag btm at 107 Ft. 18:00 - 18:30 0.50 DRILL SURF Circ spud mud, function test diverter, ( Witness of Test waived by Chuck Sheve, AOGCC ) 18:30 - 19:00 0.50 DRILL SURF Install sheaves for gyro wireline unit. 19:00 - 19:30 0.50 DRILL SURF Estab circ, check for leaks. 19:30 - 21:00 1.50 DRILL SURF Drlg 9 7/8 hole 107 - 172 ft. 500 gpm, 800 psi, 17 K on bit, 65 rpm. 21:00 - 23:00 2.00 DRILL N WAIT SURF Wait on Kuparuk bridge to open for Peak Tank trucks to pass. 23:00 - 00:00 1.00 DRILL P SURF Take delivery trucks, resume drill ahead 9 7/8 hole. 172 - 236 ft.. Parameters same. ART = 2 hrs 7/1712001 00:00 - 00:30 0.50 DRILL P SURF Cont drlg surface hole 9 7~8, to 269 ft. 00:30 - 02:30 2.00 DRILL P SURF Circ, recip pipe while gyro survey. 02:30 - 03:00 0.50 DRILL P SURF Resume drill 269 - 361 ft. 03:00 - 05:00 2.00 DRILL P SURF Circ, recip pipe while gyro survey. 05:00 - 00:00 19.00 DRILL P SURF Resume drill 9 7/8 hole, 361 - 1536 ft. Gyro at 50, 100, 155, 244, 300, 363, 456 ft. Up 65, Dn 63, Rot 64 Wt 20 K, Tq 1500, Rpm 55 Ast = 7.25 hrs, Ar[ = 8.75 hrs 7/18/2001 00:00 - 03:00 3.00 DRILL P SURF Cont drill ahead 9 7/8 hole drctnl, 1536 - 1754 ft. Up 83, Dn 77, Tq 4, Rpm 60, Wob 20-25. 03:00 - 04:00 1.00 DRILL P SURF Flow check, pump hi vis pill, shakers clean. 04:00- 06:00 2.00 DRILL P SURF Poh wiper trip. Drag normal, no swabbing, losses. Rih, no fill. 06:00 - 20:30 14.50 DRILL P SURF Flow check, Resume drlg 9 7/8 hole drctnl, 1754 - 2835 ft. Geologist confirms TD. +- 100 ft below SV 1 sand. 20:30 - 22:00 1.50 DRILL P SURF Circ hi-vis sweep, clean returns. Normal cuttings retrieval. 22:00 - 00:00 2.00 DRILL P SURF Flow check, Poh for hole opener bha, Normal drag, no swabbing, no losses. 7/19/2001 00:00 - 03:00 3.00 DRILL P SURF Poh, std back hwdp, lay out mwd / drctnl tools. 03:00 - 04:30 1.50 DRILL P SURF Clear floor, service top drive 04:30 - 07:30 3.00 DRILL P SURF Flow check, make up hole opener assy, rih same to 2645 ft (slight resistance), filling pipe at 4" dp, and 2645 ft. 07:30 - 09:30 2.00 DRILL P SURF Wash / ream 2645 - 2835 ft. to btm. No fill. Circ hi-vis pill, pump wt pill, shaker clean. Normal cuttings return. 09:30 - 13:30 4.00 DRILL P SURF Flow check, poh for 7 5/8 csg run. Hole good condition. Lay dn bha. 13:30 - 14:00 0.50 DRILL P SURF PJSM, clear rig floor. 14:00 - 16:00 2.00 DRILL P SURF Place all related equip on floor, ru to run csg. 16:00 - 17:00 1.00 DRILL P SURF Make up shoe track, guide shoe, 2 jts csg, float collar, rih same. Check floats. Floats holding. 17:00 - 21:00 4.00 DRILL P SURF Follow wth 7 5/8 csg, 29.7#, L80 BTC, Tam collar at 1018 ft, remainder csg to hgr jt. Fill every it. Make up Idg jt / csg hgr. Up 125, Dn 80. Pipe free for reciprocation. 21:00 - 22:00 1.00 DRILL P SURF Break out "Franks" tool, make up cmt hd, prepare for circ / cond. Printed: 8/6/2001 1:38:03 PM , - BP EXPLORATION Page 2 of 6 Operations Surnma Report Legal Well Name: L-1 10 Common Well Name: L-1 10 Spud Date: 7/15/2001 Event Name: DRILL+COMPLETE Start: 7/15/2001 End: 8/2/2001 Contractor Name: NABORS Rig Release: Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/19/2001 22:00 - 00:00 2.00 DRILL P SURF Begin cir¢/ condition for cmt job. Recip pipe, stage up to 12 bpm. Obtain full returns, no losses. Cont condition for cmt. 7/20/2001 00:00 - 01:00 1.00 DRILL P SURF Cont ¢irc recip pipe for cmt job 7 5/8 csg. 01:00 - 04:00 3.00 DRILL P SURF PJSM. Commence cmt 7 5/8 csg as follows: Pump 10 bbl CWl00, clear lines. Test lines 3500 psi, test good. Drp btm plug, follow with 40 bbl CW 100. Pump 75 bblMud Push spacer wt 10.2 ppg. Pump 260 bb110.7 ppg lead slurry. 6 bpm. Pump 43 bb115.8 ppg tail slurry, 6 bpm. Drop plug and verify. Chase with 10 bbls H2o. Displace with rig pumps, 117 bbls, 1640 stks, bump plug at 0322 hrs with 1236 psi, hold 15 min, bleed, floats holding, no back flow. Cont observe for flow 30 min. Pipe reciprocated entire job. FCP = 669 psi. Receive approx 10 bbls 10.4/10.5 ppg cmt returns to cellar. :04:00 - 06:30 2.50 DRILL P SURF Rig dn all related cmt equip, remove from floor. Release Cmt unit. 06:30 - 09:30 3.00 DRILL P SURF Nipple dn diverter system, secure on stand. 09:30 - 15:00 5.50 DRILL P SURF Nipple up 13 5/8 5K bope. 15:00 - 22:00 7.00 DRILL P SURF Set test plug, fill / purge all ines. Test bope. Witnessed by Lou Gramaldi, AOGCC. Annular 250 / 3500. Remainder bope, all valving, choke mnfld, floor valves, standpipe to pumps 250 / 4000 psi. Perform accum test. All tests successful, no re-tests. 22:00 - 23:00 1.00 DRILL P SURF Rih singles 4" dp, standing bk in mast. 23:00 - 23:30 0.50 DRILL P SURF Service top drive. 23:30 - 00:00 0.50 DRILL P SURF Resume pu 4" dp for drill out. 7/21/2001 00:00 - 04:00 4.00 DRILL P SURF Cont rih 4" dp in sgls. 04:00 - 06:00 2.00 DRILL P SURF Slip / cut drlg line. Clean residue beneath draw works. 06:00 - 08:30 2.50 DRILL P SURF Poh, stand back dp / hwdp in mast. 08:30 - 12:00 3.50 DRILL P SURF Assemble drctnl/Iwd bha, orient motor - mwd. Load nuclear sources into tools. Rih same. 12:00 - 13:00 1.00 DRILL P SURF Rih remainder bha / 6 3/4 drlg assy. Surface test mwd. 13:00 - 13:30 0.50 DRILL P SURF Rih 4" dp to 1016 Ft (Past port collar) 13:30 - 14:00 0.50 DRILL P SURF Close rams, test csg / port collar 1500 psi. Test successful. 14:00 - 15:00 1.00 DRILL P SURF Resume rih 4" dp to 2630 Ft. 15:00 - 16:00 1.00 DRILL P SURF Close rams, test csg t 4000 psi / 30 min. Test successful. Hold reservoir meeting during test. 16:00 - 17:30 1.50 DRILL P SURF Tag cmt at 2733 ft, commence drill float, shoe track, guide shoe. 17:30 - 18:00 0.50 DRILL P PROD1 Drill rat hole, 20 ft new formation to 2858 ft. Flow check. 18:00 - 19:30 1.50 DRILL P PROD1 Displace well with 9.3 ppg Isnd mud. Cont circ well clean. 19:30 - 20:00 0.50 DRILL P PROD1 Pull into shoe, perform LOT, ( Press 585 si, 13.69 emw, 1.3 bbls pumped, .25 bpm, 2561 tvd ) 20:00 - 20:30 0.50 DRILL P PROD1 Was to btm 2858 ft, ECD baseline, orient for direction. 20:30 - 00:00 3.50 DRILL P PROD1 Flow check, commence drill ahead 6 3/4 hole drctnl, 2858 - 3229 ft. ~Up 85, Dn 74, Rot 81 Printed: 81612001 1:38:03 PM BP EXPLORATION Page 3 of 6 Operations Summary Report Legal Well Name: L-110 Common Well Name: L-1 10 Spud Date: 7/15/2001 Event Name: DRILL+COMPLETE Start: 7/15/2001 End: 8/2/2001 Contractor Name: NABORS Rig Release: Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/21/2001 20:30 - 00:00 3.50 DRILL P PROD1 ART 1.5 hrs, AST .25 hrs 7/22/2001 00:00 - 13:00 13.00 DRILL P PROD1 Cont drill ahead 6 3/4 hole 3229 - 4786 ft. Pump hi-vis sweeps at 300 ft intervals. 13:00 - 14:00 1.00 DRILL P PROD1 Circ sweep, follow with wt pill, shaker clean returns. 14:00 - 16:00 2.00 DRILL P PROD1 Flow check, prepare and poh wiper trip. Tight at 4100, 3670, 3100 ft. Pull slow due to slight swabbing. No losses. 16:00 - 16:30 0.50 DRILL P PROD1 Flow check, Circ / rot, clean balled bit / bha. 16:30 - 17:00 0.50 DRILL P PROD1 Service top drive. 17:00-21:00 4.00 DRILL P PROD1 Flow check, rih bha / 4" dp, wash / ream 3300 - 4786 ft. Take wt at various coal stringers. 21:00 - 00:00 3.00 DRILL P PROD1 Resume drill ahead drctnl, 6 3/4 hole, 4786 - 4942 ft. ROP 200 - 300 fph, Up 110, Dn 85, Rot 96 Wob 2 - 10, Press 1900, Rpm 55, Gpm 295 Spin 100 ART = 8.5 hrs, Asr = 1 hr 7/23/2001 00:00 - 20:00 20.00 DRILL P PROD1 Cont drill ahead 6 3/4 hole drctnl, 4942 - 6277 ft. Up133, Dn 96, Rot 112 Wob 2 -10, Rpm 55-80, Press 2060, Gpm 295 20:00 - 21:30 1.50 DRILL P PROD1 Circ hi-vis sweep, clean returns at shaker, follow with ,,vt pill. 21:30 - 23:00 1.50 DRILL P PROD1 Flow check, poh wiper trip. No swabbing / losses. Tight at 3880 ft. Work back through, normal drag. cont poh to 7 5/8 csg shoe. 23:00 - 23:30 0.50 DRILL P PROD1 Flow check, ser top dry. 23:30 - 00:00 0.50 DRILL !P PROD1 Rih 4" dp to 3100 ft. 7/24/2001 00:00 - 01:30 1.50 DRILL P PROD1 Continue RIH to 6180'. 01:30 - 02:00 0.50 DRILL P PROD1 Wash & Ream to Bottom @ 6276. No Fill. 02:00 - 00:00 22.00 DRILL P PROD1 Directional Drill 6 3/4" Hole from 6276' to 7305'. 2 to 10 K WOB TQ = 6 to 7K. 295 GPM @ 2250 psi. Incl. = 34 deg, Azim = 201 deg.@ 7244'. P/U = 147K S/O = 104K ROT = 121K AST = 7 Hrs. ART = 10.25 Hrs. 7/25/2001 00:00 - 19:00 19.00 DRILL PROD1 Drill 6 3/4" Directional Hole from 7305' to 7863'. 2 to 9K WOB. TQ = 5 to 7K 295 GPM @ 2530 psi. w/10.6 ppg mud. Inc. = 19 deg. Azim. = 193 deg. P/U = 150K S/O = 113K Note: Weighted up to 10.6 ppg while drilling last stand. 19:00 - 19:30 0.50 DRILL INT1 CBU 19:30 - 21:30 2.00 DRILL INT1 Wiper trip to 5800' - 22 stands. Hole in excellent shape; Max overpull < 10K. Precautionary wash last stand to bottom - No Fill. 21:30 - 00:00 2.50 DRILL INT1 Continue drilling 6 3/4" directional hole from 7863' to 7908'. Same parameters as above. 7/26/2001 00:00 - 00:00 24.00 DRILL INT1 Drill 6 3/4" Directional Hole from 7908' to 8450'. 2 to 10K WOB. TQ = 5 to 7K 290 GPM @ 2680 psi. Inc. = 11 deg. Azim. = 190 deg. P/U -- 164K S/O = 118K ROT = 135K AST -- 3.75 Hrs. ART = 16 Hrs. K1 Marker @ 8360' MD Top of Kuparuk = 8466' MD Note: Prior to drilling HRZ; held Reservoir meeting; covering in depth the potential hazards and parameters for drilling the HRZ and Kingak 7/27/2001 00:00 - 18:30 18.50 DRILL INT1 Drill 6 3/4" Directional Hole from 8450' to 9020'. TD per Printed: 8/6/2001 1:38:03 PM BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: L-1 10 Common Well Name: L-1 10 Spud Date: 7/15/2001 Event Name: DRILL+COMPLETE Start: 7/15/2001 End: 8/2/2001 Contractor Name: NABORS Rig Release: Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/27/2001 00:00 - 18:30 18.50 DRILL INT1 Geologist. Top of Miloveach - 8849' 6 to 10K WOB TQ = 7.8K yo 8.5K 295 GPM @ 2880 psi. P/U = 176K S/O -- 122K ROT = 146K All ROT - 15.5 Hrs. Last Survey- Inc. = 14.92 deg. Azim = 197.63 deg. 18:30 - 20:00 1.50 DRILL INT1 Circulate Hi Vis Sweep, Pump Slug. 20:00 - 22:30 2.50 DRILL INT1 Wipe to shoe @ 2818'. Hole in great shape - No Overpull ! 22:30 - 23:00 0.50 DRILL INT1 Service Top Drive & Crown. 23:00 - 00:00 1.00 DRILL INT1 RIH - Slick 7/28/2001 00:00 - 02:30 2.50 DRILL INT1 RIH to 8900'. Precautionary wash to bottom @ 9020'. No Fill. Hole Slick. 02:30 - 06:30 4.00' DRILL INT1 Pump Hi Vis Sweep. Circulate and Condition mud. Vis.-- 44 PV= 15 YP = 21 Gels - 7/9 Pump 100 bbl Csg. Running . pill.& Slug. 06:30 - 15:00 8.50 DRILL INT1 POH L/D 4" DP 15:00 - 17:30 2.50 DRILL INT1 L/D HWDP, Collars. Unload nuclear sources. L/D MWD & LWD tools & Bit. 17:30 - 18:00 0.50 DRILL INT1 Clear and Clean Rig Floor. 18:00 - 18:30 0.50 CASE INT1 Pull Wear Bushing. Make dummy run w/5 1/2" Hanger. 18:30 - 20:00 1.50 CASE INT1 Rig Up to run 3 1/2" X 5 1/2" Production Casing. PJSM 20:00 - 00:00 4.00 CASE INT1 Run 3 1/2" X 5 1/2" Production Casing as per program. 7/29/2001 00:00 - 04:30 4.50 CASE P INT1 Run 5 1/2" casing to 5808'. Filling csg every jt. Up wt = 113K Dn. wt. = 75K. No problems until hitting obstruction @ 5808'. 04:30 - 07:30 3.00 CASE P INT1 Work casing with + 20K wt. down, no success. No drag coming up. M/U Circ head. Establish circ with no problem - 4 bbm @ 575 psi. with no losses. Work csg., wt fell off as if bouncing off ledge and csg slid down to 5840 to another obstruction. Continue to work csg while spotting bead pill. casing fell off again 10~ to 5850. cont. to work csg with no success. R/D circ head. M/U XO & Top drive. Rotate and reciprocate while circ. - unable to pass 5850'. Never experienced any drag Up nor any attempt to pack off with full csg wt down. No further progress with all safe and sane options tried. Confer again with Drlg. Supt. Decision made to pull casing 07:30 - 19:30 12.00 CASE N DPRB INT1 POH L/D 5 1/2" Casing, Stand 3 1/2" back in derrick. Check all threads. L/D Csg Equip. No excess drag POH. 19:30 - 22:30 3.00 CASE ~ INT1 Test BOPE 250 / 4000 psi. Annular to 3500 psi. APl. Witness waived by John Spaulding AOGCC. 22:30 - 00:00 1.50 CASE N DPRB INT1 Change out Bails. Pick up and M/U Hole Opener/Cleanout BHA. 17/30/2001 '00:00 - 01:30 1.50 CASE N DPRB INT1 Complete M/U - RIH w/BHA. 01:30-03:30 2.00 CASE N DPRB INT1 Pick Up 4" DP & RIH to 2818' 03:30 - 05:00 1.50 CASE = INT1 Cut & slip drlg. line. Service Top Drive, brakes, draworks & crown. 05:00 - 09:00 4.00 CASE N DPRB INT1 Cont. P/U 4" DP & RIH to 5805 - Taking weight. 09:00 - 12:30 3.50 CASE N DPRB INT1 Pull up to 5633', Wash & ream down w/120 RPM, 250 GPM @ 925 psi. Torque 3 to 4K to 5805'. At 5805' had 2K on reamer and torque 4 to 5K. Reamed to 5957' three times - torque down to 3 to 4K. Cont. to ream to 6008' - no resistance nor torque spikes. 12:30 - 15:00 2.50 CASE N DPRB INT1 Cont. RIH P/U 4" DP to 8967'. No resistance. Printed: 8/6/2001 1:38:03 PM ., BP EXPLORATION Page 5 of 6 Operations Summary Report ,. Legal Well Name: L-1 10 Common Well Name: Lo1 10 Spud Date: 7/15/2001 Event Name: DRILL+COMPLETE Start: 7/15/2001 End: 8/2/2001 Contractor Name: NABORS Rig Release: Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 7/30/2001 15:00 - 17:30 2.50 CASE N DPRB INT1 Wash to bottom 6 9020. Pump Hi Vis Sweep while rotating and reciprocating. Pump 6 310 GPM - 1530 psi. Spot casing running pill & pump slug. 117:30 - 23:30 6.00 CASE N DPRB INT1 POH L/D 4" DP. Pulled 15 to 20K 6 8560',8500',7471',3146'. Wiped through all these spots once and lost all drag. 23:30 - 00:00 0.50 CASE N DPRB INT1 Begin L/D BHA 7/31/2001 00:00 - 01:00 1.00 CASE N DPRB INT1 Con't ~ L/D BHA. 01:00 - 02:30 1.50 CASE N DPRB INT1 Clear floor, pull wear bushing, change out bails, & R/U to run csg. 02:30 - 08:30 6.00 CASE N DPRB INT1 PJSM. R/U & re-run 3 1/2" production csg. Note - Cut shoe track & replace float equipment & centralizers 08:30 - 09:00 0.50 CASE P INT1 Rig down 3 1/2" casing tools & rig up 5 1/2" casing tools. 09:00 - 13:00 4.00 CASE P INT1 Con't RIH w/5 1/2" 15.5#,L-80, BTC-M casing to 2880'. 13:00 - 13:30 0.50 CASE P INT1 Rig up circulating head & circulate 150 % liner volume (4 1/2 BPM 6 373 psi). 13:30-19:00 5.50 CASE :P INT1 ;Con'tRIHw/51/2"casingto8228'.Obstuction. Work pipe - no success. 19:00 - 20:00 1.00 CASE P INT1 P/U & M/U swedge & circulating line. Wash csg thru tight spot 8228' to 8298'. Pump rate = 3 BPM 6680 psi & lost 10 Bbls mud. 20:00 - 21:00 1.00 CASE P INT1 Con't RIH w/5 1/2" casing to 8967'. 21:00 - 21:30 0.50 CASE P INT1 M/U landing joint & land Hgr. in casing head. Production casing landed 6 8992'. R/U cement head & lines. 21:30 - 23:30 2.00 CASE P INT1 Break circulation & circulate hole. Displace hole to 10.4 ppg mud. 23:30 - 00:00 0.50 CASE P INT1 PJSM. Pump 5 Bbls & presure test pumps & lines to 4000 psi - OK. Pump 25 Bbl CW 100 & drop bottom plug. Pump 40 Bbl spacer (6 11.20 ppg). 8/1/2001 00:00 - 02:00 2.00 CASE P INT1 Con't ~ 3 1/2"X 5 1/2" production casing cement job. Pump 25 Bbls CW 100, drop bottom plug, pump 40 Bbls Mud Push (6 11.20 ppg), 109 Bbls liteCRETE cement (6 12.0 ppg as per program), Drop top plug, swithch to rig pump & displace cement with 203 Bbls filtered sea water. Bump plug & pressure to 2850 psi. Plug down & cement in place 6 0200 Hrs. Bleed pressure & check float equipment - OK. 02:00 - 03:00 1.00 CASE P INT1 Rig down cement head, flush stack, break out & lay down landing joint. 03:00 - 04:00 1.00 CASE P INT1 PJSM. Rig up & set pack-off. RILDS & torque to 450 fi/lbs. FMC pressure test ot 4000 psi - OK. Rig down FMC svc's. : 04:00 - 05:30 1.50 RUNCOI~ COMP Clear floor & rig up 3 1/2" tbg equipment. Make up dummy run with tubing hanger. 05:30 - 14:00 8.50 RUNCOI~F' COMP PJSM. Run 190Jts. 3 1/2' 9.2#, L-80, IBT-Mod tubing. 14:00 - 15:00 1.00 CASE P COMP Test ~5.5" X 3.5" Prod. Csg to 4000 psi for 30 minutes - OK. PJSM w/Camco. 15:00 - 21:00 6.00 RUNCOr~ COMP Simultaneous Operations: 1. R/U Camco dual control line reels, sheaves and eguipment. Hook contol lines to SSSV and test to 5000 psi. Cont. RIH w/Tbg. 2. Perform LOT on 7 5/8" X 5 1/2" annulus with 10.4 ppg. mud. Leak off pressure = 492 psi -- 14.09 ppg EMW. Established injectivity: 1 BPM 6 850 psi. initial; down to 567 psi after pumping 3 Bbls., 2 BPM 6 800 psi and 3 BPM 6 880 psi. Pumped 38 bbls 10.4 mud and 10 bbls seawater to clear lines. Printed: 8/6/2001 1:38:03 PM BP EXPLORATION Page 6 of 6 Operations Summary Report I Legal Well Name: L-110 Common Well Name: L-110 Spud Date: 7/15/2001 Event Name: DRILL+COMPLETE Start: 7/15/2001 End: 8/2/2001 Contractor Name: NABORS Rig Release: Rig Name: NABORS 9ES Rig Number: Date From - To Hours ActivityCode NPT Phase Description of Operations 8/1/2001 15:00 - 21:00 6.00 RUNCOI~ COMP Hooked up Hot Oil and pumped 33 bbls dead crude down annulus. Pumped at 1.5 Bpm. Initial pressure 800 psi. Final pressure 1250 psi Bleed pressure, RD Hot Oil. Con't RIH w/3 1/2" tbg. Space out 3 1/2' tbg. Operation Inc @ midnight. 21:00 - 22:30 1.50 RUNCO~ COMP P/U 2 extra jts tbg. M/U circulating head, break circulation & sting into PBR. Shut down pumps immediately after seeing pressure increase. Con't RIH to No Go & mark tbg. 22:30 - 00:00 1.50 RUNCO~ P COMP POH & lay down excess tbg. P/U required pups & tbg hanger. Pressure test control lines to 5,000 - OK. M/U circulating head & landing joint on tbg hanger. 8/2/2001 00:00 - 01:00 1.00 RUNCOItF) COMP Con't ~ Land 3 1/2" tbg & verify spaceout. (string wt = 106 k up & 76 k dn) 01:00 - 02:00 1.00 RUNCOI~F) COMP Pick up above PBR & reverse circulate corr inhibitor (3 BPM @ 480 psi). 02:00 - 03:00 1.00 RUNCOr~I:) COMP Land tubing & RILDS. Check control line pressure - OK. 03:00 - 05:00 2.00 RUNCOItF~ COMP Pressure test surface equipment to 4000 psi - OK. Pressure test 3 1/2" tbg to 4,000 for 30 min - OK. Bleed tbg pressure to 2,000 psi. Pressure test anulus to 4,000 psi for 30 min- OK. Bleed down tbg pressure & shear RP @ 2900 psi. Note - all 3ressure's & times charted & chart is on file. 05:00 - 06:00 1.00 RUNCOI~ COMP Back out landing joint, install TWC & pressure test from below to 2800 psi - OK. 06:00 - 07:00 1.00 RUNCOI~' COMP Rig down Camco svc's. Blow down all surface lines & drain BOP stack. 07:00 - 11:00 4.00 WHSUR 3 COMP Nipple down BOP stack & adaptor flange. Nipple up adaptor & ~roduction X-mas tree. 11:00 - 12:30 1.50 WHSUR 3 COMP Rig up FMC svc's. Install SBMS & control lines. Pressure test adaptor flange & control lines to 5,000 for 15 min - OK. Fill 3roduction X-mas tree with diesel. 12:30 - 13:30 1.00 WHSUR P COMP i Rig up DSM & recover TWC. 13:30 - 15:00 1.50 RUNCO~ COMP Rig up circulating lines on casing & tubing valves. Rig up Little Red services, pressue test pumps & lines to 3,000 psi- OK. Pump freeze protect into annulus (45 bbls), shut valve & allow diesel to U-tube into tubing. 15:00 - 16:00 1.00 WHSUR ! P COMP Install BPV & pressure test same to 1,000 psi - OK. Rig down DSM. 16:00 - 17:00 1.00 WHSUR P COMP Secure production X-mas tree & cellar area. Release rig to move to L-114 @ 1700 Hrs 8/02/2001. Printed: 81612001 1:38:03 PM Well: L-110 Rig Accept: 07/15/01 Field: Prudhoe Bay Field / Borealis Pool Rig Spud: 07/16/01 APl: 50-029-23028-00 Rig Release: 08/02/01 Permit: 201-123 Drilling Rig: Nabors 9ES POST - RIG WORK 09/01101 & 09/02/01 Standby for Field Crew to blind wing flange off and pull BPV. Pull dummy ball valve set catcher at 4536' WLMD. Pull R/P valve from GLM # 4 at 4259' MD. Set DGLV in same. Pressure test IA and tubing to 4000 PSI for 30 minutes (held good). Bleed off IA to 0 PSI tubing 3450 PSI for 30 minutes (good test). Drift with 2.50" dummy gun to 8809' WLM. 09115/01 MIRU E-Line, WHP = 0 PSI, RIH with 24', 2.5" perforating gun at 6 SPF and perforated 8497' - 8521', WHP after perforating 500 PSI, POOH, fluid at surface, temperature was 33 degrees; RIH with 30', 2.5" Perforating Gun at 6 SPF perforated 8467' - 8497', WHP = 600 PSI. Fluid at surface, temperature was 33 degrees; PERF charge SPECS: 2.5" Power flow, ENT. Hole = 0.66 IN, PENT. = 4.8", EXPL load = 10.5 GM total perforated interval: 8467'-8521 ', 54' total. 09/16101 & 09117/01 Static Survey with 2.30 CENT and Tandem Petredat gauges, all depths -23' to CORR to KB. Tagged TD at 8807' SLM. Average Pressure and Temperature at 6600' SS = 3408 PSI and 158 degrees F RDMO. 09/19/01 & 09120/01 Set 2.5" gauge carrier with Petredat gauges at TD (8817' SLM). Begin MITIA to 3500-PSI hold for 30 minutes good test. Set FRAC Sleeve at 2294' SLM. Test control lines to 5000 PSI (Good Test). 09/21101 Injectivity test, 1 BPM at 1500 PSI, 15 bbls of Diesel pumped. Pump 50 bbls of YF130LG Data FRAC ISIP = 1919 PSI, FG - .722. Observed pressure bump during fall off and decided on second Data FRAC pumped second 50 bbls Data FRAC (Pumped 5 BPM till Pad was on FM and increased RT to 25 BPM. ISIP = 1943 PSI Fluid EFF - 75% time to closure = 22.3 minutes.. Redesign FRAC - FRAC with 30 bbls YF130LG pad and a 1 to 6 PPA ramp with a 6 to 10 PPA step sand stages. Flushed well with 70 bbls 20 # slick water 3.5 bbls from top PERF. Placed 225807 #'s 16 / 20 C-Lite behind pipe, left 950 # in Well bore top of sand ~7300'. Pulled Treesaver and recovered all cups. 09/25/01 Found Ice in tubing at 34' SLM. RDMO Coil will follow with a FCO. 09/27/01 Pull 2.77 FRAC sleeve at 2299' SLM. Purge balance and control line (purge good). With 2-1/4" JSN, cleanout to 8819' CTD using Biozan sweeps. POOH laying in Diesel 1:1. 413 bbls 2% XSKCL, 127 bbls BIO, 77 bbls Diesel (totals after Slickline Operation), estimate 200 bbls additional fluid returned. 10/01/01 Well had 300 PSI of Gas upon arrival- RIH with 2.68" CENT, 2.50" LIB to 172' WLM hit ice plug at 172' WLM. ~.lJ ~ 0 0 o ~ 0 ~o~ -H i--j , o ~j I I I I ~ 0 Oo ¢} ~ . ~ co ~ ...... ~ + :~ :~ ..... ~ ~ ~+ ' 121 -~ ---' ~ · .~ ~ .u .u u~4 o o o [~- o o o 0 II II 0 ~0 II ~ 64-) II II II II II Il ~-I I II II II ~ ~ Ii ~ 0 II r,..)-,=1 ,-,. 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Oq LI'J 0 II II II ~-t J--t ~ II II 0 i1:1 Q~ II II 0 ~~ II Il .~1 J~ .i.J II II II I I I I I II C/'J 4J .IJ II II II I I I I I I 0 t-'l 0 0 0 ~ II II II ~ il ...... II (]) ..-- II I.n o,,1 o m ,,~I II r-I r-I 133 II II CJ 133 ~) II ..... ii ~ I~q:l II 0~ II t-I c~1 m ,~ u~ II · ::~ i II c~ ch o'~ o'~ ch II ~ II ~D ~'- O0 C~ 0 ~-~ O~ ~ ~ ~0 0 0 O "l""J 0 0o. 0 .~j o bp Date: 08-20-2001 Transmittal Number:92209 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type L-110 07-28-2001 ANA I 0 9020.00 DIRECTIONAL SURVEY; L-J,~, 08-12-2001 ANA 1 0 8270.00 DIRECTIONAL SURVEY; Please Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn': Lisa Weepie (AOGCC)~,~.,, Attn: Sandy Lemke (Phillips Alaska) Attn: Susan Nisbet (Exxon Mobil Production Co.) Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Stone Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 Re.' Prudhoe Bay Unit L-110 BP Exploration (Alaska) Inc. Permit No: 201-123 Sur Loc: 2365' NSL, 3772' WEL, SEC. 34, T12N, R11E, UM Btmhole Loc. 2265' SNL, 5264, WEL, SEC. 03, T1 IN, R11E, UM Dear Mr. Stone: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conduCting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit L- 110. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~~'"Daniel T. Seamount Commissioner BY ORDER OF THE COMMISSION DATED this / ~ ~ day of July, 2001 jjc/Enclosures CC: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. · OIL AND GAS CONSERVATION CO ,,,,,SSION I~r~J°~ I,[~_ PERMIT TO DRILL 20 AAC 25.005 I Exploratory [] Stratigraphic Test 511 Development Oil la. Type of work [] Drill [] Redrill lb. Type of well [] Service B [] Re-Entry [] Deepen Development Gas Single Zone Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 77' Prudhoe Bay Field / Borealis 3. Address 6. Property Designation Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028241 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 2O AAC 25.025) 2365' NSL, 3772' WEL, SEC. 34, T12N, R11E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 2175' SNL, 5235' WEL, SEC. 03, T11N, R11E, UM L-110 Number 2S100302630-277 At total depth 9. Approximate spud date 2265' SNL, 5264' WEL, SEC. 03, T11N, R11E, UM 07/10/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028239, 2265' MDI No Close Approach 2560 9099' MD / 7189' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 400' MD Maximum Hole Angle 49 o Maximum surface ~ psig, At total depth (TVD) 6561' / 3532 psig 18. Casing Program Specifications Setting Depth ,=~"~ ~-~'~ Size Top Bottom Quantity of Cement Hole Casin,q Wei,qht Grade Couplin.q Len,qth MD TVD MD TVD (include sta,qe data) 30" 20" 91.5# H-40 Weld 80' Surface Surface 110' 110' 260 sx Arctic Set (Approx.) 9-7/8" 7-5/8" 29.7# L-80 BTC 2839' Surface Surface 2839' 2577' 285 sx Arcticset Lite, 205 sx Class 'G' 6-3/4" 5-1/2,,x3-1/2. 15.5#/9.2# L-SO BTC-M/IBT-M 9099' Surface Surface 9099' 7189' 245 sx LiteCrete lg. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface IntermediateRECEIVED Production Liner JUN I 9 Z001 Alaska Oil & Gas Cons. Commission Perforation depth: measured Anchorage true vertical '20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program ' [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Nurnbec Nail Magee, 564-5119 Prepared By Name/Numbec Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge .... Signed Dan Stone ~-----~.--.. ,'~, ~ Title Senior Drilling Engineer Date (;/IR ,..' :'. ,,' .'.' :':" :, ":'; :':' ':' '., .',' :.,.. '.~. '".. :. ,'. '. ~.".. ': ,.,,',' ~ :...., ~:..'.. !...,.,'.?,.::,~'~.'::,,.: :..,,,. :.~ ,m....ml~sion:,U~e,:,.O.:p!]/' .,.;' :,, ,: ,,",., ::,,., .:....~;i,i.! :;: .,~?,.',.. ,.,. :.,.':.,....., ::,. ,.,! ',::..' ~. ,:, Permit Number I APl Number I A~'/°~, val ~F'~tI ISee c°ver letter .~o.,,,-. /.2_.~ 50- O ~- ~ - ~' ,_3' o ~-. ~ ~. for other requirements Conditions of Approval: Samples Required [] yes .~ NO MUd Log Required [] Yes 'j~ No Hydrogen Sulfide Measures [] Yes ~No Directional Survey Required 'J~ Yes [] No Required Working Pressure for BOPE [] 2K [] 3K ]~4K [] 5K [] 10K [] 15K [] 3.5K psi for CTU by order of Approved By Returned Commissioner the commission Date Form 10-401 Rev. 12-01-85 ORIGINAL Sub'mit In Triplicate IWell Name: IL-110 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Producer Surface Location: As-Built Target Location: Top Kuparuk Bottom Hole Location: X = 583,144.73' Y = 5,978,086.04' 2363' FSL (2915' FNL), 3771' FEL (1508' FWL), Sec. 34, T12N, R11E X = 581,740.09' Y = 5,973,529.97' 3104' FSL (2175' FNL), 5235' FEL (43' FWL), Sec. 03, TllN, R11E X = 581,712.01' Y = 5,973,438.94' 3013' FSL (2265' FNL), 5264' FEL (14' FWL), Sec. 03, T11N, R11E I AFE Number: 15M4022 I Estimated Start Date:17/10/2001 I IMD:19099' I ITvD: 17189' I Rig: I Nabors 9ES I Operating days to complete' 1 13.0 I BFIMS: 130' I I RKB: 177.0' I Well Design (conventional, slimhole, etc.): I Microbore (Iongstring) I Objective: ] Kuparuk Formation Mud Program: 9-7~8" Surface Hole (0-2840' ,: Fresh Water Surface Hole Mud Density Viscosity Yield Point APl FI. PH (ppg) (seconds) (Ib/100ftz) (mls/30min) Initial 8.5 - 8.6 300 50 - 70 15 - 20 8.5 - 9.5 below Permafrost 9.3 - 9.5 200-150 30 - 45 < 10 8.5 - 9.5 interval TD 9.6 max 150 25 - 35 < 10 8.5 - 9.5 6 3,4" Intermediate I Production Hole (2840'- 9099'): Fresh Water LSND Interval Density Tau o ~P PV ' pH APl HTHP (ppg) Filtrate Filtrate Upper 9.1-9.5 4-7 20-25 8-14 8.5-9.5 4-6 Interval Top of 10.8 5-8 20-25 8-14 8.5-9.5 3-5 <10 by HRZ HRZ L-110 Permit to Drill Page 1 Directional: Ver. Sperry WP-04 KOP: 400' Maximum Hole Angle: 49° at 2601' MD Close Approach Wells: All wells pass major risk criteria. Logging Program: Surface Intermediate/Production Hole Drilling: MWD / GR Open Hole: None Cased Hole: None Drilling: MWD / GR / Res Open Hole: GR-Res-Neu-Den, Cuttings samples Cased Hole: USIT cement evaluation (contingency) Formation Markers: Formation Tops MDbkb TVDss SV5 1465 SV4 1610 Base Permafrost 1775 SV3 1950 SV2 2120 SVl 2440 UG4A 2740 UG3 315O UG1 3594 Ma 3866 WS2 (N sands) 3890 Not hydrocarbon bearing WS1 (O sands) 4239 Not hydrocarbon bearing Obf Base 4665 CM2 (Colville) 5159 THRZ 629O BHRZ (Kalubik) 6412 K-1 6455 TKUP 6561 Hydrocarbon Bearin,g 3532 psi, 10.3 ppg Kuparuk C 6585 LCU Kuparuk B Kuparuck A TM LV (Miluveach) 7030 TD Criteria 9099' 7189 150' below Miluveach top L-110 Permit to Drill Page 2 Casincl/Tubinq Proqram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tb~l O.D. MD/TVD MD/TVD bkb 30" 20" 91.5# H-40 WLD 80' GL 80/80 9-7/8" 7 5/8" 29.7# L-80 BTC 2839' GL 2839'/2577' 6-3/4" 5-1/2" 15.5# L-80 BTC-m 8388' GL 8388'/6290' 6-3/4" 3-1/2" 9.2# L-80 IBT-mod 711' 8388'/7189' 9099'/7189' Tubing 3-1/2" 9.2# L-80 IBT-mod 8388' GL 8388'/6290' Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. Casino. Basis: Size 17-5/8" Surface I Lead: Based on 1896' of annulus in the permafrost @ 175% excess and 156' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface ITotal Cement Volume: Tail: Based on 500' TVD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2052' MD (1991' TVDbkb). Lead 225 bbl / 1265ft~ / 285 sks of Dowell ARTICSET Lite at 10.7 ppg and 4.44 cf/sk. Tail 43 bbl / 240 ft~ / 205 sks of Dowell Premium 'G' at 15.8 ppg and 1.17 cf/sk. Casing Size 1 5'1/2"x3'1/2" Pr°ducti°nILongstring Basis: I Lead: Based on TOC 1000' above top of Kuparuk formation & 30% excess + 80' shoe. I Lead TOC' 7538' MD, 5730' TVDbkb T°talCementV°lume: I Lead 1104bbls/585ft~/245sks°fD°weilLiteCreteat12'0ppgand2.39cf/sk. L-110 Permit to Drill Page 3 Well Control: Surface hole will be drilled with diverter. The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 4000 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Maximum anticipated BHP: 3532 psi @ 6561' TVDss - Kuparuk Sands · Maximum surface pressure: ~.3.1.-7~psi @ surface ~"'t (o (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: 4000 psi (for future frac stimulation treatments) · Planned completion fluid: 8.6 ppg filtered seawater / 6.8 ppg Diesel Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. L-110 Permit to Drill Page 4 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor is in place. 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and / or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig 1. 2. 3. 4. Operations: MIRU Nabors 9ES. Nipple up diverter spool and riser. Function test diverter. PU 4" DP as required and stand back in derrick. MU 9 7/8" drilling assembly with MWD/GR and directionally drill surface hole to approximately 2839' MD / 2577' TVD. The actual surface hole TD will be +/-100' TVD below the top of the SV1 sand. Run and cement the 7-5/8", 29.7# surface casing back to surface. A port collar will be run in the casing to allow for secondary cementing if cement is not circulated to surface during primary cementing operations. 5. ND diverter spool and NU casing / tubing head. NU BOPE and test to 4000 psi. 6. MU 6-3/4" drilling assembly with MWD/GR/NEU/DENS/RES and RIH to float collar. Test the 9-5/8" casing to 4000 psi for 30 minutes. 7. Drill out shoe joints and displace well to LSND drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. 8. Drill ahead to -150' of rat hole into the Miluveach formation. Condition hole for liner and POOH. 9. Run and cement the tapered production casing as required from TD to 1000' above the Kuparuk. Displace the casing with seawater during cementing operations and freeze protect the 5 Y2" x 7-5/8" annulus as required. 10. Test the casing to 4000 psi for 30 min. 11. Run the 3-1/2", 9.2#, L-80 gas lift completion assembly. Sting seal assembly into tieback receptacle and test to 4000 psi for 30 minutes both the tubing and annulus. Release tubing pressure ans shear RP valve. 12. Install TWC and nipple down the BOPE. Nipple up and test the tree to 5000 psi. 13. Freeze protect the well to -2200' and secure the well. 14. Rig down and move off. Estimated Spud Date: 7-10-2001 L-110 Permit to Drill Page 5 L-110 Hazards and Contingencies Job 1: MIRU Hazards and Contingencies > L-Pad is not designated as an H2S site. NWE1-01 and NEW 1-02 did not report H2S as being present. (Confirmed per J. Copen.) As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. > The closest surface locations are NWE1-01, NWE1-02 and L-01. All are greater then 85' from well L-116. No surface shut-in's will be required. Reference RPs Operational Specifics Job 2: Drillinq Surface Hole Hazards and Contingencies No faults are expected to be penetrated by L-110 in the surface interval. There are no close approach issues in the surface hole. All wells pass major risk criteria. Gas hydrates were observed by the NWE1-01and NWE1-02 wells. These were encountered near the base of the Permafrost at 1795' and 1730' TVD. L-01 surface interval encountered hydrates from the base of permafrost to TD in the SV1 sand. Expect to encounter hydrates from the base of permafrost to the surface shoe setting depth. Hydrates will be treated at surface with appropriate mud products. Refer to Baroid mud recommendation ~ Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. (Milne Point has encountered stuck pipe from this situation.) ~ No faults are mapped in the direction of the planned wellbore Reference RPs Operational Specifics Job 3: Install surface Casinq Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. 175% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. As a contingency, a 7-5/8" port collar will be positioned at _+1000'MD to allow a secondary circulation as required. Reference RPs L-110 Permit to Drill Page 6 Operational Specifics Job 7: Drillinc~ Intermediate / Production Hole Hazards and Contingencies KICK TOLERANCE: In the worst case scenario of 10.3 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 13.5 ppg at the surface casing shoe, 10.8 ppg mud in the hole, kick tolerance is 18 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 13.5 ppg. Reference RPs Operational Specifics Job 9: Case & Cement Production Hole Hazards and Contingencies The 5-1/2" casing will be cemented to 1000' above the Kuparuk sand, the upper most hydrocarbon bearing zone. The top of the hydrocarbon interval should be verified with LWD resistivity log. ~ After freeze protecting the 5 Y2" x 7-5/8" casing annulus with 33 bbls of dead crude, the hydrostatic pressure will be greater than the formation pressure, (11.1 EMW.) ;> Ensure a minimum hydrostatic equivalent of 10.8 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. Reference RPs Operational Specifics Job 12: Run Completion Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs Operational Specifics L-110 Permit to Drill Page 7 Job 13: ND/NU/Release Ricl Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs Operational Specifics L-110 Permit to Drill Page 8 L-110 Well Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: · Gas hydrates were observed in both NWE offset wells. These are expected to be encountered near the base of the Permafrost at 1850' and near the TD hole section as well. · Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. ° On S pad well S-30 has reported 1200 psi pressure on the outer casing annulus. Although this well is some 7 miles away, precautions should be in place while drilling through the upper Sagavanirktok (1600' to 2700' SS) . Production Hole Section: The production section will be drilled with a recommended mud weight of 10.8 ppg to ensure shale stability in the HRZ shale and Kingak shale section. Read the Shale Drilling Recommended Practice. Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. HYDROGEN SULFIDE - H2S · This drill-site not designated as an H2S drill site. Recent wells NEW 1-01 and NEW 1-02 did not report H2S as being present. As a precaution Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies Page ! of 1 TREE: 3-1/8" - 5M ClW L-80 WELLHEAD: 11" - 5M FMC G5 Borealis L-110: Proposed Completion Cellar Elevation = 47' RKB - MSL = 77' 3-1/2" 'X' Landing Nipple with 2.813' seal bore. I 2200' I 7-5/8", 29.7 #/ft, L-80, BTC 3-1/2" x 1" Gas Lift Mandrels with handling pups installed. GAS LIFT MANDRELS MD Size Valve Type TBD 1" DV TBD 1" DV TBD 1" DV TBD 1" DV 3-1/2" 9.2# IBT Mod L-80, Tubing 5-1/2", 15.5 #/ft, L-80, BTC-Mod 3-1/2" 'X' Landing Nipple with 2.813" seal bore 3-1/2" Seal Asembly 3-1/2" PBR 5-1/2"x3-1/2" XO placed at +/-150' above the Kuparuk Formation Plug Back Depth :3-1/2", 9.2 #~fi, L-80,1BT Mod 3-1/2" 'X' Landing Nipple with 2.813" seal bore ID 3-1/2" 'X' Landing Nipple with 2.813" seal bore ID. Date Rev By Comments 2-21-01 LRC Proposed Seal Bore Completion - WP4 Microbore with 5-1/2"x3-1/2" tapered Iongstring Borealis WELL: L-110 APl NO: 50-029-????? BP Alaska Drilling & Wells BP Amoco Anticollision Report Company: BP Amoco Date: 6/19/2001 Time: 09:42:21 Page: 1 Field: Prudhoe Bay Reference Site: PB L Pad Co-ordinate(NE) Reference: Well: Plan L-110, True North Reference Well: Plan L-110 Vertical (TVD) Reference: Temp Plan elevation 77 77.0 ReferenceWellpath: Plan L-110 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There ar~svells in thiR~s~al Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 77.00 to 9099.14 ft Scan Method: Trav Cylinder North Maxi_mu~.Radi_u_.s: 1102.21 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 12/26/2000 Validated: No Version: 4 Planned From To Survey Toolcode Tool Name 77.00 500.00 Planned: L-110 WP04 V1 CB-GYRO-SS Camera based gyro single shots 500.00 9099.14 Planned: L-110 WP04 V1 MWD MWD - Standard Casing Points ft: ft in in : : 9099.13 7189.94 5.500 6.750 5 1/2" Summary :i-i~'i~[~-iL-~'-~-~i~)-fi'~-i~ellpath ~-~=2-~.~ e> : :i R~ferefice Offsbt :~]~'~i' ':~'~': Allowable site: :: Well:: [ : ::: :: W~Iip:ath : :: : ::: MD ; :MD:: :DiStance Area: :i:De~iaii0n warning : ; :, : : : : : ;:: ft : : :: ::ft::: EX NWE#1 NWE1-01A NWE1-01A V4 300.03 300.05 242.60 5.60 237.01 Pass: Major Risk EX NWE#1 NWEI-01 NWEI-01 V3 299.98 300.00 242.60 5.60 237.00 Pass: Major Risk EX NWE#1 NWEI-02 NWE1-02 V2 447.17 450.00 209.48 7.73 201.75 Pass: Major Risk PB L Pad L-01 Plan L-01 V9 Plan: L-0 349.76 350.00 115.24 9.44 105.80 Pass: Major Risk PB L Pad L-116 Plan L-116 V3 Plan: L- 499.36 500.00 32.00 14.33 17.67 Pass: Major Risk PB L Pad Plan L-02 Plan L-02 V1 Plan: L-0 348.69 350.00 181.44 7.81 173.63 Pass: Major Risk PB L Pad Plan L-100 kwa Plan L-100 V0 Plan: L- 300.00 300.00 30.01 5.70 24.31 Pass: Major Risk PB L Pad Plan L-104 Plan L-104 V3 Plan: L- 446.59 450.00 251.09 8.74 242.35 Pass: Major Risk PB L Pad Plan L-105 Plan L-105 V5 Plan: L- 398.12 400.00 205.50 8.82 196.69 Pass: Major Risk PB L Pad Plan L-106 Plan L-106 V7 Plan: PI 446.91 450.00 221.07 9.43 211.64 Pass: Major Risk PB L Pad Plan L-107 Plan L-107 V6 Plan: L- 349.33 350.00 145.25 7.66 137.60 Pass: Major Risk PB L Pad Plan L-108 Plan L-108 V3 Plan: L- 447.31 450.00 191.08 8.95 182.12 Pass: Major Risk PB L Pad Plan L-109 Plan L-109 V3 Plan: L- 499.16 500.00 46.12 9.55 36.57 Pass: Major Risk PB L Pad Plan L-111 Plan L-111 V11 Plan: L 449.13 450.00 61.08 9.62 51.46 Pass: Major Risk PB L Pad Plan L-112 Plan L-112 V2 Plan: L- 446.86 450.00 191.95 9.44 182.51 Pass: Major Risk PB L Pad Plan L-113 Plan L-113 V3 Plan: L- 1058.26 1075.00 192.37 17.98 174.93 Pass: Major Risk PB L Pad Plan L-114 Plan L-114 SW V6 Plan: 876.45 875.00 67.28 19.25 48.04 Pass: Major Risk PB L Pad Plan L-115 Plan L-115 V5 Plan: L- 575.18 575.00 29.23 15.35 13.88 Pass: Major Risk Site: EX NWE#1 Well: NWEI-01A Rule Assigned: Major Risk Wellpath: NWE1-01A V4 Inter-Site Error: 0.00 ft [:?~' .......... l~';t~;"~;~";e" ................. . Offset· ' '"'"":'~Semi-Major .................................................................................................. Axis.. ? ..................... :""-~;-:-(~-~'~'--~;'"~' ............. ~ii-~-;';-I~-i';' ................ J ................... :. ......................... F--7'--], M:D 'TVD MD .TVD Ref" Offset TFO+AZI TFO-HS Casing Distance Area Deviation Warning I . ft ft' ft. .ft. · · ft ft. deg deg .' in ... ft. ft .. ft 99.99 99.99 100.00 100.00 0.05 0.06 285.71 285.71 241.41 1.24 240.17 Pass 124.99 124.99 125.00 125.00 0.16 0.07 285.71 285.71 241.46 1.83 239.63 Pass 149.99 149.99 150.00 150.00 0.26 0.07 285.71 285.71 241.52 2.42 239.11 Pass 174.99 174.99 175.00 175.00 0.36 0.08 285.70 285.70 241.60 3.00 238.60 Pass 199.99 199.99 200.00 200.00 0.47 0.10 285.69 285.69 241.69 3.63 238.07 Pass 224.99 224.99 225.00 225.00 0.52 0.13 285.67 285.67 241.82 4.12 237.70 Pass 249.99 249.99 250.00 250.00 0.58 0.16 285.63 285.63 242.01 4.63 237.38 Pass 274.99 274.99 275.00 275.00 0.63 0.18 285.58 285.58 242.27 5.12 237.15 Pass 300.03 300.03 300.05 300.04 0.69 0.20 285.50 285.50 242.60 5.60 237.01 Pass 325.02 325.02 325.00 324.98 0.69 0.24 285.41 87.63 243.01 5.96 237.06 Pass 350.05 350.05 350.00 349.97 0.69 0.27 285.32 87.54 243.50 6.30 237.21 Pass 375.09 375.09 375.00 374.96 0.69 0.30 285.23 87.45 244.06 6.63 237.44 Pass 400.13 400.12 400.00 399.94 0.70 0.33 285.13 87.35 244.69 6.98 237.73 Pass 425.17 425.16 425.00 424.91 0.70 0.36 285.04 87.26 245.37 7.34 238.05 Pass 450.21 450.19 450.00 449.88 0.70 0.39 284.94 87.16 246.09 7.69 238.42 Pass BP Amoco Planning Report - Geographic Company: BP Amoco Date: 2/14/2001 Time: 17:19:17 Page: Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan L-110, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: Plan L-110 Section (VS) Reference: Well (0.00E,0.00N,197.78Azi) Wellpath: Plan L-110 Plan: L-110 WP04 Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: BGGM2000 Site: PB L Pad UNITED STATES · North Slope Site Position: Northing: 5978232.73 ft Latitude: 70 21 1.823 N From: Map Easting: 582996.83 ft Longitude: 149 19 34.141 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.63 deg Well: Plan L-110 Slot Name: S-H Surface Position: +N/-S -149.31 ft Northing: 5978085.07 ft Latitude: 70 21 0.355 N +E/-W 146.66 ft Easting: 583145.12 ft Longitude: 149 19 29.855 W Position Uncertainty: 0.00 ft Reference Point: +N/-S -149.31 ft Northing: 5978085.07 ft Latitude: 70 21 0.355 N +E/-W 146.66 ft Easting: 583145.12 ft Longitude: 149 19 29.855 W Measured Depth: 77.00 ft Inclination: 0.00 deg Vertical Depth: 77.00 ft Azimuth: 0.00 deg Wellpath: Plan L-110 Drilled From: Well Ref. Point Tie-on Depth: 0.00 ft Current Datum: Temp Plan elevation 77 Height 77.00 ft Above System Datum: Mean Sea Level Magnetic Data: 12/26/2000 Declination: 26.47 deg Field Strength: 57446 nT Mag Dip Angle: 80.74 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 197.78 Plan: L-110 WP04 Date Composed: 1/30/2001 Version: 1 Principal: Yes Tied-to: From Well Ref. Point Plan Section Information MD ' lncl Azim' TvD +N/'S +E/-W · DLS .BUild. Turn · TFO Target ft deg. deg ft .. ft ft deg/100ft degtl'00ft deg/100ft deg " 77.00 0.00 0.00 77.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 800.00 5.00 197.78 799.37 -20.76 -6.66 1.00 1.00 0.00 197.78 1266.67 12.00 197.78 1260.62 -86.40 -27.71 1.50 1.50 0.00 0.00 1826.67 26.00 197.78 1788.79 -259.58 -83.24 2.50 2.50 0.00 0.00 2026.67 26.00 197.78 1968.55 -343.07 -110.01 0.00 0.00 0.00 0.00 2601.67 49.00 197.78 2421.67 -674.16 -216.17 4.00 4.00 0.00 0.00 6786.23 49.00 197.78 5167.00 -3681.48 -1180.45 0.00 0.00 0.00 0.00 8486.23 15.00 197.78 6587.62 -4526.79 -1451.50 2.00 -2.00 0.00 180.00 8538.39 15.00 197.78 6638.00 -4539.64 -1455.62 0.00 0.00 0.00 0.00 8949.14 6.79 197.78 7041.00 -4613.49 -1479.30 2.00 -2.00 0.00 180.00 9099.14 6.79 197.78 7189.95 -4630.37 -1484.71 0.00 0.00 0.00 0.00 PL12 Section 1 : Start ..... ~D inci AZim' 'TvD: ' +N/.s +E/:~-~7-"~-7-~- .... ~)-[~F ........ ~'~;i'~'-'-~"~r-n' ......... ~'~o--"~ ....:'-"~ ........ : .............. : :. ft deg deg ft ' ft · ft . ft ' deg/100ft degil00ft degll00ft deg ' ................ : ................ .~ ..................................................... .2 .................................................................. _:.._ _...: ..................................... ~. ........................................................ .:~ 77.00 0.00 0.00 77.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 BP Amoco Planning Report- Geographic Company: BP Amoco Date: 2/14/2001 Time: 17:19:17 Page: Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan L-110, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: Plan L-110 Section (VS) Reference: Well (0.00E,0.00N,197.78Azi) Wellpath: Plan L-110 Plan: L-110 WP04 Section 2: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg 400.00 1.00 197.78 399.99 -0.83 -0.27 0.87 1.00 1.00 0.00 0.00 500.00 2.00 197.78 499.96 -3.32 -1.07 3.49 1.00 1.00 0.00 0.00 600.00 3.00 197.78 599.86 -7.48 -2.40 7.85 1.00 1.00 0.00 0.00 700.00 4.00 197.78 699.68 -13.29 -4.26 13.96 1.00 1.00 0.00 0.00 800.00 5.00 197.78 799.37 -20.76 -6.66 21.80 1.00 1.00 0.00 0.00 Section 3: Start MD lncl Azim TVD +N/'S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg 900.00 6.50 197.78 898.86 -30.30 -9.72 31.82 1.50 1.50 0.00 0.00 1000.00 8.00 197.78 998.06 -42.32 -13.57 44.44 1.50 1.50 0.00 0.00 1100.00 9.50 197.78 1096.90 -56.80 -18.22 59.65 1.50 1.50 0.00 0.00 1200.00 11.00 197.78 1195.30 -73.75 -23.65 77.45 1.50 1.50 0.00 0.00 1266.67 12.00 197.78 1260.62 -86.40 -27.71 90.73 1.50 1.50 0.00 0.00 Section 4: Start 1300.00 12.83 197.78 1293.17 -93.22 -29.90 97.90 2.50 2.50 0.00 0,00 1400.00 15.33 197.78 1390.16 -116.39 -37.33 122.23 2.50 2.50 0.00 0.00 1500.00 17.83 197.78 1485.99 -143.57 -46.04 150.77 2.50 2.50 0.00 0.00 1600.00 20.33 197.78 1580.49 -174.70 -56.03 183.46 2.50 2.50 0.00 0,00 1700.00 22.83 197.78 1673.47 -209.72 -67.26 220.25 2.50 2.50 0.00 0.00 1800.00 25.33 197.78 1764.76 -248,58 -79.72 261.05 2.50 2.50 0.00 0.00 1826.67 26.00 197.78 1788.79 -259.58 -83.24 272.60 2.50 2.50 0.00 0,00 Section 5: Start 1900.00 26.00 197.78 1854.70 -290.19 -93.06 304.75 0.00 0.00 0.00 0.00 2000.00 26.00 197.78 1944.58 -331.93 -106.44 348.58 0.00 0.00 0.00 0.00 2026.67 26.00 197.78 1968.55 -343.07 -110.01 360.28 0.00 0.00 0.00 0.00 Section 6: Start MD Incl' . Azim 'TVD ' +N/-S +E/-W VS DLS Build Turn TFO ft deg. · deg ft ft. ft ft deg/lOOft deg/lOOft deg/lOOft deg 2100.00 28.93 197.78 2033.61 -375.27 -120.34 394.10 4.00 4.00 0.00 0.00 2200.00 32.93 197.78 2119.37 -424.21 -136.03 445.49 4.00 4.00 0.00 0.00 2300.00 36.93 197.78 2201,33 -478.73 -153.51 502.74 4.00 4.00 0.00 0.00 2400.00 40.93 197.78 2279.10 -538,56 -172.70 565.57 4.00 4.00 0.00 0.00 2500.00 44.93 197.78 2352.30 -603.40 -193.49 633.67 4.00 4.00 0.00 0.00 2601,67 49.00 197.78 2421.67 -674.16 -216,17 707.97 4.00 4.00 0,00 0.00 Section 7: Start MD Incl . .Azim . TVD +N/-S. .+E/-W vS. DLS Build Turn TFO ft ' deg deg ft ft ft ft deg/100ft .deg/100ft deg/100ft deg 2700.00 49.00 197.78 2486.18 -744,83 -238.83 782,18 0.00 0.00 0.00 0.00 2800.00 49.00 197.78 2551.79 -816.69 -261.88 857.65 0.00 0,00 0.00 0.00 2900.00 49.00 197.78 2617.39 -888.56 -284.92 933.12 0.00 0.00 0.00 0.00 3000.00 49.00 197.78 2683.00 -960.42 -307.97 1008,59 0.00 0.00 0.00 0.00 3100.00 49.00 197.78 2748.60 -1032.29 -331.02 1084,06 0.00 0.00 0.00 0.00 3200.00 49.00 197.78 2814.21 -1104.16 -354.06 1159.54 0.00 0.00 0.00 0.00 3300.00 49.00 197.78 2879.82 -1176.02 -377.11 1235.01 0.00 0.00 0.00 0.00 3400.00 49.00 197.78 2945.42 -1247.89 -400.15 1310.48 0.00 0.00 0.00 0.00 3500.00 49.00 197.78 3011.03 -1319.76 -423.20 1385.95 0.00 0.00 0.00 0.00 3600.00 49.00 197.78 3076.63 -1391.62 -446.25 1461.42 0.00 0.00 0.00 0.00 3700.00 49.0Q 197.78 3142.24 -1463.49 -469.29 1536.89 0.00 0.00 0.00 0.00 3800.00 49.00 197.78 3207.85 -1535.35 -492.34 1612.36 0.00 0.00 0.00 0.00 3900.00 49.00 197.78 3273.45 -1607.22 -515.38 1687.83 0.00 0.00 0.00 0.00 BP Amoco Planning Report- Geographic Company: BP Amoco Date: 2/14/2001 Time: 17:19:17 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan L-110, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: Plan L-110 Section (VS) Reference: Well (0.00E,0.00N,197.78Azi) Wellpath: Plan L-110 Plan: L-110 WP04 Section 7: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg 4000,00 49,00 197,78 3339,06 -1679,09 -538,43 1763,30 0.00 0,00 0,00 0,00 4100,00 49,00 197,78 3404,66 -1750,95 -561,48 1838,77 0,00 0,00 0,00 0,00 4200,00 49,00 197,78 3470,27 -1822,82 -584,52 1914,24 0,00 0,00 0,00 0,00 4300,00 49,00 197,78 3535,87 -1894,68 -607.57 1989,72 0,00 0,00 0.00 0,00 4400,00 49,00 197,78 3601,48 -1966,55 -630,61 2065,19 0,00 0,00 0,00 0,00 4500,00 49,00 197,78 3667,09 -2038,42 -653,66 2140,66 0,00 0,00 0,00 0,00 4600,00 49,00 197,78 3732.69 -2110,28 -676,71 2216,13 0,00 0,00 0,00 0,00 4700,00 49,00 197,78 3798,30 -2182,15 -699,75 2291,60 0,00 0,00 0,00 0,00 4800,00 49,00 197,78 3863,90 -2254,02 -722,80 2367,07 0,00 0,00 0,00 0,00 4900,00 49,00 197,78 3929.51 -2325,88 -745,84 2442,54 0,00 0,00 0,00 0,00 5000,00 49,00 197,78 3995,12 -2397,75 -768,89 2518,01 0,00 0,00 0,00 0,00 5100,00 49,00 197,78 4060,72 -2469,61 -791,94 2593,48 0,00 0,00 0,00 0,00 5200,00 49,00 197.78 4126,33 -2541,48 -814.98 2668,95 0,00 0,00 0,00 0,00 5300,00 49,00 197,78 4191,93 -2613,35 -838,03 2744,43 0,00 0,00 0,00 0,00 5400,00 49,00 197,78 4257,54 -2685,21 -861,07 2819,90 0,00 0,00 0,00 0,00 5500,00 49.00 197.78 4323,15 -2757,08 -884,12 2895,37 0,00 0,00 0,00 0,00 5600,00 49,00 197,78 4388,75 -2828,94 -907,17 2970,84 0,00 0,00 0,00 0,00 5700,00 49,00 197,78 4454,36 -2900,81 -930,21 3046,31 0,00 0,00 0,00 0,00 5800,00 49,00 197,78 4519,96 -2972.68 -953,26 3121,78 0,00 0,00 0,00 0,00 5900,00 49,00 197,78 4585,57 -3044,54 -976,30 3197,25 0,00 0,00 0,00 0.00 6000,00 49,00 197,78 4651,18 -3116,41 -999,35 3272,72 0,00 0,00 0,00 0,00 6100,00 49,00 197,78 4716,78 -3188,28 -1022,40 3348,19 0,00 0,00 0,00 0,00 6200,00 49,00 197,78 4782,39 -3260,14 -1045,44 3423,66 0,00 0,00 0,00 0,00 6300,00 49,00 197,78 4847,99 -3332,01 -1068,49 3499,13 0,00 0,00 0,00 0,00 6400.00 49,00 197,78 4913.60 -3403,87 -1091,53 3574,61 0,00 0,00 0,00 0,00 6500,00 49,00 197,78 4979,20 -3475,74 -1114,58 3650,08 0,00 0,00 0,00 0,00 6600,00 49,00 197,78 5044,81 -3547,61 -1137,63 3725,55 0,00 0,00 0,00 0,00 6700,00 49.00 197.78 5110,42 -3619,47 -1160,67 3801,02 0,00 0,00 0,00 0,00 6786,23 49,00 197,78 5167,00 -3681,48 -1180,45 3866,10 0,00 0,00 0.00 0.00 Section 8: Start MD ' Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft . deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg 6800,00 48,72 197,78 5176,06 -3691,36 -1183,62 3876,47 2,00 -2,00 0,00 180,00 6900,00 46,72 197,78 5243,32 -3761,81 -1206,21 3950,46 2,00 -2,00 0,00 180,00 7000,00 44,72 197,78 5313,13 -3829,99 -1228,07 4022,06 2,00 -2,00 0,00 180,00 7100,00 42,72 197,78 5385,40 -3895,80 -1249,18 4091.17 2,00 -2,00 0,00 180.00 7200,00 40,72 197,78 5460,03 -3959,17 -1269,50 4157,73 2,00 -2,00 0,00 180,00 7300,00 38.72 197,78 5536,94 -4020,03 -1289,02 4221,63 2,00 -2,00 0,00 180,00 7400,00 36,72 197,78 5616,03 -4078,29 -1307,70 4282,82 2,00 -2,00 0,00 180,00 7500,00 34,72 197,78 5697,21 -4133,89 -1325,53 4341,20 2,00 ~ -2,00 0,00 180,00 7600,00 32,72 197,78 5780,37 -4186,75 -1342,48 4396,72 2,00 -2,00 0,00 180,00 7700,00 30,72 197,78 5865,43 -4236,82 -1358,54 4449.30 2,00 -2.00 0,00 180,00 7800,00 28,72 197,78 5952,27 -4284,03 -1373,68 4498,88 2,00 -2,00 0,00 180,00 7900,00 26,72 197,78 6040,78 -4328,33 -1387,88 4545,40 2,00 -2,00 0,00 180,00 8000,00 24,72 197,78 6130,87 -4369,66 -1401,14 4588,80 2.00 -2,00 0,00 180,00 8100,00 22,72 197,78 6222,41 -4407,97 -1413,42 4629,03 2,00 -2,00 0,00 180,00 8200,00 20,72 197,78 6315,30 -4443,22 -1424,72 4666,05 2,00 -2,00 0,00 180,00 8300,00 18,72 197,78 6409.43 -4475,35 -1435.03 4699,80 2,00 -2,00 0,00 180,00 8400,00 16,72 197,78 6504,68 -4504,34 -1444,32 4730,24 2,00 -2,00 0,00 180,00 8486,23 15,00 197,78 6587,62 -4526,79 -1451,50 4753,81 2,00 -2,00 0,00 180,00 Section 9: Start ;:'~:~'~D · Incl ~im TVD +N/'s +E/-W VS DLS ' ~ui-~d"~* ....... ~I'-U'~';;- ..... -~--~'-: ft . ". deg deg" . ft ' ft ft . "ft . deg/100ftdeg/!00ftdegll00ft' deg. I-~'3~; ....... 'i-~'~'~- .............. i-~-~i'~" .......... ~-(~;~3-~ ......... :~-~3-~ ...... :~';~-~'~'~- .......... ;~'~'~'~-~ .................... ~-i~- ............. ~i'~-~- ................. ~'~-(; ........................ ~i~;~ ....................................... [8538,39 15,00 197.78 6638,00 -4539,64-1455,62 4767,30 0,00 0,00 0,00 0,00 BP Amoco Planning Report - Geographic Company: BP Amoco Date: 2/14/2001 Time: 17:19:17 Page: Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan L-110, True North Site: PB L Pad Vertical (']'VD) Reference: Temp Plan elevation 77 77.0 Well: Plan L-110 Section (~S) Reference: Well (0.00E.0.00N, 197.78Azi) W_e~!p_a_th!_._ Plan L-110 Plan: L-110 WP04 ........................................ Section 10: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg . deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg 8600.00 13.77 197.78 6697.68 -4554.21 -1460.29 4782.61 2.00 -2.00 0.00 180.00 8700.00 11.77 197.78 6795.20 -4575.26 -1467.04 4804.70 2.00 -2.00 0.00 180.00 8800.00 9.77 197.78 6893.43 -4593.05 -1472.75 4823.39 2.00 -2.00 0.00 180.00 8900.00 7.77 197.78 6992.26 -4607.56 -1477.40 4838.63 2.00 -2.00 0.00 180.00 8949.14 6.79 197.78 7041.00 -4613.49 -1479.30 4844.85 1.99 -1.99 0.00 180.00 Section 11 : Start ft deg deg ft ft ft ft degllOOftdegllOOftdegllOOft deg I'-"~',~0~-i'~(~ ................. ~;~ .............. "~'~7'17-~' ........ ~-(~'~(~ ........ -:;~-6~0~2-~'-:~-;~'~-4- ....... ;~'~'i~ .............. ~)'i'~)' .............. ~'i-~'~ .......... ~ ....... i'~01'~)'6' ...... ~ 9099.14 6.79 197.78 7189.95 -4630.37 -1484.71 4862.58 0.00 0.00 0.00 180.00 Survey = MD = :Incl: :Azim ::; TVD ;: :+N/-S +E/aW: : Northing :: :;Eas:tingll : ;:~Deg Min sec: Deg Min ::; sec:: ;: ::: : ft::;,:;; ::=;: d~g, ;:::; :deg :: :: ::ftc:: ;: ~ft::: :ft::=::: :: ft: ;::: : ft:::: ; =:: ;: ;;:~;:: : : 77.00 0.00 0.00 77.00 0.00 0.00 5978085.07 583145.12 70 21 0.355 N 149 19 29.855 W 100.00 0.00 0.00 100.00 0.00 0.00 5978085.07 583145.12 70 21 0.355 N 149 19 29.855 W 200.00 0.00 0.00 200.00 0.00 0.00 5978085.07 583145.12 70 21 0.355 N 149 19 29.855 W 300.00 0.00 0.00 300.00 0.00 0.00 5978085.07 583145.12 70 21 0.355 N 149 19 29.855 W 400.00 1.00 197.78 399.99 -0.83 -0.27 5978084.23 583144.86 70 21 0.346 N 149 19 29.862 W 500.00 2.00 197.78 499.96 -3.32 -1.07 5978081.73 583144.09 70 21 0.322 N 149 19 29.886 W 600.00 3.00 197.78 599.86 -7.48 -2.40 5978077.56 583142.81 70 21 0.281 N 149 19 29.925 W 700.00 4.00 197.78 699.68 -13.29 -4.26 5978071.73 583141.01 70 21 0.224 N 149 19 29.979 W 800.00 5.00 197.78 799.37 -20.76 -6.66 5978064.24 583138.69 70 21 0.150 N 149 19 30.049 W 900.00 6.50 197.78 898.86 -30.30 -9.72 5978054.66 583135.74 70 21 0.057 N 149 19 30.139 W 1000.00 8.00 197.78 998.06 -42.32 -13.57 5978042.61 583132.02 70 20 59.938 N 149 19 30.251 W 1100.00 9.50 197.78 1096.90 -56.80 -18.22 5978028.07 583127.54 70 20 59.796 N 149 19 30.387W 1200.00 11.00 197.78 1195.30 -73.75 -23.65 5978011.07 583122.29 70 20 59.629 N 149 19 30.546W 1266.67 12.00 197.78 1260.62 -86.40 -27.71 5977998.37 583118.37 70 20 59.505 N 149 19 30.664W 1300.00 12.83 197.78 1293.17 -93.22 -29.90 5977991.53 583116.26 70 20 59.438 N 149 19 30.728W 1400.00 15.33 197.78 1390.16 -116.39 -37.33 5977968.28 583109.09 70 20 59.210 N 149 19 30.946W 1500.00 17.83 197.78 1485.99 -143.57 -46.04 5977941.01 583100.68 70 20 58.943 N 149 19 31.200W 1600.00 20.33 197.78 1580.49 -174.70 -56.03 5977909.77 583091.04 70 20 58.636 N 149 19 31.492W 1700.00 22.83 197.78 1673.47 -209.72 -67.26 5977874.63 583080.20 70 20 58.292 N 149 19 31.820W 1800.00 25.33 197.78 1764.76 -248.58 -79.72 5977835.64 583068.17 70 20 57.910 N 149 19 32.184W 1826.67 26.00 197.78 1788.79 -259.58 -83.24 5977824.60 583064.77 70 20 57.802 N 149 19 32.287W 1900.00 26.00 197.78 1854.70 -290.19 -93.06 5977793.89 583055.30 70 20 57.501 N 149 19 32.574W 2000.00 26.00 197.78 1944.58 -331.93 -106.44 5977752.00 583042.38 70 20 57.090 N 149 19 32.965W 2026.67 26.00 197.78 1968.55 -343.07 -110.01 5977740.83 583038.93 70 20 56.981 N 149 19 33.070W 2100.00 28.93 197.78 2033.61 -375.27 -120.34 5977708.52 583028.97 70 20 56.664 N 149 19 33.371 W 2200.00 32.93 197.78 2119.37 -424.21 -136.03 5977659.41 583013.82 70 20 56.183 N 149 19 33.830W 2300.00 36.93 197.78 2201.33 -478.73 -153.51 5977604.71 582996.94 70 20 55.646 N 149 19 34.341 W 2400.00 40.93 197.78 2279.10 -538.56 -172.70 5977544.68 582978.42 70 20 55.058 N 149 19 34.901 W 2500.00 44.93 197.78 2352.30 -603.40 -193.49 5977479.61 582958.35 70 20 54.420 N 149 19 35.509W 2601.67 49.00 197.78 2421.67 -674.16 -216.17 5977408.61 582936.46 70 20 53.724 N 149 19 36.172W 2700.00 49.00 197.78 2486.18 -744.83 -238.83 5977337.71 582914.59 70 20 53.029 N 149 19 36.834W 2800.00 49.00 197.78 2551.79 -816.69 -261.88 5977265.60 582892.35 70 20 52.322 N 149 19 37.507W 2900.00 49.00 197.78 2617.39 -888.56 -284.92 5977193.48 582870.10 70 20 51.616 N 149 19 38.180W 3000.00 49.00 197.78 2683.00 -960.42 -307.97 5977121.37 582847.85 70 20 50.909 N 149 19 38.854W 3100.00 49.00 197.78 2748.60 -1032.29 -331.02 5977049.26 582825.61 70 20 50.202 N 149 19 39.527W 3200.00 49.00 197.78 2814.21 -1104.16 -354.06 5976977.15 582803.36 70 20 49.495 N 149 19 40.200W 3300.00 49.00 197.78 2879.82 -1176.02 -377.11 5976905.04 582781.12 70 20 48.788 N 149 19 40.874W 3400.00 49.00 197.78 2945.42 -1247.89 -400.15 5976832.93 582758.87 70 20 48.082 N 149 19 41.547W 3500.00 49.00 197.78 3011.03 -1319.76 -423.20 5976760.82 582736.63 70 20 47.375 N 149 19 42.220W BP Amoco Planning Report- Geographic Company: BP Amoco Date: 2/14/2001 Time: 17:19:17 Page: Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan L-110, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: Plan L-110 Section (VS) Reference: Well (0.00E,0.00N,197.78Azi) Wellpath: Plan L-110 Plan: L-110 WP04 Survey Map Map <-- Latitude --> <-- Longitude MD Incl Azim TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec ft deg deg ft ft ft ft ft 3600.00 49.00 197.78 3076.63 -1391.62 -446.25 5976688.71 582714.38 70 20 46.668 N 149 19 42.893 W 3700.00 49.00 197.78 3142.24 -1463.49 -469.29 5976616.60 582692.14 70 20 45.961 N 149 19 43.567 W 3800.00 49.00 197.78 3207.85 -1535.35 -492.34 5976544.49 582669.89 70 20 45.254 N 149 19 44.240 W 3900.00 49.00 197.78 3273.45 -1607.22 -515.38 5976472.38 582647.65 70 20 44.548 N 149 19 44.913 W 4000.00 49.00 197.78 3339.06 -1679.09 -538.43 5976400.27 582625.40 70 20 43.841 N 149 19 45.586 W 4100.00 49.00 197.78 3404.66 -1750.95 -561.48 5976328.15 582603.16 70 20 43.134 N 149 19 46.260 W 4200.00 49.00 197.78 3470.27 -1822.82 -584.52 5976256.04 582580.91 70 20 42.427 N 149 19 46.933 W 4300.00 49.00 197.78 3535.87 -1894.68 -607.57 5976183.93 582558.67 70 20 41.720 N 149 19 47.606 W 4400.00 49.00 197.78 3601.48 -1966.55 -630.61 5976111.82 582536.42 70 20 41.014 N 149 19 48.279 W 4500.00 49.00 197.78 3667.09 -2038.42 -653.66 5976039.71 582514.18 70 20 40.307 N 149 19 48.952 W 4600.00 49.00 197.78 3732.69 -2110.28 -676.71 5975967.60 582491.93 70 20 39.600 N 149 19 49.625 W 4700.00 49.00 197.78 3798.30 -2182.15 -699.75 5975895.49 582469.69 70 20 38.893 N 149 19 50.298W 4800.00 49.00 197.78 3863.90 -2254.02 -722.80 5975823.38 582447.44 70 20 38.186 N 149 19 50.972W 4900.00 49.00 197.78 3929.51 -2325.88 -745.84 5975751.27 582425.20 70 20 37.479 N 149 19 51.645W 5000.00 49.00 197.78 3995.12 -2397.75 -768.89 5975679.16 582402.95 70 20 36.773 N 149 19 52.318W 5100.00 49.00 197.78 4060.72 -2469.61 -791.94 5975607.05 582380.71 70 20 36.066 N 149 19 52.991 W 5200.00 49.00 197.78 4126.33 -2541.48 -814.98 5975534.94 582358.46 70 20 35.359 N 149 19 53.664W 5300.00 49.00 197.78 4191.93 -2613.35 -838.03 5975462.82 582336.22 70 20 34.652 N 149 19 54.337W 5400.00 49.00 197.78 4257.54 -2685.21 -861.07 5975390.71 582313.97 70 20 33.945 N 149 19 55.010W 5500.00 49.00 197.78 4323.15 -2757.08 -884.12 5975318.60 582291.73 70 20 33.239 N 149 19 55.683W 5600.00 49.00 197.78 4388.75 -2828.94 -907.17 5975246.49 582269.48 70 20 32.532 N 149 19 56.356W 5700.00 49.00 197.78 4454.36 -2900.81 -930.21 5975174.38 582247.24 70 20 31.825 N 149 19 57.029W 5800.00 49.00 197.78 4519.96 -2972.68 -953.26 5975102.27 582224.99 70 20 31.118 N 149 19 57.702W 5900.00 49.00 197.78 4585.57 -3044.54 -976.30 5975030.16 582202.74 70 20 30.411N 149 19 58.375W 6000.00 49.00 197.78 4651.18 -3116.41 -999.35 5974958.05 582180.50 70 20 29.704 N 149 19 59.048W 6100.00 49.00 197.78 4716.78 -3188.28 -1022.40 5974885.94 582158.25 70 20 28.998 N 149 19 59.721 W 6200.00 49.00 197.78 4782.39 -3260.14 -1045.44 5974813.83 582136.01 70 20 28.291 N 149 20 0.394W 6300.00 49.00 197.78 4847.99 -3332.01 -1068.49 5974741.72 582113.76 70 20 27.584 N 149 20 1.067W 6400.00 49.00 197.78 4913.60 -3403.87 -1091.53 5974669.61 582091.52 70 20 26.877 N 149 20 1.739W 6500.00 49.00 197.78 4979.20 -3475.74 -1114.58 5974597.50 582069.27 70 20 26.170 N 149 20 2.412W 6600.00 49.00 197.78 5044.81 -3547.61 -1137.63 5974525.38 582047.03 70 20 25.463 N 149 20 3.085W 6700.00 49.00 197.78 5110.42 -3619.47 -1160.67 5974453.27 582024.78 70 20 24.757 N 149 20 3.758W 6786.23 49.00 197.78 5167.00 -3681.48 -1180.45 5974391.06 582005.70 70 20 24.147 N 149 20 4.336W 6800.00 48.72 197.78 5176.06 -3691.36 -1183.62 5974381.15 582002.64 70 20 24.050 N 149 20 4.428W 6900.00 46.72 197.78 5243.32 -3761.81 -1206.21 5974310.45 581980.83 70 20 23.357 N 149 20 5.088W 7000.00 44.72 197.78 5313.13 -3829.99 -1228.07 5974242.05 581959.73 70 20 22.686 N 149 20 5.726W 7100.00 42.72 197.78 5385.40 -3895.80 -1249.18 5974176.01 581939.36 70 20 22.039 N 149 20 6.342W 7200.00 40.72 197.78 5460.03 -3959.17 -1269.50 5974112.42 581919.74 70 20 21.416 N 149 20 6.935W 7300.00 38.72 197.78 5536.94 -4020.03 -1289.02 5974051.36 581900.90 70 20 20.817 N 149 20 7.505W 7400.00 36.72 197.78 5616.03 -4078.29 -1307.70 5973992.90 581882.87 70 20 20.244 N 149 20 8.050W 7500.00 34.72 197.78 5697.21 -4133.89 -1325.53 5973937.11 581865.66 70 20 19.697 N 149 20 8.571 W 7600.00 32.72 197.78 5780.37 -4186.75 -1342.48 5973884.07 581849.30 70 20 19.177 N 149 20 9.066W 7700.00 30.72 197.78 5865.43 -4236.82 -1358.54 5973833.83 581833.80 70 20 18.685 N 149 20 9.534W 7800.00 28.72 197.78 5952.27 -4284.03 -1373.68 5973786.45 581819.19 70 20 18.220 N 149 20 9.976W 7900.00 26.72 197.78 6040.78 -4328.33 -1387.88 5973742.00 581805.47 70 20 17.785 N 149 20 10.391W 8000.00 24.72 197.78 6130.87 -4369.66 -1401.14 5973700.53 581792.68 70 20 17.378 N 149 20 10.778W 8100.00 22.72 197.78 6222.41 -4407.97 -1413.42 5973662.09 581780.82 70 20 17.001N 149 20 11.137W 8200.00 20.72 197.78 6315.30 -4443.22 -1424.72 5973626.73 581769.91 70 20 16.655 N 149 20 11.466W 8300.00 18.72 197.78 6409.43 -4475.35 -1435.03 5973594.48 581759.97 70 20 16.339 N 149 20 11.767W 8400.00 16.72 197.78 6504.68 -4504.34 -1444.32 5973565.39 581750.99 70 20 16.054 N 149 20 12.039W 8486.23 15.00 197.78 6587.62 -4526.79 -1451.50 5973542.87 581744.07 70 20 15.833 N 149 20 12.248W 8500.00 15.00 197.78 6600.92 -4530.18 -1452.59 5973539.46 581743.02 70 20 15.799 N 149 20 12.280W BP Amoco Planning Report- Geographic Company: BP Amoco Date: 2/14/2001 Time: 17:19:17 Page: 6 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan L-110, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: Plan L-l'10 Section (VS) Reference: Well (0.00E,0.00N,197.78Azi) Wellpath: Plan L-110 Plan: L-110 WP04 Survey Map Map <M Latitude ---> <-- Longitude MD lncl Azim TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec ft deg deg ft fl: fi: ft ft 8538.39 '15.00 197.78 6638.00 -4539.64 -1455.62 5973529.98 581740.09 70 20 15.706 N 149 20 12.368 W 8600.00 '13.77 '197.78 6697.68 -4554.2'1 -1460.29 5973515.35 581735.58 70 20 '15.563 N 149 20 '12.505 W 8700.00 '1'1.77 '197.78 6795.20 -4575.26 -'1467.04 5973494.24 58'1729.07 70 20 '15.356 N 149 20 '12.702 W 8800.00 9.77 '197.78 6893.43 -4593.05 -1472.75 5973476.39 58'1723.56 70 20 15.'181 N 149 20 '12.868 W 8900.00 7.77 '197.78 6992.26 -4607.56 -'1477.40 597346'1.82 58'17'19.07 70 20 15.038 N '149 20 '13.004 W 8949.14 6.79 197.78 704'1.00 -46'13.49 -1479.30 5973455.87 58'17'17.23 70 20 '14.980 N '149 20 '13.060 W 9000.00 6.79 '197.78 7091.50 -4619.22 -'1481.'14 5973450.'13 5817'15.46 70 20 14.924 N '149 20 13.'113 W 9099.'14 6.79 '197.78 7189.95 -4630.37 -'1484.71 5973438.94 58'17'12.01 70 20 '14.8'14 N '149 20 '13.217 W Targets TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK 1 CHECK WHAT APPLIES STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR. O~[~OSAL ( ~)NO ANNULAR DISPOSAL ( ) YES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS ( ) YES + SPACING EXCEPTION "CLUE" The permit is for a new weilbore segment of existing well , Permit No, APl No. ~. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be Clearly differentiated in both name (name on permit plus PH) and APl number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested... Annular Disposal of drilling wastes will not be approved... Annular Disposal of drilling wastes will not be approved... Please note that an disposal of fluids generated... Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conserVation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates I DATE / CHECK NO. 9114~ p~./o,~.,oz poi~li4a VENDOR i~iL..iI ~SKAO I LA OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET &O101 CKO&OIOID 1OO. CO 1OO. CO PYMT COMMENTS: PERffIT TO DRILL FEE HANDLING INST' S/H - TERRIE HUBBLE X4&28 ~ll[e~;~=~ ~ 1OO_ O0 100_ O0 : ATTACHED CHECK IS IN PAYMENT FOR ~EMS DESCRIBED ABOVE, AY, BP EXPLORATION, P.O:BOX'196612. :. ANcHoRAGEi ALASKA 99519-6612 'o The tRDER O~ CLEVELAND, OHIO 56-389 412 cONSOLIDATED 'COMMERCIAL 00191 l'.'4B US! DOLLAR,, :':','. ~:::~o',~:/o ~ .,.......:. - NOT'VALID 'AFTER 120 DAYS WELL PERMIT CHECKLIST FIELD & POOL CoMpANy WELL NAMF:~'/~"//~:3 PROGRAM: exp ADMINIS~leu~.TION INIT CLASS ENGINEERING . 2. 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in drilling unit ............ 8. If deviated, is wellbore plat included ............. ·.. 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. ATE 32. ,TE 33. 34. Permit fee attached ....................... Lease number appropriate ................... ANNULAR DISPOSAL35. APPR DATE G~L AREA · dev ,~'* reddl serv wellbore seg ann. disposal para req (A) will contain waste in a suitable receiving zonei ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for diSposal; (D) will not damage producing formation or impair recovery from a pool; and (E) wi!l. not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOLOGY: ENGINEERING:. ' UlClAnnular COMMISSION: UNIT# ,//'~'_<-~ ON/OFF SHORE Conductor string provided ......... .......... /~.N. Surface casing protects all known USDWs ........... N CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to.tie-in long string to surf csg ........ CMT will cover all known productive horizons. ' N. Casing designs adequate for C, T, B & permafrost ....... If a re-drill, has a 10-403 for abandonment been approved... ~ ~ ~ ~ --) '-- ~ ~"~ ' If diverter required, does it meet regulations ........... ~.~N Drilling .fluid program schematic & equip list adequate ..... Yd. N Choke manifold complies w/APl RP-53 (May 84) ......... . Work will occur without operation shutdown ........... (._~)..J~l_~ Is presence of H2S gas probable ................. P~rmit can be issued wlo hydrogen sulfide measures ...... Y N Data presented on potential overpressure zones .. ...... Y ~ .Z-/' ?//'"/) ' seismic analysis of shallow gas zones ............. seabed condition survey (if off-shore) ........... . . · ~ Y N" "' ~ ' ' Contact name/phone for weekly progress reports [exploratory ~O~fly] Y N With proper cementing records, this plan Y N Y N Y N Comments/instructions: ~ .... "' ' , ,,, f , O Z O z --I -I- c:~nsoffice\wordian~liana\checklist (rev. 11101//00)