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Home My WebLink About202-006 Im~ Project Well History File Coy(Oage 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. a 0 ~ 00 to Well History File Identifier Organizing {done} R?CAN VI Color items: 0 Grayscale items: "'"11111111'"111 0 Two-Sided DIGITAL DATA ~ Diskettes, No. f 0 Other, Noffype 0 Poor Quality Originals: Other: 0 NOTES: BY: BEVERLY ROBIN VINCENT SHERyBvINDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~INDY Scanning Preparation -L x 30 = 3 (J BY: BEVERLY ROBIN VINCENT SHERY~INDY Production Scanning ~e'can Needed 111111111111/111111 OVERSIZED (Scannable) 0 Maps: Other items scannable by large scanner 0 OVERSIZED (Non-Scannable) 0 Logs of various kinds 0 Other D"'lf '¡~lr#' mf 1111111111111111111 DATE If íbftJifol v11P + ¡ i = TOTAL PAGES L¡.-~ DATE~ í"/tI-f" VVlf tit Stage 1 BV:W Stage 2 v/ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: - YES B""'RLV Ro"," V'"C'"' S>ÆR" MAR~ W'"DY Dm'1f~4 ,,' IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: - YES PAGE COUNT FROM SCANNED FILE: BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIALAHENTION IS REQUIREO ON AN INOIVlOUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReScanned (imlividual!ug,,-[r,paci,J/.JtlûiHi(}!Jj .sCiHJniHg cnmp/Olûd) RESCANNEDB'f: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: _NO _NO DATE: Isl 1111111111111111111 1111111111111111111 DATE: Isl Quality Checked (dolle) 11111111111111111" 12/1 OiO2Rev3NOTScanned. wpd NOT OPERBALE: Producer L -120 #2020060) Secured with a load and 16 Page 1 of 3 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelllntegrityCoordinator @bp.com] C, Sent: Sent: Tuesday, November 30, 2010 2:19 PM� To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad LV; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr Cc: Janowski, Carrie; Greaves, Damien C Subject: NOT OPERBALE: Producer L -120 (PTD #2020060) Secured with a load and kill All, Producer L -120 (PTD #2020060) was unable to be placed on production to perform a TIFL due to ongoing electric panel repairs. The well was temporarily secured with a load and kill on 11/29/10. Therefore, the well will be reclassified as Not Operable until the electric repairs are complete. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 AAWEV D C tr, 8' 2UIV From: AK, D &C Well Integrity Coordinator Sent: Sunday, November 14, 2010 7:15 AM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; "Schwartz, Guy (DOA'; AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field 0 &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad LV; AK, OPS Prod Controllers; AK, RES GPB East Wells Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr Cc: King, Whitney; AK, D &C Well Integrity Coordinator; Greaves, Damien C Subject: UNDER EVALUATION: Producer L -120 (PTD #2020060) Evaluate for TxIA communication All, Producer L -120 (PTD #2020060) has been secured and shut in following sustained casing above MOASP (see e-mail chain below). Work has been completed on the L -118 tie -in, allowing L -120 to be put back into production. The well has been reclassified as Under Evaluation. The well may be brought back online while work is attempted to restore integrity. The plan forward: 1. DHD: Re -TIFL with a warm well 2. Slickline: Evaluate for gas lift valve change out based on the results of the warm TIFL Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 12/7/2010 NOT OPERBALE: Producer L -120 #2020060) Secured with a load and Page 2 of 3 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Saturday, October 16, 2010 6:55 AM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA) <guy.schwartz @alaska.gov >'; AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field 0 &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad LV; AK, OPS Prod Controllers; AK, RES GPB East Wells Opt Engr; AK, RES GPB Central Prod Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead Cc: King, Whitney; AK, D &C Well Integrity Coordinator; Greaves, Damien C Subject: NOT OPERABLE: Producer L -120 (PTD #2020060) Secured w/ a load & kill All, Producer L -120 (PTD #2020060) was secured w/ a load and kill on 10/16/10 after the IA was confirmed to have sustained casing pressure. The plan forward is to place the well on production after the L -118 tie -in work is complete and re -TIFL. In the interim, the well has been reclassified as Not Operable. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Wednesday, September 22, 2010 9:31 AM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA) <guy.schwartz @alaska.gov >'; AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field 0 &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad LV; AK, OPS Prod Controllers; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Oakley, Ray (PRA) Cc: King, Whitney; Quy, Tiffany; AK, D &C Well Integrity Coordinator Subject: UNDER EVALUATION: Producer L -120 (PTD #2020060) Confirmed Sustained Casing Pressure Above MOASP All. Producer L -120 (PTD #2020060) has confirmed sustained casing pressure above MOASP due to TAA communication. The wellhead pressures were tubing /IA/OA equal to 2080/2100/530 on 9/21/2010. A cold TIFL failed on 9/21/2010. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. The plan forward is to: 1. DHD: Re -TIFL with a warm well 2. Slickline: Evaluate for gas lift valve change out based on the results of the warm TIFL A TIO plot and wellbore schematic have been included for reference. << File: Producer L -120 (PTD #2020060) TIO Plot.doc >> Please call if you have questions or concerns. 12/7/2010 NOT OPERBALE: Producer L -120 (PTD #2020060) Secured with a load and k Page 3 of 3 Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext, 1154 12/7/2010 UNDER EVALUATION: Producer *0 (PTD #2020060) Evaluate for TxI *mmunication Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] 'Zlf 415 -11C Sent: Sunday, November 14, 2010 7:15 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad LV; AK, OPS Prod Controllers; AK, RES GPB East Wells Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr Cc: King, Whitney; AK, D &C Well Integrity Coordinator; Greaves, Damien C Subject: UNDER EVALUATION: Producer L -120 (PTD #2020060) Evaluate for TxIA communication All, i Producer L -120 (PTD #2020060) has been secured and shut in following sustained casing above MOASP (see e-mail chain below). Work has been comp a on the L -118 tie -in, allowing L -120 to be put back into production. The well has been reclassified as Under Evaluation. The well may be brought back online while work is attempted to restore integrity. The plan forward: 1. DHD: Re -TIFL with a warm well 2. Slickline: Evaluate for gas lift valve change out based on the results of the warm TIFL Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) NOV Well Integrity Coordinator 9 Y Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Saturday, October 16, 2010 6:55 AM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA) <guy.schwartz @alaska.gov >'; AK, OPS GC2 OSM; AK, Field &M TL; AK OPS GC2 Well ad Lead; AK OPS Well Pad LV• AK OPS Prod Controllers; AK OPS GC2 Facility OTL; AK, OPS GC2 e d 0 p , RES GPB East Wells Opt Engr; AK, RES GPB Central Prod Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead Cc: King, Whitney; AK, D &C Well Integrity Coordinator; Greaves, Damien C Subject: NOT OPERABLE: Producer L -120 (PTD #2020060) Secured w/ a load & kill All, Producer L -120 (PTD #2020060) was secured w/ a load and kill on 10/16/10 after the IA was confirmed to have sustained casing pressure. The plan forward is to place the well on production after the L -118 tie -in work is complete and re -TIFL. In the interim, the well has been reclassified as Not Operable. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 11/15/2010 UNDER EVALUATION: Producer *0 (PTD #2020060) Evaluate for TxI *mmunication Page 2 of 2 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Wednesday, September 22, 2010 9:31 AM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA) <guy.schwartz @alaska.gov >'; AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field 0 &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad LV; AK, OPS Prod Controllers; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Oakley, Ray (PRA) Cc: King, Whitney; Quy, Tiffany; AK, D &C Well Integrity Coordinator Subject: UNDER EVALUATION: Producer L -120 (PTD #2020060) Confirmed Sustained Casing Pressure Above MOASP All. Producer L -120 (PTD #2020060) has confirmed sustained casing pressure above MOASP due to TAA communication. The wellhead pressures were tubing /IA/OA equal to 2080/2100/530 on 9/21/2010. A cold TIFL failed on 9/21/2010. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. The plan forward is to: 1. DHD: Re -TIFL with a warm well 2. Slickline: Evaluate for gas lift valve change out based on the results of the warm TIFL A TIO plot and wellbore schematic have been included for reference. << File: Producer L -120 (PTD #2020060) TIO Plot.doc >> Please call if you have 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 11/15/2010 M BP Expioration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 ~r,~-_~, f ~ ~; `~E~iC~ .._ , ~~- ,,,{~,. ~ ~{.,:.^,. Lut.,~. f 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, ~ bp ~~~~I~~~ 0 C T 4i 5 Z009 ~tas~~ ~il ~C Gas Cuns. Ca[rxunis~io~ Anchorage ~ ~' oa ~ ~,-,a° Enclosed please find multipie 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 e~ernal 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 ~ i BP Exploration (Alaska ) Inc. Surface Casing by Conductor Mnulus Cement, Conosion inhibftor, Sealant Top-off Report of Sundry Operations (10~04) Date L pad 8/13/2009 Well Name PTD # API # Inidal to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitoN sealant date ft bbls ft na al L-01 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 62 NA 57.8 6/29/2009 ~-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 10.2 6/26/2009 L-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 316.2 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 5002923t290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 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 225 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 6/27/2009 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 ~-200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 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 1/10/2009 L-210 2031990 50029231870000 NA 325 NA 31.4 5/5/2009 L-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 6/25/2009 L-214A 2060270 50029232580100 NA 025 NA 10.2 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 500292320fi0000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late blockin 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 50028232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 . . -, '" MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc STATE OF ALASKA . RE~~~~ ~FA~~G~~~~S:~~~~~E~~~~~1?2 ~ ZOO5 Alaska Oil & Gas Cons. C-urmnts3ììJí, A6ilQ8tqe 0 Time Extension 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADl 028238 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structu ral Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): 181 Repair Well 0 Plug Perforations 0 Stimulate 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 4. Current Well Class: 181 Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Drill Number: 202-006 6. API Number: 50-029-23064-00-00 99519-6612 79.1' 9. Well Name and Number: PBU L-120 10. Field / Pool(s): Prudhoe Bay Field / Borealis Pool 9474 7156 9358 7041 107' 3013' feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD 34" x 20" 107' 107' 7-5/8" 3042' 2658' 5-1/2" x 3-1/2" 9459' 7141' 4990 Burst Collapse 1490 6890 470 4790 9433' 7000 SCANNED ~lAN 2 1 2005 8870' - 8920' 6556' - 6606' 3-1/2",9.2# L-80 8672' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 3-1/2" HES 'X' Nipple 1930' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS BFl .IAN 2 1 20U5 Treatment description including volumes used and final pressure: 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl CasinQ Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Shane Gagliardi, 564-5251 N/A Printed Name Terrie Hubble Signature --1~, ~ Form 10-404 Revised 04/2004 Title Technical Assistant Ph Of ~ 1\ / r. c:- Prepared By NameINumber: one 564-4628 Date I~( Vv Terrie Hubble, 564-4628 , , ~{'\ A L Submit Original Only ) ) BPEXPLORATIDN O.pètØtiöl1$..$l.IrijlÎlary..'.~èp()rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L -120 L -120 WORKOVER NABORS ALASKA DRILLING I NABORS 9ES Start: 1/1/2005 Rig Release: 2/15/2002 Rig Number: Spud Date: 1/31/2002 End: 1/3/2005 Date Främ 7'Tä HoUrs Täsk Code NPT D~scriptiänof Operations 1/2/2005 00:00 - 03:00 3.00 MOB P PRE Move storage tanks and pit complex, Move rig off well L-02A, 03:00 - 03:30 0.50 MOB P PRE Lay mats and herculite. 03:30 - 04:30 1.00 MOB P PRE Spot rig over L-120. 04:30 - 05:00 0.50 MOB P PRE Spot pits and cuttings tank. 05:00 - 07:30 2.50 WHSUR P DECOMP Rig circulating lines. Accept rig at 05:30 hrs. 07:30 - 09:30 2.00 WHSUR P DECOMP Rig up DSM. Pull BPV with lubricator. Rig down lubricator. 09:30 - 12:30 3.00 WHSUR P DECOMP Pressure test lines to 2000 psi, Displace diesel freeze protect from well with 8.5 ppg seawater, Pump down annulus until all diesel is displaced. Swap lines and circ the long way with 50 bbls soap sweep. followed w/ sea water. 12:30 - 13:00 0.50 WHSUR P DECOMP Install TWC, Test from below to 1000 psi. 13:00 - 15:00 2.00 WHSUR P DECOMP Nipple down tree, and adapter flange. Plug control line. 15:00 - 17:30 2.50 BOPSUP. P DECOMP Nipple up BOP's. 17:30 - 18:00 0.50 BOPSURP DECOMP Rig up testing equipment. 18:00 - 21 :00 3.00 BOPSUR P DECOMP Test BOP and related equipment to BP & AOGCC regs, Test to 250 low - 3500 high. Witnessing waived by Lou Gramaldi--AOGCC Field Inspector. 21 :00 - 21 :30 0.50 BOPSUP P DECOMP Lay down test joint, Blow down lines. 21 :30 - 00:00 2.50 BOPSURP DECOMP Pick up DSM lubricator, Attempt to pull TWC, RD lubricator, MU joint and circulate on top of TWC to wash out trash. Pick up lubricator and pull TWC. Rig down DSM lubricator. 1/3/2005 00:00 - 01 :30 1.50 PULL P DECOMP Make up xo and drill pipe joint to hanger, Pull seals from PBR, Circ while pulling hanger to rig floor. PU wt 170k, String wt 100k. 01 :30 - 02:30 1.00 PULL P DECOMP Circulate bottoms up to clean well bore. Rig up Camco spooling unit to recover the control line, Remove Tubing hanger (Redress) 02:30 - 06:00 3.50 PULL P DECOMP Pull out of hole with 3.5" tubing, Pull 17 joints with bands attached, after pulling 17 joints the tubing has no bands and shows no wear marks where the bands should have been. The tubing is showing wear marks on one side of the pipe where it looks like it is rubbing against the casing. Pulled slips, drain stack, and inspect down in the stack to ensure that pipe is centered. Pipe is in the center on the stack. Install slips and continue pulling tubing, Making sure that the control line is keep tight. 06:00 - 06:30 0.50 PULL P DECOMP Continue POH & LD 3.5" tubing to the SSSV,(Retrieved 29 of 74 control line bands). LD SSSV, The control line was parted at the SSSV. 06:30 - 17:00 10.50 PULL P DECOMP Continue POH with 3.5" tubing & jewelry (271 jts). 3ea GLM, Sliding SLV, and Baker seal assy. (GLM # 3 had some tangled control line & some bands around the top of mandrel) 17:00 - 17:30 0.50 PULL P DECOMP Clean & Clear rig floor. 17:30 - 18:30 1.00 PULL P DECOMP RU & Test lower pipe rams to 250 psi low - 3500 psi high. RD test equipment. 18:30 - 19:30 1.00 CLEAN N DPRB DECOMP RU Schlumberger Slickline to recover control line bands. 19:30 - 00:00 4.50 CLEAN N DPRB DECOMP RIH with 4.75 Junk basket to 2850', POH, Recoverd 16 bands, Control line, and Shale - Cement. 1/4/2005 00:00 - 02:00 2.00 CLEAN N DPRB DECOMP RIH with Junk Basket (4.75) to 8658', POH to surface, Recovered 12 band & more control line. 02:00 - 03:00 1.00 CLEAN N DPRB DECOMP Run back in hole with Junk Basket (4.75) to 8658', POH to surface, Recovered small amount of control line. 03:00 - 04:00 1.00 CLEAN N DPRB DECOMP LD Junk Basket, PU brushes (4.90), RIH to bottom of PBR Printed: 1/10/2005 9:24: 16 AM ) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L -120 L -120 WORKOVER NABORS ALASKA DRILLING I NABORS 9ES Start: 1/1/2005 Rig Release: 2/15/2002 Rig Number: Spud Date: 1/31/2002 End: 1/3/2005 Datë From.~To 1/4/2005 03:00 - 04:00 1.00 CLEAN N DPRB DECOMP 04:00 - 05:00 1.00 CLEAN N DPRB DECOMP 05:00 - 06:00 1.00 CLEAN N DPRB DECOMP 06:00 - 07:00 1.00 CLEAN N DPRB DECOMP 07:00 - 11 :00 4.00 CLEAN N DPRB DECOMP 11 :00 - 12:30 1.50 CLEAN N DPRB DECOMP 12:30 - 13:30 1.00 RUNCOMP RUNCMP 13:30 - 00:00 10.50 RUNCOMP RUNCMP 1/5/2005 00:00 - 02:00 2.00 RUNCOMP RUNCMP 02:00 - 02:30 0.50 RUNCOMP RUNCMP 02:30 - 04:00 1.50 RUNCOMP RUNCMP 04:00 - 06:30 2.50 RUNCOMP RUNCMP 06:30 - 08:00 1.50 SIT OTHCMP P 08:00 - 08:30 0.50 WHSUR P WHDTRE 08:30 - 10:00 1.50 BOPSUR P OTHCMP 10:00 - 12:00 2.00 WHSUR P WHDTRE 12:00 - 14:00 2.00 WHSUR P WHDTRE 14:00 - 15:00 1.00 WHSUR P WHDTRE 15:00 - 17:00 2.00 WHSUR P WHDTRE 17:00 - 19:00 2.00 WHSUR P WHDTRE 19:00 - 20:00 1.00 WHSUR P WHDTRE 8675', POH to surface, Brush was clean. LD Brush, PU Junk Basket (2.88) RIH to bottom of PBR 8675', POH to surface, Basket had about a cup full of cement & rocks. LD Junk Basket, PU Gauge Ring (3.815) RIH to bottom ofPBR 8675', POH to surface, RD GR. PU 3.5" Gauge ring, RIH to to 8680', POH, lay down gauge ring. P/U 2.75" lead impression block, RIH to 8677', POH and lay down impression block, impression block showed no signs of junk. Rig down slick line unit. Rig up to run 3.5" completion string. Make up Baker 4" seal assembly, X nipple assembly, 3.5" 9.2# L-80 IBT-M tubing, per running order, makeup torque == 2300 ftllbs. Continue running 3.5" 9.2# L-80 IBT-M completion, pickup joint # 268 & #269 makeup head pin and circulating hose, tag top of PBR with seal assembly @ 8658' , up wt == 100k, dn wt == 75k Pump 20 bbl high vis sweep, to clean up any debris left in hole @ 235 gpm, 1625 psi. Reverse 75 bbls clean seawater, followed by 75 bbls seawater treated with corrosion inhibitor @ 135 gpm, 755 psi. Locatet top of PBR, pumping 1 bpm @ 85 psi, pressure increased to 150 psi shut down pumps, slacked off 12' and set down 10K, repeated process with same results. Test seals to 1,500 psi to insure fully inserted, lay down joints #269,#268,#267, make up two space out pups totaling 17.71' makeup tubing hanger and land tubing RILDS. Pressure up to 3,500 psi on tubing hold for 30 min record on chart, bleed tubing pressure to 2,00 psi, pressure up on annulus to 3,500 psi hold for 30 min record on chart, bleed annulus pressure to zero, bleed tubing pressure to zero, pressure up on annulus to shear DCK valve in upper GLM, valve sheared @ 2,100 psi. Back out landing joint, install TWC and test from below to 1,000 psi. Drain Stack, remove mouse hole, nipple down BOP. Nipple up adapter flange and tree. Test adapter flange and tree to 5,000 psi, wing valve on tree leaked, replace valve and re-test. Rig up DSM lubricator, pull TWC. Rig up Little Red, test lines to 2,500 psi, freeze protect tubing and annulus with 45 bbls diesel @ 3 bpm, 1 ,200 psi. Allow diesel to U-tube. Install BPV with lubricator, test BPV from below to 1,000 psi. Rig down Little Red, remove secondary valve on IA and install flange, install VR plugs in both IA valves, Secure well. Release Rig @ 20:00 hrs 1/5/2005 Printed: 1/10/2005 9:24:16 AM TREE..:: 3-1/8" 5M CrN WELLHEAD = 11" FMC < .. < ACTUATOR = NA KEf ELEV =" 79.10' SF. ELEV =' . 5'5~4Öi ....,...'" ,.,' KOP = 950' Max Anglë = "PS5 @ 4615' DatumMD ~." . "8994' Öatum ìVD =" . . 660Öi ss ) L-120 SAI '} NOTES: - =-i 986' 1-17-5/8" TAM PORT COLLAR I - I . 1930' 1-13-1/2" HES X NIPPLE, ID = 2.813" 17-5/8" CSG, 29.7#, L-80, ID = 6.875" 1-1 3042' ~ Minimum ID = 2.813" @ 1930' 3-1/2" HES X NIPPLE ÆRFORA TION SUMMARY REF LOG: ANGLEATTOPÆRF: 8@8870' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 8870 - 8904 0 03/17/02 2-1/2" 6 8914 - 8920 0 03/17/02 13-1/2" TBG, 9.2#, L-80, IBT-M, .0087 bpf, ID = 2.992" 1-1 8654' I 5-1/2" CSG, 15.5#, L-80, BTC, ID = 4.950" 1-1 8657' 14-3/4" X 3-1/2" CSG XO, ID = 3.000" 1-1 8675' PBTD 1-1 9358' 13-1/2" CSG, 9.2#, L-80, ID = 2.992" 1-1 9459' L I . \ I r I I I I ~ DATE 02/15/02 03/02/02 03/17/02 03/24/02 04/08/03 11/24/03 REV BY DA TE REV BY 01/05/05 TA RWO COMMENTS COMMENTS ORIGINAL COMPLETION CH/TP CORRECTIONS CWS/tlh ADD PERF JB/KAK GLV C/O DRS/TP ìV D/MD CORRECTIONS JLJ/PA G GL V C/O ~ ST MD 7 2076 6 3014 5 4266 4 5455 3 6615 2 7677 1 8577 GAS LIFT MANDRELS ìVD DEV TYÆ VLV LATCH PORT 1985 33 KBG2-9 DMY BTM 0 2642 53 KBG2-9 DMY BTM 0 3393 55 KBG2-9 DCK BTM 0 4094 52 KBG2-9 DMY BTM 0 4803 52 KBG2-9 DMY BTM 0 5498 44 KBG2-9 DMY BTM 0 6272 15 KBG2-9 DMY BTM 0 8633' 1-13-1/2" HES X NIP, ID = 2.813" 8654' 1-1 BKR LOC SEAL ASSY, ID = 2.990" 1 8658' I-1TOP OF BKR PBR, ID = 4.00" I 8672' I--J BTM OF 3-1/2" BKR SEAL ASSY, ID = 2.990" 1 8695' 1-13-1/2" HES X NIP, ID = 2.813" 1 8716' 1-13-1/2"HESXNIP, ID=2.813" 1 8790' 1-116' PUPJT W / RA TAG 1 9215' 1-115' PUP JT W / RA TAG 1 DATE 01/04/05 01/04/05 01/04/05 01/04/05 01/04/05 01/04/05 01/04/05 BOREALIS UNrr WELL: L-120 ÆRMrr No: 2020060 API No: 50-029-23064-00 SEC 34, T12N, R11 E 2608' NSL & 3545' WEL BP Exploration (Alaska) 1~ A-V:I ~hð'-{ DATA SUBMITTAL COMPLIANCE REPORT 4/2/2004 Permit to Drill 2020060 Well Name/No. PRUDHOE BAY UNIT L-120 Operator BP EXPLORATION (ALASKA) INC Sf ttd J / J Ow-- ^"~~ API No. 50-029-23064-00-00 MD 9474 ..--- TVD 7156 ..... Completion Date 3/17/2002"""'--- Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log Log Run Scale Media No 1 Interval Start Stop 2990 9474 107 9474 ) Log/ Electr Data Digital Dataset Type Med/Frmt Number Name +~ C cAO700 C JØ698 Well Cores/Samples Information: OH/ CH Received Comments Open 3115/2002 rEX AIT BHC data Case 3122/2002 Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y Il&, Daily History Received? ~ QIN Chips Received? - Y I N Formation Tops Analysis Received? Y/N ) Comments: f\I\~ ~ ~~~ K.V>\'~i Compliance Reviewed By: l~ Date: J;( /Jp NN '-I :~ ~, ,"- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well iii Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface r óOMrlEmiil. 2608' NSL, 3545' WEL, SEC. 34, T12N, R11E, UM , DAre ~ AI top of productive interval , 3 '/~J 4~~~~t~~~é~t~50' WEL, SEC. 35, T12N, R11E, UM '.~' \I~.~..-..: ¡'., 10. Well Number 4776' NSL, 3904' WEL, SEC. 35, T12N, R11 E, UM L...:..:.:. -. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. . . 11. F~~~~~~ ~~~I Field / Borealis Pool RKB :;::: 79.1' ADL 028238 (Undefined) 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband. 115. Water depth, if offshore 116. No. of Completions 1/31/2002 2/8/2002 3/17/2002 N/A MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 1190 Directional Survey 120. Depth where SSSV setl21. Thickness of Permafrost 9474 7156 FT 9392 7074 FT iii Yes 0 No (Nipple) 2220' MD 1900' (Approx.) 22. Type Electric or Other Logs Run RES / AIT, DT / BHC, CNL, LDL, GR, Caliper, SP, MRES, MWD, LWD, SONIC, MDT 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE 34" X 20" 91.5# H-40 Surface 107' 42" 7-5/8" 29.7# L-80 29' 3042' 9-7/8" 5-1/2" 15.5# L-80 26' 8675' 6-3/4" 3-1/2" 9.2# L-80 8675' 9459' 6-3/4" Classification of Service Well 7. Permit Number 202-006 8. API Number 50- 029-23064-00 9. Unit or Lease Name Prudhoe Bay Unit L-120 CEMENTING RECORD 260 sx Arctic Set (Approx.) 376 sX AS Lite, 137 sx Class 'G' 169 sx Lite Crete, 158 sx Class 'G' Longstring, Cemented with 5-1/2" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 6 SPF MD TVD 25. SIZE 3-1/2",9.2#, L-80 MD TVD AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 8674' PACKER SET (MD) N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MO) AMOUNT & KIND OF MATERIAL USED 8870' - 8920' Fractured: Placed 176,400 #'s of 16/20 & 12/18 Carbolite behind pipe. Freeze Protected with 100 Bbls of Diesel. 8870' - 8904' 8914' - 8920' 6556' - 6590' 6600' - 6606' 27. Date First Production April 23,2002 Date of Test Hours Tested 5/12/2002 4 Flow Tubing Casing Pressure Press. PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR TEST PERIOD CALCULATED 24-HoUR RATE OIL-BBL 3596 OIL-BBL GAs-McF 3094 GAs-McF WATER-BBL 186 WATER-BBL CHOKE SIZE I GAS-OIL RATIO 65 861 OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or waterRttcEet'r£ D No core samples were taken. . . ^', J ., ~ n f"'" 'v', -" 'I i >, iUIV l ¡r" i J b vI.. AlasJ<a Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 () I"i 7BDMS BFL Submit In Duplicate MAY ?O 2002- GF ,~ 29. Geologic Markers Marker Name Measured True Vertical UG4/ Depth Depth 3370' 2860' UG4A 3416' 2888' UG3/ 4034' 3256' UG1 ' 4981' 3807' Schradder Bluff 'M' ,/ 5237' 3960' Schradder Bluff 'N' 5673' 4227' Schradder Bluff '0" 5963' 4404' Base of Schrader Bluff \ Top of Colville 6606' 4796' CM1 7852' 5629' THRZ / 8550' 6244' TKLB 8756' 6444' Kuparuk 'D' 8866' 6552' Top of Kuparuk 'C' 8869' 6555' LCU /Top of Kuparuk 'B' 9051' 6735' Kuparuk A 9196' 6879' Top of Miluveach / Base of 9259' 6942' Kuparuk 31, List of Attachments: ,~ 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. MDT was ran, log supplied for detail. D I'. C ~- q p"'r')' r~;'~'"i,,"~~}~":j ~ '" Ð = 'b",' <. ~~ ,J , ~ " " ~. '"¡ OJ J iUUL Alaslm Œ18~ Cons. GO!1HmSSlOì AnchoraQ€'. Summary of Daily Drilling Reports, Surveys, Post Rig work summary and a Leak Off Test Summary. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~~ ~ Title Technical Assistant L-120 202-006 Well Number Permit No. / Approval No. INSTRUCTIONS Date O$.14'O~ Prepared By Name/Number: Sandra Stewman, 564-4750 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 28: If no cores taken, indicate 'none', ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. Form 10-407 Rev. 07-01-80 r,\Pi " ¡, ',,' \ ! ! I', ¡ \.j '\ . ¡ ¡ 00 NN ..- ..- I I ...J...J Qj E ., ro ~ Z ro c: Z 0 - E ro E 0)0 ~() Cì a. ,e, èXi rri ...... ~ ,j¡ ,e, I'- a a>. ~ ,j¡ ,e, M N <0 Cì a. ,e, a M cri g a <Xi It) <0 C\Î g a N '<t a C""Î l- e ...I N a a ~ It) Ñ ~ ~, ~ '" '" ,:.: <:'! ;: '" a a ~ \::! '" Ü Q ë: & ,""--"" . "-...,, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-120 L-120 DRILL +COMPLETE NABORS NABORS 9ES Start: 1/30/2002 Rig Release: Rig Number: 9-ES Spud Date: 1/31/2002 End: 1/30/2002 12:00 -13:00 1.00 MOB P PRE Rig dn, prepare for move to L 120 13:00 - 15:30 2,50 MOB P PRE PJSM, move off well L 104, move on to L 120. 15:30 - 17:00 1,50 RIGU P PRE Spot rig modules, Hook up power and fluid lines. Install diverter valves. RIG ACCEPTED 1700 HRS ON 1/3012002. 17:00 - 00:00 7,00 WHSUR P SURF NU diverter and riser. Take on water, Start building spud mud, Start taking BHA tools into pipe shed, 1/31/2002 00:00 - 02:00 2,00 DRILL P SURF Cont mix spud mud while service top drive, change saver sub, 02:00 - 05:00 3,00 DRILL P SURF MU bha #1, drctnl assy, MWD / LWD 05:00 - 05:30 0,50 DRILL P SURF Pre - spud meeting, all personnel, rig team, 05:30 - 06:00 0,50 DRILL P SURF Function test diverter system. Witness waived by John Crisp AAOGC 06:00 - 10:30 4,50 DRILL P SURF Spud well, drill ahead 9 7/8 hole drctnl107 - 541 ft, 10:30 -12:00 1,50 DRILL N WAIT SURF Wait on "Guzzlers" to arrive. Road delay. 12:00 - 22:30 10,50 DRILL P SURF Resume drill ahead 541 - 1751 ft, No gain flosses. Parameters normal. WOB 30, RPM 70, SPM 202, GPM 600, PRESS 2000, TO 4500 UP 83, DN 76, ROT 78 AST = 4,2 hrs, ART = 6.18 hrs 22:30 - 00:00 1.50 DRILL P SURF Circ well clean, Pump wt pill, flow check, blow dn surface equip 2/1/2002 00:00 - 02:00 2,00 DRILL P SURF Cont poh for bit, 15 - 30K overpull at 1650,1450,1200 ft, Slight swabbing, work free, 02:00 - 02:30 0,50 DRILL P SURF Flow check, handle bha #1, make up bit #2, 02:30 - 03:30 1,00 DRILL P SURF Service top drive, change out saver sub. 03:30 - 05:00 1,50 DRILL P SURF Flow check, rih, take wt at 850, 1000, 1100, 1545, slight downdrag to btm, 05:00 - 12:30 7.50 DRILL P SURF Precaution wash 90 ft to btm, Resume drill ahead 9 7/8 drctnl hole 1751 - 3055 ft td, Confirmed on site geologist. WOB 30, RPM 70, SPM 202, GPM 600, PRESS 2800, TQ 4500 UP 94, DN 83, ROT 85 AST = 2,83 hrs ART = 2 hrs 12:30 - 13:30 1.00 DRILL P SURF Circ / cond mud, shaker clean, normal cuttings return. 13:30 - 16:30 3,00 DRILL P SURF Flow check, poh for csg run, Intermittent swabbing, 15 - 20 overpull to 1500 ft. 16:30 - 19:00 2,50 DRILL P SURF Flow check, handle bha #2, layout drctnl equip motor / MWD I LWD, 19:00 - 19:30 0,50 DRILL P SURF Clear rig floor, clear tools, 19:30 - 20:30 1.00 DRILL P SURF Make up hole opener bha, rih same, 20:30 - 00:00 3,50 DRILL P SURF Follow bha with 4"dp, Down drag at 1560,1650 - 1980, 2466, ( 20-25K ) Ream at 1825, 2260, 2535, 2616, 2876, Will not ream past 2876 ft. 212/2002 00:00 - 01 :00 1.00 DRILL P SURF Cont attempt ream at 2886 ft. No further progress, 01 :00 - 02:30 1.50 DRILL P SURF Flow check, poh for drilling assy, wellbore good cond to shoe. Slight swabbing, 02:30 - 04:30 2,00 DRILL P SURF Handle bha, Layout hole opener assy. 04:30 - 05:30 1,00 DRILL P SURF MU bha #4, adjust motor, MWD / motor, rih same, 05:30 - 07:00 1,50 DRILL P SURF Cut drlg line, service top drive, 07:00 - 08:00 1.00 DRILL P SURF Flow check, rih bha, shallow test motor I MWD, Printed: 2/20/2002 11 :28:05 AM ,r--..., .~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-120 L-120 DRILL +COMPLETE NABORS NABORS 9ES Start: 1/30/2002 Rig Release: Rig Number: 9-ES Spud Date: 1/31/2002 End: 2/2/2002 08:00 - 10:00 2,00 DRILL P SURF Follow bha with 4" dp to 2700 ft, 10:00 - 11 :00 1,00 DRILL P SURF Commence ream wellbore 2700 - 3055 td, bridged over at 2886 ft, 11 :00 - 12:00 1,00 DRILL P SURF Circ sweep / wt pill, cond mud, Shaker clean, normal cuttings returns. 12:00 - 13:00 1,00 DRILL P SURF Flow check, poh for 7 518 csg run, 13:00 -15:00 2,00 DRILL P SURF Layout motor I MWD assy. 15:00 - 15:30 0,50 DRILL P SURF Clear rig floor. 15:30 - 17:00 1,50 CASE P SURF Rig up for 7 5/8 csg run, perform csg hgr dummy run. 17:00 - 21:30 4,50 CASE P SURF Flow check, Make up float equip, rih / test same, Rih 7 5/8 - 29.7# - L80 - BTC Mod csg, Wellbore free of obstruction, No loss / gains, 21 :30 - 22:00 0,50 CASE P SURF Install hgr /Idg jt. Make up cmt hd. Seat hgr temporarily. 22:00 - 00:00 2,00 CASE P SURF Flow check, recip csg, stage up pumps to 7 bpm, 100% returns. Cont circ / cond, 2/3/2002 00:00 - 01 :00 1.00 CASE P SURF Cont circ / cond in preparation cmt 75/8 csg, 100% returns, Recip csg, normal drag, 01 :00 - 04:00 3,00 CASE P SURF PJSM, Cmt 7 5/8 csg as follows: Pump 5 bbl CW100, test lines to 3500 psi. Pump remaining 5 bbls CW100. Pump 75 bbls Mud Push - 10,2 ppg with red dye, Drop btm plug, pump 306 bbl10,7 ppg - Arctic set Lite III-lead slurry at 6 bpm, Pump 29 bbl 15,8 ppg - "G" - tail slurry at 6 bpm. Drop top plug, displace with rig pump, 137 bbls mud, Bump plug 0315 hrs - correct displacement. Build to 1236 psi, hold 5 min, bleed, floats holding, FCP = 646 psi at 2 bpm, 60 bbls cmt returns at surface, Recip csg during job. 04:00 - 06:00 2.00 CASE P SURF Remove cmt hd, layout all cmt run equip, 06:00 - 09:00 3,00 CASE P SURF N/D diverter system. 09:00 - 10:30 1,50 CASE P SURF Install speed hd, tbg hd - dsa. 10:30 - 12:00 1,50 CASE P SURF N/U bope, test all seals 4500 psi. All tests successful. No re-test. 12:00 - 14:00 2.00 CASE P SURF N/U remainder bope, riser, turnbuckles, 14:00 -18:30 4,50 CASE P SURF Set test plug, test bope as follows: Annular - 250 / 3500 psi - 10 min, Blind - pipe rams - 250 /4500 psi - 10 min, Choke / kill lines / choke manfld / all outlet valves 250 / 4500 psi - 10 min. Standpipe to pumps, floor valves, safety valves, 250 / 4500 psi. Accumulator time / volume test. Test witnessed by Jeff Jones AAOGC. All tests successful, no re-tests, 18:30 - 19:00 0.50 CASE P SURF Rig dn bop test equip, pull test plug, install wear ring. 19:00 - 19:30 0.50 CASE P SURF Service top drive, 19:30 - 00:00 4.50 CASE P SURF Begin P/U 4" dp from shed, standing back in mast. 21412002 00:00 - 04:00 4.00 CASE P SURF PU DP fl pipe shed & stand back in derrick. 04:00 - 06:00 2,00 CASE P SURF PU & MU BHA, Orient motor & MWD, Load nuke source, 06:00 - 00:00 18,00 CASE N WAIT SURF Phase 3 called field wide, WOW, Perform rig maintenance. Clean rig. 2/5/2002 00:00 - 11 :00 11,00 CASE N WAIT SURF Continue W,O,W, Conserve Water & Fuel. Printed: 2/2012002 11 :28:05 AM ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-120 L-120 DRILL +COMPLETE NABORS NABORS 9ES Start: 1/30/2002 Rig Release: Rig Number: 9-ES Spud Date: 1/31/2002 End: 2/5/2002 11 :00 - 13:00 2.00 DRILL P PROD1 RIH w/ BHA. LD ADN. PU NM DC's. Shallow test MWD, 13:00 -15:00 2,00 DRILL P PROD1 P/U 4" DP from shed - RIH to 2830', 15:00 -16:00 1,00 DRILL P PROD1 Test 7 5/8" Casing to 3500 psi for 30 minutes. 16:00 - 18:00 2,00 DRILL P PROD1 Tag Cement @ 2932', Drill Cement, Shoe Track And 20 ft, of new hole to 3076' 18:00 - 19:00 1.00 DRILL P PROD1 Displace Mud to 9,3 ppg. LSND system. 19:00 - 20:00 1.00 DRILL P PROD1 Perform LOT, 623 psi surface pressure w/ 9,3 ppg mud. LOT = 13,81ppg EM W, 20:00 - 00:00 4,00 DRILL P PROD1 Directional drill 6 3/4" Hole from 3076' to 3839'. WeB = 5. 10K , 325 GPM @ 2300 psi. P/U = 88K 8/0 = 72K ROT = 81 K TQ = 2 to 2.9K. AST = 0.5 Hrs, ART = 2 Hrs. 2/6/2002 00:00 - 03:00 3.00 DRILL P PROD1 Drill from 3829' to 4483',325 GPM @ 2550 psi. TQ = 4K WeB = 5 to 15K, P/U = 94K, S/O = 73K, ROT = 85K. AST = 0.5 Hrs ART = 2 Hrs. 03:00 - 03:30 0.50 DRILL P PROD1 Circulate Hi-Vis Sweep, 03:30 - 07:00 3.50 DRILL P PROD1 Wipe hole to shoe, Pulling tight - 30K over, and trying to swab, Pump out of hole to shoe, backreaming where necessary 07:00 - 07:30 0.50 DRILL P PROD1 Circulate bottoms up. 07:30 - 08:00 0,50 DRILL P PROD1 Service top drive. 08:00 - 09:30 1.50 DRILL P PROD1 RIH Tight @ 4109'. Wash and ream to bottom @ 4483' - No Fill. 09:30 - 00:00 14.50 DRILL P PROD1 Drill from 4483' to 6257'. 325 GPM @ 2650 psi. TQ = 4,8K, WeB = 5 to 15K, P/U = 120K SIC = 91 K, ROT = 102K. AST = 3 Hrs ART = 6,5 Hrs, 217/2002 00:00 - 02:30 2,50 DRILL P PROD1 Drill from 6257' to 6631', 325 GPM @ 2700 psi. TQ = 5.5K, WeB = 5 to 15K, P/U = 123K SIO = 88K, ROT = 106K AST = 0,5 Hrs, ART = 1.75 Hrs, 02:30 - 03:30 1,00 DRILL P PROD1 Circulate Hi-Vis sweep @ 325 GPM, Rotate @ 110 RPM & reciprocate. 03:30 - 08:00 4,50 DRILL P PROD1 Wiper trip to shoe, Wipe twice every stand. Pump & backream from 5375' to 5200', Continue Poh to shoe wiping every stand, 08:00 - 09:00 1,00 DRILL P PROD1 Service Top Drive, 09:00 - 12:30 3,50 DRILL P PROD1 RIH, Tight @ 4200', ream to 4560', Having to ream every other stand to 5000'. Cont RIH, Work through tight spot @ 6130'. Cont. RIH to 6530', Wash last stand to bottom, 12:30 . 00:00 11,50 DRILL P PROD1 Drill from 6631' to 7800', 325 GPM @ 3030 psi. TQ = 6.3K, WOB = 10 to 15K P/U = 140K SIC = 98K, ROT = 117K. AST = 1.6 Hrs. ART = 6,9 Hrs, Lost 30 bbls Mud drilling from 6890' to 7011', then no further losses. 2/8/2002 00:00 - 09:00 9.00 DRILL P PROD1 Drill from 7800' to 8316'. Weight up mud to 10,3 ppg while drilling ahead to 8504', 325 GPM @ 3135 psi. WeB = 8 to 15K. P/U = 152K, SIC = 106K, ROT = 123K, TQ = 7,2K ART = 7,5 Hrs. No Sliding. 09:00 - 10:00 1,00 DRILL P PROD1 Circulate Hi - Vis Sweep. 325 GPM & 110 RPM, 10:00-11:00 1,00 DRILL P PROD1 POH to 6256', 20K over @ 6745' & 6500'. Wiped through - OK, 11:00-12:00 1.00 DRILL P PROD1 RIH to 8410', Wash last stand to bottom @ 8504'. No problems, 12:00 - 00:00 12,00 DRILL P PROD1 Drill from 8504' to 9474' - TD per Geologist. 310 GPM @ 3050 Printed: 2/20/2002 11 :28:05 AM r'-- ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-120 L-120 DRILL +COMPLETE NABORS NABORS 9ES Start: 1/30/2002 Rig Release: Rig Number: 9-ES Spud Date: 1/31/2002 End: 2/812002 12:00 - 00:00 12,00 DRILL P PROD1 psi, WeB + 10 to 15K P/U = 180K, SIC = 120K, ROT = 144K, TQ = 9 K. ART = 9.66 Hrs, No sliding, 2/9/2002 00:00 - 01 :30 1,50 DRILL P PROD1 Circulate Hi- Vis Sweep while reciprocating pipe and rotating @ 110 RPM. 01 :30 - 05:00 3,50 DRILL P PROD1 Wiper Trip to shoe. Max overpull 25K. Wiped through tight spots @ 8950, 6500, 6140, 5350 & 4100. No pump nor backreaming necessary. 05:00 - 07:00 2,00 DRILL P PROD1 Cut & slip drilling line, Service Top Drive & Crown. 07:00 - 10:00 3,00 DRILL P PROD1 RIH. Work through tight spot @ 6145 - Ok. 10:00 -12:30 2.50 DRILL P PROD1 Wash last stand to bottom. Circ. Hi-Vis sweep. spot logging pill, pump slug. 12:30 -17:00 4,50 DRILL P PROD1 POH, standing back all 4" DP & HWDP. 17:00 -19:00 2,00 DRILL P PROD1 UD & load out BHA, 19:00 - 00:00 5,00 EVAL P PROD1 PJSM wI SWS and Rig Team. RlU SWS E - Line, Run PEX I BHC Sonic as per program, 2/10/2002 00:00 - 02:00 2.00 EVAL P PROD1 Complete Logging PEXlBHC Sonic on E-Line.. Logging interval: 3034' to 9429'. POH 02:00 - 03:00 1,00 EVAL P PROD1 UD PEX tools and RID sheaves, 03:00 - 05:30 2,50 EVAL P PROD1 MIU MDT tools on 1st stand HWDP. Latch & surface check tools - OK, 05:30 - 06:30 1,00 EVAL P PROD1 RIH wlMDT on DP to 7 5/8" shoe. 06:30 - 07:30 1.00 EVAL P PROD1 Circulate - 3 BPM @ 245 psi. 07:30 - 11 :00 3,50 EVAL P PROD1 Continue RIH, breaking circulation every 10 stands to 8227' 11:00-13:00 2.00 EVAL P PROD1 Circulate bottoms up - 3 BPM @ 490 psi. 13:00 - 14:30 1.50 EVAL P PROD1 MIU Latch tool and Side Entry Sub wlMDT @ 8203'. Pump Latch tool down to MDt wI 3,5 BPM @ 650 psi. Good Latch - Tool operational. 14:30 - 22:30 8.00 EVAL P PROD1 Log down wI MDT from 8225' to 9233', Work through tight spot @ 8872' - no further problems, Attempt 20 pressure readings and 3 fluid samples, Successfuly completed 15 pressure readings and 2 fluid samples. 22:30 - 23:30 1.00 EVAL P PROD1 POH to SES ( MDT @ 8203') 23:30 - 00:00 0.50 EVAL P PROD1 Un- Latch E-Line from MDT, POH wI E-Line, 2/11/2002 00:00 - 01 :00 1,00 EVAL P PROD1 POH wI E-Llne, Break out and set aside SES and tool head. 01 :00 - 03:00 2,00 EVAL P PROD1 POH to 4956', breaking circulation every 10 stands, 03:00 - 04:00 1,00 EVAL P PROD1 CBU - 3 BPM @ 310 psi. 04:00 - 05:00 1.00 EVAL P PROD1 M/U SES. RIH wI E-Line, Bring pumps on line and latch into MDT. Secure E-Line wI clamp, Test MDT - OK. 05:00 - 00:00 19,00 EVAL P PROD1 Log Schrader Bluff formation wI MDT from 5243' to 6531', Attempted 24 pressure points -successful wI 15. Attempted 5 Fluid Samples - successful wI 4. 2/1212002 00:00 - 01 :00 1.00 EVAL P PROD1 Continue taking Schrader fluid samples. 01 :00 - 03:30 2,50 EVAL P PROD1 POH to SES@4956'. POH wI Schlumberger E-line, RD SWS. 03:30 - 04:30 1.00 EVAL P PROD1 CBU. 3 BPM w/310 psi. RD SWS sheaves. 04:30 - 05:30 1.00 EVAL P PROD1 POH wI logging tools. 05:30 - 09:00 3.50 EVAL P PROD1 Stand back HWDP. Recover fluid samples and LD SWS logging tools, 09:00 - 12:00 3,00 EVAL P PROD1 Pull wear ring, Set test plug, Test BOPE to 250 14500 psi; annular to 250 I 3500 psi. Witnessing waived by Chuck Scheve-AOGCC Field Inspector, Pull test plug, Set wear ring. Printed; 2/20/2DD2 11 ;28;05 AM ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-120 L-120 DRILL +COMPLETE NABORS NABORS 9ES Start: 1/30/2002 Rig Release: Rig Number: 9-ES Spud Date: 1/31/2002 End: 2/12/2002 12:00 - 13:30 1.50 DRILL P PROD1 MU hole opener BHA. 13:30 -15:30 2,00 DRILL P PROD1 RIH slow to shoe, 15:30 - 16:00 0.50 DRILL P PROD1 CBU. Stage pump up slow to 300 gpm w/ 805 psi. No losses. 16:00 -18:00 2,00 DRILL P PROD1 RIH slowly to 6071'. Break circ every 10 stds, No losses. Good displacement. 18:00 - 19:00 1.00 DRILL P PROD1 CBU, Stage pump up slow to 310 gpm w/1350 psi. 100 RPM, Mud thick, Recovered moderate cuttings, No losses, 19:00 - 21 :00 2,00 DRILL P PROD1 RIH slowly to 8688', Break circ every 10 stds. No losses. Good displacement. 21 :00 - 22:00 1.00 DRILL P PROD1 CBU, Stage pump up slow to 310 gpm wI 1800 psi. 100 RPM, Mud thick, Recovered heavier cuttings. No losses. 22:00 - 22:30 0,50 DRILL P PROD1 RIH slowly to bottom @ 9474', Wash last stand to bottom. No losses. Good displacement. 22:30 - 00:00 1,50 DRILL P PROD1 Stage pumps up slowly to 310 rpm w/1860 psi. 110 rpm, Pump sweep, Circ & cond mud. No losses. 2/13/2002 00:00 - 02:00 2,00 DRILL P PROD1 Fin pump sweep around to clean hole. Spot liner running pill. Monitor well. POH for casing, 02:00 - 07:30 5.50 DRILL P PROD1 POH for casing, Work tight spots 9100,8975-8879,8570-8500, Cont POH LDDP leaving 40 stands in derrick, Monitor well @ 7 5/8" shoe - OK. 07:30 - 08:30 1,00 DRILL P PROD1 LD cleanout BHA. 08:30 - 09:00 0.50 CASE P CaMP Pull wear ring & make dummy run with casing hanger, 09:00 - 10:30 1.50 CASE P CaMP RU to run 3.5" & 5.5" casing. 10:30 -10:45 0,25 CASE P CaMP PJSM for running casing. 10:45 - 16:00 5,25 CASE P CaMP MU shoe track. Run 22 jts 3,5" casing followed by 5.5" casing to 3040'. 16:00 -16:30 0,50 CASE P CaMP Circ 1,5 csg vol to cond mud prior to run in OH. 16:30 - 21 :30 5,00 CASE P CaMP Run casing to 6000', 21 :30 - 22:00 0,50 CASE P CaMP Break circ and clear 1.5x pipe vol to cond mud & break gels. 22:00 - 00:00 2.00 CASE P CaMP Cont running casing. No losses to this point. Fill pipe every jt. Break circ every 10 joints while running, 2/1412002 00:00 - 01 :30 1.50 CASE P CaMP Continue running casing to 8000' - no problems, no losses, 01 :30 - 03:30 2.00 CASE P CaMP Circ & cond mud. Stage pump slowly up to 4.5 BPM monitoring losses, Lost approx 10 bbl mud while breaking circ slowly, Circ out barafiber and some sand plus viscous mud (100+ FV), 03:30 - 05:00 1,50 CASE P CaMP Run casing to bottom. No further losses when RIH, MU casing hanger and landing jt. Land casing with shoe at 9459' MD, 05:00 - 05:30 0,50 CEMT P CaMP RU cement head and lines, Break circ and work pipe up to 240 klbs to break free. Reciprocate and circ at 180k up and 80k down, Circ at 4.5 BPM, 05:30 - 06:45 1,25 CEMT P CaMP Circ and cond hole for cement. Stage pump up to 5,5 BPM while continue reciprocate pipe - OK, 06:45 - 07:00 0,25 CEMT P CaMP PJSM for cement job, BP, NAD, DS, Baroid, Peak, 07:00 - 08:15 1.25 CEMT P CaMP Cont circ 4.5-5 BPM and recip pipe while batch up spacer and tail slurry, 08:15 - 08:45 0.50 CEMT P CaMP Pump 5 bbl CW100, Test lines to 4500 psi. Pump 20 bbl CW100 followed by 40 bbl Mudpush XL at 11.0 ppg. 08:45 - 09:15 0,50 CEMT P CaMP Mix & pump 70 bbl LiteCrete lead slurry at 11.9 ppg 3 bpm 580 psi followed by 33 bbl Class G at 15,8 ppg - 3 bpm 500 psi. 09:15 - 09:30 0,25 CEMT P CaMP SD pumping, Knock cap off cmt head, Install latched btmltop plug combo in head and push down inside casing - OK. Replace cap. Attempt to reciprocate up to 80% tensile for 5,5" casing - no success, Pipe appears differentially stuck, Full circ Printed: 2/20/2002 11 :26:06 AM ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-120 L-120 DRILL +COMPLETE NABORS NABORS 9ES Start: 1/30/2002 Rig Release: Rig Number: 9-ES Spud Date: 1/31/2002 End: 2/1412002 0,25 CEMT 1,00 CEMT caMP caMP P P 09:15 - 09:30 09:30 - 10:30 10:30 - 11 :00 0,50 CEMT P caMP 11:00 -12:00 1,00 WHSUR P CaMP 12:00 -13:00 1,00 RUNCOfvP COMP 13:00 - 13:30 0,50 RUNCOfvP COMP 13:30 - 23:00 9,50 RUNCOfvP COMP 23:00 - 23:30 0,50 RUNCOfvP CaMP 23:30 - 00:00 0,50 RUNCOfvP CaMP 2/15/2002 00:00 - 04:30 4,50 RUNCOfvP CaMP 04:30 - 07:00 2,50 RUNCOfvP CaMP 07:00 - 08:00 1.00 RUNCOfvP CaMP 08:00 - 08:30 0,50 RUNCOfvP CaMP 08:30 - 10:00 1.50 RUNCOfvP caMP 10:00 - 11 :00 1,00 RUNCOfvP CaMP 11 :00 - 13:00 2.00 WHSUR P CaMP 13:00 - 16:00 3.00 WHSUR P COMP 16:00 - 20:00 4,00 WHSUR P CaMP 20:00 - 22:00 2,00 WHSUR P CaMP 22:00 - 00:00 2,00 RIGD P COMP & no losses. Displace cement with seawater at 4.5-5 bpm: Lead slurry at shoe 1600 stks @ 705 psi, 5 bpm Tail slurry at shoe 2600 stks @ 1740 psi, 5 bpm, Final circ pressure at 3050 stks @ 1950 psi, 2 bpm, No losses noted during displacement. Bump plug with 2500 psi. CIP at 10:20 hrs, Bleed off pressure. Floats holding - OK, RD cement head, lines. LD landing it, elevators. Drain stack. Install packoff, RILDS. Test packoff to 5000 psi - OK. Clear floor. RU to run tubing. Dummy run with tbg hanger on LJ to verify spaceout. MU seal assembly, sliding sleeve, i jt, #1 GLM with DCK-3 shear valve, Run 3 1/2" tubing. Install head pin. Test casing to 3500 psi - 10 min. Good test. RU control line spooling unit. attach control line to SSSVLN. Freeze protect OA - off critical path. See remarks for details, Continue running 3,5" Production tubing, Total 272 Jts, Space out seal assy, into PBR Pull up MIU Hanger, attach control line and re-verify space out. Displace wI corrosion inhibited, filtered sea water. Pump 4 BPM @ 775 psi. Drain stack and land Hanger. RI.L.D.S Torque to 450 ftflbs. Pressure test Tubing to 4500 psi for 30 minutes, Bleed down tubing to 2000 psi. Pressure test Annulus to 4500 psi for 30 minutes. Bleed down tubing pressure & shear RP valve, Install TWC and test to 2800 psi from below. NID BOPE Install Adapter flange & Tree. Test to 5000 psi. Pull TWC. RlU Little Red, PJSM. Test lines to 3500 psi. Reverse circulate 99 bbls diesel, allow to U-Tube to freeze protect 3,5" X 5,5" annulus to 4940', RlU DSM. Install BPV, RID DSM. Test BPV from below to 1000 psi. RID Little Red. Install tree cap. N/D seondary annulus valve, Install Valves and guages - Secure Tree, Off load remaining fluid from pits, RlU floor & secure derrick for move. RIG RELEASED 0211512002 - 23:59 HRS, Printed: 2/20/2002 11 :26:05 AM ~ ~ L-120 Prudhoe Bay Field / Borealis Pool 50-029-23064-00 202-006 Rig Accept: Rig Spud: Rig Release: Drillin Ri : 01/30/02 01/31/02 02115/02 Nabors 9ES POST RIG WORK 03/15/02 DUMMY OFF STATION #1, D & T WI 2.5" X 11' DG TO 9291' SLM, SET FRAC SLEEVE IN SSSVN. 03/16/02 PULL FRAC SLEEVE @ 2203' SLM. 03/17/02 COMPLETED JEWLERY LOG, IPERF & STATIC SURVEY, SHOT INTERVALS: (8870'-8904') & (8914'-8920') WI 2-1/2" POWERFLOW 2506 - 6 SPF - +1-10 DEG ORIENTED - 60 DEG PHASED GUNS. 03/19/02 RUN SBHPS WIDUAL PETREDAT (GOOD DATA) SET FRAC SLEEVE. 03/21/02 MIT IA TO 4000 PSI PASS, TUBING INJECTIVITY RATE OF 0,5 BPM AT 1500 PSI FOR 10 BBLS. 03/22/02 FRAC'D C3/4 PERFS 8870'-8920' WITH YF-125LG SYSTEM AND 176.4 K# OF 16/20 AND 12/18 C-LlTE BEHIND PIPE. NWB SIO @ 101 BBLS INTO 10 PPGA, 12118L STG, (23 BBLS 10 PPGA 12/18 IN PERFS). TOS TO: NEAR SURFACE, 19.6K# SAND LEFT IN TBG/CSG. MAX TREAT= 6090 PSI, AVG TREAT= 4212 PSI. LOAD TO RECOVER IS 987 BBLS. ALL TREESAVER CUPS RECOVERED. 03/23/02 MIRU DOCT #3. RIH W/1,75" JSN. JET WASH TBG W/SLK 1 % KCL. CIRC TBG/LINER CLEAN FROM 8830' CTM, JET THRU PERFS TO 8935' CTM. LOSING RETURNS AS PERFS WERE OPENED UP. PUH ABOVE PERFS TO 8860' AND CIRC'D GEL SWEEPS UP W/50% RETURNS. POOH JETTING JEWELRY ON WAY OOH. FP'D WELL TO 4800' W/DIESEL. 03124/02 PULLED FRAC SLEEVE FROM BVN @ 2201' WLM --- DRIFTED TUBING INTO LINER TO 8760' AMS/SLM = +1- 160' OF FILL no PULLED INTEGRAL DGL V' S FROM GLM' S #1,2 & 3 no SET NEW DESIGN IN GLM'S # 1,2,& 3. 04/19/02 FCO TO 9300' CTD, RIH WITH 2.25" JSN, RETURNS TO SYSTEM ON GL, TUBING CLEAR TO A TAG AT 8429' CTD, JET HARD BRIDGE TO 8490' CTD, THEN SEE NO TAG, NO SAND UNTIL BELOW PERFS, (BOTTOM PERF AT 8920') TAG AT 8962', STICKY, PULL WT NUMEROUS TIMES, FCO WITH SKCL TO 9300' CTD, (380' RAT HOLE). BULLHEAD 30 BBLS NEAT METH. 04/21/02 START EQUALIZING TUBING W/IA. SET 3-112" SLIP STOP CATCHER SUB @ 4595' SLM. PULL & REPLACE 1" GLV @ 4444' MD. (16/64" PORT, TRO-1819#, INT LATCH). PULL SLIP STOP CATCHER SUB, 04/23/02 PUMP 100 BBLS DIESEL @ 190 DOWN IA. ANADRILL SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field....................: Prudhoe Bay/Borealis Well.....................: L-120 API number...............: 50-029-23064-00 Engineer... ..............: St. Amour COUNTY:.... ..............: Nabors 9ES STATE:...................: Alaska ----- Survey calculation methods------------- Method for positions. ....: Minimum curvature Method for DLS....... ....: Mason & Taylor ----- Depth reference ----------------------- Permanent datum.... ......: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 50.60 ft KB above permanent.......: N/A DF above permanent.......: 79.10 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-) ........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-) .........: -999.25 ft Departure (+E/W-). ..,.. ..: -999.25 ft Azimuth from rotary table to target: 67.35 degrees [(c)2002 Anadrill IDEAL ID6_1C_10J 9-Feb-200203:14:56 Spud date................: Last survey date. ........: Total accepted surveys...: MD of first survey.......: MD of last survey.... ....: Page 1 of 5 31-Jan-02 09-Feb-02 102 ) 0.00 ft 9475.33 ft ----- Geomagnetic data ---------------------- Magnetic model...... .....: BGGM version 2000 Magnetic date....... .....: 31-Dec-2001 Magnetic field strength..: 1149.06 RCNT Magnetic dec (+E/W-) .....: 26.14 degrees Magnetic dip......... ....: 80.75 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G.............. : H.............. : Dip............ : of G...........: of H...........: of Dip. . . . . . . . . : Criteria --------- 1002.68 mGal 1149.06 RCNT 80.75 degrees (+/-) 2.50 mGal (+/-) 6.00 RCNT (+/-) 0.45 degrees ) ----- Corrections --------------------------- Magnetic dec (+E/W-).. ...: 26.12 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 26.12 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........: No degree: 0.00 ANADRILL SCHLUMBERGER Survey Report 9-Feb-200203:14:56 Page 2 of 5 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP - 2 203.93 0.73 41.16 203.93 203.92 1.17 0.98 0.86 1.30 41.16 0.36 MWD Inc. Only 3 295.27 1.22 41.16 91. 34 295.25 2.56 2.15 1.88 2.85 41.16 0.54 MWD_IFR_MSA 4 387.24 2.29 56.28 91. 97 387.18 5.24 3.91 4.05 5.63 46.05 1.26 MWD_IFR_MSA 5 474.73 3.28 70.65 87.49 474.56 9.46 5.71 7.87 9.72 54.05 1.38 MWD_IFR_MSA 6 569.74 4.59 67.41 95.01 569.35 15.97 8.07 13.94 16.11 59.95 1.40 MWD_IFR_MSA ) 7 661.01 5.22 67.98 91.27 660.28 23.78 11. 03 21.16 23.86 62.48 0.69 MWD~IFR_MSA 8 753.11 6.32 67.74 92.10 751. 91 33.03 14.52 29.74 33.09 63.98 1.19 MWD_IFR_MSA 9 845.10 7.59 65.18 91. 99 843.23 44.17 18.99 39.94 44.22 64.58 1.42 MWD_IFR_MSA 10 939.69 9.50 64.17 94.59 936.76 58.21 25.01 52.63 58.27 64.59 2.03 MWD_IFR_MSA 11 1032.65 11.54 67.51 92.96 1028.16 75.17 31. 91 68.13 75.23 64.90 2.29 MWD_IFR_MSA 12 1125.88 13 .87 68.15 93.23 1119.10 95.67 39.64 87.12 95.72 65.54 2.50 MWD_IFR_MSA 13 1219.40 15.44 66.41 93.52 1209.57 119.33 48.79 108.94 119.36 65.87 1. 74 MWD_IFR_MSA 14 1313.60 17.15 67.52 94.20 1299.98 145.75 59.12 133.26 145.79 66.08 1. 85 MWD_IFR_MSA 15 1406.41 19.80 69.79 92.81 1388.00 175.15 69.78 160.66 175.17 66.52 2.96 MWD_IFR_MSA 16 1500.04 22.74 69.90 93.63 1475.25 209.08 81. 48 192.55 209.08 67.06 3.14 MWD_IFR_MSA 17 1593.58 23.90 68.60 93.54 1561.14 246.08 94.61 227.17 246.08 67.39 1.36 MWD_IFR_MSA 18 1688.44 27.42 68.16 94.86 1646.64 287.15 109.75 265.35 287.15 67.53 3.72 MWD_IFR_MSA 19 1782.39 28.07 67.73 93.95 1729.78 330.88 126.18 305.88 330.88 67.58 0.72 MWD_IFR_MSA 20 1876.02 29.82 68.61 93.63 1811. 72 376.19 143.02 347.95 376.19 67.66 1.92 MWD_IFR_MSA ) 21 1970.06 30.84 68.48 94.04 1892.88 423.67 160.39 392.14 423.68 67.76 1. 09 MWD_IFR_MSA 22 2063.28 32.97 68.83 93.22 1972 . 02 472.92 178.32 438.03 472.94 67.85 2.29 MWD_IFR_MSA 23 2156.21 35.65 68.70 92.93 2048.77 525.28 197.29 486.85 525.31 67.94 2.88 MWD_IFR_MSA 24 2247.65 37.95 67.92 91. 44 2121. 98 580.04 217.54 537.74 580.08 67.97 2.57 MWD_IFR_MSA 25 2341.71 40.75 66.42 94.06 2194.71 639.67 240.70 592.69 639.70 67.90 3.14 MWD_IFR_MSA 26 2434.97 42.08 65.75 93.26 2264.65 701. 35 265.71 649.08 701.36 67.74 1.50 MWD_IFR_MSA 27 2528.86 44.88 65.37 93.89 2332.77 765.91 292.44 707.89 765.92 67.55 3.00 MWD_IFR_MSA 28 2621.43 47.87 67.48 92.57 2396.64 832.90 319.21 769.30 832.90 67.46 3.63 MWD_IFR_MSA 29 2715.02 51. 32 67.76 93.59 2457.29 904.15 346.33 835.19 904.16 67.48 3.69 MWD_IFR_MSA 30 2808.19 51. 31 66.59 93.17 2515.53 976.88 374.55 902.23 976.88 67.45 0.98 MWD_IFR_MSA [(c)2002 Anadrill IDEAL ID6_1C_l0J ANADRILL SCHLUMBERGER Survey Report 9-Feb-200203:14:56 Page 3 of 5 --- -------- ------ ------- ------ -------- ======== ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2900.84 52.87 66.42 92.65 2572 .45 1049.97 403.69 969.26 1049.97 67.39 1. 69 MWD_IFR_MSA 32 2995.72 52.58 66.71 94.88 2629.92 1125.46 433.72 1038.53 1125.46 67.33 0.39 MWD_IFR_MSA 33 3120.77 51. 86 66.20 125.05 2706.52 1224.28 473.20 1129.14 1224.28 67.26 0.66 MWD_IFR_MSA 34 3213.74 51. 68 66.74 92.97 2764.06 1297.30 502.35 1196.10 1297.31 67.22 0.50 MWD_IFR_MSA 35 3306.31 51. 67 66.89 92.57 2821. 46 1369.92 530.94 1262.85 1369.93 67.20 0.13 MWD_IFR_MSA 36 3398.80 52.94 69.11 92.49 2878.02 1443.09 558.34 1330.71 1443.10 67.24 2.34 MWD_IFR_MSA ) 37 3492.06 52.41 69.39 93.26 2934.56 1517.21 584.62 1400.06 1517.21 67.34 0.62 MWD_IFR_MSA 38 3586.29 52.13 69.49 94.23 2992.23 1591.69 610.79 1469.84 1591.69 67.43 0.31 MWD_IFR_MSA 39 3680.09 54.20 71.45 93.80 3048.46 1666.64 635.87 1540.59 1666.66 67.57 2.77 MWD_IFR_MSA 40 3773.45 54.23 71.40 93.36 3103.05 1742.19 659.99 1612.38 1742.23 67.74 0.05 MWD_IFR_MSA 41 3866.73 54.17 71. 20 93.28 3157.62 1817.66 684.25 1684.04 1817.74 67.89 0.19 MWD_IFR_MSA 42 3959.97 54.01 71.98 93.24 3212.31 1892 . 97 708.10 1755.69 1893.11 68.03 0.70 MWD_IFR_MSA 43 4053.38 53.71 72.11 93.41 3267.40 1968.16 731.36 1827.45 1968.37 68.19 0.34 MWD_IFR_MSA 44 4146.77 53.39 72.44 93.39 3322.88 2043.00 754.23 1899.01 2043.30 68.34 0.45 MWD_IFR_MSA 45 4240.62 54.72 72.72 93.85 3377.97 2118.66 776.97 1971.50 2119.08 68.49 1.44 MWD_IFR_MSA 46 4333.91 54.56 73.02 93.29 3431. 96 2194.39 799.38 2044.21 2194.95 68.64 0.31 MWD_IFR_MSA 47 4430.21 54.26 70.28 96.30 3488.01 2272.47 824.03 2118.53 2273.14 68.75 2.33 MWD_IFR_MSA 48 4521.54 53.59 70.07 91. 33 3541. 79 2346.19 849.06 2187.97 2346.94 68.79 0.76 MWD_IFR_MSA 49 4614.61 55.35 66.80 93.07 3595.88 2421. 90 876.91 2258.38 2422.65 68.78 3.43 MWD_IFR_MSA 50 4709.18 55.30 66.50 94.57 3649.69 2499.67 907.74 2329.78 2500.38 68.71 0.27 MWD_IFR_MSA ) 51 4802.65 55.10 63.34 93.47 3703.04 2576.34 940.26 2399.29 2576.95 68.60 2.78 MWD_IFR_MSA 52 4894.64 54.34 63.56 91.99 3756.17 2651. 26 973.83 2466.46 2651.75 68.45 0.85 MWD_IFR_MSA 53 4987.43 54.25 63.81 92.79 3810.32 2726.45 1007.23 2534.00 2726.84 68.32 0.24 MWD_IFR_MSA 54 5080.21 53.77 64.42 92.78 3864.84 2801. 40 1040.01 2601. 54 2801.72 68.21 0.74 MWD_IFR_MSA 55 5174.34 52.29 64.07 94.13 3921. 45 2876.49 1072.68 2669.27 2876.74 68.11 1. 60 MWD_IFR_MSA 56 5267.75 52.02 65.81 93.41 3978.77 2950.19 1103.93 2736.09 2950.39 68.03 1.50 MWD_IFR_MSA 57 5360.67 52.82 66.27 92 .92 4035.43 3023.81 1133.83 2803.38 3023.99 67.98 0.95 MWD_IFR_MSA 58 5454.18 52.43 67.24 93.51 4092.20 3098.11 1163.16 2871. 66 3098.28 67.95 0.92 MWD_IFR_MSA 59 5547.80 52.18 67.95 93.62 4149.44 3172.19 1191. 39 2940.14 3172.36 67.94 0.66 MWD_IFR_MSA 60 5640.02 51. 21 67.29 92.22 4206.60 3244.55 1218.94 3007.06 3244.72 67.93 1.19 MWD_IFR_MSA [(c)2002 Anadrill IDEAL ID6_1C_l0) AWADRILL SCHLUMBERGER Survey Report 9-Feb-200203:14:56 Page 4 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5733.71 51. 73 68.29 93.69 4264.97 3317.84 1246.65 3074.91 3318.01 67.93 1.00 MWD_IFR_MSA 62 5827.44 53.12 68.75 93.73 4322.12 3392.11 1273.84 3144.04 3392.29 67.94 1.53 MWD_IFR_MSA 63 5921.42 52.47 68.52 93.98 4378.95 3466.94 1301.11 3213.75 3467.14 67.96 0.72 MWD_IFR_MSA 64 6014.51 51. 78 68.71 93.09 4436.10 3540.41 1327.91 3282.17 3540.61 67.97 0.76 MWD_IFR_MSA 65 6108.01 51. 87 69.92 93.50 4493.89 3613.86 1353.87 3350.93 3614.09 68.00 1.02 MWD_IFR_MSA 66 6200.59 53.08 70.03 92.58 4550.28 3687.21 1379.01 3419.91 3687.48 68.04 1.31 MWD_IFR_MSA ) 67 6295.75 53.36 67.46 95.16 4607.26 3763.39 1406.64 3490.93 3763.68 68.05 2.18 MWD_IFR_MSA 68 6388.11 53.41 64.80 92.36 4662.36 3837.50 1436.63 3558.72 3837.76 68.02 2.31 MWD_IFR_MSA 69 6480.78 52.45 65.16 92.67 4718.22 3911.37 1467.91 3625.72 3911.60 67.96 1. 08 MWD_IFR_MSA 70 6574.29 51. 59 65.39 93.51 4775.76 3985.03 1498.74 3692.67 3985.22 67.91 0.94 MWD_IFR_MSA 71 6666.89 51.09 65.18 92 .60 4833.61 4057.29 1528.97 3758.35 4057.46 67.86 0.57 MWD_IFR_MSA 72 6760.74 51.69 65.70 93.85 4892 .17 4130.59 1559.45 3825.05 4130.73 67.82 0.77 MWD_IFR_MSA 73 6854.53 50.93 66.07 93.79 4950.80 4203.77 1589.36 3891. 87 4203.89 67.79 0.87 MWD_IFR_MSA 74 6948.19 52.16 65.69 93.66 5009.05 4277.09 1619.33 3958.81 4277 .19 67.75 1. 35 MWD_IFR_MSA 75 7041. 59 51. 65 64.92 93.40 5066.67 4350.55 1650.04 4025.59 4350.63 67.71 0.85 MWD_IFR_MSA 76 7135.21 50.27 64.02 93.62 5125.64 4423.17 1681. 37 4091.20 4423.23 67.66 1. 65 MWD_IFR_MSA 77 7229.21 49.34 64.05 94.00 5186.30 4494.85 1712.81 4155.76 4494.89 67.60 0.99 MWD_IFR_MSA 78 7323.26 48.19 63.39 94.05 5248.30 4565.43 1744.12 4219.17 4565.46 67.54 1.33 MWD_IFR_MSA 79 7416.83 46.30 66.53 93.57 5311. 82 4634.06 1773.22 4281. 39 4634.07 67.50 3.19 MWD_IFR_MSA 80 7510.42 45.27 64.88 93.59 5377 . 09 4701.10 1800.81 4342.53 4701.11 67.48 1.68 MWD_IFR_MSA ) 81 7604.20 44.34 64.23 93.78 5443.63 4767.11 1829.20 4402.20 4767.11 67.44 1.11 MWD_IFR_MSA 82 7697.18 43.27 62.83 92.98 5510.73 4831. 32 1857.88 4459.82 4831. 32 67.38 1. 55 MWD_IFR_MSA 83 7790.84 39.49 60.56 93.66 5581.00 4892.92 1887.18 4514.33 4892.92 67.31 4.34 MWD_IFR_MSA 84 7884.08 37.57 61.80 93.24 5653.94 4950.66 1915.19 4565.21 4950.67 67.24 2.22 MWD_IFR_MSA 85 7978.61 33.89 60.37 94.53 5730.66 5005.52 1941.85 4613.53 5005.54 67.17 3.99 MWD_IFR_MSA 86 8072 . 60 31. 52 59.26 93.99 5809.75 5055.86 1967.37 4657.44 5055.91 67.10 2.60 MWD_IFR_MSA 87 8166.46 28.15 57.17 93.86 5891.16 5101.96 1991.92 4697.14 5102.04 67.02 3.76 MWD_IFR_MSA 88 8260.22 26.24 54.49 93.76 5974.55 5143.94 2015.95 4732.60 5144.08 66.93 2.42 MWD_IFR_MSA 89 8353.18 23.53 53.85 92.96 6058.87 5182.03 2038.84 4764.32 5182.24 66.83 2.93 MWD_IFR_MSA 90 8443.83 20.31 55.55 90.65 6142.96 5215.03 2058.42 4791.91 5215.31 66.75 3.62 MWD_IFR_MSA [(c)2002 Anadrill IDEAL ID6_1C_10] ANADRILL SCHLUMBERGER Survey Report 9-Feb-200203:14:56 Page 5 of 5 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (degl tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8540.53 16.62 52.33 96.70 6234.67 5244.83 2076.37 4816.71 5245.19 66.68 3.96 MWD_IFR_MSA 92 8632.59 14.02 51. 21 92.06 6323.45 5268.26 2091. 40 4835.82 5268.69 66.61 2.84 MWD_IFR_MSA 93 8723.82 11. 68 49.44 91.23 6412.39 5287.66 2104.33 4851.45 5288.18 66.55 2.60 MWD_IFR_MSA 94 8817.76 9.44 47.38 93.94 6504.73 5303.95 2115.73 4864.35 5304.55 66.49 2.42 MWD_IFR_MSA 95 8911.38 8.43 44.76 93.62 6597.22 5317.51 2125.81 4874.83 5318.18 66.44 1.16 MWD_IFR_MSA 96 9006.09 7.90 41. 76 94.71 6690.97 5329.79 2135.59 4884.05 5330.55 66.38 0.72 MWD_IFR_MSA ) 97 9097.37 7.29 43.47 91.28 6781. 45 5340.74 2144.47 4892.22 5341.59 66.33 0.71 MWD_IFR_MSA 98 9191.98 6.85 41. 82 94.61 6875.34 5351. 32 2153.03 4900.11 5352.25 66.28 0.51 MWD_IFR_MSA 99 9285.54 5.38 42.18 93.56 6968.36 5360.32 2160.44 4906.77 5361. 34 66.24 1. 57 MWD_IFR_MSA 100 9377 . 86 4.06 48.24 92.32 7060.37 5367.33 2165.83 4912.12 5368.40 66.21 1.53 MWD_IFR_MSA 101 9418.74 3.63 51. 09 40.88 7101.15 5369.94 2167.60 4914.20 5371.02 66.20 1.15 MWD_IFR_MSA Final Survey Projected to TD: 102 9474.00 3.05 55.67 55.26 7156.32 5373.06 2169.53 4916.78 5374.16 66.19 1.15 Projected [(c)2002 Anadrill IDEAL ID6_1C_I0] ) bp L-120 Schlumberger Survey Report - Geodetic Report Date: 12-Feb-2002 Survey 1 DLS Computation Method: Minimum Curvature 1 Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 66.190° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 It, E 0.000 It Structure 1 Slot: L.Pad IL -120 TVD Reference Datum: KB Well: L-120 TVD Reference Elevation: 79,100 It relative to MSL Borehole: L-120 Sea Bed I Ground Level Elevation: 44.100 It relative to MSL UWIIAPI#: 500292306400 Magnetic Declination: +0.000° ) Survey Name 1 Date: L-120 I February 11,2002 Total Field Strength: 0,000 nT TortI AHDI DDIf ERD ratio: 151.398° 1 5392.63 Itl 6.034/0.754 Magnetic Dip: 0,000° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Declination Date: February 11, 2002 Location Lat/Long: N 70 212.761, W 14919 23.24~ Magnetic Declination Model: BGGM 2000 Location Grid NtE YfX: N 5978332,240 flUS, E 583368,610 flUS North Reference: True North Grid Convergence Angle: +0,63746504° Total Corr Mag North -) True North: +0,000° Grid Scale Factor: 0.99990790 Local Coordinates Referenced To: Well Head I Grid Coordinates I Geographic Coordinates Station ID I MD I Incl I Azim I TVD I vSec I Nt-S I Ef-W I DLS Northing I Easting Latitude I Longitude (ft) (') (O) (ft) (ft) (ft) (ft) ('/10Oft) (ftUS) (ftUS) 0.00 0.00 0.0 0.00 0.00 0,00 0.00 5978332.24 583368.61 N 7021 2.761 W 149 1923.243 203,93 0,73 41.2 203.92 1.18 0,98 0.86 0.36 5978333.23 583369.45 N 70212,771 W 149 1923.218 295,27 1,22 41.2 295.25 2.59 2.15 1.88 0.54 5978334.41 583370.46 N 70 212.782 W 149 1923,188 387.24 2,29 56,3 387.18 5,28 3,91 4.05 1.26 5978336.19 583372.62 N 7021 2.800 W 1491923.124 474.73 3.28 70.7 474.56 9,50 5,71 7.87 1.38 5978338.03 583376.41 N 7021 2.817 W 1491923.013 569,74 4,59 67.4 569.35 16,01 8.07 13.94 1.40 5978340.46 583382.46 N 70212.841 W 149 1922,835 661,01 5,22 68.0 660.28 23.81 11,03 21.16 0.69 5978343.50 583389,65 N 70 21 2.870 W 149 19 22.62/ ) 753,11 6,32 67,7 751.91 33.07 14.52 29.74 1.19 5978347.09 583398.18 N 70 212.904 W 14919 22.374 845.10 7.59 65,2 843.23 44.20 18.99 39.94 1.42 5978351.67 583408.33 N 7021 2.948 W 149 1922.076 939.69 9.50 64.2 936.76 58.25 25.01 52.63 2,03 5978357.83 583420.96 N70213,O07 W1491921,705 1032.65 11.54 67.5 1028.16 75.22 31,91 68.13 2,29 5978364,90 583436.38 N 7021 3.075 W 149 1921,252 1125.88 13.87 68.2 1119,10 95.71 39.64 87,12 2.50 5978372,84 583455,28 N70213.151 W1491920,697 1219.40 15.44 66.4 1209.57 119.36 48.79 108.94 1.74 5978382,24 583476.99 N 70 21 3.241 W 149 1920.059 1313,60 17.15 67,5 1299.98 145.79 59.12 133.26 1.85 5978392.83 583501.20 N 70 21 3.343 W 149 19 19,348 1406.41 19.80 69.8 1388.00 175,16 69.78 160.66 2.96 5978403.80 583528.47 N 70213.448 W 1491918,547 1500.04 22.74 69,9 1475,25 209.06 81.48 192,55 3,14 5978415.85 583560.22 N 70213.563 W 149 19 17,616 1593,58 23.90 68,6 1561.14 246.03 94.61 227,17 1,36 5978429.36 583594.69 N 70213.692 W 1491916,604 L-120 ASP Final Survey.xls Page 1 of 4 4/18/2002-1 :39 PM I Grid Coordinates I Geographic Coordinates Station ID I MD I Incl I Azim I TVD I vSec I NI-S I E/-W I DLS Northing I Easting Latitude I Longitude (ft) ¡OJ (') (ft) (ft) (ft) (ft) ('¡100ft) (ftUS) (ftUS) 1688.44 27.42 68.2 1646,64 287,07 109.75 265.35 3.72 5978444.93 583632.69 N 70213.841 W 149 19 15.488 1782,39 28,07 67.7 1729,78 330,79 126.18 305.88 0.72 5978461.80 583673.04 N 70214,002 W 1491914,303 1876.02 29,82 68.6 1811,72 376,07 143.02 347.95 1.92 5978479.11 583714,91 N 70214.168 W 1491913,074 1970.06 30.84 68.5 1892.88 423.52 160.39 392,14 1.09 5978496.97 583758,91 N70214.338 W1491911.782 2063.28 32.97 68.8 1972,02 472,74 178.32 438.03 2.29 5978515.40 583804,59 N 70214.515 W 1491910.441 2156,21 35.65 68.7 2048,77 525,06 197.29 486,85 2.88 5978534.91 583853.19 N 7021 4.701 W 149 199.014 2247,65 37,95 67,9 2121 ,98 579,79 217,54 537.74 2.57 5978555.73 583903.85 N 7021 4.900 W 149197,527 2341,71 40,75 66.4 2194,71 639.42 240,70 592.69 3.14 5978579.49 583958.53 N 7021 5,128 W 149 195,921 2434.97 42.08 65.8 2264,65 701.11 265.71 649.08 1.50 5978605.13 584014,63 N 7021 5.374 W 149194.273 ) 2528.86 44.88 65.4 2332.77 765,70 292.44 707,89 3.00 5978632.51 584073.14 N 7021 5.637 W 14919 2.55L, 2621.43 47.87 67.5 2396,64 832,69 319.21 769,30 3.63 5978659.96 584134.24 N 7021 5.900 W 149190,759 2715,02 51,32 67,8 2457,29 903,93 346,33 835.19 3.69 5978687,81 584199.82 N 7021 6.167 W 149 18 58,833 2808,19 51,31 66,6 2515,53 976,64 374,55 902.23 0.98 5978716.76 584266.53 N 7021 6.444 W 149 1856.874 2900,84 52.87 66.4 2572.45 1049,74 403.69 969.26 1.69 5978746.65 584333.23 N 70216.731 W 1491854.914 2995.72 52.58 66.7 2629.91 1125.24 433.72 1038.53 0.39 5978777.44 584402,16 N 70217.026 W 1491852.890 3120.77 51.86 66.2 2706.52 1224.07 473,20 1129.14 0,66 5978817.92 584492,31 N 70217.414 W 1491850.241 3213,74 51.68 66.7 2764.06 1297.10 502.35 1196.10 0.50 5978847.82 584558,93 N 70217.701 W 1491848.284 3306,31 51,67 66,9 2821.46 1369.72 530,94 1262.85 0.13 5978877.15 584625.36 N 70217.982 W 149 1846.333 3398,80 52,94 69.1 2878,02 1442,86 558,34 1330.71 2.34 5978905.30 584692.90 N 70218.251 W 149 1844.350 3492.06 52.41 69.4 2934.56 1516.91 584.62 1400.06 0.62 5978932.34 584761.94 N 7021 8.510 W 149 1842.323 3586,29 52.13 69.5 2992.23 1591.32 610.79 1469.84 0.31 5978959.29 584831.42 N 70218.767 W 1491840.283 3680,09 54,20 71.4 3048.46 1666.17 635,87 1540.59 2.77 5978985.15 584901.88 N 70219.013 W 1491838.215 3773.45 54,23 71,4 3103,05 1741.59 659,99 1612.38 0.05 5979010.07 584973.39 N 70219.250 W 149 1836.117 3866,73 54,17 71.2 3157.62 1816.94 684.25 1684.04 0.19 5979035.12 585044.77 N 70219.489 W 149 1834.022 3959.97 54.01 72.0 3212.31 1892.13 708.10 1755.69 0.70 5979059.76 585116.15 N 70219,723 W 149 1831.921 ) 4053,38 53.71 72.1 3267.40 1967.17 731.36 1827.45 0.34 5979083.81 585187.64 N 70219.952 W 1491829.830 4146,77 53,39 72.4 3322.88 2041.87 754,23 1899.01 0.45 5979107.47 585258.93 N 7021 10.177 W 1491827.738 4240,62 54,72 72,7 3377.97 2117.37 776,97 1971.50 1.44 5979131.02 585331.16 N 7021 10.400 W 1491825.619 4333,91 54,56 73,0 3431,96 2192.94 799,38 2044.21 0.31 5979154,24 585403.61 N 70 21 10.620 W 149 18 23.494 4430,21 54,26 70.3 3488.01 2270.88 824,03 2118.53 2.33 5979179.71 585477.64 N702110.862 W1491821.322 4521,54 53.59 70.1 3541,79 2344.52 849.06 2187.97 0.76 5979205.51 585546.79 N 702111.108 W 1491819.292 4614.61 55.35 66.8 3595.88 2420.18 876.91 2258.38 3.43 5979234.14 585616.88 N 702111.382 W 149 18 17.233 4709.18 55.30 66.5 3649.69 2497.95 907.74 2329.78 0.27 5979265.76 585687.93 N702111.685 W1491815.146 4802,65 55.10 63,3 3703.04 2574.67 940.26 2399.29 2.78 5979299.05 585757.06 N702112.005 W1491813.114 4894,64 54,34 63,6 3756.17 2649.68 973,83 2466.46 0.85 5979333.36 585823.85 N 7021 12.335 W 149 18 11.151 L-120 ASP Final Survey,xls Page 2 of 4 4/18/2002-1 :39 PM I Grid Coordinates I Geographic Coordinates Station ID I MD I Incl I Azim I TVD I VSec I NI-S I EI-W I DLS Northing I Easting Latitude I Longitude (ft) (') (') (ft) (ft) (ft) (ft) ('¡100ft) (ftUS) (ftUS) 4987.43 54.25 63,8 3810.32 2724,96 1007,23 2534.00 0.24 5979367.51 585891,01 N 7021 12,663 W 14918 9.176 5080.21 53,77 64.4 3864,84 2799,98 1040.01 2601.54 0.74 5979401.03 585958.17 N 7021 12,985 W 149 187.202 5174,34 52,29 64.1 3921.45 2875,14 1072,68 2669,27 1.60 5979434.45 586025.53 N 7021 13.306 W 149 185.222 5267.75 52.02 65,8 3978.76 2948.88 1103,93 2736.09 1,50 5979466.43 586091.99 N 70 21 13.613 W 149183.268 5360.67 52,82 66,3 4035.43 3022.51 1133,83 2803.38 0,95 5979497,08 586158.94 N 7021 13.907 W 149 18 1.301 5454.18 52.43 67,2 4092,20 3096,82 1163,16 2871.66 0,92 5979527,16 586226.88 N702114.195 W1491759.305 5547,80 52,18 67.9 4149.44 3170,88 1191 ,39 2940.14 0,66 5979556,16 586295,04 N 7021 14.473 W 149 1757.303 5640,02 51.21 67.3 4206,60 3243,22 1218,94 3007.06 1,19 5979584.45 586361,64 N702114.743 W1491755.347 5733.71 51.73 68,3 4264,97 3316.48 1246.65 3074,91 1.00 5979612.90 586429,17 N 7021 15,016 W 1491753.363 ) 5827.44 53.12 68,8 4322.12 3390,70 1273,84 3144.04 1.53 5979640.86 586497.99 N 70 21 15.283 W 14917 51.34~ 5921.42 52.47 68.5 4378.95 3465,49 1301,11 3213.75 0.72 5979668,90 586567,38 N 7021 15.551 W 149 1749,304 6014,51 51,78 68.7 4436,10 3538,90 1327,91 3282.17 0,76 5979696.45 586635.49 N 7021 15.814 W 149 1747.304 6108,01 51,87 69.9 4493,89 3612,29 1353.87 3350.93 1,02 5979723,18 586703,95 N 70 21 16.069 W 149 1745.294 6200.59 53.08 70,0 4550,28 3685,55 1379.01 3419,91 1.31 5979749,08 586772,65 N 7021 16.316 W 149 1743,277 6295.75 53.36 67,5 4607.26 3761.69 1406,64 3490,93 2.18 5979777,50 586843,35 N 702116,587 W 1491741,200 6388.11 53,41 64,8 4662.36 3835.81 1436,63 3558,72 2.31 5979808,24 586910,79 N 7021 16,882 W 1491739,219 6480.78 52.45 65,2 4718.22 3909.73 1467,91 3625.72 1.08 5979840,25 586977.43 N702117,189 W1491737,260 6574.29 51.59 65.4 4775,76 3983.43 1498,74 3692.67 0.94 5979871.82 587044,03 N 70 21 17.492 W 149 1735,302 6666,89 51,09 65.2 4833.61 4055,73 1528.97 3758.35 0,57 5979902.78 587109.37 N 7021 17.789 W 149 1733,382 6760.74 51.69 65,7 4892.17 4129,06 1559.45 3825,05 0,77 5979934,00 587175,72 N 7021 18.089 W 149 1731.432 6854.53 50.93 66,1 4950.80 4202,26 1589.36 3891 ,87 0.87 5979964.65 587242,19 N702118.382 W1491729.478 6948.19 52,16 65.7 5009.05 4275.60 1619,33 3958.81 1.35 5979995,36 587308,79 N 7021 18.677 W 14917 27,521 7041.59 51,65 64.9 5066,67 4349.10 1650,04 4025.59 0.85 5980026,81 587375,22 N 7021 18.978 W 1491725,568 7135,21 50,27 64.0 5125,64 4421,78 1681,37 4091.20 1.65 5980058,86 587440.47 N 7021 19.286 W 1491723,650 7229,21 49,34 64.1 5186.30 4493,53 1712.81 4155.76 0.99 5980091,01 587504,67 N702119,595 W1491721.76~ ) 7323.26 48,19 63.4 5248.30 4564,19 1744.12 4219,17 1.33 5980123.03 587567,72 N 7021 19.903 W 1491719.908 7416.83 46,30 66.5 5311.82 4632.86 1773.22 4281,39 3.19 5980152.81 587629.61 N 70 2120.189 W 1491718.089 7510.42 45,27 64.9 5377.09 4699.93 1800.81 4342,53 1,68 5980181,07 587690.43 N 70 21 20.459 W 149 17 16.301 7604.20 44,34 64.2 5443.63 4765.99 1829.20 4402.20 1.11 5980210.12 587749.78 N 7021 20.738 W 1491714,556 7697.18 43,27 62.8 5510.73 4830.27 1857.88 4459.82 1.55 5980239.44 587807.06 N 7021 21.020 W 1491712.871 7790,84 39.49 60.6 5581.00 4891.98 1887,18 4514.33 4.34 5980269.35 587861.25 N 702121.308 W 1491711,277 7884,08 37,57 61.8 5653.94 4949,83 1915.19 4565.21 2.22 5980297.92 587911.80 N 70 21 21.583 W 149 179,790 7978,61 33,89 60.4 5730.66 5004,81 1941.85 4613.53 3.99 5980325.11 587959.82 N 70 21 21.845 W 149178,376 8072.60 31.52 59.3 5809.75 5055,27 1967.37 4657.44 2.60 5980351.11 588003,43 N 70 21 22.096 W 149177,093 8166.46 28.15 57.2 5891.16 5101,51 1991 .92 4697.14 3.76 5980376.10 588042,86 N 70 21 22.337 W 14917 5.931 L-120 ASP Final Survey,xls Page 3 of 4 4/18/2002-1 :39 PM I Grid Coordinates I Geographic Coordinates I Station ID I MD I Incl I Azim I TVD I vSec I Nf-S I EI-W I DLS Northing I Easting Latitude I Longitude (ft) (') (') (ft) (ft) (ft) (ft) ('/100ft) (ftUS) (ftUS) 8260.22 26,24 54.5 5974,55 5143,66 2015,95 4732,60 2.42 5980400,53 588078.05 N 7021 22.573 W 149 174.894 8353.18 23.53 53.8 6058.87 5181.91 2038,84 4764,32 2.93 5980423.76 588109,51 N 7021 22,798 W 149 173,967 8443.83 20.31 55.5 6142,96 5215,06 2058.42 4791.91 3.62 5980443,64 588136,88 N 7021 22,990 W 149 173,160 8540,53 16,62 52.3 6234,67 5244,99 2076,37 4816,71 3,96 5980461,87 588161.47 N702123.167 W 149 172.435 8632.59 14.02 51.2 6323.45 5268.55 2091.40 4835,82 2.84 5980477,11 588180.41 N 7021 23.314 W 149171.876 8723,82 11.68 49.4 6412,39 5288.07 2104.33 4851,45 2.60 5980490.22 588195,90 N 70 21 23.442 W 149171.418 8817,76 9.44 47.4 6504.73 5304.47 2115.73 4864.35 2.42 5980501.76 588208,66 N 7021 23.554 W 149 171.041 8911,38 8.43 44.8 6597,22 5318.13 2125.81 4874.83 1.16 5980511.94 588219,03 N 7021 23.653 W 149 170,735 9006.09 7,90 41,8 6690,97 5330.52 2135.59 4884,05 0.72 5980521,83 588228.14 N 7021 23.749 W 149 17 0.46F ) 9097.37 7.29 43,5 6781.45 5341 ,57 2144.47 4892.22 0.71 5980530.80 588236.21 N 7021 23.836 W 149 17 O,22l 9191 ,98 6.85 41,8 6875,34 5352,25 2153.03 4900.11 0.51 5980539.45 588244,00 N 70 2123.920 W 149 1659,995 9285,54 5.38 42.2 6968,36 5361.34 2160.44 4906.77 1.57 5980546.93 588250,58 N 70 21 23.993 W 149 16 59,800 9377,86 4.06 48,2 7060.37 5368.40 2165.83 4912.12 1.53 5980552.37 588255,87 N 702124.046 W 149 1659,644 9418,74 3.63 51,1 7101,15 5371.03 2167.60 4914.20 1.15 5980554,17 588257.93 N 7021 24.063 W 149 1659,583 9474,00 3.63 51,1 7156,30 5374.40 2169.80 4916.93 0.00 5980556.40 588260.63 N 7021 24.085 W 149 1659,503 ) L-120 ASP Final Survey,xls Page 4 of 4 4/18/2002-1 :39 PM Se.lIDbiil"- Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie ( Well Job # L-117 L-120 ~Ol-Ilo 7 ;).Od-. -ooco ( Log Description PRODUCTION LOG PRESSrrEMP LOG PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED l. Cp 0 Q ...,001") ""Î " ; I , r Alaska Oil & Gas COns. ComnlÎ&Siún Ant!hNSHI9 03/08/02 03/17/02 Date 4/4/2002 NO. 1955 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Aurora Color Sepia BL CD Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie Received 4'ïrì, ~ Sc~blblPII8P Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage. AK 99503-5711 ATTN: Sherrie ( Well Job # L-104 aOJ-d."<,'l L-106 ñJOJ-dd.3 S-105 dOD -/5 ~ L-120 L-120 rlOrl-OO~ L-120 Log Description 22110 SCMT 22111 SCMT PROD PROFILEIDEFT/GLS 22086 PP IMP DATA. 22086 MD VISION RESiSTIVITY 22086 TVD VISION RESISTIVITY { PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotectnical Data Center LR2-1 900 E Benson Blvd, Anchorage AK 99508-4254 Date Delivered: RECEIVED NAR 2 2 2002 l\Iuka 011 & s.s Cons. ConUlJiUlon Anchorage 3/20/2002 NO. 1910 Company: Alaska Oil & Gas Cons Comm Aftn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Aurora Date Color Sepia 02111/02 2 02110/02 2 02128/02 02109/02 02109/02 02109/02 Bl CD Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 AnN: Sherrie Receive4 (j Qo~ SCb.b..,.. Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie ( Well Job # Log Description L-120 L-120 '\.9. L-120 C) L-120 0 L-120 \ f(\ L-120 c::J'L-120 f'(jL-120 22103 PEX AIT BHC V 22103 PEX-AIT V 22103 PEX-D/N I' 22103 PEX & BHC SSTVD v' 22103 BHC ,/ 22103 COMPOSITE LOG V 22103 MDT V 22103 MDT (SECTION 2 OF 2) V ( PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotectnical Data Center LR2- 1 900 E Benson Blvd. Anchorage AK 99508-4254 RECEIVED Date Delivered: ri! ~ Q "I r:: "002 ., ,1 \ .J L Alaska Oil & Gas COns. Corlll1JÌ8fCJn Ar.chorage Date 02109/02 02109/02 02109/02 02109/02 02109/02 02109/02 02109/02 02109/02 3/14/2002 NO. 1902 Company: Alaska Oil & Gas Cons Comm Aftn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Color Sepia BL CD Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie Rece"ed~ ~~ .~ :.---\ MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No L-120 Date Dispatched: 14-Feb-O2 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys ~ 2 RECE,"EJ fEß 1. 9 2.00'2. þJ;/I.a Oï & GaS eons. eonm\$$\OO ~ Received By: ~¡ ~.) Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 ! -"'" ;--... ~~~~E (ffi F ~~íÆ~[~íÆ TONY KNOWLES, GOVERNOR ALAS IiA 0 IL AND GAS CONSERVATI ON COMMISSION 333 W, 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lowell Crane Sr. Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudboe Bay Unit L-120 BP Exploration (Alaska), Inc. Permit No: 202-006 Sur Loc: 2608' NSL, 3545' WEL, Sec. 34, T12N, RIlE, UM Btmhole Loc. 4705' NSL, 3790' WEL, Sec. 35, T12N, RIlE, UM Dear Mr. Crane: 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 Prudboe Bay Unit L-120. Blowout prevention equipment (BOPE) must be tested in accordance with 20 MC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test ofBOPE 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. sinc7Þf i-=y Oechsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 24th day of January, 2002 jjc/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Hole 42" 9-7/8" 6-3/4" 6-3/4" STATE OF ALASKA /---, ,"---'" ALASKA ( AND GAS CONSERVATION COMMION PERMIT TO DRILL 20 AAC 25.005 11 b. Type of well 0 Exploratory Dßtratigraphic Test III Development Oil 0 Service 0 Development Gas [if Single zon;gb 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB = 79.1' Prudhoe Bay Field / Borealis 6. Property Designation Pool (Undefined) DZ$Z3f 6i ADL 028238 þþ 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number L-120 9. Approximate spud date 01/25/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 9526' MD / 7147' TVD 0 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 54 Maximum surface 2852 psig, At total depth (TVD) 6625' / 3515 psig Setting Depth Top Bottom MD TVD MD TVD Surface Surface 80' 80' Surface Surface 2856' 2579' Surface Surface 8795' 6435' 8795' 6435' 9525' 7147' ~II'Ð .¡' 1 a. Type of work III Drill 0 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2608' NSL, 3545' WEL, SEC. 34, T12N, R11 E, UM At top of productive interval 4670' NSL, 3876' WEL, SEC. 35, T12N, R11E, UM At total depth 4705' NSL, 3790' WEL, SEC. 35, T12N, R11 E, UM 12. Distance to nearest property line 113. Distance to nearest well ADL 028259, 3790' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casinç¡ Program Specifications Size Casino Weiaht Grade Couplina 34" X 20" 91.5# H-40 Weld 7-5/8" 29.7# L-80 BTC 5-1/2" 15.5# L-80 BTC-M 3-1/2" 9.2# L-80 IBT-M 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Lenath 80' 2856' 8795' 730' Quantitv of Cement (include staae data) 260 sx Arctic Set (Approx.) 301 sx AS Lite, 137 sx Class 'G' 169 sx Lite Crete, 156 sx Class 'G' Longstring, Cemented with 5-1/2" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RECEIVED JAN 1. 1 200Z Perforation depth: measured Alaska Oil & Gas C0i1S. Commission Anchorage true vertical 20. Attachments III Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch III Drilling Program III Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Robert Odenthal, 564-4387 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the to the best of my knowledge ftG-. Title Senior Drilling Engineer ¿... Permit Number , ,/, API Number -::1 , / ~ 'P\qvfl ~9~t~ See cover letter ;2l)? - -rJ'DI.p 50- (lZfl ~ ¿.:...JOb..,.- DO /~, '1 IU 0 for other requirements Conditions of Approval: Samples Required 0 Yes gNo Mud Lo£ Requir d 0 Yes I8fNo Hydrogen Sulfide Measures 0 Yes t8 No Directional Survey Required l2JYes 0 No Required Worki,ng pr~~sure for BOPE 0 ~Lq ~K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU ~ lAer: 45::'ð ~ '"'::. \ ~ ç> ~ ~ ~'7Y\ Original Signed By by order of Approved By ~ *' '~. ner the commission Date Form 10-401 . 12-01-85) 0 R I G1~r Submit In Triplicate ,. "- , ~ /~ ... bp ,\,f.'". ..~~ ~~. ~- _w-. ...,~ ~...~ .'i"""~ ". dO;)-oa<Q SK<¿ L-\ \~ 1\0\ l\(JÇ To: Tom MaunderlWinton Aubert, AOGCC Date: January 23. 2002 From: Robert Odenthal Subject: Dispensation for 20 AAC 25.035 (c) on L-120 BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements". Experience and data gathered, summarized herein, support the rationale for the request. To date, none of the 7 Borealis/Ivishak wells at L-pad, nor the two NWE wells 1-01 and 1-02 drilled in 1998 experienced pressure control or shallow gas problems above the surface casing depth, apart from minor and inconsequential hydrate shows. All six of the surface holes for the Borealis Development (L-1l6, L-llO, L-1l4, L-1l5, L-I06 and L- 107) and the first Ivishak well (L-Ol) were drilled to the shale underlying the SV-l sands. The shale underlying the SVI is the deepest planned surface casing setting depth for future pad development wells. This casing point is BOO' TVD above the U gnu horizon. RFT's from NWE 1-02 recorded pore pressures of 1,275 psi at 2782' TVDss (8.8 ppg EMW) and 1387 psi at 3059' TVDss (8.7 ppg EMW) in the Ugnu. L-120 is planned to reach a 9.5 ppg mud weight before TD at 2,600' TVDss. This request is being made based data submitted regarding mud weight, gas monitoring, RFT and the recent open hole surface logging (L-1O6--PEX/Di-pole sonic) for L-Pad. Your consideration of the waiver is appreciated. Sincerely, I ~S: V .L~ J. Robert Odenthal ADW Engineer 564-4387 RECEIVED JAN 2 :3 200;> Alaska Oil & Ga~ Cons, Commission AnCl1Orage - A- ¥"' '--to -~ "~ Borealis Surface Hole Mud Weight MW (ppg) 8.5 9 9.5 8 0 500 1000 - ~ 1500 c ~ - .c .... g. 2000 c 2500 10 x . -+-L-O1 ~L-116 -+-L-110 ~L-114 3000 - ~ Pore Pressure ~L-107 -L-106 -+-L-115 3500 NM 8/22/2001 RECEiVED Jl\N 2 3 2002 L-117 Drilling Permit Alaska Oil & Gas Cons. Commission Anchorage r---- , /~ Well Name: I L-120 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Producer Surface Location: As-Built Target Location: Bottom Hole Location: x = 583,368.61' Y = 5,978,332.24' 2608'FSL,3545'FEL,Sec.34,T12N, R11E X = 588,290' Y = 5,980,450' 4670'FSL,3876'FEL, Sec. 35,T12N, R11E X = 588,375.52' Y = 5,980,486.80' 4705'FSL,3790'FEL,Sec.35, T12N,R11E I AFE Number: 15M-4032 I Estimated Start Date: 101/25/2002 I I Rig: I Nabors 9ES I Operating days to complete: 118.9 I MD: 19526' 1 I TVD: 17147' 1 I BF/MS: 144.1' 1 IRKB: 179.1' I Well Design (conventional, slimhole, etc.): I Microbore (Iongstring) 1 Objective: I Kuparuk Formation Mud Program: 9-7/8" Surface Hole (0-2856'): Densitv (ppg) Viscosity (seconds) Yield Point (lb/100ft::) APIFL (mls/30min ) 15 - 20 < 10 <8 Spud Mud PH Initial 8.5 - 8.6 300 50 - 70 below Permafrost 9.3 - 9.5 200-250 45 - 60 interval TO 9.6 max 200-250 45-60 6 3;4" Intermediate / Production Hole (2856' - 9526'): Interval Density Tau 0 YP PV (ppg) 9.3-9.5 8.5-9.5 8.5-9.5 8.5-9.5 pH LSND API HTHP Filtrate Filtrate 6-8 Upper Interval Top of HAl 4-7 20-25 8-12 8.5-9.5 10.3 5-8 20-25 10-18 8.5-9.5 4-6 <10 by HAl Hydraulics: L-120 Permit to Orill- Version 1 Page 2 (~ .~ Surface Hole: 9 7/8" (0-2856') Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 0-2,856' 620 4" 17.5# 190 2300 9.8 N/A 18,18,18,12 .856 Production Hole: 6 3fi¡" (2856-9526') Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA GPM (fpm) ppg-emw ("/32) (in2) 2856' -9526' 295 4" 17.5# 240 3500 11.7 N/A 5x12 .552 Directional: Ver. (Anadrill) WP-04 KOP: 300' Slot NX Maximum Hole Angle: Close Approach Wells: Logging Program: Surface Production Hole 54.33° at 2749-6956' MD All wells pass major risk criteria. Formation Markers: Formation Tops MDbkb SV5 SV4 Base Permafrost SV3 SV2 SV1 UG4A UG3 UG1 Ma Na Oa Dbf Base CM2 CM1 L-120 Permit to Drill- Version 1 1563 1718 1899 2095 2296 2753 3525 4202 5068 5463 5917 6231 6844 7398 8270 Drilling: MWD (GR/Directional) Open Hole: Gas Detection Cased Hole: None Drilling: MWD(Dir/GR/RES/Density/Neutron) Open Hole: MDT, PEX, BHC Sonic, Gas Detection, Cuttings samples Cased Hole: None Note: Logs to be run over Schrader and Kuparak. DPC MDT in Kuparak and Schrader Bluff formations. Four samples in Schrader bluff and two in the Kuparak. TVD Pore Press (EMW) Hydrocarbon bearing 1544 8.4 No 1689 8.4 No 1854 8.4 No 2029 8.4 No 2199 8.4 No 2519 8.4 No A 95(~ 2969 8.4 No 3364 8.4 Yes 3869 8.4 Yes 4099 8.4 Yes 4364 8.4 Yes 4547 8.3 Yes 4904 9.0 Yes 5254 9.0 No 5949 9.0 No Page 3 ,. r---- .~ THRZ BHRZ (Kalubik) K.1 TKUP Kuparuk C LCU Kuparuk B Kuparuk A TMLV (Miluveach) 8708 8885 8942 8995 6349 6519 6574 6625 10.0 10.02 10 10 9.5 No No No Yes Yes No Yes No 9442 7064 CasingITubing Program: Hole Csgl WtlFt Grade Conn Length Top Btm Size Tbg O.D. MDfTVD MDfTVD bkb 42" 34 x 20" 91.5# H.40 WLD 80' GL 80/80 9-7/8" 75/8" 29.7# L-80 BTC 2856' GL 2856'/2579' 6-3/4" 5-1/2" 15.5# L-80 BTC-m 8795' GL 8795'/6435' 6-3/4" 3-1/2" 9.2# L-80 IBT-mod 730' 8795'/6435' 9525'/7147' Tubing 3-1/2" 9.2# L-80 IBT-mod 8795' GL 8795'/6435' Integrity Testing: Test Point Depth Surface Casing Shoe 20' min from surface shoe Test Type LOT EMW 14.7 ppg target 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. The production cement calculation assumes cement will be required to cover 500' above the top of the Schrader with 1000 psi compressive strength and covering the entire Kuparuk interval with 2000 psi compressive strength cement. If logs indicate the Schrader not to be oil bearing, the program will be amended to provide 2000 psi compressive strength cement above the top of the Kuparuk only. Casing Size 17-518" Surface 1 Basis: Lead: Based on 1899' of annulus in the permafrost @ 250% excess and 957' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOG: To surface Tail: Based on 500' TVD open hole volume + 30% excess + 80' shoe track volume. Tail TOG: At -2356' MD (2240' TVDbkb). I Total Cement Volume: Lead 238 bbl 1 1336ft~ 1 301 sks of Dowell ARTIGSET Lite at 10.7 ppg and 4.44 fe Isk. Tail 28.5 bbl 1 160.7 fe 1 137 sks of Dowell Premium 'G' at 15.8 ppg and 1.17 ft3/sk. Casing Size I 5-1 12"x3-1 12" Production I Longstring Basis: I Lead: Based on TOG 500' above top of Schrader formation & 30% excess + 80' shoe. Lead TOG: 4960' MD, 3789' TVDbkb Total Cement Volume: I Lead 170.1 bbls 1 394 fe 1 169 sks of Lite Grete at 12 ppg and 2.33 fe/sk. L-120 Permit to Orill- Version 1 Page 4 .~, ~, I Tail 132.3 bbls / 182 ft;j / 155.6 sks of Dowell Premium 'G' at 15.8 ppg and 1.17fe/sk. 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 the planned casing test for future frac considerations, the BOP equipment will be tested to 4500 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Maximum anticipated BHP: . Maximum surface pressure: 3515 psi @ 6625' TVDss - Kuparuk Sands 2852 psi @ surface (based on BHP and a full column of gas from TO @ 0.10 psi/H) '-\S"C(J ~bQ psi 8.6 ppg filtered seawater or brine / 6.8 ppg Diesel . Planned BOP test pressure: . Planned completion fluid: Disposal: . 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. Hydrogen Sulfide: . H2S has not been recorded on l-Pad wells. As a precaution, Standard Operating Procedures for H2S are followed at all times. L-120 Permit to Drill - Version 1 Page 5 -. I . ~. DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor. 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 plugslwell shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig Operations: 1. MIRU Nabors 9ES. Slot NX. 2. Nipple up diverter spool and riser. Function test diverter. PU 4" DP as required and stand back in derrick. 3. MU 9 7/8" drilling assembly with MWD/GR and directionally drill surface hole to approximately 2631' MD I 2579' TVD. Surface hole TD will be +1-100' TVD below the top of the SV1 sand. POH LD BHA. 4. Run and cement the 7-5/8",29.7# surface casing back to surface. Port collar will be run in the casing to allow for secondary cementing if cement is not circulated to surface during primary cementing operations depending on the Port guidelines established January 2002. 5. ND diverter spool and NU casing I tubing head. NU BOPE and test to 4500 psi. 6. MU 6-3/4" drilling assembly with MWD/GR/NEUT/DEN/RES and RIH to float collar. Test the 7 5/8" casing to 4500 psi for 30 minutes. 7. Drill out float equipment and displace well to LSND drilling fluid. 8. Drill new formation to 20' below 7-5/8" shoe and perform Leak Off Test. 9. Drill to :t100' above the HRZ, ensure mud is condition to 10.3 ppg and perform short trip as needed. During this time hold the 'Pre-Reservoir' meeting highlighting kick tolerance and detection. 10. Drill ahead to -150' of rat hole into the Miluveach formation. 11. Condition hole for logging and POOH. Make wiper trip as required by hole conditions, circulate and condition hole for logging. POOH 12. Perform open hole logging program. Run PEX/BHC Sonic (wireline only) and MDT logs. If logging time is excessive, RIH with 6-3/4" clean out assembly and condition hole for running the 5 W' x 3 W' casing. POOH laying down excess 4" DP. 13. Run and cement the tapered production casing as required from TD to 500' above the Kuparuk. Displace the casing with heated seawater during cementing operations and freeze protect the 5 W' x 7-5/8" annulus as required. (Annular Disposal Requirement - Prior to freeze protecting annulus, perform second leak off test below the 7 5/8" shoe. Record on chart and submit to town.) 14. Test the casing to 4500 psi for 30 min. 15. Run the 3-1/2",9.2#, L-80 gas lift completion assembly. Circulate around corrosion inhibitor. 16. Sting seal assembly into tieback receptacle and test to 4500 psi for 30 minutes both the tubing and annulus. Release tubing pressure and shear RP valve. 17. Install TWC and test from below to 1000 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 18. RU hot oil truck and freeze protect the well by reverse circulating in a sufficient volume of diesel to freeze protect both the tubing and annulus to lower GLM. 19. Rig down and move off. L-120 Permit to Drill- Version 1 Page 6 ,'--"'. ~, L-106 Job/Operational Breakdown ~, ,,"'~~ .._,~ Job 1: MIRU Hazards and Contingencies ~ L-Pad is not designated as an H2S site. In the wells drilled to date on this pad there has been no report H2S as being present. As a pre-caution, follow at all times the Standard Operating Procedures for H2S. ~ The closest surface location is L-104. L-104 will be -180' wellhead to wellhead from the proposed well location. The well does not require a surface shut-in. ~ Check landing ring height on L-120 conductor, the BOP stack may need to be run with a double flange on bottom (13-5/8" x 11 ") Reference RP's .:. Operational Specifics . """"--""-"""""'- _'=~mIT^'~,~' Job 2: DrillinQ Surface Hole Hazards and Contingencies ~ In this interval, no faults should be penetrated. ~ Drilling Close Approach: All wells pass BP Close Approach Guidelines. The nearest close approach well is L-106 (drilling) which will have a center-center distance of 178'@ 1150' MD. The wells with the next close approach is L-104 which has a center to center distance of 183' at 400' MD and L-116 with 231' @ 450' MD. All well pass under Major Risk Rules. ~ There has been consistent observation of gas hydrates while drilling wells off this pad. Expect to encounter hydrates from the base of permafrost to the shoe setting depth. To combat the hydrate problem, appropriate mud products will be implemented at surface. 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 circulated out. Maintain adequate viscosity. (Milne Point has encountered stuck pipe from this situation.) Reference RP's .:. OperationalSpe~fics . -=""~ '--'ITn~'-" '" n""'_~-,._-" 'W --~,,',"=,=,=, Job 3: Install Surface CasinQ Hazaros and Conüngencœs ~ It is critical that cement is circulated to surface for well integrity. Plan of 250% excess cement through the permafrost zone and 30% excess below the permafrost. A 7-5/8" port collar positioned at :t1000'MD to allow a secondary circulation as required. ~ "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement. 2. Cement - Top of tail >500' TVD above shoe, (using 30% excess.) 3. Casing - Shoe set -100' TVD below SV1 sand. Reference RPs .:. L-120 Permit to Drill- Version 1 Page 7 /~ /'---"" Operational Specifics . =~---- --.........................---- --'~~-"m.~.~nmn~=--- ----------,--- Job 7: DrillinQ Production Hole Hazards and Contingencies ~ KICK TOLERANCE: In the worst case scenario of 10.1 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 14.7 ppg at the surface casing shoe, 10.3 ppg mud in the hole, kick tolerance is 25.7 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 14.7 ppg. ~ Faults: The well trajectory is expected to intersect a fault at approximately 5475' TVD ss (Colville Formation). The fault has an estimated throw of 100'. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. This is not considered a high risk for lost circulation while drilling, however, losses maybe encountered when running the production casing string. ~ L-Pad development wells have kick tolerances approaching 25 bbl s. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. ~ There are no "close approach" issues with the production hole interval of L-106. Reference RPs .:. Operational Specifics . -=~.._.. Job 8: LoCI Production Hole Hazards and Contingencies ~ Ensure the hole is in very good condition to avoid a stuck tool string ~ If logging time is excessive or hole conditions dictate, perform a clean out run prior to running the 5 W' x 3 %" longstring casing. Reference RPs .:. Operational Specifics . - ------- Job 9: Case & Cement Production Hole Hazards and Contingencies ~ The 5-1/2" casing will be cemented to 500' above the Schrader Bluff sand. The top of the hydrocarbon interval should be verified with open hole logs. ~ If losses are encountered while running the production casing, be prepared to treat with Barafiber when circulating on bottom prior to the cement displacement. Consider increasing cement volume if 100% returns are not established. ~ Freeze protect the 5 W' x 7-5/8" casing annulus to 2856' TVD (base of surface casing) with 78 bbls of diesel. (Anchorage Drilling Engineer to verify hydrostatic pressure calculations.) It is L-120 Permit to Drill- Version 1 Page 8 Î" ~ , .. essential that freeze protection of the 7" annulus be performed only after the UCA indicates 500 psi compressive strength is indicated. A second LOT may be required prior to displacing freeze protect. This would be to satisfy AOGCC for future annular pumping permits.) > The well will be under-balanced after displacing the cement with heated sea water. Verify that the floats are holding before continuing operations and hold pressure on the well if they are not holding. > Ensure a minimum hydrostatic equivalent of 10.3 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 > The X-Nipples, with an I.D. of 2.813" is the tightest tolerance for the Weatherford Dual - Plug system, (tapered cement plugs to be used in the 5 112" X 3 112" tapered casing string.) Caliper and confirm the I.D. of all X-Nipples prior to make-up to ensure conformity with proposed design. The By-Pass plug head has been modified for a maximum a.D. of 2.5". Caliper to confirm, prior to use. Reference RPs .:. Operaüona/Spe~fics . -, -~ ~'"" "-~, ..,«.~~- ~nm." , ,.~,,~ '---~;", 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 .:. "Completion Design and Running" .:. "Freeze Protection of Inner Annulus" Operational Specifics . _..~"~ ~. -..., .... ;;.,,; ~--~~~==_.. .._-- Job 13: ND/NUlRelease Ria Hazards and Contingencies > No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Operationa/Specifics . ..~. "'.~,. .__.... mw" ..."r"'wm"'-~'~'" L-120 Permit to Orill- Version 1 Page 9 ,------ /'"" Borealis L-120: Proposed Completion TREE: 3-1/8" - 5M CIW Carbon WELLHEAD: 11" - 5M FMC G5 Cellar Elevation = 44' RKB - MSL = 79' 3-1/2" 'X' Landing Nipple with 2,813" seal bore, I 2200' I 7-518", 29.7 #Ift, L-80, BTC 1 2856' 1- ~ 3-1/2" x 1" Gas Lift Mandrels with handling pups installed. L GAS LIFT MANDRELS # TVD Size Valve Type 1 8745 1" RP 2 8685 1" DV 3 3500 1" DV L - ~ 3-1~.9-"'BTMod L-80,",""'" L <:)-----3-1/2" Baker CMD Sliding Sleeve 5-1/2",15.5 lIft, L-80, BTC-Mod "" .4- 3-1/2" Seal Stack Asembly '.- 3-112" PBR ;7 5-1/2"x3-1/2" XO Plug Back Depth 19446' 3-1/2",9.2 lIft, L-80, IBT Mod 19526' ] . 3-1/2" 'X' Landing Nipple with 2.813" seal bore C 3-1/2" 'X' Landing Nipple with 2.813" seal bore +/- 150' above Kuparak. . Date 1/10/2002 Rev By RSO Comments Borealis WELL: L-120 API NO: 50-029-XXXXX-XX Proposed Seal Bore Completion Microbore with 5-1/2"x3-1/2" tapered longstring BP Alaska Drilling & Wells bp L-120 Schlumberger Proposed Well Profile - Geodetic Report Report Date: January 8, 2002 Survey / DLS Computation Method: Minimum Curvature 1 Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 67.350° Field: Prudhoe Bay Unit - WOA (Drill Pads) dy Vertical Section Origin: N 0,000 ft, E 0.000 fi Structure/Slot: L-Pad/L-120 IIIIIt 5tll TVDReferenceDatum: KB Well: L-120 IIIIIbill Y TVD Reference Elevation: 79,1 ftrelativetoMSL Borehole: L-120 Feasl Sea Bed/Ground Level Elevation: 44.100 ft relative to MSL UWI/API#: Magnetic Declination: 26,117" Survey Name / Date: L-120 (P4) 1 January 8,2002 Total Field Strength: 57470.401 nT Tort/AHD/DDI/ERDratio: 101,278° 15451.32 ft/5.867 10.762 Magnetic Dip: 80.761° ) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: February 05, 2002 Location LaULong: N 70.35076700, W 149.3231230C Magnetic Declination Model: BGGM 2001 Location Grid N/E YfX: N 5978332.240 flUS, E 583368,610 flUS North Reference: True North Grid CDnvergence Angle: -+(),63746504° Total Corr Mag North .> True North: +26.117" Grid Scale Factor: 0,99990790 Local Coordinates Referenced To: Well Head I Grid Coordinates I Geographic Coordinates Station ID I MD I Incl I Azim I TVD I VSec I N/.S I EI.W I DLS Northing I Easting Latitude I Longitude (ft) (O) (O) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) KBE 0.00 0.00 67.35 0,00 0,00 0.00 0.00 0.00 5978332.24 583368,61 N 70,35076700 W 149,32312300 KOP Bid 1/100 300,00 0.00 67.35 300.00 0.00 0.00 0.00 0.00 5978332,24 583368.61 N 70,35076700 W 149,32312300 400.00 1,00 67.35 399.99 0.87 0,34 0.81 1,00 5978332,59 583369,42 N 70,35076793 W 149,32311643 500.00 2,00 67,35 499,96 3.49 1.34 3.22 1,00 5978333,62 583371.81 N 70,35077066 W 149,32309686 600.00 3,00 67.35 599.86 7.85 3,02 7,25 1,00 5978335,34 583375.83 N 70,35077525 W 149.32306415 Bid 1.5/100 700.00 4,00 67,35 699,68 13,96 5,37 12.88 1,00 5978337,75 583381.43 N 70,35078167 W 149.32301844 800,00 5,50 67,35 799,33 22.24 8,56 20,52 1,50 5978341,03 583389.03 N 70,35079038 W 149.32295642 900.00 7.00 67.35 898,73 33,12 12.75 30.57 1.50 5978345.33 583399.03 N 70.35080183 W 149,32287483 1000.00 8,50 67,35 997,82 46.61 17,95 43,02 1,50 5978350,67 583411.42 N 70.35081604 W 149,32277376 ) BId 2/100 1100,00 10.00 67,35 1096,51 62.68 24,14 57.85 1.50 5978357,02 583426,18 N 70.35083295 W 149,32265337 1200.00 12,00 67,35 1194,67 81.76 31.48 75.46 2.00 5978364,55 583443.71 N 70,35085300 W 149,32251041 1300.00 14.00 67,35 1292,10 104,26 40.14 96.22 2,00 5978373.44 583464.37 N 70,35087666 W 149,32234187 1400.00 16,00 67,35 1388,69 130.14 50.11 120.10 2,00 5978383,68 583488,13 N 70,35090389 W 149,32214801 1500.00 18,00 67,35 1484,32 159,37 61.36 147.09 2,00 5978395,23 583514.99 N 70.35093462 W 149.32192890 SV5 1563.09 19,26 67,35 1544,10 179,53 69.12 165.69 2,00 5978403.19 583533,51 N 70,35095582 W 149,32177790 1600.00 20.00 67.35 1578,86 191.93 73.90 177.13 2.00 5978408,10 583544,89 N 70,35096888 W 149,32168503 1700.00 22.00 67.35 1672,22 227.76 87,70 210.20 2.00 5978422,26 583577,80 N 70,35100658 W 149,32141656 SV4 1718.23 22.36 67.35 1689.10 234.65 90.35 216.56 2,00 5978424.99 583584,13 N 70,35101382 W 149.32136492 L-120 (P4) report,xls Page 1 of 3 1/8/2002-1 :24 PM I Grid Coordinates I Geographic Coordinates Station ID I MD I Incl I Azim I TVD I VSec I N/.S I EI.W I DLS Northing I Easting Latitude I Longitude (ft) (O) (O) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 1800,00 24,00 67,35 1764.26 266.83 102.74 246,26 2.00 5978437,70 583613.69 N 70.35104766 W 149,32112381 End Bid 1871,38 25,43 67,35 1829,10 296,68 114.23 273.80 2.00 5978449,50 583641.10 N 70.35107905 W 149,32090023 Base Permafrost 1899,06 25.43 67.35 1854,10 308,56 118.81 284.77 0,00 5978454,20 583652,01 N 70.35109156 W 149,32081117 Bid 1.5/100 1926.74 25.43 67.35 1879,10 320.45 123.38 295.74 0,00 5978458,89 583662,93 N 70.35110405 W 149,32072211 2000,00 26.53 67.35 1944,96 352,53 135.74 325,35 1.50 5978471,58 583692.40 N 70.35113781 W 149,32048173 Bid 2.5/100 2026,74 26.93 67.35 1968,84 364,56 140.37 336.45 1,50 5978476,33 583703,45 N 70.35115046 W 149.32039161 SV3 2094.85 28.63 67.35 2029,10 396,30 152,59 365,75 2.50 5978488,88 583732,61 N 70,35118384 W 149.32015374 2100.00 28.76 67.35 2033,62 398,78 153,54 368,03 2,50 5978489.85 583734,87 N 70,35118643 W 149,32013523 Bid 4/100 2126.74 29.43 67.35 2056,98 411,78 158,55 380,03 2,50 5978494,99 583746,82 N 70,35120012 W 149,32003781 2200.00 32.36 67.35 2119,84 449,39 173,03 414,74 4,00 5978509,86 583781.36 N 70,35123967 W 149.31975602 ) SV2 2295.93 36.20 67.35 2199,10 503,41 193,83 464.59 4,00 5978531,21 583830,97 N 70,35129648 W 149.31935131 2300.00 36.36 67.35 2202,38 505,81 194,76 466,81 4,00 5978532,16 583833,18 N 70.35129903 W 149.31933329 2400.00 40.36 67.35 2280,78 567,86 218.64 524,08 4.00 5978556,68 583890.18 N 70,35136425 W 149.31886834 2500.00 44,36 67.35 2354,66 635.22 244,58 586,24 4,00 5978583,30 583952,04 N 70.35143511 W 149.31836369 2600.00 48,36 67.35 2423,66 707,57 272,44 653,02 4,00 5978611,90 584018,50 N 70.35151120 W 149.31782152 2700,00 52,36 67,35 2487,44 784,56 302.08 724,07 4,00 5978642,33 584089,21 N 70.35159216 W 149.31724468 End Bid 2749.40 54,33 67,35 2516,93 824,19 317.34 760,64 4,00 5978657,99 584125,60 N 70.35163384 W 149,31694778 SV1 2753.12 54,33 67.35 2519.10 827.21 318.50 763,43 0.00 5978659.18 584128,38 N 70.35163700 W 149,31692513 7-5/8" Csg Pt 2856.02 54,33 67.35 2579.10 910,81 350,69 840,59 0.00 5978692.23 584205.17 N 70,35172492 W 149,31629868 UG4A 3524,90 54.33 67.35 2969,10 1454,23 559,92 1342,11 0.00 5978907,00 584704.28 N 70,35229632 W 149,31222679 UG3 4202,36 54.33 67.35 3364,10 2004.61 771.84 1850.07 0.00 5979124,54 585209.81 N 70,35287497 W 149,30810238 UG1 5068.48 54.33 67.35 3869,10 2708.27 1042,77 2499.48 0.00 5979402,65 585856,10 N 70.35361461 W 149.30282912 Ma 5462,95 54,33 67,35 4099,10 3028,75 1166,16 2795.25 0.00 5979529.31 586150,45 N 70.35395141 W 149.30042732 Na 5917.44 54,33 67.35 4364.10 3398,00 1308,33 3136.02 0,00 5979675,25 586489.59 N 70,35433944 W 149,29766000 Oa 6231.31 54,33 67.35 4547.10 3652.98 1406.51 3371,35 0.00 5979776,04 586723,79 N 70.35460738 W 149,29574888 Obf Base 6843.59 54,33 67.35 4904,10 4150.42 1598.03 3830,44 0,00 5979972,63 587180,68 N 70,35512999 W 149,29202044 ') Drp 2/100 6957.55 54,33 67.35 4970,55 4243,01 1633,68 3915,89 0.00 5980009.23 587265,72 N 70,35522726 W 149.29132645 7000,00 53.48 67.35 4995,55 4277.31 1646,89 3947.55 2.00 5980022,79 587297,22 N 70.35526330 W 149,29106932 7100,00 51.48 67.35 5056.45 4356.62 1677.43 4020,75 2.00 5980054,14 587370.07 N 70,35534663 W 149.29047481 7200.00 49.48 67.35 5120,07 4433.77 1707,13 4091.94 2.00 5980084,62 587440.92 N 70,35542766 W 149,28989662 7300,00 47.48 67.35 5186,35 4508.64 1735,96 4161.04 2.00 5980114,22 587509.69 N 70.35550632 W 149,28933540 Top Colville CM2 7398.43 45.52 67,35 5254.10 4580.04 1763.45 4226,93 2.00 5980142,44 587575.26 N 70.35558132 W 149,28880025 7400.00 45.48 67.35 5255.20 4581.16 1763.88 4227.97 2,00 5980142.88 587576.30 N 70,35558249 W 149,28879180 7500.00 43,48 67.35 5326.54 4651,22 1790.86 4292.63 2,00 5980170.57 587640,65 N 70,35565610 W 149.28826663 7600,00 41.48 67.35 5400,28 4718,76 1816.86 4354,96 2,00 5980197,26 587702.68 N 70.35572703 W 149.28776039 L.120 (P4) report,xls Page 2 of 3 1/812002-1:24 PM I Grid Coordinates I Geographic Coordinates Station ID I MD I Incl I Azim I TVD I VSec I NI.S I EI.W I DLS Northing I Easting Latitude I Longitude (ft) (O) (O) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 7700.00 39.48 67.35 5476,34 4783,68 1841.86 4414,88 2,00 5980222.93 587762,31 N 70,35579523 W 149.28727372 7800,00 37,48 67.35 5554.61 4845.91 1865,82 4472,31 2.00 5980247,52 587819.47 N 70.35586059 W 149.28680726 7900,00 35.48 67,35 5635.01 4905.37 1888,71 4527.18 2.00 5980271,02 587874.07 N 70,35592304 W 149,28636160 8000,00 33.48 67,35 5717,43 4961,98 1910,51 4579,44 2,00 5980293.40 587926,08 N 70.35598251 W 149,28593713 8100.00 31.48 67.35 5801,78 5015.69 1931.19 4629,00 2,00 5980314.62 587975.40 N 70.35603892 W 149,28553459 8200.00 29.48 67.35 5887,95 5066.42 1950.72 4675,82 2,00 5980334.67 588022,00 N 70,35609219 W 149,28515431 CM1 8269.77 28.09 67.35 5949,10 5100.02 1963.66 4706,83 2.00 5980347.96 588052,86 N 70,35612749 W 149,28490243 8300.00 27.48 67,35 5975,84 5114,11 1969,08 4719,83 2.00 5980353,52 588065,80 N 70.35614228 W 149.28479684 8400.00 25.48 67.35 6065,34 5158.70 1986,25 4760.99 2.00 5980371,14 588106.76 N 70,35618911 W 149.28446252 8500,00 23.48 67,35 6156.34 5200,14 2002.21 4799,23 2.00 5980387.53 588144,82 N 70,35623265 W 149.28415192 ) 8600.00 21.48 67.35 6248,74 5238,39 2016.93 4834,53 2,00 5980402,64 588179,95 N 70.35627280 W 149.28386520 8700.00 19.48 67.35 6342,41 5273.38 2030.41 4866.82 2,00 5980416,47 588212,08 N 70,35630957 W 149.28360292 Top HRZ 8707.09 19.34 67,35 6349.10 5275,74 2031,32 4869.00 2.00 5980417,41 588214.25 N 70,35631205 W 149.28358522 8800,00 17.48 67,35 6437,24 5305,08 2042,61 4896,08 2.00 5980429,00 588241,20 N 70,35634284 W 149,28336526 Base HRZ 8885.43 15,78 67.35 6519.10 5329.53 2052,03 4918,65 2,00 5980438.67 588263,66 N 70,35636854 W 149,28318193 8900.00 15.48 67.35 6533,13 5333.46 2053.54 4922,27 2,00 5980440.22 588267,27 N 70,35637266 W 149.28315253 End Drp 8924.24 15.00 67,35 6556,52 5339.83 2055,99 4928,15 2,00 5980442,73 588273,12 N 70,35637934 W 149.28310477 K-1 8942.44 15.00 67,35 6574,10 5344,54 2057,81 4932.50 0.00 5980444.60 588277.45 N 70.35638430 W 149,28306944 Top Kuparuk 8995,23 15,00 67.35 6625,09 5358,21 2063,07 4945,11 0,00 5980450,00 588290,00 N 70,35639865 W 149.28296701 Target! Drp 2/100 8995,24 15,00 67.35 6625,10 5358.21 2063,07 4945,11 0.00 5980450.00 588290,00 N 70,35639865 W 149.28296701 9000.00 14.90 67,35 6629,70 5359.44 2063,54 4946,25 2.00 5980450,48 588291,13 N 70,35639993 W 149,28295775 9100.00 12.90 67,35 6726,76 5383.47 2072,79 4968.42 2,00 5980459.98 588313,20 N 70,35642516 W 149.28277767 9200,00 10,90 67.35 6824,61 5404.09 2080.74 4987.46 2.00 5980468,14 588332,14 N 70.35644685 W 149.28262302 9300.00 8,90 67,35 6923,11 5421,29 2087,36 5003,33 2,00 5980474,93 588347,94 N 70,35646490 W 149,28249411 End Drp 9375.76 7,39 67,35 6998,10 5432,03 2091.49 5013.24 2,00 5980479,17 588357,80 N 70.35647617 W 149,28241362 Top Miluveach 9442.31 7,39 67,35 7064.10 5440,59 2094,79 5021.14 0,00 5980482,56 588365,66 N 70.35648517 W 149,28234945 ) TO /5-112" Csg pt 9525,76 7,39 67,35 7146.85 5451.32 2098.92 5031.05 0.00 5980486,80 588375.53 N 70.35649643 W 149.28226895 Leqal Description: Surface: 2608 FSL 3545 FEL S34 T12N R 11 E UM Target: 4670 FSL 3876 FEL S35 T12N R11E UM BHL: 4705 FSL 3790 FEL S35 T12N R11E UM Northinq ey) [nUSl 5978332,24 .5980450,00 5980486,80 Eastinq eX) [nUSl 583368.61 588290.00 588375.52 L-120 (P4) report.xls Page 3 of 3 118/2002-1:24 PM .......... +-' Q) .......... ~~ g~ 0 Q) C\I > II .8 c: CO :;:4= .........0 ..c:""': ã.~ Q) ......... om co~ .~ ã5 ~a:: > > Q)..!!2 ~w .... I- .~ ~, bp VERTICAL SECTION VIEW Client: Well: Field: BP Exploration Alaska (P4) L-120 Schlumberuer Prudhoe Bay Unit - WOA L-pad Structure: Section At: 67.35 deg Date: January 08, 2002 -2000 -i i I O_..i.. Bid 700 TVD ..... ~;~~:~~t~:~7~l~i""""""'" h 25.43. 6p5." 297 departure . Bid 1.5(100 1927 MD 1879 TVD j", ~~~~,: . i 2~,~3' ....7.~~~ ""..41~.~ap~rt",.a..i EndBld2749MD 2517TVQ '54:33.67.35" ai624dep¡¡¡¡u.. .., I "'kV$"16(3'Mr;"15'~;¡ TVD - 'l,vn7f~MD-'Q,l'l"D ,.t""i.jþ",h,,'ii:;I! jS9¡¡MO 2000 -"fiV'j'16J"',¡:B""ji)ï~1"vD" "ßVTn"r. MO"21¡¡g WD I rV127f3t.",n'j9 TVO 'UG4Ä ~525MD 1%9W"" -.. --. -.. ,- -- .7.,<;i~..~'Q.Pt2856M.D ..2.~79TVQ... 54.33' 67.35' az 911 deli""",a "Tvc'", Œi2 "'o 315.1 NO .. -.., . . . . ~old Angle 54.33°: 4000 ~....I;'I.Ø...j(ê,'Y.,i.¡:",:i.1Y¡¡.... "!'Má"'O"",,¡j"'C%TJr:> .. ~f~:.~~~;';;i;~~~~;~~~~ ..; ....; "'TObfB.,."G&'. MO' 4%' r>'O ..t , , .. "!",;)ZiO",;n" CM; 73HMO"SÔ'TVO" ...1 End Drp ....8924MO... 6&,j,7 lYD 15.00" 67.35. az 5340 departu,e 6000 --...."<,..1'.01",.,-,1').-{-9;,9.,\I"..=.....=.....". ...CiCi.....Ci'.... .., -- ..,TargetlDrp2l100 8995 MD 6625 TVD 15.00' 67.35' az ..~/(G: -~ ; J35~~da~~rtui~ J~ .- - - .... -. - -ìop1'RZ 8ioi MD- 634- T'!ò --V --, --- - .., -- -- -- -- -- - .- -- -- '= ~~~~;;'u~i"~I~i2~ff',jif:":¡¡""R-,¡)i;5iin,;¡j c= ='i== =- è=, ..... = =j = End Drp ..~37.~ .MD. ..998 TVD 7.39' 67.35' az 5432 departure . .... ..... ..... ..... .... .... ..' T09 "Hum" 9442 .,,) ">64 'VO 8000 --,-- nÜ 5-112" Cog PI 95~6 MD 71471VD 7:~""6i:35ö'äZ""""'" 54~1 departure . . 1 0000 -......-i--................ _u......_---~';'---_..__.._--;.._---_._..._--- --------"'---m - ... --.......-.-...---, , I -2000 i 0 i 2000 I 4000 i 6000 Vertical Section Departure at 67.35 deg from (0.0, 0.0). (1 in = 2000 feet) PLAN VIEW Client: BP Exploration Alaska Well: L-120(P4) Field: Prudhoe Bay Unit - WOA Structure: L-pad Scale: 1 in = 1000 ft Date: 08-Jan-2002 Schlumberger -1000 0 1000 2000 3000 4000 5000 6000 , , , '¡ I I True North I ! I Ta",.t/Ol> 21100 3000 -~~I Mag Dee ( E 26, 120) .... mm mLa99~~¡:>ß~~1Yqm.;~m; - 3000 ) i I 15.00' G7.35'az TOI5.1I2"Cag PI 9526 MO 7147 TVD 7.39' 67.35' az 2099 N 5031 E ,a.. . End Ol> , F- ;\. a924MD 6557TVD ^ ^ ^ J: 2000 _mml;mmL:/~m m - 2000 ~ . a::: 0 z I . J. :i.\\x,1 ;:>'" I ~ \ \ ! -,«\~ , ~ !\ EndDI> 9376 MD 699a TVD 1 000m~m+'+695aMD4.1tTV)m+~;.,~9;1\J6!~~~~~..... m - 1000 B'dl.51100 1927 MD la79 TVD 25.43' GH5'az 123N 296E J: § 0 _m~~~4~~!4~~~az:~1~m mL, .. - 0 ) CJ) V V V B'dl.51100 700MD 700TVD 4.00' G7.3S' az -1000 _m ON O.¡m - -1000 I I I I I I -1000 0 1000 2000 3000 4000 5000 6000 «< WEST EAST »> ~ "--\ Schlum berger Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.50 to 9525.76 ft Maximum Radius: 1144.55 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive WeJlpath Date: 12/2112000 Validated: No Planned From To Survey ft ft 28.50 9525,76 Version: Toolcode 5 Tool Name Planned: Plan #4 V1 MWD+IFR+MS MWD + IFR + Multi Station Casing Points 2856.05 9525.76 2579.10 7147.14 7.625 5.500 8.750 6.750 75/8" 5 1/2 x 3 1/2" Summary EX NWE#1 NWE1-01 NWE1-01 V3 299.99 300.00 493,91 4,80 489.11 Pass: Major Risk EX NWE#1 NWE1-01 NWE1-01A VO 299,99 300.00 493.91 4.80 489.11 Pass: Major Risk EX NWE#1 NWE1-02 NWE1-02 V2 1392.98 1500.00 357.26 25,69 332,35 Pass: Major Risk PB L Pad L-01 L-01 V14 348.40 350,00 244.76 5.37 239.39 Pass: Major Risk PB L Pad L-104 Plan L-104 V6 Plan: PI 399.03 400.00 183.42 8,25 175.17 Pass: Major Risk PB L Pad L-106 Plan L-106 V9 Plan: PI 1125.71 1150.00 178.14 19,29 158.89 Pass: Major Risk PB L Pad L-107 L-107 V14 445.50 450,00 231.55 8.58 222.97 Pass: Major Risk PB L Pad L-110 L-110 V11 299,99 300,00 333.37 5.14 328.23 Pass: Major Risk PB L Pad L-114 L-114 V14 393.80 400.00 397.71 5,84 391.87 Pass: Major Risk PB L Pad L-115 L-115V7 491.12 500.00 264.44 7.86 256.60 Pass: Major Risk PB L Pad L-116 L-116 V10 443.13 450.00 309.38 6.32 303.08 Pass: Major Risk PB L Pad L-117 L-117 V11 347.93 350.00 250.30 5.17 245.13 Pass: Major Risk Polygon I 2 3 4 Site: PB L Pad Drilling Target Conf.: 99% Centre Location: Map Northing: 5980450.00 ft Map Easting : 588290.00 ft Latitude: 70°21 '23.035N +N/-S ft 404.44 395.58 -404,44 -395.58 ,~~, Target: L-120 +E/-W ft -395.58 404.44 395,58 -404.44 ~Il: L-120 ,ed on: Planned Program Vertical Depth: 6546.00 ft below Mean Sea Level Local +N/-S: 2063.31 ft Local +E/-W: 4945.00 ft Longitude: l49°l6'58.68IW Northing ft 5980850.00 5980850.00 5980050.00 5980050.00 Easting ft 587890.00 588690.00 588690.00 587890.00 ~ / ~ 1\ ~ ~ / ~ D D J J D D LD J D D CO J D D D Lf) D D N Lf) D D J Lf) D D LD Lf) 300 280 250 24-0 220 200 180 150 14-0 D CJ CO Lf) '~" ~\ L-120 Well Summary of DrillinQ Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: . Gas hydrates were observed in 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. Production Hole Section: . The production section drilled with a recommended mud weight of 10.3 ppg to ensure shale stability in the HRl shale. 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. . In the worst case scenario of 10.1 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 14.7 ppg at the surface casing shoe, 10.6 ppg mud in the hole, kick tolerance is 25.7 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 14.7 ppg. . The faults expected to be penetrated by L-120 in the base of the UGNU/ Top of Schrader at 3865' TVD. The throw is 100' to the West.. The Colville fault at -5095' TVDss. The throw is -60' down to the west. There is not a high risk for lost circulation while drilling, however, losses maybe encountered when running the production casing string. . A majority of the L-Pad development "Microbores" will have "kick tolerances" in the 25-40 bbl range. At least 100' prior to entering the Kuparuk reservoir, the drill crews will hold a safety meeting to discuss steps to ensure that a heightened awareness of kick detection will be in place while drilling/tripping through the intermediate/production intervals. HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. Recent wells drilled on L-pad did not report H2S as being present. As a precaution Standard Operating Procedures for H2S precautions should be followed. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies Page 1 of 1 /~, ~.-~, TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME $a i - /ZÓ CHECK 1 STANDARD LETTER DEVELOPMENT ~/ DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL RED RILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If apl number last two (2) digits are between 60-69) PILOT HOLE (PH) // / ANNUL~~~SAL ANNULAR DISPOSAL <.-> YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing weD ~PermitNo, . API No. . . Production should continue to be reported as a function of the original API number stated above. . In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logS acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated.. . ANNULUS <.-> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed Is the approved application for permit to drill the above referenced well. The permit is approved .sùbject 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. ~ ,~\ H 202454 1 DATE 1 12/07/01 I CHECK NO, I 00202454 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS 100.00 VENDOR DISCOUNT ALASKAOILA NET 00 120501 CK120501D PYMT COMMENTS: HANDLING INST: 100.00 Permit to Drill 7ee S/H - Terrie Hub)le X4628 ~v\20 "j,- :-- '" " " ,', J 4 \" , .. ,',' ¡ i/a:,,¡.c; THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100.00 .100. 00 BP EXPLORATION, (ALASKA) INC. p,o, BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFlUATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H2O 2 4 5 4 I I CONSOLIDATED COMMERCIAL ACCOUNT 56.389 4'i"2' 00202454 PAY ONE HUNDRED & 00/100************************************* US DOLLAR DATE 12/07/01 I I AMOUNT $100.001 To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE NOT VALID AFTER 120 DAYS AK 99501 \( e' f ,> J 1"; Í' I:, f LA , ' ~ß'¿. >., . '\,~ ~ III 20 2~ 5~1I1 I:O~ * 20 ~BI1 51: OOB~~ .11111 I?ða WELL PERMIT CHECKLIST COMPANY ß¡!J¿ - WELL NAME L -I zD PROGRAM: exp - dev ./ redrll- serv - well bore seg _ann. disposal para req - FIELD & POOL foc!(")/¿Z")(i) INITCLASS ~bV í OIL GEOLAREA Brn UNIT# ()¡/&5"O ON/OFF SHORE 0/1. ADMINISTRATION 1. Pennit fee attached. . . . . . . . . . . . . . . . . . . . . .. ~N. / / 2. Lease number appropriate~ . . . . . . . . . . . . . . . . . Y N * ..5u-r#C-L- /4>~h~ ~ /It::>z- Ó28z..3'~ ~¡=> rd(>,.d. ¿4..-~t/~( 3. Unique well ~ame and number... . . . . . . . . . . . , . , . ~ --T:.Þ. ~ /h::/L. c;>zf5"Z3ð1 ~/-!D " " 4. Well located In a defined pool:~. . . . . . . . . . . . . . . N .~* (!o '981'1 c.:ur1<-i1-1I'1 ~u-I.:¿-1e..6 '¡«¿';-/:::i-J~~ßP-'-A (J/ ( fZ( 5. Well located proper distance from drilling unit boundary. . . . iN ¡,J ,,;.I'(~, ../tu:,q þ;h--/7~ ¿f";tþ", ~d'Ku-<'_t ~,,7< 6. Well located proper distance from other wells.. . . . . . . . . N {/ 0 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . N 8. If deviated, is wellbóre plat included.. . . . . . . . . . . . . . iN 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . ~ N 11. Pennit can be issued without conservation order. . , . . . . . ' N 12. Pennit can,be issued without administrative approval. . . . . . .' N 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y N 14. Conductor string provided . . . . . . . . " . . . . . . . .-: 15. Surface casing protects all known USDWs. . . . . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. GMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will COver all known productive horizons. . . . . . . . . . 19. Casing designs adequate for C, T, B & pennafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . 23. If diver1er required, does it meet regulations. . . . . . . . . . 24. Drilling fluid program schematic & equip list adequate. . . . . 25. BOPEs, do they meet regulation. . . . . . . . . . .Ð' . . . 26. BOPE press rating appropriate; test to L...\SQ psig. , 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdbwn. . . . . . . . . . . 29. Is presence of H25 gas probable.. . . . . . . . . . . . . . . . ~y N , N ~~ ~' N , ~ ~ ~',,>,\'\.~ ~"- ~~~~ &:>\~ "f-+ \-.!)þ.., oJ ~ ~ " S\ - N c \c~ C,Q ~~~¥'> '\è )(('\1'.,,\' ,\~~ I N N N N K~<;\' ~\- ~:l<;sS;) ~\. ,-\g:::(',) ~~\-\<:..~~ ..ç~,-: N ~~ : GEOLOGY, 30. Pennit can be issued w/o hydrogen sulfide measures. . . .. á) N 31. Data presented on potential overpressure zones. . . . . . . ~ 32. Seismic analysis of shallow gas zones. . . . . . . . .~. . . Y N . AP R DATE 33. Seabed condition survey (If off-shore). . . . . . . . . . . . . Y N ~ ¡. IS. 6~ 34. Contact name/phone for weekly progress reports [explo ry only] Y N ¡ANNULAR DISPOSAL35. With proper cementing records, this plan. (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; . (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing fonnation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION~IIJ#.loz.-. C<m1 me ntsJInstroctions: . ¡J'. ..£-." ~þgf'~ ~~ WM"-- ~ 8~s"eMAfp (:!)-TÁL- ßO~/¡'5 .+t.e-IJ/¡:>bO/ Cðct- to ~ ~ a, A ' ~ 'fEMA;~~ v,~.. JMH H(J~~A¡rW/NSR tLc..C-DLI..+\./rx< Uød[~'-t..~ Kupa.-ruL ~~Uð!r- , I(VýID-z.,¡~ ÙJ -¿;;j~~~,!~ (lntd'Æ6<- ~ ' K¿,/'~<" £¡~ {)Ii (f:/ ~ h c u V'~ð -0 v¿~ h¿r t!-o qt It < þj) / A~.R DATE pc:> / ' /5;:0 z-. ENGINEERING '~D~~ APPR DATE c:\msoffice\wordian\diana\checklist (rev. 11/011100) ~ E><'-4-c-l<-d lre-$SU~ U..- k~~A.-r(/-L /"'L~Vðl" &d 357Ç¡si. f/DffûtJ1:V. Y N Y N / c"'~'-.) \o,~'>~ ' ~>~ \-ö <3...Jr r ~~ ? '0 0 Z 0 -t :E ::0 ') / -t m Z -t :I: - en » ::0 m » ).