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Home My WebLink About205-160MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-31A PRUDHOE BAY UNIT 13-31A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 13-31A 50-029-22459-01-00 205-160-0 W SPT 8709 2051600 2177 1332 1318 1322 1328 38 38 39 38 REQVAR P Brian Bixby 8/18/2024 2 Year MIT-IA as per AIO 4G.003 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 13-31A Inspection Date: Tubing OA Packer Depth 222 2431 2390 2385IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB240820130933 BBL Pumped:1.4 BBL Returned:1.4 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 99 9 99 99 99 9 9 9 AIO 4G.003 James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 10:38:35 -08'00' David Douglas Hilcorp North Slope Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt and return one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 06/26/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL Folder Contents: Log Print Files, Reports and Digital Data Files: Well API #PTD #Log Company Log Date Log Type AOGCC E-Set # PBU 13-31A 50029224590100 205160 SCHLUMBERGER 12/23/2005 MEMORY CBL (SCMT) Please include current contact information if different from above. T39052 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.26 14:48:45 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, August 29, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-31A PRUDHOE BAY UNIT 13-31A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2022 13-31A 50-029-22459-01-00 205-160-0 W SPT 8709 2051600 2177 1526 1526 1526 1526 33 33 36 36 REQVAR P Adam Earl 8/2/2022 MIT-IA tested as per AIO 4G.003 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 13-31A Inspection Date: Tubing OA Packer Depth 56 2424 2380 2377IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220803173526 BBL Pumped:1.6 BBL Returned:1.6 Monday, August 29, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9James B. Regg Digitally signed by James B. Regg Date: 2022.08.29 15:21:48 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Monday, August 31, 2020 P.I. Supervisor F149"', C 1 W/1 27OZIO SUBJECT: Mechanical Integrity Tests C BP Exploration (Alaska) Inc - 13 -31A FROM: Jeff Jones PRUDHOE BAY UNIT 13-3]A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Comm Well Name PRUDHOE BAY UNIT 13-31A API Well Number 50-029-22459-01-00 Inspector Name: Jeff Jones Permit Number: 205-160-0 Inspection Date: 8/13/2020 Insp Num: mitJJ200813114416 Rel Insp Num: Monday, August 31, 2020 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-31A Type jn� W -1TVD I 8709 Tubing 1573 1570 - 1569 1558 - Ii — PTD zosl600 -I T e SPT' yP Test' Test psi 2177 IA -- 281 2490 �- 2456 24s t -- - BBL Pumped. 1.5 - BBL Returned: 16 OA 45 46 46 46 Interval REQVAR PIF P / Notes' 2 year MIT required by AA 4G.003 fo max- anticipated injection pressure. 1 well inspected, no exceptions noted. Monday, August 31, 2020 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, September 06, 2016 7:13 PM To: AK, OPS FS3 OSM;AK, OPS FS3 Field OTL;AK, OPS FS3 Facility OTL;AK, OPS FS3 DS Ops Lead;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AKOpsProdEOCTL;G GPB FS3 Drillsites; 'chris.wallace@alaska.gov' Cc: AK, GWO Projects Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep; Regg, James B (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J Subject: OPERABLE:Injector 13-31A(PTD#2051600)Administrative Approval AIO 4G.003 for Water Injection Only Attachments: 13-31A aio4G.003 09-06-16.pdf All, Injector 13-31A(PTD#2051600)was classified Not Operable on 06/23/16, due to slow inner annulus repressurization while on MI.A passing non-witnessed MIT-IA was performed on 08/13/16,demonstrating two competent well barrier envelopes. On 09/01/16,the AOGCC granted Administrative Approval,AIO 4G.003,allowing water injection only,subject to conditions specified in the attached AA. The well is reclassified as Operable,and may be brought online in water only injection service as required. Please be aware of the fluid-packed annuli. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 SCANNED JAN 2 5 2017 H:2376 Email: AKDCWelllntegritvCoordinator@BP.com From: A', • • PT Well Integrity Sent: Thursday, June , e • 5:22 PM To: AK, OPS FS3 OSM; AK, OPS FS • OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, GWO SUPT Special Projects; AK, GWO SUPT Slickline; Cis .i Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AKOpsProdEOCTL; AK, OP = Ops Lead; G GPB FS3 Drillsites; 'chris.wallace@alaska.gov' Cc: AK, GWO Projects Well Integrity; AK, GWO DHD Well Inte• • • AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Dickerman, Eric; 'Regg, James B (DOA)'; Morrison, Spencer; Munk, Co - • Odom, Kristine; AK, GWO SUPT Well Integrity Subject: NOT OPERABLE: Injector 13-31A (PTD #2051600) Slow Tubing x - Annulus communication • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Thursday, June 23, 2016 5:22 PM To: AK, OPS FS3 OSM;AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL;AK, OPS FS3 DS Ops Lead; AK, GWO SUPT Special Projects; AK, GWO SUPT Slickline; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; 'chris.wallace@alaska.gov' Cc: AK, GWO Projects Well Integrity; AK, GWO DHD Well Integrity;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Dickerman, Eric; Regg, James B (DOA); Morrison, Spencer; Munk, Corey; Odom, Kristine; AK, GWO SUPT Well Integrity Subject: NOT OPERABLE:Injector 13-31A (PTD #2051600) Slow Tubing x Inner Annulus communication Attachments: 13-31 TIO 6-23-16.docx All, Injector 13-31A (PTD#2051600) has been identified to have slow tubing by inner annulus communication on MI. An MIT-IA conducted June 23, 2016 failed to show stabilization.The well is now classified as Not Operable and will remain shut in to evaluate repair/secure options. Plan Forward: 1. Anchorage PE: Evaluate leak detection/AA for water only -- 2. —2. Well Integrity: Further diagnostics as required Please reference attached TIO/ Rate plot. Ryan Holt CANNE� ° �12 8 201 . Well Integrity –GWO Alaska (Alternate:Lee Grey) Office: (907)659-5102 Email: AKDCWellIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: TuesOay, March 22, 2016 12:57 PM To: AK, OPS SM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations`S perntendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr;-K, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Chou, Irwin; 'chris.wattace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver'R; ayers, Jessica; Dickerman, Eric; 'Regg, James B (DOA)'; Morrison, Spencer; Munk, Corey; Odom, Kristine Subject: OPERABLE: Injector 13-31A (PTD #2051600) Stabilized Inner Annulus Pressure All, Injector 13-31A(PTD#2051600) inner annulus (IA) pressure was bled from 1060 psi dow t 0 psi on February 28, 2016. During a 30 minute monitor following the bleed, the IA increased 10 psi to a final pre re of 310 psi. A follow up monitor obtained on March 22, 2016 confirmed an IA pressure of 580 psi, over a three week period indicating pressures appear to have stabilized.The Miscible Injection gas temperature increase from 58°to 100°. The well has been 1 • 13-31 TIO 3/23/16 -06/23/16 WWI I1-31 026 3W0 -a- t 4 4 1000 001 1000• 012126 03]016 060616 061116 0620.26 0627.16 030616 001116 Oe,"616 0115.16 069116 060116 061516 012216 13-31 Rate 3/23/16—6/23/16 Well 1331 1600 110 ..0M 3 MO 22 OW KO 600 600 Kan 1.00 -�_ 1000 :100 15.000 1CO0 WOW 40001 1 KO 1 600 ^ r�6 _:. 1 200 3000 60W MO ero 6610 '. 200 2 j 012316 031016 460626 0611% 062016 0621,16 030626 ONIM mi61t MS% 0651151 06EY16 we.* 06an • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, March 22, 2016 12:57 PM To: AK, OPS FS3 OSM;AK, OPS FS3 Field OTL;AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead;AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Chou, Irwin; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer;AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA); Morrison, Spencer; Munk, Corey; Odom, Kristine Subject: OPERABLE:Injector 13-31A(PTD#2051600) Stabilized Inner Annulus Pressure Attachments: Injector 13-31A (PTD #2051600) TIO and Injection Plot.docx All, Injector 13-31A(PTD#2051600) inner annulus (IA) pressure was bled from 1060 psi down to 300 psi on February 28, 2016. During a 30 minute monitor following the bleed, the IA increased 10 psi to a final pressure of 310 psi. A follow up monitor obtained on March 22, 2016 confirmed an IA pressure of 580 psi,over a three week period indicating pressures appear to have stabilized.The Miscible Injection gas temperature increase from 58°to 100°. The well has been reclassified to Operable status but will remain on the Well Integrity monitor list for a period of up to 30 days to confirm pressure stabilization. If the IA shows any signs of anomalous pressure gain, the well will be reclassified as Not Operable to evaluate for well repair or pursuit of an AA for Tubing x Inner Annulus communication. An updated TIO and injection plot has been included for reference. Please call with any questions or concerns. Thank you, Kevin Parks (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator GlobGVV ONED APi Wells rR Organization 0 8 20,6 Office: 907.659.5102 WIC Email:AKDCWellIntegritvCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, March 03, 2016 7:42 PM To: AK, OPS FS3 QSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations uperintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr;-AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Chou, Irwin; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C-Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; 'Regg, James B (DOA)'; Pettus, Whitney; Morrison, Spencer; Munk, Corey; Odom, Kristine --- Subject: UNDER EVALUATION: Injector 13-31A (PTD #2051600) Inner Annulus Repressurization 1 • • • Injector 13-31A(PTD#2051600) Injection Plot .111121 I.1 2. A.2 WO i r I I v t-I Injector 13-31A(PTD#2051600)TIO Plot .11 Il II 2219 N .. —•--W. , ..—. --..- ,-•—•—...- 1.2.2.1.0.....ma.am It 02.1t 12.14 02.14 O..1.116 261.30.2 2,3 211.14 21:11.2.1.11.106 0./4 02.2.MX nws maws MOM MO%111-1214 0.1.2 can.WA%W.212.1, • • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, March 03, 2016 7:42 PM To: AK, OPS FS3 OSM;AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL;AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS PCC EOC TL;AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Chou,Irwin; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA); Pettus,Whitney; Morrison, Spencer; Munk, Corey; Odom, Kristine Subject: UNDER EVALUATION:Injector 13-31A (PTD #2051600)Inner Annulus Repressurization Attachments: Injector 13-31A (PTD #2051600) TIO and Injection Plot.docx All, Injector 13-31A(PTD#2051600) is showing anomalous inner annulus pressure trends while on miscible injection. The well has been reclassified as Under Evaluation for further diagnostics and may remain online throughout this period. Plan Forward: 1. Downhole Diagnostics: Monitor Inner Annulus pressure for 10 to 14 days 2. Well Integrity Engineer: Additional diagnostics as needed A copy of the TIO and injection plot has been included for reference. Please call with any questions or concerns. Thank you, Whitney Pettus SCANNED MAR 1 5 2016 (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com 1 • • Injector 13-31A(PTD#2051600) TIO Plot March 03, 2016 • • -I r y-44 L4H16 Rh:t m. rte.184 0221,6 _. ,»,M 01,3,4 marc 0111-40111-4rt Injection Plot Wel!13 31 Z. ,1410" 1. • fXYN f].',m6 e>n>M awn ¢11.15 0.<7.,e ot, 0294!4 e.:+ .18,1* tali RECEI\/EV STATE OF ALASKA JUN 17 2015 A,_ .AKA OIL AND GAS CONSERVATION COMA ION • REPORT OF SUNDRY WELL OPERATIONS AOGCC 1 Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubin❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate E Other Stimulate ❑ Alter Casinn-7 Change Approved Program ❑ Plug for Rednll ❑ierforate New Pool ❑ Repair Well n Re-enter Susp Well n Other ❑ 2 Operator 4 Well Class Before Work 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Development ❑ Exploratory ❑ 205-160-0 3 Address P 0 Box 196612 Stratigraphic ❑ Service ❑✓ 6.API Number Anchorage,AK 99519-6612 50-029-22459-01-00 7 Property Designation(Lease Number) 8.Well Name and Number ADL0028314 PBU 13-31A 9 Logs(List logs and submit electronic and printed data per 20AAC25 071) 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 13928 feet Plugs measured None feet true vertical 9040.76 feet Junk measured None feet Effective Depth measured 13893 feet Packer measured See Attachment feet true vertical 9038 04 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"Conductor 36 2-116 2 36 2-116 2 0 0 Surface 3494 9-5/8"40#NT-80 35 59-3529 59 35 59-3245 4 5750 3090 Intermediate 12105 49 5-1/2"17#L-80 33 95-12139 44 33 95-9060 72 7740 6280 Production None None None None None None Liner 2226 57 2-3/8"4 44#L-80 11716 37-13942 94 8795 28-9041 88 9844 9979 Perforation depth Measured depth 11975-12000 feet 13233-13258 feet 13258-13283 feet 13310-13350 feet 13390-13670 feet True Vertical depth 8999 31 -9020 05 feet 8954 64-8957 03 feet 8957 03-8959 64 feet 8962 85-8967 66 feet 8972 51-9010 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9 3#L-80 33 95-11739 94 33 95-8811 9 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) SCANNED 2 015 TreatmentTreatment descriptions including volumes used and final pressure ` 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 8960 0 0 2256 Subsequent to operation 0 8978 0 0 2252 14 Attachments(required per 20 MC 25 070 25 071,8 25 283) 15 Well Class after work Daily Report of Well Operations E Exploratory❑ Development ❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16 Well Status after work Oil ❑ Gas ❑ WDSPL Li Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑✓ GINJ ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt N/A Contact Nita Summerhays Email Nita.Summerhays(U7bp corn Printed Name Nita ummerhay / Title Data Manager Signatu - /A gr��i.0..--s-,,..., i Phone 564-4035 Date 6/16/2015 YTL - -/q//5- RBDMS JUN 2 5 2015 rlr- Form 10-404 Revised 10/2012 Submit Original Only • Daily Report of Well Operations ADL0028314 PAINNOMINalaiiPINVO """*WELL INJECTING UPON ARRIVAL"***(perforating) PULLED 3 1/2"MCX FROM 2,409' MD (ser#BPX-330) DRIFTED TO DEVIATION W/10'x 1.56"DUMMY GUN, SAMPLE BAILER DOWN TO 12,060' SLM (1.64"max od) 4/22/2015 ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS"** T/I/0=2200/700/0 temp=100* Assist SL with TBG load (PERFORATING) Pumped 5 bbls meth followed by 100 bbls DSL to load for SL. SL in control of well upon departure. CVs OTG DSO/PE 4/22/2015 notified FWHP=1300/460/0 CTU#8- 1.5"Coil Job Objective:Add Perf MIRU CTU. Make up Drift BHA with 1.5"JSN. Load well with 1% KCI and RIH. FP well to 2000'with 50/50. Tag TD@13662E (231' shallow from PBTD). PUH and paint white/yellow flag at 13,500'. POOH w/drift bha. POOH. MU/RIH w/PDS memory gr/ccl to flag, 5min stop, log up 50fpm to 12,600' paint White/Blue flag 5min stop, log up 50fpm to 11,500 5min stop. POOH. +10'correction from log. Make up 1st perf gun run 25'x 1.56"PJ,6 spf. RIH and tie into flag, perforate 13250-13275'. POOH. 5/17/2015 ...Continued on WSR 5-18-15... CTU#8- 1.5"Coil***Continued from WSR 5-17-15*** Job Objective:AddPerf Complete POOH. Make up Perf gun run#2-25'x 1.56" PJ, 6 spf, RIH. Tie in at flag and perforate 13225-13250'. POOH. Make up Perf gun run#3 25'x 1.56" PJ, 6 spf, RIH. Tie in at flag and perforate 11975-12000 using 50/50 meth. POOH. RDMO 5/18/2015 ...Job Complete... FLUIDS PUMPED BBLS 5 METH 101 DIESEL 122 50/50 METH 260 1% KCL 488 TOTAL Packers and SSV's Attachment ADL0028314 SW Name Type MD TVD Depscription 13-31A PACKER 11606.78 8719.16 3-1/2" Baker SABL-3 Packer 13-31A PACKER 11712.54 8792.59 2-3/8" KB Liner Top Packer TREE= 4-1/6"CIW 5M waLHEAD= FMC S. r NOTES:H2S READINGS AVERAGE 125 ACTUATOR= BAKER C 13-31 A ppm WHEN ON MI.WELL REQUIRES A SSSV • OKB B41/T 82.3, WHEN ON MI. 'WELL ANGLE>-70 @ 12055a"" BF.ELEV= __, KOP= 1449 21' -I4-112"X 3-1/2"XO,D=2.992" Max Angle= 100°@ 12946' D®hxn MD= 11838' ( um TVD= 8800'SS ' I _ 2409' H3-1/2"I-ES X NP,D=2.813" 4-1/2"TBG,12.6#,L-80 TCI..0152 bpf,D=3.958" H 21' 9-5/8'CSG,40#,NT-80,D=8.835' -{ 3627' , I I 7998' 1 5-1/2"PARKER SWS NP MILLED ID=4.75' 'Minimum ID = 1.731" @ 11701' SEAL ASSY w/NO GO I I 8978' H 5-1/2"OTIS XN NP, MILLED ID=4.75- I I 11570' H 3-1/2"HES X NP,D=2.813" PRORATION SUMMARY b 11591' H BKR K81+22 ANCHOR SEAL ASSY,D=2.98' REF LOG:MWD ON 04/14/94 x 11592' H5-1/2"X 3-1/2"BKR SABL-3 PKR,D=2.78" ANGLE AT TOP PERF:29°@ 11975' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE I I 11617' 1-3-1/2"I C X NP,D=2.75" 1.56" 6 11975-12000 0 05/18/15 1.56" 6 13233-13258 0 05/18/15 1.56" 6 13258-13283 0 05/17/15 11698' -I KB LNR TOP PKR D=1.810" 1-9/16" 6 13390-13670 O 12/24/05 1-9116" 6 13390-13670 O 12/24/05L..............---- -111701' SEAL ASSY w/NOLO,D=1.731" 1 11704' -12.70"BKR DEPLOY SLV,D=2.25' 3-1/2"TBG,9.3#,L-80 TCII,.0087 bpf,D=2.992" H 11725' / \ 11725' H3-112"WLEG,C=2.992"(BMW PIPE) MILLOUT WINDOW (13-31A) 11854'-11860' TOC(12/09/05) _-1 11866' ;t�1�1�1�4�4�1�4�4�4�/ 1111111111 1111111111111111111 4.4. 11111 .1111111111 1111111111 M..1.1.1.1.1..AV PBTD ---3 12060' ; IIIV•V•11y •1111111/1/1111111111 5-1/2"CSG,17#,L-80,D=4.892" —I 12137' ••••••••••• PBTD (-- 13893' `•sim�' 2-3/8"LNR 4 7#,L-80 STL,.0039 bpf,D=1.995" 13928' DATE REV BY COMMENTS DATE REV BY COMMENTS NNTS FRIJDFDE BAY UNIT 04/17/94 ORIGINAL COMPLETION 05/26/15 JTCIJMD ADPE RFS(05/17-18-15) WELL: 13-31A 12/04/05 N4ES RWO(PRE CTD SDTRCK) PERMT No:"2051600 12/12/05 NORDIC1 CTD SIDETRACK(13-31A) AFI No: 50-029-22459-01 01/02/06 KSB/TLH DRLG DRAFT CORRECTIONS 4 SEC 14,TUN,R14E, 1579'FSL&1423'FH 02/09/11 MAC ADDED SSSV SAFETY NOTE 01/16/12 TM MAIM ADDS)H2S SAFETY NOTE EP Exploration(Alaska) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q~ - 1 ~ 0 Well History File Identifier Organizing (done) RE AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: „~..d~ IIIIIIIIIIIIIIIIIII DIGITAL DATA Diskettes, No. ^ Other, No/Type: ae=~,~~~aed iuiuuioiiuuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ !s! Project Proofing III IIIIII IIIII II III BY: Maria Date: ~ (] /s/ Scannin Pre aration x 30 = 60 + ~ =TOTAL PAGES trr/ v 9 p (Count does not include cover sheet) FF BY: Maria Date: ,~ ' ~ ~ ~~ ~ /s/ E Production Scanning Stage 1 Page Count from Scanned File: (Count does include cover sheet) Page Count Matches Number in Scanning Pre aration: f/ YES NO BY: Maria Dater ~~ O ~ /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s! Scanning is complete at this point unless rescanning is required. II I II'I II (IIII I I III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked -~ 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 `l August 10, 2012 DECEIVED Mr. Jim Regg � Alaska Oil and Gas Conservation Commission 333 West 7 Avenue A000C Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS -13 _ 1 0 Dear Mr. Regg, 13 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 13 were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as h treatments took place and meet the requirements of form 10 -404, notification that the u p q Report of Sundry Operations. if you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Alf r Mehreen Vazir BPXA, Well integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -13 Date: 10/31/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal 13 -028 1990110 50029203246000 Sealed conductor NA NA NA NA NA 13-03A 2090480 50029203250100 Sealed conductor NA NA NA NA NA 13 1780630 50029203260000 Sealed conductor NA NA NA NA NA 13 1811030 50029206260000 Sealed conductor NA NA NA NA NA 13 - 06A 1972180 50029206420100 Sealed conductor NA NA NA NA NA 13 1811290 50029206500000 Sealed conductor NA NA NA NA NA 13 - 08A 1982150 50029206670100 Sealed conductor NA NA NA NA NA 13 - 09 1811580 50029206710000 Sealed conductor NA NA NA NA NA 13-10 1811650 50029206780000 Sealed conductor NA NA NA NA NA 13 -11 1810760 50029206040000 0.0 NA 0.0 NA 11.1 10/31/2011 13 - 12 1801420 50029205380000 Sealed conductor NA NA NA NA NA 13 2030360 50029208520100 0.4 NA 0.4 NA 11.1 10/31/2011 13 1821710 50029208450000 2.0 NA 2.0 NA 13.6 10/6/2009 13 - 15 1821570 50029208310000 Sealed conductor NA NA NA NA NA 13 - 16 1821480 50029208230000 0.4 NA 0.4 NA 13.6 10/31/2011 13 1820260 50029207180000 Sealed conductor NA NA NA NA NA 13 - 18 1820350 50029207240000 Sealed conductor NA NA NA NA NA 13 - 19 1811800 50029206900000 Sealed conductor NA NA NA NA NA 13 -20 1820090 50029207050000 Sealed conductor NA NA NA NA NA 13-21 1820530 50029207890000 Sealed conductor NA NA NA NA NA , 13 - 22 1820770 50029207490000 Sealed conductor NA NA NA NA NA 13 - 23A 1820230 50029207150000 Sealed conductor NA NA NA NA NA 13 - 24A 2042430 50029207390100 Sealed conductor NA NA - NA NA NA 13 - 25 1820910 50029207610000, Sealed conductor NA NA NA NA NA , 13 1820740 50029207460000 Sealed conductor NA NA NA NA NA , 13 - 27 1961210 50029209490200 17.0 NA 17.0 NA 130.9 11/22/2009 13 -28 1830600 50029209420000 5.0 NA 5.0 NA 144.5 11/19/2009 13 - 29L1 2020690 50029209286000 Dust Cover NA NA NA NA NA , 13 - 30C 2080870 50029207680300 Sealed conductor NA NA NA NA NA ...ur '13 -31A 2051600 50029224590100 0.5 NA 0.5 NA 3.4 10/6/2009 13 2012350 50029207980100 0.0 NA 0.0 NA 10.2 10/31/2011 13 1821060 50029207730000 5.2 NA 5.2 NA 27.2 11/17/2009 13 - 34 1821360 50029208110000 0.3 - NA 0.3 NA 11.1 10/31/2011 13 - 35 1940410 50029224600000 0.9 NA 0.9 NA 5.1 11/17/2009 13 - 36 1951670 50029226130000 0.0 NA 0.0 NA 4.3 10/31/2011 13 2100820 50029234280000 3.8 NA 3.8 NA 33.2 10/31/2011 13 -98 1822070 50029208780000 1.0 NA 1.0 NA 5.1 10/6/2009 MEMORANDUM To: Jim Regg ~~~~. 4~~ ~ ~ ~ P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, March 10, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-31A PRUDHOE BAY iJNIT 13-31A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ R~ Comm Well Name: PRUDHOE BAY UNIT 13-31A Insp Num: mitCS100308154721 Rel Insp Num: API Well Number: 50-029-22459-01-00 Permit Number: 205-160-0 Inspector Name: Chuck Scheve Inspection Date: 3/8/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 13-31A~ Type Inj. jj W "I TVD 8709 / IA~ 160 2300 ~ 2300 2300 / P.T.D zo516oo TypeTest SPT Test psi z177 r OA o 0 0 0 Interval aYRTST p~ P Tubing 920 9zo 9zo 9zo Notes: -~ ~~ K ~ ,,;~~s ~~rr ~ =, L~1i ~3'..a~~: t. t..,~~, Wednesday, March 10, 2010 Page 1 of 1 DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051600 Well Name/No. PRUDHOE BAY UNIT 13-31A MD 13928 TVD 9041 REQUIRED INFORMATION Completion Date 12/25/2005 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22459-01-00 Completion Status WAGIN Current Status WAGIN UIC Y Mud Log No Samples No Directional S DATA INFORMATION Types Electric or Other Log s Run: CNL, SCMT GR, CCL, MWD, ROP, GR, BHC, Memory Induction Resi Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No ~,elg Pressure 5 Blu 1 'ED A Di sc u rectional Survey Pdf 13466 Induction/Resistivity 1 13466 Induction/Resistivity 5 Blu 1 ;~C Las 15428 See Notes ,. LIS Verification l5' jf3 / I F,Pl C Lis 15838 I LIS Verification ~ F~ C 15854 Gamma Ray ~; (~~ , ~ tl~1~ , ~ ~Jf= Well Cores/Samples Information: (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 11600 13928 Case Memory Jewerly Log & Pressure Survey. Memory CCL/GR/TEMP/PRES 07- Jan.-2006 0 0 1/17/2006 DEFINITIVE SURVEY 11860 12452 2/2/2006 INDUCTION LOG MEMORY INDUCTION RESISTIVITY GR-CCL 11860 12452 2/2!2006 INDUCTION LOG MEMORY INDUCTION RESISTIVITY GR-CCL 11802 13927 Open 9/17/2007 Feild GR, ROP w/EMF Graphics 11803 13933 Open 1/15/2008 LIS Veri, ROP, GR 11803 13933 Open 1/15/2008 LIS Veri, ROP, GR 11874 13928 Case 1/31/2008 TVD and MD for ROP, Q~ PCG in PDF, EMF and DGM graphics Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051600 Well Name/No. PRUDHOE BAY UNIT 13-31A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22459-01-00 MD 13928 TVD 9041 ADDITIONAL INFORM~ON Well Cored? Y Chips Received? ~'i-I~~ Analysis 1}T 1'~ Received? Completion Date 12/25/2005 Completion Status WAGIN Current Status WAGIN UIC Y Daily History Received? °~, / N Formation Tops V / N Comments: - _ _- -. -- -- - ---_ _ - -- - --- ------ --- .~ - - ----- Compliance Reviewed By; _ __ _ _ Date S __ ~~~~ • ~ WELL LOG TRANSMITTAL To: State of Alaska January 11, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs : 13-31A AK-MW-4094476 13-31A: Digital Log Images: 50-029-22459-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alask~.~.~518 ~.~ ~ *~° , . Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: UT~ ao5 -i~0 ~ l ~~ S~~ M ~ WELL LOG TRANSMITTAL To: State of Alaska December 19, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`~ Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 13-31A AK-MW-4094476 1 LDWG formatted CD rom with verification listing. API#: 50-029-22459-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~;~i~~ ~ 7 ~~~ Date: ~'' =~ >; =U ~' ~.~ ~ ~, _. ~„ BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: } V~CadS- i6d ~ 1s ~s3~ Date 09-14-2007 Transmittal Number:92903 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) have any questions, please contact llouglas llortch at trie Ylll: at Jb4-4y is u~C slivery Contents CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 06-06B ~ z5 yab 06-066PB1 ~ a~-~~ ~ ~ e~a~ 13-31 A - CrSCaoS -~~Oo '~ ~~a~ 14-11 APB1 rS~a '14-21A uzcaoti -r~~ ~ r5 ~~31 15-39A do(o-~6'~' ~ ibTN3a '~16-146ao(o-DO3 "csvay 'c-03B ao5- 05'~ '~ c5~3,5 C-10ASaS-t3~ •+5~l3~ J-17C c~ofS-o~s2 '~ +5`+3~ NGI-07A uieacx.-,ac, ~ tS~lc3~ r %'~ ~l~ ;' ; li /i Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 ~~3~'~,' <, Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 1.96612 Anchorage, AK 995 1 9-66 1 2 MEMORANDUM To: Jim Regg ~~„! 2),1~,~~,~ P.I. Supervisor FROM: Chuck Scheve Petroleum Iuspector State of Alaska Alaska Oil and Gas Conservation Commission DATE; Wednesday, February 22, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-31A PRUDHOE BAY UNIT 13-31A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~~ Comm Well Name: PRUDHOE BAY UNIT 13-31A Insp Num: mitCS060220064331 Rel Insp Num API Well Number Permit Number: 5 0-029-224 5 4-0 1-0 0 205-160-0 Inspector Name: Chuck Scheve Inspection Date: 2/19/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 13-31A I,Type Inj. ~ G ~ TVD ~ " a~os ~~ IA I so ~ zsoo 2soo 4 2soo ~ j p T ~ zosiboo ITypeTest 1 sPT I Test psi I ~ 177 I OA z o I o o ! o Interval ~'IIT~ p/F' P Tubing ~ zlso ~ ziso ziso ziso ~ Notes Pretest pressures observed and found stahle Wednesday, February 22, 2006 Page 1 of I • Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wull _Inh 3! ~_.. _-. ~~,:.,...~illtftl~,SIU11 A,-~Choc,e I nn nuarrin4inn N0.3677 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay n~re al c..l... rn 02!09/06 13-31A ao5- Ino 11162828 MEM JEWELRY 8 PRESSURE SURVEY 01/07/06 1 DS 18-03B ~p3 ~p 11057071 SBHP SURVEY 12/02/05 1 NK-43 / - 8 0 1 10987562 SBHP W/SPINNER PASSES 01/07/06 1 B-13A gtiy -- c5 11183463 LEAK DETECTION LOG 01/28/06 1 DS 06-22A / J, ~-per J N/A SENSA/MEM LDL .01/28/06 1 DS 11-26 / (p- 13¢- 11183462 INJECTION PROFILE 01/28/06 1 P1-09 /"q(~-. J,5 11098756 PROD PROFILE W/DEFT 8<GHOST 01/30/06 1 L5-05 / - C)(p 11058541 RST 11/11/05 1 1 Z-29 J -~~? ~ 11051081 RST 08/10/05 1 1 L5-09 j qQ - / 11090725 RST 11/11/05 1 1 15-44 /c~(_p - / /p 11194155 RST 01!15/06 1 1 C-20B O~I?/- / /4 11075913 MCNL 08/29/05 1 1 02-14A ~ Q` - ~ 17075901 MCNL 07/29/05 1 1 Z-21A ~(} 1, fO 1 11076449 RST 06/30/05 1 1 F-27A q'~p - w74"' 10928641 MCNL 09/01/05 1 1 MPH-15 Q5' ~~~ 11076486 USIT 12/15/05 1 13-31A bCj-~ (pb 11133211 SCMT 12123105 1 WGI-04 J - 11183461 USIT 01/26/06 1 WGI-04 /~4-osb 11211566 USIT 02/03106 1 WGI-08 i' QY b 10987559 USIT 01/02/06 1 WGI-08 ~r0 a ~4y 11058259 USIT 01/12/06 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~~ ~~ ~ ©(,.~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by:_~~_ ~-' ~ STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COM SION cc~~''''-- WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~G~.'~~~ FEg 1 7 2006 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned zoAAC 2s.,os `J~ ^ WINJ ^ WDSPL No. of Completions ^ Suspended WAG~~'a~f. _ 20AAC 25.110 !• One Other ~ ~ ~ ib• W~~$~j' & C ^ Development xp~~dtr~ ^ Stratigraphic ~~ 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 12/25/2005 12. Permit to Drill Number 205-160 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 12/10/2005 i 3. API Number 50-029-22459-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 12/14/2005 14. Well Name and Number: PBU 13-31A 1579 FSL, 1423 FEL, SEC. 14, T10N, R14E, UM Top of Productive Horizon: 298' FSL, 3181' FEL, SEC. 15, T10N, R14E, UM g• KB Elevation (ft): 82.3' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pooi Total Depth: 1351' FSL, 1788' FEL, SEC. 15, T10N, R14E, UM 9. Plug Back Depth (MD+ND) 13893 + 9038 Ft 4b. Location of Well (State Base Plane Coordinates): 685803 5931612 Zone- ASP4 Surface: x- y- 10. Total Depth (MD+ND) 13928 + 9041 Ft 16. Property Designation: ADL 028314 _ _ __ TPI: x-_678800 y- 5930161 Zone- ASP4 Total Depth: x- 680166 Y- 5931247 Zone- ASP4 11 • Depth where SSSV set None MD 17. Land Use Permit: ------------ ----------- ------ ---- ------~--- f h ff f Thi f P k t 20 18. Directional Survey ®Yes ^ No ore 19. Water depth, i o s N/A MSL erma ros c ness o . 1900' (Approx.) 21. Logs Run: CNL , SCMT GR , CCL , MWD , ROP , GR , BHC ,Memory Induction Resistivity GR 2. CASING, LINER AND CEMENTING RECORD CASING ETTING EPTH MD ETTING EPTH ND HOLE- OUNT $IZE WT. PER FT. GRADE OP TTOM OP TTOM $IZE CEMENTING RECORD PULLED 20" 91.5# H-40 32' 112' 32' 112' 30" 60 sx Arctic Set A rox. 9-5/8" 47# L-80 33' 3527 33' 3244' 12-1 /4" sz cs ul, sus sx ~r;•, 2so sz cs n 5-1/2" 17# L-80 32' 11854' 32' 8894' 8-1/2" 21 sxClass'G' 2-3/8" 4.6# L-80 11698' 13928' 8782' 9041' 3" 131 sx Class 'G' 23. Perforations open to Produc tion (MD + N D of Top and " " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 1.56" Gun Diameter, 6 SPF 3-1/2", 9.3#, L-80 TCII 11725' 11592' MD ND MD TVD f 33 f 0' - f 3350' 8963' - 8968' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13390' - 13670' 8973' - 9010' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 2874' Freeze Protected with 25 Bbls Diesel 26• PRODUCTION TEST Date First Production: February 8, 2006 Method of Operation (Flowing, Gas Lift, etc.): Gas Injection Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE $IZE GAS-OIL RATIO Flow Tubing PreSS. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". i ,. ~~ ~~ ~~.n. o~ None t a, ~~ ~ , -.~~~ i~~si-~j'~'8'~2- T~,~ f.~~-~C'c+a+- ~ ~ y _/L~Lt:~ ~. _.... ilOfl .w~;j Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE i 28. GEOLOGIC MARKER 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 11830' 8876' None Shublik 11860' 8898' Sadlerochit /Zone 46 11946' 8890' 45N 11970' 8995' Top of Sadlerochit 13015' 8952' Zone 46 / 46P 13090' 8946' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondraa Stewman ~ Title Technical Assistant Date ~ ~~~7~0 PBU 13-31 A 205-160 Prepared ey Name/Number.~ Sondra Stewman, 564-4750 Well Number Permit No. / A royal No. Drilling Engineer: Barbara Holt, 564-5126 INSTRUCTIONS GEWERAL: 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Page 1 of 17 Operations Summary Report Legal Well Name: 13-31 Common Well Name: 13-31 Spud Date: 4/2/1994 Event Name: REENTER+COMPLETE Start: 11/18/2005 End: 12/25/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/6/2005 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours ~, Task 'Code NPT Phase Description of Operations 12/8/2005 00:00 -04:30 4.50 RIGU N WAIT PRE Wait on completion of wireline work. Ran 2.72" by 8' long drift to 11,869'. Drifted thru tailpipe with 2.733" drift. 04:30 - 05:00 0.50 RIGU P PRE PJSM and move rig over well. 05:00 - 07:45 2.75 BOPSU P PRE ACCEPT RIG AT 0500 HRS. 12/08/05. NU BOP. Continue installation of traction motor on injector power pack. 07:45 - 08:00 0.25 RIGU P PRE PJSM for coil swap. 08:00 - 12:00 4.00 RIGU P PRE Swap reel and complete installation of traction motor on injector power pack. 12:00 - 20:30 8.50 BOPSU P PRE Test BOPE. Witnessing of BOP test waived by Jeff Jones AOGCC. 20:30 - 00:00 3.50 RIGU P PRE Pull coil to injector head and stab coil. M/U coil packoff. Weld on 2" CTC. Pull test CTC with 45K. Prep to pump 5 bbls MEOH ahead of KCL water. 12/9/2005 00:00 - 01:30 1.50 RIGU P PRE Fill coil with 5 bbl MEOH and 40 bbl KCL water. Pump dart. Dart landed at 40.3 bbls. Press test inner reel valve. 01:30 - 01:45 0.25 WHIP P WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for M/U BOT whipstock and Sperry BHA. 01:45 - 02:50 1.08 WHIP P WEXIT M/U BHA #1, BOT 3-1/2 x 5-1/2" Whipstock, Setting tool, FAIV, Sperry MW D, orienter and BOT MHA. BHA OAL = 73.9'. 02:50 - 05:30 2.67 WHIP P WEXIT RIH with Whipstock BHA. Circ KCL water at 0.3 bpm. Take returns to tiger tank. Check orienter at 2700', OK, RIH at 90 fpm. RIH clean thru packer and nipples. 05:30 - 06:00 0.50 WHIP P WEXIT Log GR tie-in with CMT/GR of 05/02/94. Log up. Added 5' to CTD. 06:00 - 06:40 0.67 WHIP P WEXIT RIH with whipstock. Up wt = 38K, Dwn wt = 19K. Tag PBTD at 11,866'. Pick up 2 ft off bottom to 11,864'. Whipstock TF at 155R. Increase rate to 1.9 bpm, 3700 psi, Hold rate for 4 minutes. Stop pump for 4 minutes. Pump 0.2 bpm, increasing press, setting tool sheared at 1800 psi, circ at 1 bpm, Whipstock top set at 11,851' BKB. TF at 160L. 06:40 - 08:30 1.83 WHIP P WEXIT POH. 08:30 - 10:15 1.75 WHIP P WEXIT LD WS setting tool and PU window milling assy. 10:15 - 12:30 2.25 WHIP P WEXIT RIH. Swapping to 2# bio. Up wt 38K, DN wt 17K, Tag and correct 11853.8. Pinch point 2.8 below Top of WS. 12:30 - 18:00 5.50 STWHIP P WEXIT Mill window, 1.54/1.57 bpm @ 2150 psi 1900 psi FS. Mill to 11857 start losing returns as high as .5 bpm. 15-20 bph. 18:00 - 20:00 2.00 STWHIP P WEXIT Mill window, 1.6/1.2 bpm, 2000/2080 psi, 1 fph, Still losing .4 bpm. Time Milled to 11,859'. 20:00 - 23:00 3.00 STWHIP P WEXIT Mill window, 1.6/1.2 bpm, 2000/2080 psi, 1 fph, Still losing .4 bpm. Stalled 2 times at 11860' at bottom of window. Ream window. Clean window. Time mill at 1 fph to 11862'. Window at 11854-11860'. 23:00 - 00:00 1.00 STWHIP P WEXIT Mill formation, 10 fph, 1.6! 1.2 bpm, 2130 psi, 1 K WOB, Swap well over to rebuilt FloPro system while milling formation. Have 1 bpm fluid loss with used FloPro at window. Did not heal up. 12/10/2005 00:00 - 01:00 1.00 STWHIP P WEXIT Ream window area 4 times up and down while circ well to used FloPro. Printed: 12/27/2005 8:36:13 AM BP EXPLORATION Page 2 of 17 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ~ Name: 1 ell Name: 1 e: Name: From - To 3-31 3-31 REENTE NABOR NABOR Hours i R+COM S ALASK S 4ES Task PLET A DRI Code E LLING NPTI Start I Rig Rig Phase Spud Date: 4/2/1994 : 11/18/2005 End: 12/25/2005 Release: 12/6/2005 Number: 4ES Description of Operations 12/10/2005 00:00 - 01:00 1.00 STWHIP P WEXIT Fluid loss of 1 bpm with FloPro at window. 1.6 / 0.6 bpm. Stop pump and went thru window OK. Window is clean. Flag coil at 11,700' EOP. 01:00 - 03:00 2.00 STWHIP P WEXIT POH with 2.74" wiindow milling BHA. 03:00 - 03:30 0.50 STW HIP P WEXIT L/O milling BHA. Mills drifted at 2.74 / 2.73 go / no-go. 03:30 - 04:00 0.50 DRILL P PROD1 PRE-SPUD MEETING, Reviewed well plan, hazards and mitigation with crew. 04:00 - 06:45 2.75 DRILL P PROD1 M/U build BHA#3 with 2.8 deg extreme motor and re-build HC bi-center bit. OAL = 60.2'. 06:45 - 09:00 2.25 DRILL P PROD1 RIH .Tie in to flag No correction. RIH to 11834 attempt to orientate. 1.71 /.2 bpm 3200 psi FS. 09:00 - 09:40 0.67 DRILL N DFAL PROD1 Attempt to orient. Pulser failure. POH. 09:40 - 11:30 1.83 DRILL N DFAL PROD1 POH for MW D pulser failure. POH to 6618. 'Lost one pump assignment incorrect i.e so second pump not accessible. Change assignments. Continue to POH. 11:30 - 12:30 1.00 DRILL N DFAL PROD1 Change out MWD pulser. 12:30 - 14:30 2.00 DRILL N DFAL PROD1 RIH. Shallow hole test orienter OK. Continue to RIH. 14:30 - 15:00 0.50 DRILL P PROD1 Orient 145R. 15:00 - 19:30 4.50 DRILL P PROD1 Directionally drill 1.71/.66 bpm at 3330 psi FS = 3230 psi. Loss rate gradually diminishing to .6 bpm after 18 ft of new hole. Then losses increased back to 1.2 bpm. Slow drilling in shale. 10-15 fph. 19:30 - 21:00 1.50 DRILL P PROD1 Drilling build section with 1.1 bpm fluid loss. 1.7 / 0.5 bpm, 3150 psi, 5K WOB, 10-15 FPH. Drilled to 11931'. 21:00 - 22:30 1.50 DRILL P PROD1 Drilling build section with 1.0 bpm fluid loss. 1.7 / 0.7 bpm, 3250 psi, 5K WOB, 10-15 FPH. Drilled to 11950' 22:30 - 23:30 1.00 DRILL P PROD1 Orient around to 80R. Had to pull up above window to get clicks. 23:30 - 00:00 0.50 DRILL P PROD1 Drilling build section with 0.9 bpm fluid loss. 1.6 / 0.7 bpm, 3250 psi, 5K WOB, 10-15 FPH. Drilled to 11955'. 12/11/2005 00:00 - 01:30 1.50 DRILL P PROD1 Drilled build section in Zone 4. Had 0.9 bpm losses to 11,994'. Lost full returns at 11,994'. Drilling indicated a fault at this depth, stalled motor and GR spike. Drill ahead with 1.7 / 0.1 bpm, 60 deg incl. Drilled to 12050'. 01:30 - 02:15 0.75 DRILL P PROD1 Wiper trip to window. Clean trip. RIH clean. No overpulls or weight loss due to cuttings. 02:15 - 03:30 1.25 DRILL P PROD1 Drilled build section in Zone 4. Full losses. 1.6 bpm, 3100 psi, 2 K WOB, End build section at 12,100'. Estimate 90 deg incl at bit. 03:30 - 04:00 0.50 DRILL P PROD1 Log up to window at 10 fpm. No returns. Clean hole up to window. Log GR tie-in at window. 04:00 - 06:00 2.00 DRILL P PROD1 POH for lateral BHA. 06:00 - 08:00 2.00 DRILL P PROD1 Dial down motor to .9 degree. Swap bits. 08:00 - 10:00 2.00 DRILL P PROD1 RIH 11895 to log up to tie in. 10:00 - 10:30 0.50 DRILL P PROD1 Tie -in zero correction.. 10:30 - 10:40 0.17 DRILL P PROD1 RIH and tag TD at 12103' 10:40 - 11:10 0.50 DRILL P PROD1 Orient to 6R 11:10 - 14:10 3.00 DRILL P PROD1 Directionally drill 1.77 / .06 bpm at 2911 psi ,FS = 2700 psi. Drilled to 12250'. 14:10 - 14:30 0.33 DRILL P PROD1 Wiper to window. Clean trip. No over pulls or packoff's. 14:30 - 16:45 2.25 DRILL P PROD1 Directionally drill 1.85 / .11 bpm at 3200 psi ,FS = 3000 psi. WOB 2-3K,ROP 100+. Printed: 12/27/2005 8:36:13 AM BP EXPLORATION Operations Summary Report Page 3 of 17 Legal Well Common W Event Nam Contractor Rig Name: Date ~ Name: 1 ell Name: 1 e: Name: From - To 3-31 3-31 REENTE NABOB NABOB Hours R+COM S ALASK S 4ES Task PLET A DRI Code E LLING NPT Start I Rig Rig Phase Spud Date: 4/2/1994 : 11/18/2005 End: 12/25/2005 Release: 12/6/2005 Number: 4ES Description of Operations 12/11/2005 16:45 - 17:45 1.00 DRILL N WAIT PROD1 Wiper to window while waiting on mud. 17:45 - 18:00 0.25 DRILL P PRODi RIH 18:00 - 20:45 2.75 DRILL P PRODi Directionally drill 1.5810 bpm at 2600 psi WOB 2-3K, ROP 90, 97 deg incl. Drilled to 12,470'. Motor or bit partially plugged, free spin went from 2700 to 3130 psi, unable to drill, stack wt with no drill off and very little motor work. Checked rig suction screen and found screen had parted, letting paint chips from rig pits & scale from vacuum truck go down coil. Rig pits were painted this summer and we have had a lot of paint chips in the suction screens. The failed suctin screen still had 1/2 cup of paint chips in it. Surge pumps and wiper trip. Free spin fell back to 2400 psi. RIH and try to drill again. Not able to Drill. Stack wt with little motor work. 20:45 - 22:45 2.00 DRILL N DFAL PROD1 POH, pump 1.6 / 0.3 bpm. Partial returns. Best returns for day, the paint chip LCM must have helped 22:45 - 00:00 1.25 DRILL N DFAL PROD1 Inspect BHA. Bit had 2 plugged ports, orienter had plugged bleed port and possible debris inside. C/O motor, orienter, MWD probe and BOT MHA. 12/12/2005 00:00 - 00:30 0.50 DRILL N DFAL PROD1 M!U LAT BHA #6 with 0.95 motor and HC 8i-center Bit. OAL = 60.15'. 00:30 - 02:30 2.00 DRILL N DFAL PROD1 RIH with Lateral BHA #6. 02:30 - 03:15 0.75 DRILL N DFAL PROD1 Log GR tie-in at window. Add 3 ft CTD. 03:15 -04:00 0.75 DRILL N DFAL PROD1 RIH, stack wt in shale at 12290', ream shale, getting 0.5 bpm returns. RIH and tag bottom at 12,470'. 04:00 - 07:30 3.50 DRILL P PROD1 Drill lateral in Zone 4. 1.7 / 0.6 bpm, 2600 psi, 7K WOB, Drilling with KCL water with FloPro sweeps as needed. Drilled to 12,530'. 07:30 - 08:45 1.25 DRILL P PRODi Wiper to tail pipe Sweep 5". Sweep didnt bring much back but it temporarily carsed the return rate to increase as high as 1.5 bpm maybe plugging off below us. Went down thru 5" slow hoping to wash cuttings below to loss zone. Decided to close in well and drill with 2% KCL without returns. 08:45 - 14:00 5.25 DRILL P PROD1 Shut in WH pressure 400-500 psi. @ 1.65 bpm drill without returns having trouble sliding due to stacking. Tried 20 bbl Flo Pro pill No improvement. Gamma show it as shale. Drilling shale at 1.67/0 bpm C~3 2400 psi. Well head 280 psi. 30 fUhr.Drilled to 12690 out of shales. 14:00 - 16:00 2.00 DRILL P PROD1 Wiper to window. On trip in set down 12270. Orient 135R set down 12277. Wait for pop thru No Go. After several attempts at min rate. Attempted at drilling rate. Got Lucky. Continue to RIH 12545 set down. 12535. 12525 Cirlate at 1.7 bpm. PU to 12510. RIH 60 ft/min to 12557 set down. Circulate at 1.7 bpm. RIH to 12578 set down. PU Losing ground to 12537. Not seeing any motor work. PU Work to 12584 after numerous attempts. RIH to 12602 set down. Losing ground. Acting like we are chasing somthiing up and down. Clay Ball?? Work back to 12604. Loss ground to 12586. No motor work. Decide to POH. 16:00 - 18:00 2.00 DRILL P PROD1 POH. Lay mud in open hole. Printed: 12(27/2005 8:36:13 AM BP EXPLORATION Page 4 of 17 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To 3-31 3-31 REENTE NABOB NABOB Hours R+COM S ALASK S 4ES Task ' PLET A DRI Code E LLING NPT I Start I Rig Rig Phase ! Spud Date: 4/2/1994 : 11/18!2005 End: 12/25/2005 Release: 12/6/2005 Number: 4ES Description of Operations 12/12/2005 18:00 - 20:15 2.25 DRILL P PROD1 _ -- - - C/O motor and MWD probe. Check bit, orienter and MHA. Press test coil and MHA. No obvious problem with BHA. Adjust motor to 1.0 deg. M/U HC Bi-center bit #5. OAL = 60.14'. 20:15 - 22:45 2.50 DRILL P PROD1 RIH with Lateral BHA #7 with 1.0 deg motor and HC Bi-center bit #5. SHT tools at 1500'. OK. RIH with choke closed to push cuttings to fault. Pump 0.15 bpm. SIWHP = 30 psi. Wash down inside 5-1/2" casing at 1.7 bpm with KCL water, Ran thru window Clean. 22:45 - 23:15 0.50 DRILL P PROD1 Log GR tie-in. add 1 ft to CTD. Orient TF to 40R 23:15 - 00:00 0.75 DRILL P PROD1 RIH, pump 1.6 bpm, 350 SIWHP, RIH clean past 12300' and 12550'. RIH clean and set down at 12675'. Pump FloPro w/ 3% LT and ream down. Pipe would not slide, W HP up to 620 psi, so open well slow. Ream down, motor work at 12665'. Drill ahead at 82L, 1.7 / 0.7 bpm, 12/13/2005 00:00 - 01:10 1.17 DRILL P PROD1 Ream thru shale at 12670'. RIH to bottom. 01:10 - 02:00 0.83 DRILL P PROD1 Drill Zone 4 lateral, Try to drill with well shut in. Coil would not slide with well shut in, even with new FloPro with 3% LT. Open well slow and drill ahead with 0.2 bpm returns. 1.7 / 0.2 bpm, 2100 psi, 90L TF, 98 deg incl, Drilled to 12767' 02:00 - 03:30 1.50 DRILL P PROD1 Drill Z4 Lateral, drilling with FloPro, not able to drill ahead with KCL water. 1.7 / 0.2 bpm, 2100 psi, 95L, Drilled to 12857'. 03:30 - 04:30 1.00 DRILL P PROD1 Wiper trip to window. Switch to KCL water during wiper trip. Over pull in shales at 12,670, 12,300', pull to 11,870'. RIH clean to 12474', stack wt and fell thru. RIH to 12857'. 04:30 - 05:30 1.00 DRILL P PROD1 Drill Z4 Lateral, switch back FloPro, stacking weight with slick KCL water, coil does not want to slide with KCL water. Drilled to 12,918'. 05:30 - 05:45 0.25 DRILL P PROD1 Orient TF to right side. 05:45 - 07:00 1.25 DRILL P PROD1 Drill Z4 Lateral with FloPro, 1.7 / 0.4 bpm, 0.4 bpm returns. 3200 pp, 81 R, Drilled to 13010'. 07:00 - 09:30 2.50 DRILL P PROD1 Wiper to tailpipe. Over pull 12470. Wash thru 5' twice lost all returns. RIH without returns pumping Flo Pro. Set down 12465, Orient 90R. Set down NO Go. Orient 126R Set down 12473 pop thru. RIH 12745 pop thru. Continue to RIH and tag 09:30 - 12:30 3.00 DRILL P PROD1 Orient to 126R. Directionally drill 1.7/.04 bpm at 3600 psi. FS = 3200 psi Up Wt 34K,Dn Wt 13K, ROP 60-100. Drilled to 13120'. 12:30 - 14:15 1.75 DRILL P PROD1 Wiper trip to tailpipe, clean hole. Wash 5-1/2" casing from 1 1 725-1 1 840', no returns. RIH clean to bottom. 14:15 - 15:10 0.92 DRILL P PROD1 Drill Z4 Lateral with FloPro, no returns, well on strong vac after losses at 0800 hrs, during wiper trip, [had drilled to 13,010' before wiper j, 1.7 / 0.0 bpm, 2200 pp, 130R. Drilled to 13202'. 15:10 - 19:30 4.33 DRILL P PROD1 Orient TF to 110R. - Orienting taking patience due to loss of returns. Getting clicks by pumping down the backside, taking care not to overshoot desired toolface. Targeting 84 deg inclination to TD. Printed: 12/27/2005 8:36:13 AM BP EXPLORATION Page 5 of 17 Operations Summary Report Legal Well Name: 13-31 Common Well Name: 13-31 Spud Date: 4/2/1994 Event Name: REENTER+COMPLETE Start: 11/18/2005 End: 12/25/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/6/2005 Rig Name: NABOBS 4ES Rig Number: 4ES Hours Task ~, Code ~ NPT Phase Date ~ From - To _- i 12/13/2005 19:30 - 21:30 2.00 DRILL P PROD1 21:30 - 23:30 2.00 DRILL P PROD1 23:30 - 00:00 I 0.501 DRILL I P 12/14/2005 100:00 - 02:00 I 2.001 DRILL I P PROD1 PROD1 02:00 - 02:45 I 0.751 DRILL I P I I PROD1 02:45 - 03:30 0.75 DRILL P PRODi 03:30 - 04:15 0.75 DRILL P PROD1 04:15 - 05:00 0.75 DRILL P PROD1 05:00 - 05:45 0.75 DRILL P PROD1 05:45 - 06:25 0.67 DRILL P PROD1 Description of Operations Drill ahead in zone 4 with flo pro to 13,294' MD. Ratty drilling to start. - 100% losses, well open. - Pumping 1.7 / 0.0 bpm - 2000 psi free spin. - 2200 -2400 psi on bottom drilling. - ROP 100 - 200 fph. - 14k CT weight. - BHA wiper trips as needed. - Drilling at 120 - 130 deg ROHS Wiper trip to window. - Circulating flo pro, hole conditions improved while maintaining flo pro in hole. Fighting BHA to bottom while using KCI. Minor set down at 12,460', 12,966' MD while pumping flo pro. Drili ahead in zone 4 with flo pro to 13,325' MD. - 100% losses, well open. - Pumping 1.7 / 0.0 bpm - 2000 psi free spin. - 2200 -2400 psi on bottom drilling. - ROP 120 fph. - 12k CT weight. - BHA wiper trips as needed. - Drilling at 120 - 130 deg ROHS Drill ahead in zone 4 with flo pro to 13,460' MD. - 100% losses, well open. - Pumping 1.7 / 0.0 bpm - 2000 psi free spin. - 2200 -2400 psi on bottom drilling. - ROP 70-120 fph. - 15-12k CT weight. - BHA wiper trips as needed. - Drilling at 120 - 130 deg ROHS Wiper trip to window. - Pumping flo pro. Tie in to GR. Correct +24'. Continue wiper trip to bottom. Drill ahead in zone 4 with flo pro to 13,550' MD. - 100% losses, well open. - Pumping 1.7 / 0.0 bpm - 2000 psi free spin. - 2200 -2400 psi on bottom drilling. - ROP 70-120 fph. - 15-12k CT weight. - BHA wiper trips as needed. - Drilling at 120 - 130 deg ROHS Orient TF to 100 LOHS. Drill ahead in zone 4 with flo pro. - 100% losses, well open. - Pumping 1.7 / 0.0 bpm - 2000 psi free spin. - 2200 -2400 psi on bottom drilling. - ROP 70-120 fph. Printed: 12/27/2005 8:36:13 AM BP EXPLORATION Operations Summary Report Page 6 of 17 Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To 3-31 3-31 REENTE NABOB NABOB I Hours R+COM S ALASK S 4ES Task PLET A DRI Code i E LLING NPT ~ Start I Rig Rig Phase Spud Date: 4/2/1994 : 11/18/2005 End: 12/25/2005 Release: 12/6/2005 Number: 4ES Description of Operations 12/14/2005 05:45 - 06:25 0.67 DRILL P PROD1 - 15-12k CT weight. - BHA wiper trips as needed. - Drilling at 120 - 130 deg ROHS 06:25 - 06:35 0.17 DRILL P PROD1 Orient TF 2 clicks, hole angle at 80 deg, need to be at 83 deg 06:35 - 06:52 0.28 DRILL P PROD1 Drilling Zone IV lateral Op = 1.68 / 0.00 bpm, no returns since 13,120 ft, lost 800 psi CTP CT wt = Hole angle dropped to 80 deg using 90L TF ROP = 125 fph, drilling in good sand 06:52 - 09:30 2.63 DRILL P PRODi Wiper trip at 13,650 ft Pulled tight at 13,347 ft worked through orientation problem Pulled tight at 13,325 ft worked through Pulled tight at 12,512 ft worked through. Worst area on trip out RIH at 20 to 25 fpm Set down at 12,520 ft PU and fell through. RIH (orientation) 09:30 - 09:35 0.08 DRILL P PRODi Drilling Zone IV Lateral at 122E TF Qp = 1.74 / 0 bpm. no circulation. WOB = 4k ROP = 130 to 140 fph 09:35 - 09:38 0.05 DRILL P PROD1 Orient TF to level out at 83 deg 09:38 - 10:48 1.17 DRILL P PRODi Drilling Zone IV Lateral at 82L to 20L TF. TF is rolling up Op = 1.74 / 0 bpm. no circulation. WOB = 4k ROP = 130 to 150 fph 10:48 - 11:15 0.45 DRILL P PRODi Orienf TF around to 120E from 20L 11:15 - 12:00 0.75 DRILL P PROD1 Drilling Zone IV Lateral at 110E TF. Op = 1.74 / 0 bpm. no circulation. WOB = 4k ROP = 140 to 160 fph 12:00 - 15:35 3.58 DRILL P PROD1 Wiper trip to WS Pulled tight at 13,357 ft pulled through at 5 fpm 13,306 ft with motor work 13,288 ft with some motor work 12,548 ft, no motor work 12,512 ft, (ratty) pulled up to 56k clean above 12,466 ft. Clean above 12,466 ft to 11,900 ft. RIH, reduced Qp to 0.4 bpm at 12,473 ft RIH Tagged at 13,685 ft. Finally pushed through, Tagged C~ 13,730 ft. Worked down to 13,800 ft. Wiper back 70 ft. Still have trouble getting back on bottom. Tagged at 13,800 ft 15:35 - 16:00 0.42 DRILL P PROD1 Drilling Zone IV Lateral at 99L TF. Op = 1.79 / 0 bpm. No circulation. WOB = 3-4k ROP = 15 to 160 fph. Hole angle still dropping, need to land at 8960 ft TVD aat approximately 13,923 ft MD 16:00 - 16:15 0.25 DRILL P PROD1 Orient TF up to level at to land at 8,960 ft TVD 16:15 - 17:00 0.75 DRILL P PROD1 Drilling Zone IV Lateral at 48L to 82L TF. Op = 1.79 / 0 bpm. No circulation. WOB = 3-4k ROP = 15 to 160 fph. ROP increased at 13,850 ft to f 88 fph Printed: 12/27/2005 8:36:13 AM BP EXPLORATION Operations Summary Report Legal Well Name: 13-31 Common Well Name: 13-31 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 4ES Date I From - To Hours ~ Task Code ~ NPT '~~ 12/14/2005 17:00 - 17:15 0.25 DRILL P 17:15 - 18:45 1.50 DRILL P 18:45 - 19:30 0.75 DRILL P 19:30 - 21:00 1.50 DRILL P 21:00 - 22:30 1.50 DRILL P 22:30 - 00:00 1.50 DRILL P 12!15/2005 00:00 - 00:30 0.50 DRILL P 00:30 - 01:30 1.00 DRILL P 01:30 - 02:00 0.50 BOPSU P 02:00 - 03:00 1.00 EVAL P 03:00 - 05:00 2.00 EVAL P 05:00 - 05:30 0.50 EVAL P 05:30 - 06:00 0.50 EVAL P 06:00 - 07:37 1.62 EVAL P 07:37 - 08:30 0.88 EVAL P 08:30 - 10:45 2.25 CLEAN P 10:45 - 14:28 3.72 CLEAN P 14:28 - 14:47 14:47 - 18:30 18:30 - 20:00 0.321 CLEAN I P 3.72 CLEAN P 1.50 CLEAN P Page 7 of 17 Spud Date: 4!2!1994 Start: 11 /18/2005 End: 12/25/2005 I Rig Release: 12/6/2005 Rig Number: 4ES Phase Description of Operations PRODi PUH need to orient TF around and due to hole conditions, re-surveyed at 13,919 ft Projected 8,958 ft TVD at a MD of 13,919 ft PROD1 Wiper trip to tie-in PROD1 Tie in. Correct +10.5'. PROD1 RBIH. Confirm TD at 13,928' MD - SO 20k, PU 38k. Pumping at 0.5 bpm. - Stack up and ream at 12,640' , 12,875' MD, 13,850' MD. - Minor stacking at 12,680', 13,120', 13,387', 13,840' MD. PROD1 POOH for logging run - PUH paint flag at 13,808' EOP for logging run. - A few overpulls, no motor work on POOH. PROD1 Cont. POOH to surface. - Paint flag at 11,650' EOP (liner at TD) and 9600' (liner above window), in case logs are not run. PROD1 POOH to surface. PROD1 LD BHA - Close well. Zero pressure. - Open well to LD BHA. - Rig up to circulate through the coil and across the top, simultaneously. - Discovered a small (1/2") piece of rubber in one of the bit nozzles. PROD1 Function test rams. PROD1 PU logging tools for OH resistivity, GR, CCL. - OAL 26.6' - Install encoder. PROD1 RIH with logging assy in cased hole. - RIH 100 fpm, 0.66 bpm. - Repair pump #2 packing. PROD1 RIH to openhole, logging at 60 fpm. - Stack up at 12,060' MD (4k) while RIH at 60 fpm. - Slow to 30fpm. RIH. Stack up (4k) at 12,468' MD. Attempted to pass through, no go. - Decide to POOH with logging assy. PROD1 POH with logging assembly, logging at 40 fpm. PRODi POH to surface. PROD1 OOH, pump fluid while RU to LD BHA and PDS tools. Conveyed with town on way forward. Will RU to run IBP and 100 ft of 2-3/8" tubing to isolated the lower sand. BOT will take 3 hrs to make IBP well ready PRODi RU to RIH for cleanout run conducted JSA. PU Sperry's BHA w/ 1 deg motor PROD1 RIH with cleanout BHA Corrected to 11,650 EOP flag (-2 ft) Tagged btm of WS at 11,861 ft RIH and tagged at 12,476 ft went through Tagged at 12,685 ft and went through. Tagged at 13,690 ft and W/R through. PROD1 Tagged bottom at 13928 ft, Tested Sperry's dual equalizing subs above and below orienter PROD1 POOH, painted EOP 13639 ft and 11600 ft PROD1 OOH. PJSM. SIB injector. UD cleanout BHA. Inspect weld-on Printed: 12/27/2005 8:36:13 AM BP EXPLORATION Operations Summary Report Page 8 of 17 Legal Well Name: 13-31 Common Well Name: 13-31 Spud Date: 4/2/1994 Event Name: REENTER+COMPLETE Start: 11/18/2005 End: 12/25/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/6/2005 Rig Name: NABORS 4ES Rig Number: 4ES Date !From - To Hours ,I Task '~, Code ~ NPT 12/15/2005 18:30 - 20:00 1.50 CLEAN P 20:00 - 20:15 0.25 LCR P 20:15 - 21:15 I 1.001 LCR I P 21:15 - 00:00 I 2.751 LCR I P 12/16/2005 ~ 00:00 - 01:15 ~ 1.25 ~ LCR N 01:15 - 04:00 I 2.751 LCR I N 04:00 - 04:45 I 0.751 LCR I N 04:45 - 06:35 I 1.831 CLEAN I N 06:35 - 07:00 0.42 CLEAN N 07:00 - 07:15 0.25 CLEAN N 07:15 - 08:15 1.00 CLEAN N 08:15 - 10:30 I 2.251 CLEAN I N 10:30 - 10:55 0.42 CLEAN N 10:55 - 11:15 0.33 CLEAN N Phase Description of Operations PRODi CTC - OK. Line-up & pump via CT to kill-line to keep hole full. PROD1 Held PJSM for M/U &RIH Baker Inflatable bridge plug BHA#10. PROD1 M/U BHA#10 with guide shoe, 3jts of 2-3/8" Lnr, Baker Retrievable bridge plug (pinned with 6 steel set screws), R/tools, 2 pup jts of 1-1/4" CSH &MHA. M/U injector. PRODi RIH with BHA#10 pumping down the CT @ 0.20bpm/100psi & down the backside C~ 0.20bpm. Correct CTD by -4.7' C~3 1st flag. Correct CTD by +2.93' C~J 2nd flag. Wt check - Up = 38k, Run-in = 21 k. RIH smoothly C~3 20fpm thru window. Set down C~3 12470' & 12876'. P/U clean @ 40k & run thru. DPRB ~ PROD1 Continue RIH smoothly in OH C~ 30fpm. Set down C~3 13137' P/U & not able to run thru tight spot. Attempt to wash down 1.23bpm/420psi - no luck. RIH fast @ 100fpm & set down 13139'. Set down on tool & wash for 15mins C~ 1.1bpm/355psi. Work pipe with max 10k set down & 2k O/Pull to 13141'. Making no further progress. Decide to POOH. DPRB PROD1 POOH BKR IBP BHA#10. EOP flags C~3 11600' & 9600'. Review forward plan with ANC & decide to make another cleanout run. DPRB PROD1 OOH. PJSM. S/B injector. UD & inspect BKR IBP BHA#10. Did not observe any tell-tales on BHA components. Line-up & pump via CT to kill-line to keep hole full. DPRB PROD1 M/U cleanout BHA #11 with ldeg X-treme motor, MWD/GR, 2 orienter with 2 equalizer subs, & used Hycalog 2.7" x 3" DS100 bicenter bit #7. Scribe tools & M/U injector. DPRB PRODi Set counter at 69.1 ft, RIH DPRB PRODi POOH from 1,500 ft to check and confirm MHA to BHA torque DPRB PRODi Checked Torque, OK, re-broke and checked all connect below MHA to orienter DPRB PRODi RIH (all tools were properly torqued) Shallow hole test at 2,581 ft. No clicks RIH to 5,000 ft unable to orient TF DPRB PROD1 RIH through open hole section DPRB PROD1 W/R open hole Small bobble at 12,670 ft. Drilled TF at 60L TF, on FCO at 90R W/R 12,685 to 12,660 ft. w/ 180 deg out TF 11:15 - 11:30 0.25 CLEAN N DPRB PROD1 W/R to bottom 11:30 - 12:46 1.27 CLEAN N DPRB PROD1 Set down at 12,871 ft Tried to orient TF to 97L to work through area. Dual orienters /equalizing valves working sometimes. RIH and tagged again at 12,871 ft Having trouble getting thro at any TF. Orient TF to HS to try and get past. Tried several TF and unable to pass 12,871 ft CTP increased 600 psi. Orient TF to 90L and try to find old hole. 12:46 - 13:08 0.37 CLEAN N DPRB PROD1 RIH and tried to find old hole at 90L TF drilled from 12871 ft 12874 ft, PU, pulled tight. Finally worked through at 90 L to 12,909 ft Orient TF to 90R at 12,909 ft 13:08 - 13:16 0.13 CLEAN N DPRB PROD1 Back ream with BC bit and low angle motor using 90R TF from 12,889 ft to 12866 ft Printed: 12/27/2005 8:36:13 AM BP EXPLORATION Page 9 of 17 Operations Summary Report Legal Well Name: 13-31 Common Well Name: 13-31 Spud Date: 4/2/1994 Event Name: REENTER+COMPLETE Start: 11/18/2005 End: 12/25/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/6/2005 Rig Name: NABOBS 4ES Rig Number: 4ES Date ~ From - To Hours ' Task Code i! NPT Phase ~ Description of Operations 12/16/2005 13:08 - 13:16 0.13 CLEAN N DPRB PRODi RIH at low CTP and tagged again at 12871 ft 13:16 - 13:53 0.62 CLEAN N DPRB PROD1 Orient TF to 90 L. RIH without a problem to 12,871 ft with 90L TF Orient TF to 180 deg for backreaming. 13:53 - 14:13 0.33 CLEAN N DPRB PROD1 Backed remed from 12,890 ft to 12,865 ft at 2 fpm. Didn't see much on back ream to 12,860 ft. Orient TF to 90L. Reamed 3 times at 110E TF. It cleaned up 14:13 - 15:16 1.05 CLEAN N DPRB PRODi RIH and washed from 12,914' and 12,980 ft twice. RIH, set down at 13,140 ft. PU and reamed through, cleaned up quickly. RIH and tagged bottom at 13,928 ft 15:16 - 16:15 0.98 CLEAN N DPRB PROD1 PUH to re-drift wellbore. Pulled tight at at BHA C~3 13,560 ft where we turned from R to L TF. Had to pull twice to get through. PUH. Pulled cleaned up to 12,600 ft 16:15 - 17:15 1.00 CLEAN N DPRB PROD1 RIH from 12,600 ft At 12871 ft, small bobble with little motor work. Re-washed through Clean RIH, took wt at 13,140 ft with HS TF. RIH to 13,150 ft and backed reamed "clean" Took wt at 13,800 ft. PUH and washed through. This section of the hole didn't act this way on the 1st RIH. Something on the side of BHA pushing to bottom.. RIH to 13,928 ft 17:15 - 20:30 3.25 CLEAN N DPRB PROD1 PUH, painted flag at 13700 ft EOP. PUH dragging a little, then pulled free. Paint EOP flags @ 11700' & 9650'. Continue POOH. 20:30 - 21:30 1.00 CLEAN N DPRB PROD1 OOH. PJSM. S/B injector. L/D cleanout BHA. Bit had 2 plugged jets & pieces of motor stator rubber. Inspect weld-on CTC OK, pull test to 35k & PT to 3500psi - OK. 21:30 - 21:45 0.25 LCR N DPRB PROD1 Held PJSM for M/U &RIH Baker Inflatable bridge plug BHA#12. 21:45 - 22:30 0.75 LCR N DPRB PROD1 M/U BHA#12 with guide shoe, 3jts of slick 2-3/8" Lnr & pup jt, Baker Retrievable bridge plug (pinned with 6 steel set screws), R/tools, 2 pup jts of 1-1/4" CSH & MHA. Conduct BOP valve drill while M/U 2-3/8" Lnr. M/U injector. 22:30 - 00:00 1.50 LCR N DPRB PROD1 RIH with BHA#12 pumping down the CT C~? 025bpm & down the backside Q 0.20bpm. 12/17/2005 00:00 - 01:30 1.50 LCR N DPRB PROD1 Continue RIH with BHA#12. Correct CTD by -8.4' @ 1st flag. Correct CTD by +5.7' Q 2nd flag. Wt check - Up = 38k, Run-in = 21 k. RIH smoothly @ 30fpm thru window. Set down C~3 12475' & 13136'. P/U clean C~3 40k & run thru. 01:30 - 03:30 2.00 LCR N DPRB PROD1 RIH & set down @ 13306'. Not able to run thru. Attempt to wash down from backsie & CT Q 1.3bpm/600psi - no luck. RIH fast C~3 100fpm & set down C~? same depth. Work pipe with max 14k set down & 2k O/Pull with no further progress. Decide to pump some crude. 03:30 - 04:30 1.00 LCR N DPRB PROD1 Line up to pump crude. Confirm Reid vapor pressure of 0.5psi @ 100F. Pump down 20bbls of crude down the CT @ 1 bpm/750psi & circ out of screen sub. 04:30 - 05:00 0.50 LCR N DPRB PROD1 Work CT from 13150' to 13306' & made no progress. 05:00 - 07:45 2.75 LCR N DPRB PROD1 POOH BKR IBP BHA#12. EOP flags @ 11696' & 9648'. 07:45 - 09:30 1.75 LCR N DPRB PROD1 OOH, LD 1BP BHA Inspected bottom 50 ft of 2" CT and found 3 flat spots. Several hard rocks in the IBP setting tool. 09:30 - 10:30 1.00 CLEAN N DPRB PROD1 Circulated CT warm. Cut off 16.4ft 2" CT and rehead w/ GBR. Printed: 12/27/2005 8:36:13 AM BP EXPLORATION Operations Summary Report Legal Well Name: 13-31 Common Well Name: 13-31 Event Name: REENTER+COMPLETE Start: 11/18/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/6/2005 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours ~, Task ~ Code NPT Phase 12/17/2005 09:30 - 10:30 1.00 CLEAN N DPRB PROD1 10:30 - 11:50 1.33 CLEAN N DPRB PROD1 11:50 - 14:10 2.33 CLEAN N DPRB PROD1 14:10 - 18:20 4.17 CLEAN N DPRB PROD1 18:20 - 20:30 2.17 I CLEAN I N DPRB I PRODi 20:30 - 21:30 21:30 - 22:25 22:25 - 00:00 12/18/2005 100:00 - 02:00 02:00 - 05:15 05:15 - 06:20 06:20 - 07:00 07:00 - 11:15 11:15 - 11:30 11:30 - 15:45 1.00 CLEAN N 0.92 CLEAN N 1.58 CLEAN N 2.00 CLEAN N 3.25 CLEAN N 1.08 CLEAN N 0.67 CLEAN P 4.25 CASE P 0.25 CASE P 4.25 CASE P DPRB PROD1 DPRB PROD1 DPRB PRODi DPRB I PROD1 DPRB PROD1 DPRB PROD1 PROD1 RUNPRD RUNPRD RUNPRD Page 10 of 17 Spud Date: 4/2/1994 End: 12/25/2005 Description of Operations Pull tested to 29k and PT to 3400 psi. PU new 1 deg motor and MHA with Sperry's MW D RIH, shallow hole test at 2600 ft W/R to bottom from 11,860 ft (No circulation) Op = 1.8 bpm Tagged at 12,478 ft, W/R clean, RIH Tagged at 12,640 ft, TF out, PU and orient TF to 155E fro 120R, Went through. RIH Tagged at 12,670 ft, oriented from 155E to 60L Went through, RIH Took wt at 13,110 ft with motor work, red Op and went through, RIH Tagged at 13,305 ft, Motor work, pulled tight coming up. Orient TF from 26 L to 154L. W/R through area, hard with motor work. Drilled at 90 to 100R Orient ti 25R and W/R down and tagged again at 13,31.1 ft, PU, orient TF Trying to get through at various TF. At 109R TF, washed throught to 13,325 ft, backed reamed.clean. Orient TF to 40L and backed reamed area Clean. Orient TF to 109R to get past Tagged at 13,350 with 70R TF. Orient TF to 109R. RIH to 13,362 ft. Working to get past shale. RIH past 13,362 ft. Tagged at 13,650 ft, had to orient TF to driilled TF on L-side, RIH Tagged at 13,691 ft washed through. Hole getting worst on the revert side. RIH and TF rolled 180 deg out, PUH and orient TF to 90L. Tagged at 13,840 ft, having trouble sliding at drilled TF. Tagged bottom at 13928 ft, set counters. Backream from 13928' C 160E - 175R TF, 1.5bpm/1750psi, 7-10fpm. Had 15k O/pull @ 13696' & 13560'. Had 200psi motor work @ 13500'. Ream down from 13450'. Set down C~3 13682'. Ream down with as drilled TF of 70L to 13704'. Continue RIH relatively clean to btm. Wiper trip relatively clean to 12570'. RBIH & tag @ 12870'. Orient to as drilled TF & run thru. PUH clean to 12850'. RBIH & tag C~ 13020' (top of shublik). Observe 600psi pressure increase -likely due to plugged jet(s). Orient to as drilled TF of 140E & drill thru restriction. Continue RIH relatively clean. Tag C~ 13125'. Orient to as drilled & run thru. Observe circ pressure return to normal +/-2000psi ~ 1.7bpm. RIH & tag @ 13503'. PUH, orient & run thru. Tag C~? 13563'. PUH, orient & run thru. RIH to btm. POOH for liner. Wellbore relatively clean with only some minor bobbles. Paint EOP flag @ 11600' & 9500'. OOH. PJSM. S/B injector. L/D cleanout BHA#13. Pump 1 bpm across top of wellhead. PJSM on handling liner and liner running equipment. SD pump and load dart catcher, Sperry RD tools and cleaning catwalk Pump 2" dart at 2.0 bpm (no circulation). Pumped 3 darts. Darts hanging up in the CTC. Modified new dart and pumped. Heard dart hit at 40.3 bbl. PJSM and make ready to run liner Running liner. Torqued STL threads to 1,100 ft-Ib-1500 ft-Ib, Printed: 12/27/2005 8:36:13 AM BP EXPLORATION Page 1 i of 17 Operations Summary Report Legal Well Name: 13-31 Common Well Name: 13-31 Spud Date: 4/2/1994 Event Name: REENTER+COMPLETE Start: 11/18/2005 End: 12/25/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/6/2005 Rig Name: NABOBS 4ES Rig Number: 4ES Date 'From - To Hours Task 12/18/2005 111:30 - 15:45 4.25 (CASE Code NPT 'i Phase P 15:45 - 16:15 0.50 CASE P 16:15 - 18:45 2.50 CASE P 18:45 - 20:40 I 1.921 CASE I N 20:40 - 21:10 0.50 CASE N 21:10 - 23:00 1.83 CASE N 23:00 - 23:45 0.75 CASE P 23:45 - 00:00 12/19/2005 ~ 00:00 - 01:40 0.251 CEMT I P 1.671 CEMT ~ P 01:40 - 04:15 I 2.581 CEMT I P 04:15 - 04:45 0.50 CEMT P 04:45 - 05:00 0.25 CLEAN P 05:00 - 05:15 0.25 CLEAN P 05:15 - 08:15 3.00 CLEAN P 08:15 - 13:41 1 5.431 CLEAN I P Description of Operations.. RUNPRD and drifted 1st 10 connects using 1.875" drift (OK). Running liner filling down annulus w/ flo- fro at 0.50-1.0 bpm. Drift several connections using BOT 1.875" drift RUNPRD MU BOT CTLRT and PJ. RUNPRD RIH with Liner Corrected to EOP flag at 11600 ft (-13.9ft) Wt check above window = 38.5 k RIH and tagged at 12495 ft, PU RIH Tagged at 12865 ft working to get past ledge. This has been a problem area in the past After 30 min pushed through area. RIH and set down at 13125 ft Working to get past this area DPRB RUNPRD Continue to work CT. Getting clean P/Us. PUH +/-100' &RIH fast C~3 +/-120fpm. Set down max wt & wash on btm. Could be dealing with cuttings build-up across shublik fault. Circ down 10bbls of KCL & wash on btm C~3 max rate without luck. Line up & pump both down the CT & the backside while moving CT up slowly to 13050'. RBIH C 85fpm pumping C~? 1.15bpm on the backside & 0.35bpm down the CT. Still tagging hard @ same depth. Suspect a ledge C«~ the shublik fault crest. DPRB RUNPRD Commence "stop & sneak" hesitations while RIH to wiggle shoe past ledge. Finally manage to work past ledge. DPRB RUNPRD Continue RIH with liner Ca? +/-60fpm &circ C«? min rate. Tag & work thru restrictions @ 13323', 13500', 13535', 13542' 13672', 13720' & 13792' - 13907'. See 2nd flag -7' off. Tag TD hard G 13914' CTD. Wash on btm for 15mins & can't go deeper. Call it good. P/U @ 46k. RBIH C~3 & retag TD C~ same depth. Correct CTD to 13928'. RUNPRD Establish circ. Load 5/8" AL ball &circ with C~ 1.7/1230psi. Set down 10k down on LBRT. Continue circ ball to seat. Slow down 28bbls away. Ball on seat C«? 36.3bbls. Pressure up to 3200psi & release LBRT. P/U C~? 35k & confirm release. RUNPRD PJSM with all personnel concerning cementing operations. Meanwhile continue circulating flopro down the CT @ 1.2bpm/600psi. RUNPRD Batch mix 33bbls 15.8ppg 'G' latex cmt with additives. Cmt to wt C~3 00:30hrs. Flush/PT lines to 4k. Pump 15bbls of KCL water ahead. Pump 27bbls cmt slurry @ 1.79bpm/1730psi. Close inner reel valve & clean lines. Load/launch CTWP with 500psi. Chase with 30bbls bio-KCL Q 2.48bpm/2050psi. CTWP engage LWP @ 41.4bbls away. Shear plug with 3550psi. Continue displacing LWP @ 1.47bpm/750psi & bump @ 49.9bbls away with 1000psi over. Bleed off & check floats no backflow. Pressure up to 200psi & sting out of liner. Observed no returns during cement job. CIP C~? 01:40hrs. RUNPRD Circ lbbl of bio-KCL @ 0.5bpm on TOL. POOH @ 65fpm pumping @ 0.55bpm. RUNPRD OOH. PJSM. UD LBRT. RUNPRD R/U to P/U cleanout mill/motor & 1" CHS tbg. Meanwhile circ ~ 1 bpm via CT to kill-line to keep hole full. RUNPRD PJSM on P/U &RIH cleanout BHA. RUNPRD M/U cleanout BHA #15 with 1.875" mill, 1-11/16" straight motor, lower MHA, 74jts of 1" CSH tbg & upper MHA. M/U injector. RUNPRD RIH, Corrected -14.9 ft at 11,600 ft EOP flag. RIH at Op = 1.1 Printed: 12/27/2005 8:36:13 AM BP EXPLORATION Page 12 of 17 Operations Summary Report Legal Well Name: 13-31 Common Well Name: 13-31 Spud Date: 4/2!1994 Event Name: REENTER+COMPLETE Start: 11/18/2005 End: 12/25/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/6/2005 Rig Name: NABORS 4ES Rig Number: 4ES Date ~ From - To !Hours ' Task Code NPT ~ Phase Description of Operations - _ __._ I 12/19/2005 08:15 - 13:41 I 5.43 (CLEAN I P 13:41 - 14:03 0.37 CLEAN P 14:03 - 16:30 2.45 CLEAN P 16:30 - 17:45 1.25 CLEAN P 17:45 - 18:30 0.75 CLEAN P 18:30 - 19:00 19:00 - 22:00 22:00 - 00:00 12/20/2005 00:00 - 00:45 00:45 - 01:00 ~ 01:00 - 02:45 0.50 LCR N 3.00 LCR N 2.00 LCR N 0.75 LCR N 0.25 LCR N 1.75 LCR N 02:45 - 03:00 03:00 - 03:50 03:50 - 04:45 04:45 - 11:35 11:35 - 13:13 13:13 - 14:12 14:12 - 14:53 0.25 LCR N 0.83 LCR N 0.921 LCR N 6.831 LCR N 1.63 ~ LCR ~ N 0.98 I LCR I N 0.68 I LCR I N RUNPRD bpm at 12-20 fpm cleanout out liner. AV at 500 fpm. RIH. Pumped 3 bbl 3ppb bio at 11,850 ft PUW @ 12,555 ft = 37.5k Started taking wt at 13,040 ft 37.5k (going over the hump) PU at 13,179, taking wt with inc in CTP. PUW = 3.5k clean PUW at 13,213 ft = 37k. RIH at 1 bpm circulating down 3ppg biozan PU at 13,560 ft 40k, PU at13842 ft = 40k. RIH set down at 13,836 ft Set down at 13,822ft Red Op to 0.4 bpm and RIH to tag (hydraulics) RIH and tagged at 13,892 ft corrected. RUNPRD Circulated 35 bbl 3ppb biozan fluid down CT RUNPRD POOH laying in 3ppb biozan RUNPRD Stood back 1" CSH and LD mill and motor RUNPRD Wells Group shoot fluid level down well - 1st shot FL = 600' & 2nd shot FL = 580'. CEMT RUNPRD PJSM. M/U slick cementing BHA# 16 with big hole (0.95" ID) nozzle & 6' CSH tbg pup. M/U injector. CEMT RUNPRD RIH with cementing BHA#16 to EOP flag @ 11600'. Sutract 15.8' from CTD. RIH & park nozzle @ 11650'. CEMT RUNPRD Held PJSM with LRS. LRS preheat diesel to +/-120F. R/U 4-1/2" 1502 integral flange to flow-tee. CEMT RUNPRD LRS continue preheating diesel to +/-120F. R/U LRS pumping hardline to flow tee. CEMT RUNPRD PJSM with all personnel concerning hot oil pumping operations. CEMT RUNPRD Flush & P/test LRS hard lines to 4k. SI well. LRS bullhead 56bbls of 120E diesel down the CT/Tbg annulus @ !bpm/0-750psi. Fluid level was caught @ 2500' (after pumping 12bbls diesel). SI well & allow WHP to stabilize. Final stabilized WHP after 15mins - 350psi. CEMT RUNPRD PJSM with all personnel concerning cementing operations. CEMT RUNPRD Flush & P/test cmt lines to 4k. Batch mix 23bbls 15.8ppg 'G' latex cmt with additives. Cmt to wt @ 03:15hrs. Pump 5bbls of water ahead, 20bbls cmt slurry & 5bbls of water behind @ 1.95bpm/2550psi & +/-SOOpsi WHP. Chase with diesel @ 2.43bpm/3880 & +/-650psi WHP. Downsqueeze 20bbls of cmt behind TOL @ 2.36bpm/3600psi & 650psi - 1080psi WHP. Left 0.5bbls of cmt (50') above TOL. CIP @ 03:50hrs. CEMT RUNPRD POOH replacing CT voidage to 9000'. SI inner reel valve. Final WHP - 220psi, CEMT RUNPRD W.O. cement to get to 500psi compressive strength. Final WHP gradually stabilize @ 179psi. CEMT RUNPRD At 1135 hrs the cement was at +500 psi compressive strength Pressured up to 500 psi at 0.6 bpm using 3.1 bbl SWI at 322 bbl, Pressure dropped to 223 psi in 4 min. Conducted injectivity test Op = 1.00 bpm at 233 to 751 psi using 10 bbl At 9 bbl pumped Pi stablized at 750 psi and 1 bpm (8 psi /bbl pumped 1st 9 bbl pumped) CEMT RUNPRD line out to RIH while holding 250-300 psi on well. to 11,697 ft. PUW 49k. PUH to 11, 650 ft CEMT RUNPRD Conducted injectivity test while WOC Printed: 12/27/2005 8:36:13 AM BP EXPLORATION Page 13 of-17 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 12/20/2005 14:12 - 14:53 14:53 - 16:15 16:15 - 19:50 19:50 - 20:00 20:00 - 21:35 21:35 - 00:00 12/21 /2005 00:00 - 03:00 03:00 - 03:30 03:30 - 04:00 04:00 - 05:30 05:30 - 05:40 05:40 - 06:45 06:45 - 07:00 13-31 13-31 Spud Date: 4/2/1994 REENTER+COMPLETE Start: 11/18/2005 End: 12/25/2005 NABOBS ALASKA DRILLING I Rig Release: 12/6/2005 NABOBS 4ES Rig Number: 4ES Hours I Task ~' Code ~ NPT Phase Description of Operations -_ _ ~ _ __ - 0.68 LCR N -T CEMT __ RUNPRD _ _ _ _ - ______ Op = 1 bpm = P = 350 psi V= 3 bbl Qp = 1.25 bpm P = 856 psi 15 bbl SD Pi = 841 psi. P dropped to 330 psi 2%KCL got back flushed into diesel transport 1.37 LCR N CEMT RUNPRD Conduct Injectivity test using diesel (density = 6.7ppg) Op = 1.15 bpm at 1637 / 897 psi, Vp =50 psi 3.58 LCR N CEMT RUNPRD WOC SD injection test and monitor WHP = 897 psi. 10 min WHP = 267 psi, BHP = 3451 psi 30 min WHP = 190 psi, BHP = 3274 psi 50 Min WHP = 179 psi BHP = 3263 psi. Stablized as per initial liner top cement job 0.17 LCR N CEMT RUNPRD PJSM with all personnel concerning cementing operations. 1.58 LCR N CEMT RUNPRD PT SLB surface lines to 4000 psi. Little Red RU on the CT annulus. Pumped 5 bbl water, 20 bbl of 15.8ppg cement on the fly followed by 5 bbl of water. SD cementers and lined out to displace cement with 6.74 ppg diesel. Pumped 2 bbl diesel at 1.8 bpm and caught fluid. Reduced Op to 0.7 bpm, pumped 5 bbl of cement past liner top. Pressure on the CT and IA started to rise from 900 to 1,050 psi. Reduced Op to 0.6 bpm CTP at 850psi Annulus at 1050 psi. Reduced Op to 02.bpm and annulus pressure remained constant at 1055 psi. Pumped 13 bbl at lower rates. WHP not rising, decided to lay in cement on TOL. PUH laying in 2 bbl of cement on top of the liner. PUH replacing CT voidage. CTP =Pannulus = 500 psi. PUH to 9,300 ft. Pumped 1 bbl and CTP increased from 350 to 550 psi. Annulus P increased from 450 to 600 psi. SD pump. Estimated TOC at at 11,590 ft . Pannulus stablized at 212 psi in 30 minutes. 2.42 LCR N CEMT RUNPRD WOC, WHP at 205 psi 3.00 LCR N CEMT RUNPRD WOC, WHP at 205 psi 0.50 LCR N CEMT RUNPRD P/T liner lap to 500 psi w/ 1.4 bbls, lost 266 psi in 2 minutes, pressure stabilized at 209 psi after 20 mins. 0.50 LCR N CEMT RUNPRD Conduct Injectivity test using diesel (density = 6.7ppg) Qp = 1.10 bpm at 1760 psi w/ 6.2 bbls, Monitor pressure 10 min WHP = 231 psi, BHP = 3415 psi 30 min WHP = 216 psi, BHP = 3400 psi 1.50 LCR N CEMT RUNPRD RIH to TOL at 11704' w/ .15 bpm at 410 psi 0.17 LCR N CEMT RUNPRD POH to 11200' 1.08 LCR N CEMT RUNPRD WO Cementer NOTE: During 06:00 hrs TL,Safety meeting with crew change. Covered the Safety Stand slide presentation with rig crews. 0.25 LCR N CEMT RUNPRD Conducted injection test: Op = 1.25 bpm at CTP = 1734 psi WHP = 1078 psi Vp = 7 bbl. Pressure came up quicker than prior to the last squeeze SD. isolated reel Time WHP imin 624 psi 2 min 414 psi 3 min 337 psi 5 min 275 psi 8 min 245 psi ~ 10 min 240 psi Printed: 12/27/2005 8:36:73 AM BP EXPLORATION Page 14 of 17 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To 3-31 3-31 REENTE NABOB NABOB Hours R+COM S ALASK S 4ES Task PLET A DRI Code E LLING NPT Start I Rig Rig Phase Spud Date: 4/2/1994 : 11/18/2005 End: 12/25/2005 Release: 12/6/2005 Number: 4ES ', Description of Operations 12/21/2005 07:00 - 07:30 0.50 LCR N CEMT RUNPRD WO Cementers 07:30 - 08:00 0.50 LCR N CEMT RUNPRD RU Cementers and pre heat 90 bbl of diesel for upcoming squeeze 08:00 - 08:25 0.42 LCR N 5 bb RUNPRD PJSM with crew and SLBV Cementers. Topic beside the cement operations included the safety stand down slides presentation on Safety Stand Down. 08:25 - 09:10 0.75 LCR N 5 bb RUNPRD Preheating diesel to 75 deg F, remove filter from HP line. 09:10 - 10:42 1.53 LCR N With RUNPRD PT SLB surface lines to 4100 psi Pumped the following 5 bbl water 5 bbl 15.9 ppg Unisurry cement 10 bbl 16.0 ppg cement with 12ppb aggregate 5 bbl 15.9 ppg Unisurrycement 5 bbl water, displaced with 6.79 ppg diesel With lead at TOL reduced Op 1.4 to 1.1 bpm With Aggregate at TOL reduced Op to 0.8 bpm IA = 2128 psi With 5 bbl aggregate behine pipe reduce OP 0.8 to 0.6 bpm With 7.5 bbl aggregate behine pipe, reduced Op to 0.4 bpm IA 2350 psi With 10 bbl aggregate behine pipe SD Pa = 2030 psi PUH laying in the last 5 bbl of cemt at 1:1 to 11075 ft. PUH to WCTOC 10,200 ft. 10:42 - 10:47 0.08 LCR N With RUNPRD Stopped at 10,200 ft, SD pump, Pa 1871 psi in 5 minutes Pa = 1780 psi 10:47 - 11:15 0.47 LCR N With RUNPRD Pumped 0.5 bbl at 0.3 bpm Pa went from 1750 psi to 2050 psi SD and in 5 min Pa = 1987 psi Pumped 0.5 bbls at 0.3 bpm. Pa went from 1780 psi to 1838 psi, 5 min Pa = 1730 psi Pumped 0.5 bbl at 0.3 bpm. Pa = 1860 psi. 5 min P dropped to 1571 psi after SD Pumped 0.5 by at 0.3 bpm. Pa = 1835 psi. 5 min P dropped to 1468 psi after SD Pumped 0.5 bbls at 0.3 bpm. Pa = 1835 psi, 5 min P dropped to 1465 psi after SD Pumped 0.5 bbls at 03. bpm. Pa 1809 psi, 5 min Pa dropped to 1472 psi Estimated TOC at 11510 ft 11:15 - 14:15 3.00 LCR N With RUNPRD WOC waiting for cement to yield Sample in UCA at 1115 hrs Time Pa 1133 hrs 1124 psi 1155 hrs 950 psi 1235 hrs 840 ps1 1300 hrs 800 psi 1345 hrs 745 psi 1411 hrs 725 psi 14:15 - 14:26 0.18 LCR N With RUNPRD Trapped = 720 psi. Pressured up to 1200 psi Hold with small a amout leakage. 14:26 - 16:14 1.80 LCR N PUH RUNPRD RIH pumping at 0.6 bpm at WHP of 650 to 550 psi Didn't tag anything at 11650 ft (54 ft above TOL) PUH 16:14 - 16:48 0.57 LCR N CEMT RUNPRD Pumped 10 bbl 3 ppb Biowater followed by 2% KCL to fluid pack the wellbore Op = 1.7/ 1.7 bpm Stopped at 11600 ft pumping biozan around With 10 bbl Bio out Printed: 12/27/2005 8:36:13 AM BP EXPLORATION Page 15 of 17 Operations Summary Report Legal Well Name: 13-31 Common Well Name: 13-31 Spud Date: 4/2/1994 Event Name: REENTER+COMPLETE Start: 11/18/2005 End: 12/25/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/6/2005 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - To Hours ~ Task Code ._ _i _ 12/21/2005 ~ 16:48 - 18:10 1.37 LCR ~ N 18:10 - 18:30 0.33 LCR N 18:30 - 19:00 0.50 LCR N 19:00 - 23:00 4.00 LCR N 23:00 - 00:00 1.00 LCR N 12/22/2005 00:00 - 01:00 1.00 LCR N 01:00 - 01:30 0.50 LCR N 01:30 - 08:30 7.00 BOPSU N 09:30 - 09:50 0.33 COR S U ~ N 09:50 - 12:00 I 2.17 I LCR I N 12:00 - 14:00 2.00 LCR N 14:00 - 14:25 0.42 LCR N 14:25 - 15:50 1.42 LCR N 15:50 - 17:15 1.42 LCR N 17:15 - 17:30 I 0.25 I LCR I N 17:30 - 19:05 I 1.581 LCR I N 19:05 - 20:30 1.42 LCR N 20:30 - 00:00 3.50 LCR N 12/23/2005 100:00 - 04:30 I 4.501 LCR I N 04:30 - 07:04 I 2.571 LCR I N 07:04 - 08:15 I 1.181 LCR I N 08:15 - 08:45 0.50 LCR N 08:45 - 08:50 0.08 LCR N 08:50 - 10:00 1.17 LCR N 10:00 - 12:40 2.67 LCR N 12:40 - 15:09 2.48 LCR N 15:09 - 16:23 1.23 LCR N 16:23 - 18:15 1.87 LCR N NPT ' Phase I Description of Operations CEMT RUNPRD POOH displacing wellbore w/ 2% KCL. Pumped 180 bbl Turned fluid back to pits CEMT RUNPRD POH, LD BHA CEMT RUNPRD MU Cleanout Assy, MHA, stab inj CEMT RUNPRD RIH w/ Cleanout BHA, PU Wt 32.9 K, S/O WT 16.1 K, tagged TOL at 11704', found no cement, set down several times with no drill off, circ around 20 bbl Biozan sweep, no cement in returns Received UCA Report at 22:20 hours, Cement Compressive Strength -1000 psi CEMT RUNPRD POH to 5879' CEMT RUNPRD POH to BHA, Stand back inj. CEMT RUNPRD POH, LD BHA CEMT RUNPRD Testing BOP's, John Crisp w/ AOGCC waived witnessing BOP Test' While working the BOP's found some rubber on top of the MV. Will fish later Finished BOP test CEMT RUNPRD Fish annular element out from top of SV CEMT RUNPRD PJSM on running CSH. Talked about BP Safety Stand Down slides again CEMT RUNPRD PU 1.875 mill and 1-11/16" motor. 74 jts 1"CSH Checked all connects Conducted valve drill with crew CEMT RUNPRD RIH to ceanout 2-3/8" liner CEMT RUNPRD RIH through 2-3/8" liner. Found cement at 11,705 ft Drilling cement from 11704.4 ft Op = 1.0 bpm WOB = 1k. CTP inc. from 1900 psi to 3000 psi, something got partially plug. Surging CTP with Baker choke. CTP increased 3000 psi. Motor failure CEMT RUNPRD POOH, unable to reduce CTP CEMT RUNPRD Stood back injector. POOH and stand backCSH Dropped 1/2" ball to open lower cir sub CEMT RUNPRD MU new Cleanout (C/O) BHA, Changed out locked up motor, Circ sub. CEMT RUNPRD RIH with 37 stds CSH, X-O, HDC, DCV, swivel sub, CTC, stab injector CEMT RUNPRD RIH w/ C/O BHA, tagged at 11704', PU wt 34 K, S/O wt 17 K CEMT RUNPRD RIH drlg intermittent cement stringers f/ 11704' - 11709', 11806' - 11815' w/ .96 bpm at 2700 psi CEMT RUNPRD RIH to 13892', drlg intermittent cement stringers f/ 11815' - 12112' - w/ .92 bpm at 2800 psi, pumped a couple Biozan sweeps around white drlg cmt and RIH to PBTD CEMT RUNPRD POH, displacing well to new 2 percent double slick KCL water, cleaned surface pits CEMT RUNPRD Stood back injector and POOH standing back 37 stds CSH in derrick CEMT RUNPRD Held PJSM on PU and handling SMCT tool (fragile) CEMT RUNPRD PU SCMT Tool and install lithium batteries, Tool working CEMT RUNPRD PU and RIH 74 fts 1"CSH and BHA. Stab injector set counter CEMT RUNPRD RIH with SCMT tool at 75 fpm CEMT RUNPRD Stopped at 11,615 ft to start log. RIH at 15 fpm logging liner down. CEMT RUNPRD PUH logging SCMT at 30 fpm to 11600 ft CEMT RUNPRD POOH to logging BHA Printed: 12/27/2005 8:36:13 AM BP EXPLORATION Page 16 of 17 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ~ Name: 1 ell Name: 1 e: Name: From - To ! 3-31 3-31 REENTE NABOB NABOB Hours R+COM S ALASK S 4ES Task PLET A DRI Code E LLING NPT ~ Start I Rig Rig Phase Spud Date: 4/2/1994 : 11/18/2005 End: 12/25/2005 Release: 12/6/2005 Number: 4ES Description of Operations 12/23/2005 18:15 - 20:00 1.75 LCR N CEMT RUNPRD Stand injector back, crew change, Std bacl 37 stds of 1"CSH, LD CBL logging tools 20:00 - 21:00 1.00 LCR N CEMT RUNPRD Attempt to pressure test liner lap to 3000 psi ,pumped 8.5 bbls at 1.25 bpm to 2000 psi, pressure fell off to 1000 psi in 1 1/2 minutes, checked surface lines, ok, retest liner lap to 1780 psi, pumped 8 bbls at 1.25 bpm, pressure fell off to 350 psi in 15 minutes, released pressure, circ thru CT. 21:00 - 22:30 1.50 LCR N CEMT RUNPRD Downloading and process CBL log 22:30 - 00:00 1.50 LCR N WAIT RUNPRD Wait on Orders while Anchorage Office reviews CBL log 12/24/2005 00:00 - 01:30 1.50 LCR N CEMT RUNPRD MU jet nozzle, RlH w/ 37 stds of 1" CSH, HDC, DCV's, Swivel, CTC, Stab inj. 01:30 - 04:00 2.50 LCR N CEMT RUNPRD RIH w/ BHA, tagged bottom at 13892' 04:00 - 06:00 2.00 LCR N CEMT RUNPRD POH while laying bleach pill inside 2 3/8" liner, Pumped 15 bbls of 6 ppb LION bleach 06:00 - 06:45 0.75 PERFO N CEMT LOWERI Load guns in pipe shed 06:45 - 08:00 1.25 PERFO P LOW ER1 POOH standing back CSH 08:00 - 08:15 0.25 PERFO P LOWERI PJSM on handling 1.56' Guns 08:15 - 09:30 1.25 PERFO P LOWERI PU and RIH with 387 ft 1.56" Perf guns /blanks as per SLB SOP's 09:30 - 10:30 1.00 PERFO P LOWERI Run BHA and 62 jts of 1" CSH 10:30 - 13:40 3.17 PERFO P LOWERI RIH with Perf BHA and tagged at 13,892 ft corrected (-8 ft) PUH to 13,675 ft (Spotting Depth) Confirmed and dropped 1/2" ball. Line up with bleach. Pressured up to 500 psi, launched dall. 13:40 - 14:30 0.83 PERFO P LOWERI Displace ball with 13 bbl bleach & 2% KCL to firing head. Vol = 42 bbl Slowed down to 0.66 bpm at 32 bbl pumped. Circulation pressures high at 3,800 psi at 1.24 bpm. Ball on seat at 40.5 bbl. RIH and PUH and conduct drive by pert. Pressured up to 4,800 psi (trip). didn't see the pert shot. Pressured up again to 4,500 psi and while holding 4,300 psi, CTP pressure started to drop and the annulus went on vacume. Perforated using SLB's 1.56" PJ 1606 Guns: 13,310 ft to 13,350 ft 6 spf 13,390 ft to 13,670 ft 6 spf 14:30 - 16:50 2.33 PERFO P LOWERI PUH filling down backside. at 1.63 bpm tossing 1 bpm down hole 16:50 - 18:10 1.33 PERFO P LOWERi Check fluid losses. Lossing 1.1 bpm while cir across the top POOH standing back CSH 18:10 - 18:30 0.33 PERFO P LOWERI RU to LD guns, Held PJSM after crew change concerning gun handling. 18:30 - 20:00 1.50 PERFO P LOWERi POH, LD Perf Guns, all shots fired 20:00 - 20:50 0.83 PERFO P LOWERI MU polish mill assy, stab inj 20:50 - 23:05 2.25 PERFO P LOWERI RIH w/ polished mill assy, no go out at 11708' 23:05 - 23:45 0.67 PERFO P LOWERI Worked polish mill in and out of deployment sleeve several times 23:45 - 00:00 0.25 PERFO P LOWERI POH filling down backside at 1.63 bpm tossing 1 bpm down hole 12/25/2005 00:00 - 01:55 1.92 PERFO P LOWERI POH to BHA, stand back inj, keeping backside full, losing 60 bph Printed: 12/27/2005 8:36:13 AM BP EXPLORATION Page 17 of 17 Operations Summary Report Legal Well Name: 13-31 Common Well Name: 13-31 Spud Date: 4/2/1994 Event Name: REENTER+COMPLETE Start: 11/18/2005 End: 12/25/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/6/2005 Rig Name: NABOBS 4ES Rig Number: 4ES Date From - Tol Hours Task ~~ Code ~ NPT '~ Phase Description of Operations 12/25/2005 01:55 - 02:15 0.33 PERFO P LOWERI POH w/ BHA, std back ph6 tbg, LD x-o's, jar, motor and polished mill 02:15 - 02:30 0.25 PERFO P LOWERI MU KB Packer w/ seal stinger, stand of PH6 Tbg, 02:30 - 05:05 2.58 PERFO P LOW ER1 RIH w/ KB Packer Assy, sting in to deployment sleeve w/seal assy at 11704', PU 2' leaving 3.92' of seals stung in. checked space 3 times 05:05 - 05:50 0.75 PERFO P LOWERI Drop 5/8" aluminum ball, set packer with w/ 2000 psi and hold 05:50 - 06:35 0.75 PERFO P LOWERI Switch to pump down backside between CT and Tbg, P!f against packer 3000 psi Pressure stablized at 2950 pso for charted 30 min. Released annulus pressure. Pressured up on CT to 2500 psi. sheared and set 06:35 - 08:45 2.17 PERFO P LOWERI PUH filling welldown backside 08:45 - 09:00 0.25 PERFO P LOWERI LD KB Packer running tools. Load out 09:00 - 09:45 0.75 WHSUR P POST Fluid pack well using 25 bbl 80 deg diesel down tubing. Well on Vac SD and close SV 09:45 - 10:40 0.92 WHSUR P POST Held PJSM on pumping corrison inhibitor through CT 10:40 - 12:00 1.33 WHSUR P POST Pump 22 bbl bleach, 60 bbl fresh water, 15 A261, corrosion inhibitor and 5 MEOH SD 12:00 - 12:10 0.17 WHSUR P POST Held PJSM on pumping N2 12:10 - 16:00 3.83 WHSUR P POST Blow dow CT with N2 at 1500 scf/min for 15 min. Clean Pits RIG RELEASED AT 16:00 HRS 12-25-2005 Printed: 12/27/2005 8:36:13 AM Halliburton ~ ~ ~~~ ~'~ Global '~ Company: BP Amoco Dater 1/9/2006 Time: 19:24:41 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference:. Wel l: 13-31, True North Site: PB DS 13 Vertical (TVD) Reference: 46: 31 4/2/1994 00:00 82.3 Well: 13-31 Sectiou(VS}Reference: Wel l (O:OON,O.OOE,4 0.OOAzi) Wellpath:. 13=31A Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866} Coordinate System: Well Centre Sys Datum: Mean Sea Le vel Geomagnetic Model: bggm2005 Well: 13-31 Slot Name: 31 13-31 Well Position: +N/-S -1033.35 ft Northing: 5931611.22 ft Latitude: 70 13 5.281 N +E/-W -51.05 ft Easting : 685802.86 ft Longitude: 148 30 3.786 W Position Uncertainty: 0.00 ft Wellpath: 13-31A Drilled From: 13-31 118 22 57 ft 500292245901 Tie-on Depth: . Current Datum: 46:3 1 4/2/1994 00; 00 Height 82.30 ft Above System Datum: Mean Sea Level Magnetic Data: 7/5/2005 Declination: 24.93 deg Field Strength: 57606 nT Mag Dip Angle: 80.85 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36 .30 0.00 0.00 40.00 Survey Program for Definitive Wellpath Date: 12/12/2005 Validated: Yes Version: 5 Actual From To Survey Toolcode Tool Name ft ft - 57 00 11822 38 1 : Schlumberger GCT multishot (38.00- 121liCCQ01~ Schlumberger GCT multish ot . . 11851.00 13928.00 MWD (11851. 00-13928.00) MWD MWD -Standard __~ Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft; 00 30 0 36 0.00 36.30 -46.00 0.00 0.00 5931611.22 685802.86 TIE LINE . . 10 00 0 38 196.30 38.00 -44.30 0.00 0.00 5931611.22 685802.86 GCT-MS . . 06 97 0 38 178.69 38.97 -43.33 0.00 0.00 5931611.22 685802.86 GCT-MS . . 07 0 14 40 114.25 40.14 -42.16 0.00 0.00 5931611.22 685802.86 GCT-MS . . . 45.33 0.08 122.47 45.33 -36.97 -0.01 0.01 5931611.22 685802.86 GCT-MS 17 68 0 51 80.68 51.68 -30.62 -0.01 0.02 5931611.22 685802.88 GCT-MS . . 19 53 0 59 76.81 59.53 -22.77 0.00 0.04 5931611.22 685802.90 GCT-MS . . 18 63 0 71 79.03 71.63 -10.67 0.01 0.08 5931611.23 685802.94 GCT-MS . . 17 18 0 84 91.09 84.18 1.88 0.01 0.12 5931611.23 685802.98 GCT-MS . . 96.65 0.17 97.58 96.65 14.35 0.01 0.16 5931611.23 685803.01 GCT-MS 19 11 0 109 98.04 109.11 26.81 0.00 0.19 5931611.23 685803.05 GCT-MS . . 18 61 0 121 103.24 121.61 39.31 -0.01 0.23 5931611.22 685803.09 GCT-MS . . 07 0.19 134 115.54 134.07 51.77 -0.02 0.27 5931611.21 685803.13 GCT-MS . 21 50 0 146 120.93 146.50 64.20 -0.04 0.31 5931611.19 685803.17 GCT-MS . . 159.02 0.21 123.12 159.02 76.72 -0.07 0.35 5931611.17 685803.21 GCT-MS 22 47 0 171 125.36 171.47 89.17 -0.09 0.39 5931611.14 685803.25 GCT-MS . . 22 87 0 183 130.28 183.87 101.57 -0.12 0.43 5931611.11 685803.28 GCT-MS . . 23 34 0 196 130.24 196.34 114.04 -0.15 0.46 5931611.08 685803.32 GCT-MS . . 25 77 0 208 133.15 208.77 126.47 -0.19 0.50 5931611.05 685803.36 GCT-MS . . 221.18 0.27 134.74 221.18 138.88 -0.23 0.54 5931611.01 685803.40 GCT-MS 27 64 0 233 133.88 233.64 151.34 -0.27 0.58 5931610.97 685803.45 GCT-MS . . 28 14 0 246 132.74 246.14 163.84 -0.31 0.63 5931610.93 685803.49 GCT-MS . . 27 59 0 258 130.70 258.59 176.29 -0.35 0.67 5931610.89 685803.54 GCT-MS . . 27 271 10 0 126.29 271.10 188.80 -0.38 0.72 5931610.86 685803.58 GCT-MS . . 283.47 0.26 118.60 283.47 201.17 -0.42 0.77 5931610.83 685803.63 GCT-MS 26 86 0 295 114.30 295.86 213.56 -0.44 0.82 5931610.80 685803.68 GCT-MS . . 25 07 0 308 111.03 308.07 225.77 -0.46 0.87 5931610.78 685803.73 GCT-MS . . 26 29 0 320 08 112 320.29 237.99 -0.48 0.92 5931610.76 685803.79 GCT-MS . . 332.77 0.25 . 109.34 332.77 250.47 -0.50 0.97 5931610.75 685803.84 GCT-MS Halliburton Global Company: BP Amoco Date: 1/9/2006 Time: 19;24:41 Page 2 Field: Pru dhoe Bay Co-ordinate(NE) Reference: WeA: 13-31, True North Site: PB DS 13 Vertica l (TVD)`Reference: 46 :31 4/2/1994 00:00 82:3 Well: 13- 31 Section {VS) Reference: Well (O.OON,O:OOE,40:OOAzi) Wellpath: 13- 31A Survey Calculation Method: _Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft i 345.32 0.24 110.32 345.32 263.02 -0.52 1.02 5931610.73 685803.89 GCT-MS 357 76 24 0 111.20 357.76 275.46 -0.54 1.07 5931610.71 685803.94 GCT-MS . 35 370 . 0 24 110.45 370.35 288.05 -0.56 1.12 5931610.69 685803.99 GCT-MS . 88 382 . 0.23 108.83 382.88 300.58 -0.57 1.17 5931610.68 685804.04 GCT-MS ~ . 39 395 0 23 107.40 395.39 313.09 -0.59 1.21 5931610.66 685804.08 GCT-MS . 407.91 . 0.24 109.21 407.91 325.61 -0.61 1.26 5931610.65 685804.13 GCT-MS 42 420 0 26 112.04 420.42 338.12 -0.62 1.31 5931610.63 685804.19 GCT-MS ~ . 02 433 . 0 27 115.36 433.02 350.72 -0.65 1.37 5931610.61 685804.24 GCT-MS . 52 445 , 0 29 122.84 445.52 363.22 -0.68 1.42 5931610.58 685804.29 GCT-MS . 03 458 , 0 32 128.95 458.03 375.73 -0.72 1.47 5931610.54 685804.35 GCT-MS If . 470.60 . 0.36 131.05 470.60 388.30 -0.76 1.53 5931610.50 685804.41 GCT-MS 04 483 0 37 132.38 483.04 400.74 -0.82 1.59 5931610.44 685804.47 GCT-MS . 60 495 . 0 38 131.87 495.60 413.30 -0.87 1.65 5931610.39 685804.53 GCT-MS I . 14 508 . 0 38 133.46 508.14 425.84 -0.93 1.71 5931610.34 685804.59 GCT-MS . 61 520 . 0 39 135.49 520.61 438.31 -0.99 1.77 5931610.28 685804.65 GCT-MS . 533.13 . 0.41 134.94 533.12 450.82 -1.05 1.83 5931610.22 685804.72 GCT-MS 56 545 0 42 135.14 545.55 463.25 -1.11 1.90 5931610.16 685804.78 GCT-MS P . 07 558 . 0 42 135.58 558.06 475.76 -1.18 1.96 5931610.09 685804.85 GCT-MS . 62 570 . 0 43 135.67 570.61 488.31 -1.25 2.03 5931610.03 685804.91 GCT-MS . 92 582 . 41 0 135.20 582.91 500.61 -1.31 2.09 5931609.97 685804.98 GCT-MS . 595.24 . 0.42 135.16 595.23 512.93 -1.37 2.15 5931609.90 685805.04 GCT-MS 607 38 0 43 135.48 607.37 525.07 -1.44 2.22 5931609.84 685805.11 GCT-MS . 46 619 . 0 43 137.24 619.45 537.15 -1.50 2.28 5931609.78 685805.17 GCT-MS . 44 631 . 0 42 134.25 631.43 549.13 -1.57 2.34 5931609.71 685805.24 GCT-MS . 55 643 . 0 40 135.78 643.54 561.24 -1.63 2.40 5931609.66 685805.30 GCT-MS . 655.67 . 0.39 134.39 655.66 573.36 -1.69 2.46 5931609.60 685805.36 GCT-MS ~i 93 667 0 35 138.07 667.92 585.62 -1.74 2.52 5931609.54 685805.41 GCT-MS I . 28 680 . 0 34 145.12 680.27 597.97 -1.80 2.56 5931609.48 685805.46 GCT-MS . 58 692 . 0.35 154.11 692.57 610.27 -1.87 2.60 5931609.42 685805.50 GCT-MS . 704 88 0 41 182.59 704.87 622.57 -1.94 2.61 5931609.34 685805.52 GCT-MS . 717.15 . 0.54 205.31 717.14 634.84 -2.04 2.59 5931609.25 685805.49 GCT-MS 27 729 65 0 211.67 729.26 646.96 -2.15 2.53 5931609.14 685805.44 GCT-MS . 47 741 . 0 81 217.77 741.46 659.16 -2.28 2.44 5931609.01 685805.35 GCT-MS . 82 753 . 11 1 228.36 753.81 671.51 -2.43 2.29 5931608.86 685805.21 GCT-MS . 16 766 . 34 1 232.97 766.14 683.84 -2.59 2.09 5931608.68 685805.01 GCT-MS . 778.48 . 1.51 235.36 778.46 696.16 -2.77 1.84 5931608.50 685804.77 GCT-MS 92 790 1.88 238.56 790.89 708.59 -2.97 1.53 5931608.29 685804.46 GCT-MS . 22 803 21 2 239.95 803.19 720.89 -3.19 1.16 5931608.06 685804.09 GCT-MS ~ . 47 815 . 2 36 241.49 815.43 733.13 -3.43 0.73 5931607.81 685803.67 GCT-MS . 62 827 . 65 2 244.18 827.57 745.27 -3.67 0.26 5931607.56 685803.20 GCT-MS . 839.77 . 3.09 246.82 839.70 757.40 -3.93 -0.30 5931607.29 685802.66 GCT-MS 98 851 24 3 247.32 851.89 769.59 -4.19 -0.92 5931607.01 685802.04 GCT-MS . 19 864 . 29 3 247.93 864.08 781.78 -4.45 -1.56 5931606.73 685801.41 GCT-MS . 34 876 . 46 3 249.14 876.21 793.91 -4.71 -2.23 5931606.46 685800.75 GCT-MS . 49 888 . 61 3 249.80 888.34 806.04 -4.98 -2.93 5931606.18 685800.05 GCT-MS . 900.70 . 3.65 250.21 900.52 818.22 -5.24 -3.65 5931605.89 685799.33 GCT-MS 84 912 73 3 250.19 912.64 830.34 -5.51 -4.39 5931605.61 685798.60 GCT-MS . 96 924 . 85 3 251.78 924.73 842.43 -5.77 -5.15 5931605.33 685797.85 GCT-MS . 937 16 . 96 3 251.66 936.90 854.60 -6.03 -5.94 5931605.05 685797.07 GCT-MS . 949 23 . 01 4 251.12 948.94 866.64 -6.30 -6.73 5931604.76 685796.28 GCT-MS . 961.31 . 4.06 251.43 960.99 878.69 -6.57 -7.54 5931604.47 685795.48 GCT-MS 973.39 4.07 252.04 973.04 890.74 -6.84 -8.35 5931604.18 685794.68 GCT-MS I ~ Halliburton Global Companys BP Amoco Date: 1/9/2006 Time: 49: 24141 Page: 3 Field: Pru dhoe Bay Co-ord inate(NE) Reference: Well: 93-31, True North Site: PB 'bS 13 Vertica l (TVD) Reference: 46:3 1 4/2/1994 00: 00 82.3 ll: 13-31 W Section (VS) Referen ce: Well ( O.OON,O.OOE,40:OOAzi) e Wellpath: 13- 31A Survey Calculation Method: Minim um Curvature Db; Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 46 985 10 4 252.13 985.08 902.78 -7.10 -9.17 5931603.90 685793.87 GCT-MS . 58 997 . 4 19 252.91 997.17 914.87 -7.36 -10.00 5931603.62 685793.04 GCT-MS + . 74 1009 . 31 4 253.48 1009.30 927.00 -7.62 -10.87 5931603.33 685792.18 GCT-MS . 1021.83 . 4.37 253.58 1021.35 939.05 -7.88 -11.74 5931603.05 685791.31 GCT-MS 97 1033 42 4 253.71 1033.46 951.16 -8.15 -12.64 5931602.77 685790.43 GCT-MS . 07 1046 . 4 50 254.15 1045.52 963.22 -8.41 -13.54 5931602.49 685789.53 GGT-MS . 21 1058 . 57 4 254.56 1057.62 975.32 -8.67 -14.46 5931602.20 685788.61 GCT-MS . 28 1070 . 60 4 254.73 1069.65 987.35 -8.92 -15.39 5931601.93 685787.69 GCT-MS . 1082.38 . 4.71 254.97 1081.71 999.41 -9.18 -16.34 5931601.65 685786.75 GCT-MS 43 1094 4 90 255.68 1093.72 1011.42 -9.43 -17.32 5931601.37 685785.78 GCT-MS . 41 1106 . 4 99 256.52 1105.66 1023.36 -9.68 -18.32 5931601.09 685784.78 GCT-MS . 1118 40 . 07 5 257.15 1117.60 1035.30 -9.92 -19.35 5931600.83 685783.76 GCT-MS . 56 1130 . 21 5 257.65 1129.71 1047.41 -10.16 -20.41 5931600.57 685782.71 GCT-MS . 1142.76 . 5.31 258.27 1141.86 1059.56 -10.39 -21.50 5931600.31 685781.62 GCT-MS 96 1154 46 5 258.64 1154.01 1071.71 -10.62 -22.62 5931600.05 685780.50 GCT-MS . 17 1167 . 5 65 259.07 1166.16 1083.86 -10.85 -23.78 5931599.79 685779.35 GGT-MS . 32 1179 . 89 5 259.46 1178.25 1095.95 -11.08 -24.98 5931599.54 685778.15 GCT-MS . 47 1191 . 19 6 259.66 1190.33 1108.03 -11.31 -26.24 5931599.27 685776.90 GCT-MS . i 1203.57 . 6.53 259.45 1202.36 1120.06 -11.55 -27.56 5931599.00 685775.59 GCT-MS ~ I 73 1215 95 6 58 258 1214.43 1132.13 -11.82 -28.96 5931598.69 685774.20 GCT-MS . 97 1227 . 42 7 . 258.09 1226.58 1144.28 -12.13 -30.46 5931598.34 685772.71 GCT-MS . 12 1240 . 7 65 257.76 1238.62 1156.32 -12.47 -32.02 5931597.97 685771.16 GCT-MS . 22 1252 . 7 85 257.51 1250.61 1168.31 -12.82 -33.61 5931597.58 685769.57 GCT-MS . 1264.38 . 8.10 257.29 1262.65 1180.35 -13.18 -35.26 5931597.18 685767.94 GCT-MS 48 1276 38 8 257.25 1274.63 1192.33 -13.57 -36.95 5931596.75 685766.25 GCT-MS . 57 1288 . 67 8 257.14 1286.58 1204.28 -13.96 -38.70 5931596.31 685764.52 GCT-MS . 54 1300 . 87 8 257.09 1298.41 1216.11 -14.37 -40.48 5931595.86 685762.75 GCT-MS . 57 1312 . 02 9 256.91 1310.30 1228.00 -14.79 -42.30 5931595.40 685760.94 GCT-MS . 1324.38 . 9.10 256.97 1321.96 1239.66 -15.21 -44.11 5931594.93 685759.14 GCT-MS 37 1336 13 9 256.77 1333.80 1251.50 -15.64 -45.96 5931594.45 685757.30 GCT-MS . 18 1348 . 20 9 256.78 1345.46 1263.16 -16.07 -47.79 5931593.98 685755.48 GCT-MS . 99 1359 . 34 9 256.81 1357.11 1274.81 -16.51 -49.64 5931593.50 685753.64 GCT-MS . 81 1371 . 48 9 256.72 1368.78 1286.48 -16.95 -51.52 5931593.01 685751.77 GCT-MS . 1383.42 . 9.59 256.76 1380.22 1297.92 -17.39 -53.40 5931592.52 685749.91 GCT-MS 28 1395 74 9 256.76 1391.92 1309.62 -17.85 -55.33 5931592.02 685747.98 GCT-MS . 93 1406 . 82 9 256.76 1403.40 1321.10 -18.30 -57.26 5931591.52 685746.07 GCT-MS . 66 1418 . 86 9 256.64 1414.95 1332.65 -18.76 -59.21 5931591.01 685744.13 GCT-MS . 45 1430 . 96 9 256.71 1426.57 1344.27 -19.23 -61.19 5931590.49 685742.17 GCT-MS . 1442.14 . 10.10 256.67 1438.08 1355.78 -19.70 -63.17 5931589.98 685740.20 GCT-MS 83 1453 17 10 256.77 1449.59 1367.29 -20.17 -65.17 5931589.46 685738.21 GCT-MS . 54 1465 . 24 10 256.76 1461.11 1378.81 -20.65 -67.19 5931588.93 685736.20 GCT-MS . 22 1477 . 32 10 256.83 1472.60 1390.30 -21.12 -69.22 5931588.41 685734.18 GCT-MS . 83 1488 . 44 10 256.95 1484.02 1401.72 -21.60 -71.26 5931587.88 685732.16 GCT-MS . 1500.50 . 10.53 257.09 1495.50 1413.20 -22.07 -73.32 5931587.35 685730.10 GCT-MS 00 1514 57 10 257.08 1508.77 1426.47 -22.63 -75.73 5931586.74 685727.71 GCT-MS . 75 1528 . 64 10 257.15 1523.27 1440.97 -23.23 -78.38 5931586.07 685725.08 GCT-MS . 22 1545 . 69 10 257.19 1539.46 1457.16 -23.91 -81.35 5931585.32 685722.12 GCT-MS . 38 1563 . 87 10 257.60 1557.29 1474.99 -24.65 -84.67 5931584.50 685718.83 GCT-MS . 1584.34 . 11.01 257.95 1577.87 1495.57 -25.49 -88.55 5931583.56 685714.96 GCT-MS 25 j 1611 15 11 258.62 1604.28 1521.98 -26.54 -93.62 5931582.39 685709.93 GCT-MS . 82 1640 . 27 11 259.62 1633.29 1550.99 -27.63 -99.26 5931581.16 685704.31 GCT-MS . 80 1671 . 37 11 261.12 1663.67 1581.37 -28.64 -105.26 5931580.00 685698.34 GCT-MS . 1704.74 . 11.57 262.60 1695.95 1613.65 -29.57 -111.74 5931578.91 685691.88 GCT-MS Halliburton Global Company: BP Amoco Date: 1/9/2006 Time: 19 :24:41 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 13-31, True North Site:. PB DS 13 Vertica l (TVD) Reference: 46:3 1 4/2/1994 00; 00 82.3 Well's 13= 31 Section (VS) Referen ce: Well (O.OON;O:OOE,40.OOAzi) i Wellpath: 13- 31A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft ~ 1737.10 11.74 263.69 1727.64 1645.34 -30.35 -118.23 5931577.97 685685.41 GCT-MS 1I 1769 46 12 03 264.46 1759.31 1677.01 -31.04 -124.86 5931577.12 685678.80 GCT-MS . 1802 02 . 12 33 265.28 1791.13 1708.83 -31.65 -131.70 5931576.34 685671.98 GCT-MS I . 1834 32 . 12.44 265.37 1822.68 1740.38 -32.21 -138.61 5931575.61 685655.09 GCT-MS i . 72 1866 12 70 265.71 1854.31 1772.01 -32.76 -145.64 5931574.89 685658.08 GCT-MS . 1899.97 . 13.32 266.14 1886.70 1804.40 -33.29 -153.10 5931574.17 685650.63 GCT-MS 1934 07 14 31 266.29 1919.82 1837.52 -33.83 -161.23 5931573.44 685642.52 GCT-MS i . 14 1968 . 15 48 266.00 1952.74 1870.44 -34.42 -169.97 5931572.63 685633.80 GCT-MS . 2002 11 . 89 16 265.38 1985.36 1903.06 -35.13 -179.41 5931571.69 685624.38 GCT-MS ' . 25 2036 . 18 30 264.54 2017.90 1935.60 -36.04 -189.69 5931570.52 685614.12 GCT-MS . 2069.91 . 19.46 263.65 2049.75 1967.45 -37.17 -200.52 5931569.13 685603.32 GCT-MS 94 2102 20.47 262.57 2080.80 1998.50 -38.52 -211.72 5931567.50 685592.16 GCT-MS . 23 2136 21 39 261.69 2111.89 2029.59 -40.15 -223.50 5931565.58 685580.43 GCT-MS . 93 2169 . 22 32 261.06 2143.17 2060.87 -42.04 -235.90 5931563.40 685568.08 GCT-MS . 60 2203 . 60 23 260.39 2174.17 2091.87 -44.15 -248.86 5931560.96 685555.17 GCT-MS . 2237.03 . 24.73 260.07 2204.67 2122.37 -46.48 -262.35 5931558.31 685541.75 GCT-MS 82 2270 78 25 259.73 2235.23 2152.93 -49.01 -276.54 5931555.43 685527.62 GCT-MS . 2304 39 . 26 89 259.06 2265.32 2183.02 -51.75 -291.18 5931552.33 685513.06 GCT-MS . 20 2338 . 61 27 258.45 2295.37 2213.07 -54.77 -306.36 5931548.93 685497.96 GCT-MS . 2371 92 . 28 23 257.57 2325.17 2242.87 -58.05 -321.80 5931545.27 685482.60 GCT-MS . 2405.74 . 28.79 256.57 2354.89 2272.59 -61.66 -337.54 5931541.27 685466.96 GCT-MS i 79 2439 29 08 256.49 2384.69 2302.39 -65.50 -353.56 5931537.04 685451.04 GCT-MS . 90 2473 . 44 29 257.00 2414.45 2332.15 -69.32 -369.78 5931532.82 685434.91 GCT-MS . 16 2508 . 29.89 257.63 2444.21 2361.91 -73.04 -386.33 5931528.70 685418.47 GCT-MS . 2542 45 30 39 258.44 2473.87 2391.57 -76.61 -403.17 5931524.71 685401.72 GCT-MS . 2577.25 . 31.05 259.49 2503.79 2421.49 -80.01 -420.62 5931520.88 685384.36 GCT-MS 2612 15 31 82 260.67 2533.56 2451.26 -83.15 -438.55 5931517.31 685366.52 GCT-MS ~ I . 2647 33 . 32 23 260.90 2563.39 2481.09 -86.13 -456.96 5931513.87 685348.18 GCT-MS . 2682 83 . 32.58 260.64 2593.36 2511.06 -89.19 -475.74 5931510.36 685329.48 GCT-MS . 31 2718 94 32 259.98 2623.20 2540.90 -92.42 -494.66 5931506.66 685310.65 GCT-MS . 2753.88 . 33.19 259.40 2653.01 2570.71 -95.89 -513.76 5931502.72 685291.65 GCT-MS 05 2789 51 33 258.96 2682.39 2600.09 -99.52 -532.75 5931498.62 685272.75 GCT-MS . 2823 66 . 85 33 258.92 2711.19 2628.89 -103.20 -551.58 5931494.48 685254.01 GCT-MS . 77 2858 . 34.34 258.70 2740.26 2657.96 -107.02 -570.89 5931490.19 685234.81 GCT-MS . 69 2893 34 93 258.39 2768.99 2686.69 -110.97 -590.34 5931485.77 685215.46 GCT-MS . 2928.73 . 35.39 258.13 2797.64 2715.34 -115.07 -610.10 5931481.18 685195..81 GCT-MS 2963.73 35.93 257.37 2826.08 2743.78 -119.40 -630.04 5931476.36 685175.99 GCT-MS 01 2999 36.49 257.22 2854.54 2772.24 -123.99 -650.37 5931471.27 685155.78 GCT-MS . 3034 05 37.47 257.07 2882.53 2800.23 -128.68 -670.92 5931466.08 685135.35 GCT-MS . 30 3069 91 38 257.10 2910.24 2827.94 -133.55 -692.16 5931460.69 685114.23 GCT-MS . 3104.29 . 40.15 257.47 2937.23 2854.93 -138.45 -713.88 5931455.25 685092.64 GCT-MS 52 3139 41 37 258.43 2963.91 2881.61 -143.25 -736.38 5931449.90 685070.27 GCT-MS . 3174 60 . 31 42 259.05 2990.05 2907.75 -147.81 -759.33 5931444.77 685047.44 GCT-MS . 70 3209 . 42 72 259.13 3015.92 2933.62 -152.30 -782.62 5931439.71 685024.27 GCT-MS . 3244 76 . 42 55 258.55 3041.71 2959.41 -156.90 -805.92 5931434.54 685001.09 GCT-MS . 3279.82 . 42.49 257.98 3067.55 2985.25 -161.72 -829.12 5931429.15 684978.02 GCT-MS 3314 88 42.77 257.49 3093.35 3011.05 -166.76 -852.32 5931423.54 684954.95 GCT-MS . 62 3349 43 25 256.66 3118.75 3036.45 -172.06 -875.42 5931417.67 684931.99 GCT-MS . 3384 50 . 43 85 256.39 3144.03 3061.73 -177.66 -898.79 5931411.50 684908.77 GCT-MS I . 67 3419 . 44 62 256.28 3169.23 3086.93 -183.46 -922.63 5931405.12 684885.08 GCT-MS . 3454.86 . 46.00 256.33 3193.98 3111.68 -189.38 -946.93 5931398.60 684860.93 GCT-MS 3489.68 46.68 256.85 3218.02 3135.72 -195.22 -971.43 5931392.16 684836.58 GCT-MS - ~ Halliburton Global Company: BP Amoco Date: 1/9/2006 Time: 19:24:41 Page:. 5 Field: Pru dhoe Bay Co-ordinate(NE) Reference: WeI L 13-31, True North Site: PB DS 13 Vertica l (TVD) Reference: 46: 31 4/2/1994 00: 0082.3 Well: 13-31 Section (VS) Referen ce: Well (O.OOtJ;0.00E,40.00Azi) Wellpath: 13- 31A Survey Calculation Method: Mini mum Curvature Db: Qracle Survey - ~ MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ~ ft deg deg ft ft ft ft ft ft I 98 3523 46 67 257.02 3241.55 3159.25 -200.87 -995.74 5931385.92 684812.42 GCT-MS I . 3558 00 . 91 45 257.46 3265.06 3182.76 -206.30 -1019.72 5931379.90 684788.58 GCT-MS . 3592 43 . 45 78 257.38 3289.04 3206.74 -211.68 -1043.83 5931373.93 684764.61 GCT-MS . 3626.68 . 45.54 257.35 3312.98 3230.68 -217.04 -1067.74 5931367.98 684740.85 GCT-MS 3661 35 46 26 256.62 3337.11 3254.81 -222.64 -1091.99 5931361.78 684716.74 GCT-MS . 3695 88 . 77 46 256.51 3360.87 3278.57 -228.46 -1116.36 5931355.36 684692.52 GCT-MS . 3730 67 . 12 47 256.51 3384.62 3302.32 -234.39 -1141.08 5931348.83 684667.96 GCT-MS . 3765 23 . 22 48 256.23 3407.89 3325.59 -240.42 -1165.91 5931342.20 684643.29 GCT-MS . 3799.94 . 48.80 256.00 3430.89 3348.59 -246.66 -1191.15 5931335.34 684618.21 GCT-MS 3834 38 90 48 255.79 3453.55 3371.25 -252.98 -1216.30 5931328.40 684593.22 GCT-MS . 3869 02 . 87 48 255.75 3476.33 3394.03 -259.39 -1241.60 5931321.37 684568.09 GCT-MS . 77 3903 . 48 72 255.66 3499.22 3416.92 -265.85 -1266.93 5931314.29 684542.93 GCT-MS . 3938 07 . 48 68 255.60 3521.86 3439.56 -272.24 -1291.90 5931307.28 684518.13 GCT-MS . 3972.73 . 48.53 255.64 3544.78 3462.48 -278.70 -1317.08 5931300.21 684493.11 GCT-MS 4007 03 48 41 255.61 3567.52 3485.22 -285.07 -1341.95 5931293.22 684468.41 GCT-MS . 4041 37 . 48 32 255.64 3590.33 3508.03 -291.45 -1366.82 5931286.24 684443.71 GCT-MS . 4075 74 . 48 20 255.59 3613.21 3530.91 -297.82 -1391.66 5931279.26 684419.03 GCT-MS . 31 4110 . 22 48 255 50 3636.25 3553.95 -304.25 -1416.62 5931272.21 684394.24 GCT-MS . 4144.57 . 48.18 . 255.46 3659.09 3576.79 -310.65 -1441.34 5931265.20 684369.69 GCT-MS 94 4178 48 22 40 255 3682.00 3599.70 -317.10 -1466.14 5931258.15 684345.05 GCT-MS . 76 4212 . 48 01 . 255.37 3704.58 3622.28 -323.45 -1490.50 5931251.20 684320.86 GCT-MS . 44 4246 . 47 64 255.43 3727.19 3644.89 -329.74 -1514.66 5931244.32 684296.87 GCT-MS . 4280 20 . 47 82 45 255 3749.90 3667.60 -336.02 -1538.84 5931237.44 684272.85 GCT-MS . 4313.79 . 47.96 . 255.50 3772.42 3690.12 -342.27 -1562.96 5931230.60 684248.89 GCT-MS 4347 55 47 57 255.58 3795.11 3712.81 -348.52 -1587.16 5931223.77 684224.85 GCT-MS . 4381 24 . 47 44 255.54 3817.87 3735.57 -354.71 -1611.22 5931216.98 684200.95 GCT-MS . 4414 79 . 47 21 42 255 3840.61 3758.31 -360.89 -1635.10 5931210.21 684177.24 GCT-MS . 4448 49 . 46 95 . 254.96 3863.56 3781.26 -367.20 -1658.96 5931203.32 684153.54 GCT-MS . 4482.06 . 46.77 254.66 3886.52 3804.22 -373.62 -1682.60 5931196.32 684130.07 GCT-MS 4515 49 64 46 254.61 3909.44 3827.14 -380.07 -1706.06 5931189.30 684106.77 GCT-MS . 4548 96 . 46 60 254.64 3932.43 .3850.13 -386.52 -1729.51 5931182.27 684083.48 GCT-MS . 48 4582 . 46 78 254 88 3955.42 3873.12 -392.93 -1753.05 5931175.29 684060.12 GCT-MS . 4615 75 . 47 43 . 255.19 3978.07 3895.77 -399.22 -1776.59 5931168.42 684036.73 GCT-MS . ~ 4648.99 . 47.85 255.44 4000.46 3918.16 -405.45 -1800.35 5931161.61 684013.14 GCT-MS 29 4682 47 73 58 255 4022.84 3940.54 -411.62 -1824.23 5931154.85 683989.42 GCT-MS . 47 4715 . 47 72 . 255.73 4045.16 3962.86 -417.70 -1848.02 5931148.18 683965.79 GCT-MS . 92 4748 . 47 69 255.75 4067.67 3985.37 -423.80 -1872.00 5931141.50 683941.97 GCT-MS . 4782 45 . 47.67 255.76 4090.24 4007.94 -429.90 -1896.03 5931134.81 683918.10 GCT-MS . 4815.93 47.40 255.69 4112.85 4030.55 -435.99 -1919.96 5931128.13 683894.32 GCT-MS 4849 68 47 33 255.75 4135.71 4053.41 -442.11 -1944.03 5931121.42 683870.42 GCT-MS . 17 4883 . 47 37 82 255 4158.40 4076.10 -448.16 -1967.90 5931114.79 683846.70 GCT-MS . 13 4916 . 47 13 . 255.86 4180.77 4098.47 -454.08 -1991.37 5931108.29 683823.39 GCT-MS . 4948 94 . 47 06 255.75 4203.11 4120.81 -459.98 -2014.67 5931101.82 683800.24 GCT-MS . 4982.13 . 46.86 255.76 4225.76 4143.46 -465.94 -2038.18 5931095.28 683776.88 GCT-MS 5014 95 72 46 255.70 4248.23 4165.93 -471.84 -2061.37 5931088.81 683753.85 GCT-MS . 48 5048 . 46.65 255.87 4271.23 4188.93 -477.83 -2085.02 5931082.24 683730.36 GCT-MS . 5082 35 46 60 256.56 4294.49 4212.19 -483.70 -2108.93 5931075.79 683706.60 GCT-MS . 5116 51 . 21 46 257.52 4318.05 4235.75 -489.25 -2133.03 5931069.65 683682.64 GCT-MS . 5150.31 . 46.21 257.63 4341.44 4259.14 -494.50 -2156.86 5931063.82 683658.95 GCT-MS 26 5184 46 27 257.73 4364.92 4282.62 -499.73 -2180.82 5931058.00 683635.13 GCT-MS . 31 5218 . 45 98 258.04 4388.52 4306.22 -504.88 -2204.82 5931052.26 683611.27 GCT-MS . 73 5252 . 46 05 258.50 4412.42 4330.12 -509.91 -2229.06 5931046.63 683587.15 GCT-MS . 5287.01 . 46.84 259.44 4436.04 4353.74 -514.67 -2253.45 5931041_28 683562.90 GCT-MS Halliburton ~~ Global Company: BP Amoco Field: Prudhoe Bay Site: PB DS 13 Well: 13-31 Wellpath: 13-31A Date: 1/9/2006 Time: 19:24:41 page: 6 Co-ordinate(NE)Reference; Well: 1331; True North Vertical (TVD) Reference: 46:31 4/2/1994 00:00'82:3 Section (VS) Reference: WeB (O.OON,O:OOE,40:OOAzi) Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE ToQI '~ ft deg deg ft ft ft ft ft ft 5321.27 47.32 261.35 4459.37 4377.07 -518.85 -2278.18 5931036.48 683538.27 GCT-MS ' 42 5355 44 47 262.71 4482.50 4400.20 -522.33 -2303.07 5931032.39 683513.48 GCT-MS !~ ' . 5389 87 . 81 47 263.35 4505.72 4423.42 -525.42 -2328.33 5931028:68 683488.31 GCT-MS , . I 07 i 5424 . 09 48 263.76 4528.62 4446.32 -528.27 -2353.57 5931025.21 683463.15 ' GCT-MS . 5458 23 . 66 47 264.91 4551.54 4469.24 -530.77 -2378.78 5931022.09 683438.01 GCT-MS . 5492.48 . 48.41 265.83 4574.44 4492.14 -532.83 -2404.16 5931019.41 683412.69 GCT-MS 5526 59 95 48 266.35 4596.96 4514.66 -534.58 -2429.72 5931017.04 683387.18 GCT-MS . 5560 82 . 07 49 63 266 4619.41 4537.11 -536.16 -2455.51 5931014.82 683361.44 GCT-MS . 55 5594 . 07 49 . 266.63 4641.51 4559.21 -537.66 -2480.95 5931012.70 683336.05 GCT-MS . 5628 23 . 69 48 266.59 4663.66 4581.36 -539.16 -2506.27 5931010.57 683310.76 GCT-MS . 5661.73 . 48.51 266.66 4685.81 4603.51 -540.63 -2531.36 5931008.48 683285.73 GCT-MS 5695 42 48 39 266.79 4708.16 4625.86 -542.08 -2556.53 5931006.42 683260.60 GCT-MS . 5728 77 . 48 20 266.96 4730.35 4648.05 -543.43 -2581.39 5931004.45 683235.78 GCT-MS . 5762 06 . 94 47 267 03 4752.59 4670.29 -544.73 -2606.13 5931002.54 683211.09 GCT-MS . 5795 41 . 47 73 . 07 267 4774.98 4692.68 -546.00 -2630.81 5931000.66 683186.44 GCT-MS . 5829.04 . 47.67 . 267.14 4797.61 4715.31 -547.26 -2655.65 5930998.79 683161.64 GCT-MS i 5862 78 59 48 39 266 4820.13 4737.83 -548.68 -2680.74 5930996.76 683136.60 GCT-MS ~i . 5896 38 . 13 49 . 265.71 4842.24 4759.94 -550.42 -2705.98 5930994.39 683111.41 GCT-MS . 5930 12 . 64 48 266.10 4864.42 4782.12 -552.24 -2731.34 5930991.95 683086.11 GCT-MS . 5963 74 . 86 48 266.32 4886.59 4804.29 -553.91 -2756.56 5930989.66 683060.94 GCT-MS . 5997.41 . 49.47 267.41 4908.61 4826.31 -555.30 -2781.99 5930987.65 683035.54 GCT-MS I ' 6030 82 55 50 09 267 4930.08 4847.78 -556.53 -2807.56 5930985.79 683010.02 GCT-MS . 6064 52 . 03 51 . 80 265 4951.38 4869.08 -558.15 -2833.62 5930983.53 682984.00 GCT-MS . 6098 08 . 51 28 . 264.99 4972.43 4890.13 -560.25 -2859.67 5930980.79 682958.01 GCT-MS . 6131 57 . 11 52 263.86 4993.19 4910.89 -562.80 -2885.83 5930977.59 682931.93 GCT-MS , 6165.26 . 52.32 263.29 5013.83 4931.53 -565.78 -2912.29 5930973.96 682905.55 GCT-MS 6198 73 30 52 18 263 5034.30 4952.00 -568.90 -2938.59 5930970.20 682879.34 GCT-MS ~ . 6232 58 . 52 52 . 263.25 5054.95 4972.65 -572.07 -2965.22 5930966.37 682852.79 GCT-MS . 6265 88 . 16 52 263.38 5075.29 4992.99 -575.14 -2991.41 5930962.66 682826.70 GCT-MS . 6298 73 . 24 52 263.29 5095.42 5013.12 -578.15 -3017.19 5930959.01 682801.00 GCT-MS . i 6331.83 . 51.88 262.15 5115.78 5033.48 -581.46 -3043.08 5930955.07 682775.19 GCT-MS 6364 60 51 59 261 36 5136.07 5053.77 -585.15 -3068.54 5930950.76 682749.83 GCT-MS . 6397 71 . 51 69 . 261.31 5156.62 5074.32 -589.06 -3094.21 5930946.21 682724.27 GCT-MS . 6430 50 . 39 51 41 261 5177.01 5094.71 -592.92 -3119.59 5930941.73 682698.99 GCT-MS . 42 6463 . 50 96 . 261.41 5197.65 5115.35 -596.75 -3144.95 5930937.28 682673.74 GCT-MS . 6496.42 . 50.55 261.11 5218.53 5136.23 -600.63 -3170.21 5930932.78 682648.58 GCT-MS 6529 27 33 50 260.78 5239.45 5157.15 -604.62 -3195.22 5930928.18 682623.68 GCT-MS . 26 6562 . 45 50 261.05 5260.48 5178.18 -608.63 -3220.32 5930923.55 682598.69 GCT-MS . 15 6595 . 53 50 261 39 5281.41 5199.11 -612.50 -3245.40 5930919.06 682573.72 GCT-MS . 6628 10 . 63 50 . 64 261 5302.33 5220.03 -616.26 -3270.57 5930914.68 682548.64 GCT-MS . 6661.18 . 50.68 . 261.75 5323.30 5241.00 -619.95 -3295.89 5930910.37 682523.43 GCT-MS 6694 13 75 50 261.64 5344.17 5261.87 -623.64 -3321.12 5930906.06 682498.29 GCT-MS . 6726 97 . 13 50 68 260 5365.08 5282.78 -627.53 -3346.14 5930901.56 682473.38 GCT-MS . 95 6759 . 49 53 . 42 259 5386.36 5304.06 -631.88 -3370.96 5930896.60 682448.67 GCT-MS . 6793 09 . 65 49 . 259.54 5407.84 5325.54 -636.49 -3395.77 5930891.38 682423.99 GCT-MS . 6825.76 . 49.47 259.94 5429.03 5346.73 -640.92 -3420.24 5930886.35 682399.64 GCT-MS 13 6858 58 49 260.08 5450.04 5367.74 -645.19 -3444.49 5930881.48 682375.50 GCT-MS . 59 6890 . 74 48 75 259 5471.27 5388.97 -649.49 -3468.67 5930876.59 682351.44 GCT-MS . 6923 58 . 47 59 . 24 258 5493.28 5410.98 -654.18 -3492.79 5930871.31 682327.44 GCT-MS . . . $ 87 682280 GCT MS 6988.64 47.50 257.89 5537.32 5455.02 664.17 3539.62 5930860.1 . 7021.05 47.43 257.83 5559.22 5476.92 -669.19 -3562.98 5930854.57 682257.64 GCT-MS _ ____ Halliburton Global Company: BP Amoco Date: 1/9/2006 Time: 19:24:41 Page: 7 Field- Pru dhoe $ay Co-ordinate(NE) Reference: WeIL 13 31, True N orth Site: PB DS 13 Vertica l (TVD) Reference: 46 :31 4/2/1994 00 :00 82.3 Well: 13= 31 Section (VS) Reference: Well (O.OON,O:OOE,40.OOAzi) Wellpath: 13- 31A Survey Calculation Method: Minimum Curvature Db: Oracle Survey ~ MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool P ft deg deg ft ft ft ft ft ft 057 3 71 47.25 257.38 5581.35 5499.05 -674.35 -3586.44 5930848.84 682234.32 GCT-MS 7086 05 47.03 256.95 5603.35 5521.05 -679.61 -3609.55 5930843.01 682211.34 GCT-MS . 7118.67 46.90 256.89 5625.61 5543.31 -685.01 -3632.78 5930837.04 682188.26 GCT-MS 7151.05 46.87 256.89 5647.74 5565.44 -690.37 -3655.80 5930831.12 682165.38 GCT-MS 52 7183 46.82 256.78 5669.95 5587.65 -695.77 -3678.86 5930825.16 682142.46 GCT-MS . 7215 82 46.73 256.83 5692.07 5609.77 -701.14 -3701.78 5930819.22 682119.68 GCT-MS ~ . 34 7248 46 67 256.70 5714.37 5632.07 -706.56 -3724.82 5930813.24 682096.79 GCT-MS ~ . 64 7280 . 46.37 256.18 5736.60 5654.30 -712.05 -3747.60 5930807.18 682074.15 GCT-MS . 7313.08 46.39 255.36 5758.98 5676.68 -717.82 -3770.36 5930800.85 682051.53 GCT-MS 45 7345 46.33 254.37 5781.32 5699.02 -723.94 -3792.98 5930794.18 682029.08 GCT-MS 11 . 7377 97 46 23 253.67 5803.79 5721.49 -730.41 -3815.57 5930787.16 682006.65 GCT-MS . 7410 27 . 46 10 253.23 5826.16 5743.86 -737.05 -3837.91 5930779.97 681984.49 GCT-MS . 7442.68 . 45.99 252.61 5848.66 5766.36 -743.90 -3860.21 5930772.58 681962.36 GCT-MS 7475.08 45.79 251.81 5871.21 5788.91 -751.01 -3882.36 5930764.93 681940.40 GCT-MS 87 7506 45.38 251.40 5893.46 5811.16 -758.17 -3903.91 5930757.23 681919.03 GCT-MS . 27 7537 45.37 251.20 5914.81 5832.51 -765.11 -3924.40 5930749.79 681898.72 GCT-MS . 07 7567 45.47 251.15 5935.73 5853.43 -771.96 -3944.49 5930742.45 681878.80 GCT-MS . 7596 23 44.90 251.20 5956.28 5873.98 -778.63 -3964.07 5930735.30 681859.40 GCT-MS . 7623.88 45.00 251.12 5975.85 5893.55 -784.94 -3982.56 5930728.54 681841.07 GCT-MS ! 99 7649 45.17 251.06 5994.29 5911.99 -790.93 -4000.05 5930722.12 681823.73 GCT-MS . 7675.38 44.66 250.97 6012.27 5929.97 -796.77 -4017.00 5930715.87 681806.93 GCT-MS 37 7699 44.51 250.62 6029.35 5947.05 -802.30 -4032.90 5930709.94 681791.17 GCT-MS . 48 7722 44.64 250.69 6045.81 5963.51 -807.68 -4048.21 5930704.19 681776.00 GCT-MS . 7744.73 44.64 251.23 6061.65 5979.35 -812.78 -4062.99 5930698.73 681761.36 GCT-MS 61 7766 44.25 252.38 6077.27 5994.97 -817.56 -4077.54 5930693.59 681746.92 i GCT-MS . 7785 60 44.48 253.12 6090.84 6008.54 -821.50 -4090.22 5930689.34 681734.34 GCT-MS . 98 7803 44.63 253.39 6103.94 6021.64 -825.21 -4102.57 5930685.32 681722.09 GCT-MS . 26 7822 44.81 253.69 6116.93 6034.63 -828.86 -4114.90 5930681.38 681709.85 GCT-MS . 7840.67 44.66 254.32 6130.01 6047.71 -832.43 -4127.36 5930677.50 681697.49 GCT-MS 02 7859 44.36 255.22 6143.09 6060.79 -835.81 -4139.77 5930673.82 681685.16 GCT-MS . 7877 27 44.39 255.81 6156.14 6073.84 -839.00 -4152.13 5930670.32 681672.89 GCT-MS , . 51 7895 44.24 256.48 6169.19 6086.89 -842.05 -4164.50 5930666.97 681660.60 GCT-MS }j . 94 7913 44.13 257.15 6182.41 6100.11 -844.98 -4177.01 5930663.73 681648.17 ( GCT-MS . 7932.55 44.17 257.65 6195.76 6113.46 -847.81 -4189.66 5930660.59 681635.59 GCT-MS { 06 I 7951 44.39 258.03 6209.01 6126.71 -850.53 -4202.29 5930657.56 681623.03 GCT-MS . 61 7969 44.59 258.50 6222.24 6139.94 -853.18 -4215.02 5930654.60 681610.37 GCT-MS . 19 7988 44 68 258.61 6235.46 6153.16 -855.77 -4227.81 5930651.70 681597.65 GCT-Mfi . 8006.70 . 44.49 258.68 6248.65 6166.35 -858.33 -4240.55 5930648.83 681584.97 GCT-MS ~ 8025.24 44.62 258.60 6261.86 6179.56 -860.89 -4253.31 5930645.95 681572.29 GCT-MS 93 8043 44 38 258.53 6275.19 6192.89 -863.48 -4266.15 5930643.04 681559.52 GCT-MS . 47 8062 . 44 37 258.43 6288.44 6206.14 -866.07 -4278.85 5930640.14 681546.88 GCT-MS . 06 8081 . 35 44 258.35 6301.73 6219.43 -868.69 -4291.58 5930637.21 681534.22 GCT-MS . 58 8099 . 44 49 258.25 6314.96 6232.66 -871.32 -4304.27 5930634.27 681521.60 GCT-MS . 8118.08 . 44.54 258.36 6328.15 6245.85 -873.95 -4316.98 5930631.33 681508.96 GCT-MS 77 8136 44 69 258.54 6341.46 6259.16 -876.58 -4329.84 5930628.39 681496.17 GCT-MS . 8155.30 . 45.01 258.71 6354.59 6272.29 -879.15 -4342.65 5930625.50 681483.43 GCT-MS I 8173 83 45.31 258.79 6367.66 6285.36 -881.72 -4355.53 5930622.62 681470.61 GCT-MS . 38 8192 45 46 258.91 6380.69 6298.39 -884.27 -4368.49 5930619.75 681457.72 GCT-MS , . 8210.83 . 45.39 259.02 6393.64 6311.34 -886.79 -4381.39 5930616.91 681444.89 GCT-MS 3 14 8229 64 45 259.14 6406.47 6324.17 -889.26 -4394.22 5930614.12 681432.13 GCT-MS . 18 8247 . 14 46 259.18 6419.02 6336.72 -891.70 -4406.94 5930611.38 681419.47 GCT-MS . 8265 66 . 46 50 259.17 6431.79 6349.49 -894.21 -4420.06 5930608.54 681406.41 GCT-MS . 8284.25 . 46.23 259.30 6444.61 6362.31 -896.72 -4433.28 5930605.71 681393.26 GCT-MS Halliburton • Global Company: BP Amoco Date: 1/9/2006 Time: 19:24:41 Pager 8 Field: Pru dhoe Bay Co-ord inate(NE) Reference: Well : 13-31, True N orth Site: PB DS 13 Vertica l (TVD) Reference: 46: 31 4/2/1994 00: 00 82.3 1 Well: 13-31 Section (VS) Referen ce: Well (O.OON,O:OOE,40:OOAzi) Wellpath: 13- 31A Survey Calculation Method: Minimum Curvature Db: Oracle Survey -- MD lncl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 8302.92 45.93 259.44 6457.57 6375.27 -899.20 -4446.50 5930602.90 681380.11 GCT-MS 1 8321 42 46.09 259.36 6470.41 6388.11 -901.65 -4459.58 5930600.13 681367.09 GCT-MS I . 8340 08 46.26 259.34 6483.34 6401.04 -904.14 -4472.81 5930597.32 681353.93 GCT-MS ~ . 8358.58 46.10 259.34 6496.14 6413.84 -906.61 -4485.93 5930594.53 681340.87 GCT-MS ~ 8377 19 45.82 259.40 6509.08 6426.78 -909.07 -4499.08 5930591.74 681327.79 GCT-MS ~ . 8395.81 45.85 259.30 6522.05 6439.75 -911.54 -4512.21 5930588.95 681314.73 GCT-MS ~ I 8414 38 46.15 259.32 6534.95 6452.65 -914.02 -4525.33 5930586.15 681301.67 GCT-MS . 8432 98 46.49 259.46 6547.80 6465.50 -916.50 -4538.55 5930583.34 681288.51 GCT-MS . 8451 56 46.65 259.48 6560.57 6478.27 -918.96 -4551.82 5930580.55 681275.31 GCT-MS ~ . 99 8469 46.54 259.57 6573.24 6490.94 -921.40 -4564.99 5930577.80 681262.21 GCT-MS . 8488.67 46.70 259.76 6586.07 6503.77 -923.83 -4578.34 5930575.03 681248.92 GCT-MS 8507 03 47.12 259.84 6598.61 6516.31 -926.21 -4591.54 5930572.33 681235.79 GCT-MS ~ . 8525 44 47.40 259.88 6611.10 6528.80 -928.59 -4604.85 5930569.63 681222.54 GCT-MS . 64 8543 47.37 260.05 6623.43 6541.13 -930.92 -4618.04 5930566.97 681209.41 GCT-MS . 8562 00 47 24 260.31 6635.88 6553.58 -933.22 -4631.33 5930564.34 681196.18 GCT-MS i . 8580.48 . 47.17 260.49 6648.43 6566.13 -935.48 -4644.70 5930561.75 681182.87 GCT-MS 52 8599 47.29 260.66 6661.36 6579.06 -937.77 -4658.49 5930559.12 681169.14 GCT-MS . 64 8618 47.32 260.76 6674.33 6592.03 -940.04 -4672.36 5930556.51 681155.33 GCT-MS . 8637 26 46.67 261.19 6687.03 6604.73 -942.18 -4685.81 5930554.05 681141.94 GCT-MS . 8654 62 46.48 261.17 6698.96 6616.66 -944.11 -4698.27 5930551.81 681129.54 GCT-MS . 8669.08 46.62 261.16 6708.90 6626.60 -945.72 -4708.64 5930549.94 681119.21 GCT-MS ~ 40 8683 46.85 261.13 6718.72 6636.42 -947.33 -4718.94 5930548.08 681108.95 GCT-MS . 8697 72 47.16 261.12 6728.48 6646.18 -948.94 -4729.29 5930546.21 681098.64 GCT-MS . 05 8712 47.10 261.13 6738.23 6655.93 -950.56 -4739.67 5930544.34 681088.31 GCT-MS . 8726 38 47.06 260.96 6747.99 6665.69 -952.20 -4750.04 5930542.45 681077.99 GCT-MS . 8740.78 47.28 260.89 6757.78 6675.48 -953.86 -4760.46 5930540.53 681067.60 GCT-MS 12 8755 47.48 260.96 6767.49 6685.19 -955.53 -4770.88 5930538.61 681057.23 GCT-MS . 45 8769 47.70 261.03 6777.16 6694.86 -957.18 -4781.33 5930536.70 681046.82 GCT-MS . 8783.73 47.84 260.97 6786.75 6704.45 -958.84 -4791.78 5930534.79 681036.42 GCT-MS 8798 16 47.83 261.04 6796.44 6714.14 -960.51 -4802.34 5930532.85 681025.90 GCT-MS . 8812.52 47.98 261.11 6806.07 6723.77 -962.16 -4812.87 5930530.94 681015.42 GCT-MS 63 8827 48.20 261.15 6816.16 6733.8E -963.90 -4823.98 5930528.94 681004.36 GCT-MS . 61 8846 48.31 261,26 6828.80 6746.5u -966.06 -4837.97 5930526.43 680990.42 GCT-MS . 8866 68 48.22 261.50 6842.16 6759.86 -968.31 -4852.78 5930523.82 680975.68 GCT-MS . 8887 51 47.86 262.16 6856.08 6773.78 -970.51 -4868.11 5930521.24 680960.40 GCT-MS . 8908.79 47.99 262.39 6870.34 6788.04 -972.63 -4883.77 5930518.73 680944.81 GCT-MS 8930 19 48.21 262.73 6884.64 6802.34 -974.69 -4899.56 5930516.28 680929.07 GCT-MS . ~ 8954 47 48.04 263.10 6900.84 6818.54 -976.92 -4917.50 5930513.61 680911.19 GCT-MS . 8979 28 48.09 263.05 6917.42 6835.12 -979.15 -4935.82 5930510.94 680892.93 GCT-MS . 83 9005 70 48 262.74 6935.05 6852.75 -981.60 -4955.52 5930508.00 680873.30 GCT-MS . 9031.66 . 49.08 262.48 6952.03 6869.73 -984.11 -4974.82 5930505.02 680854.07 GCT-MS 92 9055 48.67 262.20 6967.99 6885.69 -986.54 -4992.93 5930502.14 680836.02 GCT-MS . 63 9080 48.52 261.66 6984.33 6902.03 -989.15 -5011.28 5930499.09 680817.74 GCT-MS . 88 9106 48.66 261.31 7001.70 6919.40 -992.06 -5030.75 5930495.69 680798.35 GCT-MS . 9134 53 48.06 261.09 7020.07 6937.77 -995.22 -5051.17 5930492.03 680778.02 GCT-MS . ~ 9162.56 47.75 261.14 7038.86 6956.56 -998.43 -5071.72 5930488.31 680757.55 GCT-MS 9192 42 47 38 261,43 7059.01 6976.71 -1001.77 -5093.51 5930484.44 680735.86 GCT-MS . 28 9223 . 46.66 261.52 7080.04 6997.74 -1005.12 -5115.83 5930480.54 680713.62 GCT-MS ~ . 70 9254 47.01 261.31 7101.54 7019.24 -1008.54 -5138.49 5930476.56 680691.06 GCT-MS i . 98 9286 13 47 260.89 7123.53 7041.23 -1012.20 -5161.85 5930472.33 680667.80 GCT-MS . 9319.20 . 46.96 260.31 7145.48 7063.18 -1016.05 -5185.11 5930467.91 680644.64 GCT-MS i ' 9352.08 46.81 260.28 7167.95 7085.65 -1020.10 -5208.77 5930463.29 680621.09 GCT-MS __ Halliburton Global Company: BP Amoco Date: 1/9/2006 .Time: 49:24;41 Page: 9 Field: Pru dhoe Bay Co-ordinate(NE) Reference: Well : 13-31, True North Site: PB DS 13 Vertica l (TVD) Reference: 46: 31 4/2/1994 00: 00.82.3 We1L• 13- 31 Section (VS) Referen ce: Well (O.OON,O:OOE,40.OOAz) Wellpath: 13-31A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool. ft deg deg ft ft ft ft ft ft ---, 9384 88 14 46 260.33 7190.54 7108.24 -1024.10 -5232.21 5930458.70 680597.76 GCT-MS j . 9417 92 . 46 15 260.31 7213.43 7131.13 -1028.11 -5255.70 5930454.12 680574.38 GCT-MS I, . 84 9450 . 45 90 260.39 7236.29 7153.99 -1032.08 -5279.05 5930449.58 680551.13 GCT-MS i . 9484.00 . 45.41 260.29 7259.47 7177.17 -1036.06 -5302.43 5930445.02 680527.86 GCT-MS 23 9516 45 50 260.23 7282.08 7199.78 -1039.94 -5325.07 5930440.58 680505.32 GCT-MS . 62 9548 . 45 51 260.39 7304.78 7222.48 -1043.83 -5347.84 5930436.13 680482.65 GCT-MS . 72 9580 . 46 29 260.80 7327.12 7244.82 -1047.60 -5370.59 5930431.81 680460.01 GCT-MS . 11 9613 . 47 39 261.38 7349.27 7266.97 -1051.26 -5393.93 5930427.58 680436.77 GCT-MS ~~ . 9645.34 . 47.85 261.84 7371.00 7288.70 -1054.73 -5417.48 5930423.53 680413.31 GCT-MS 9677 60 47 84 262.00 7392.65 7310.35 -1058.09 -5441.16 5930419.58 680389.72 GCT-MS . 72 9709 . 47 35 262.12 7414.31 7332.01 -1061.37 -5464.65 5930415.73 680366.32 GCT-MS . 77 9741 . 47 25 262.09 7436.04 7353.74 -1064.60 -5487.98 5930411.92 680343.08 GCT-MS . 97 9773 . 47.25 262.11 7457.90 7375.60 -1067.85 -5511.40 5930408.10 680319.75 GCT-MS . 9806.17 46.86 261.95 7479.84 7397.54 -1071.12 -5534.74 5930404.25 680296.49 GCT-MS 50 9838 47.46 261.71 7501.82 7419.52 -1074.49 -5558.21 5930400.31 680273.12 GCT-MS . 9870 70 47 51 261.58 7523.58 7441.28 -1077.94 -5581.69 5930396.28 680249.73 GCT-MS . 81 9902 . 47 39 261.22 7545.29 7462.99 -1081.48 -5605.08 5930392.17 680226.44 GCT-MS i ! . 89 9934 . 47.41 261.18 7567.01 7484.71 -1085.09 -5628.41 5930387.99 680203.20 GCT-MS , '~ . 9967.06 46.58 261.31 7588.95' 7506.65 -1088.67 -5651.67 5930383.83 680180.04 GCT-MS 16 9999 44 46 261.03 7611.04 7528.74 -1092.24 -5674.68 5930379.69 680157.13 GCT-MS . 10031.41 . 46.04 261.11 7633.35 7551.05 -1095.86 -5697.69 5930375.51 680134.21 GCT-MS 45 10063 45.10 261.07 7655.78 7573.48 -1099.40 -5720.29 5930371.41 680111.71 GCT-MS . 67 10095 44 68 260.80 7678.60 7596.30 -1102.99 -5742.75 5930367.28 680089.35 GCT-MS . 10127.22 . 43.83 260.60 7701.20 7618.90 -1106.54 -5764.48 5930363.19 680067.72 GCT-MS 73 10158 04 43 260.07 7724.08 7641.78 -1110.18 -5785.83 5930359.03 680046.46 GCT-MS . 10190 13 . 42 43 260.08 7747.15 7664.85 -1113.85 -5806.82 5930354.84 680025.57 GCT-MS . 62 10221 . 44 42 259.27 7770.39 7688.09 -1117.66 -5827.72 5930350.52 680004.76 GCT-MS . 09 10253 . 42 15 259.01 7793.66 7711.36 -1121.65 -5848.52 5930346.02 679984.07 GCT-MS . 10284.57 . 42.67 259.30 7816.91 7734.61 -1125.65 -5869.37 5930341.51 679963.32 GCT-MS ~ 10315 93 44 13 259.64 7839.69 7757.39 -1129.58 -5890.56 5930337.06 679942.25 GCT-MS . 10347 33 . 45.51 259.73 7861.96 7779.66 -1133.55 -5912.33 5930332.56 679920.58 GCT-MS . 82 10378 45 65 259.83 7884.00 7801.70 -1137.54 -5934.47 5930328.02 679898.55 GCT-MS . 43 10410 . 45 61 259.74 7906.11 7823.81 -1141.54 -5956.71 5930323.47 679876.42 GCT-MS . 10441.97 . 46.24 259.99 7928.05 7845.75 -1145.53 -5979.01 5930318.94 679854.22 GCT-MS 35 10473 46.29 260.43 7949.74 7867.44 -1149.39 -6001.35 5930314.53 679831.98 GCT-MS . 82 10504 46.65 260.63 7971.42 7889.12 -1153.14 -6023.86 5930310.23 679809.57 GCT-MS . 26 10536 47 16 260.60 7992.90 7910.60 -1156.88 -6046.51 5930305.93 679787.02 GCT-MS . 10567.49 . 46.89 260.61 8014.19 7931.89 -1160.61 -6069.05 5930301.64 679764.58 GCT-MS 10598.90 46.80 260.53 8035.67 7953.37 -1164.37 -6091.66 5930297.33 679742.08 GCT-MS 47 10630 52 46 260.63 8057.34 7975.04 -1168.13 -6114.31 5930293.02 679719.53 GCT-MS . 22 10662 . 45.83 260.59 8079.32 7997.02 -1171.86 -6136.91 5930288.73 679697.03 GCT-MS . 87 10693 46 22 260.75 8101.30 8019.00 -1175.56 -6159.38 5930284.48 679674.65 GCT-MS . 97 10724 . 21 46 261.20 8122.82 8040.52 -1179.08 -6181.56 5930280.42 679652.57 GCT-MS . 10755.86 . 45.52 261.73 8144.33 8062.03 -1182.37 -6203.48 5930276.59 679630.74 GCT-MS 93 10786 45.23 262.23 8166.15 8083.85 -1185.45 -6225.38 5930272.96 679608.92 GCT-MS . 10817.77 44.89 262.82 8187.94 8105.64 -1188.29 -6247.02 5930269.59 679587.36 GCT-MS 67 10848 44 85 263.10 8209.84 8127.54 -1190.97 -6268.66 5930266.39 679565.79 GCT-MS . 42 10879 . 45 66 262.64 8231.48 8149.18 -1193.68 -6290.33 5930263.15 679544.20 GCT-MS . 10910.28 . 47.31 261.81 8252.73 8170.43 -1196.71 -6312.50 5930259.57 679522.11 GCT-MS 10941 08 48 48 261.52 8273.38 8191.08 -1200.02 -6335.11 5930255.70 679499.59 GCT-MS . 55 10971 . 49.33 260.83 8293.41 8211.11 -1203.54 -6357.80 5930251.62 679476.99 GCT-MS . 19 11002 49.34 259.53 8313.38 8231.08 -1207.51 -6380.70 5930247.10 679454.20 GCT-MS ~ . 11033.01 49.40 259.32 8333.45 8251.15 -1211.80 -6403.69 5930242.24 679431.32 - GCT-MS Halliburton Global Company: BP Amoco Date: 1/9/2006 .Time: 19:24:41 Page: 10 Field: Prudhoe Bay Co-ord inate(NE) Reference: Well: 13-31, True North Site: PB DS 1 3 Vertical (TVD) Reference: 46 :31 4/2/1994 00:00 82.3 Well: 13- 31 Section (VS) Refere nce: Well. (O.OON,O.OOE,40.OOAzi) Wellpath: 13- 31A Survey Calculation Method: Minimum Curvatu re Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Toole ~ ft de g deg ft ft ft ft ft ft ~ I - _ ! I 11063.93 49 .42 259. 82 8353.56 8271 .26 -1216.05 -6426.79 5930237.42 679408.34 GCT-MS 11094.72 49 .01 260. 38 8373.68 8291 .38 -1220.06 -6449.75 5930232,85 679385.48 GCT-MS 11125.40 49 .07 260. 73 8393.79 8311 .49 -1223.86 -6472.61 5930228.49 679362.73 GCT-MS ~ 11156.27 49 .42 260. 15 8413.94 8331 .64 -1227.74 -6495.66 5930224.04 679339.78 GCT-MS 11186.95 49 .13 258. 54 8433.96 8351 .66 -1232.04 -6518.51 5930219.18 679317.04 GCT-MS 11217.73 48 .79 258. 09 8454.17 8371 .87 -1236.74 -6541.25 5930213.92 679294.43 GCT-MS 11248.57 48 .49 258. 44 8474.55 8392 .25 -1241.45 -6563.91 5930208.65 679271.89 GCT-MS 11279.52 48 .19 258. 84 8495.12 8412. 82 -1246.01 -6586.58 5930203.54 679249.34 GCT-MS 11309.67 47 .87 259. 37 8515.28 8432 .98 -1250.24 -6608.59 5930198.76 679227.44 GCT-MS 11339.96 47 .45 259. 82 8535.68 8453 .38 -1254.29 -6630.61 5930194.18 679205.53 GCT-MS 11370.06 47 .13 260. 58 8556.10 8473 .80 -1258.05 -6652.41 5930189.88 679183.83 GCT-MS 11400.18 46 .82 261. 24 8576.65 8494. 35 -1261.53 -6674.15 5930185.87 679162.19 GCT-MS 11430.42 46 .58 261. 84 8597.39 8515. 09 -1264.77 -6695.92 5930182.09 679140.51 GCT-MS 11460.49 46 .13 262. 55 8618.14 8535. 84 -1267.73 -6717.48 5930178.61 679119.03 GCT-MS 11490.70 45 .88 263. 21 8639.13 8556. 83 -1270.42 -6739.04 5930175.39 679097.54 GCT-MS 11520.94 46 .15 263. 46 8660.13 8577. 83 -1272.94 -6760.65 5930172.33 679076.00 GCT-MS 11551.01 46 .64 263. 31 8680.87 8598. 57 -1275.45 -6782.28 5930169.29 679054.44 GCT-MS 11581.28 46 .71 263. 40 8701.64 8619. 34 -1278.00 -6804.15 5930166.20 679032.63 GCT-MS 11611.44 46 .45 263. 96 8722.37 8640. 07 -1280.41 -6825.93 5930163.26 679010.93 GCT-MS 11641.67 46 .39 263. 67 8743.21 8660. 91 -1282.77 -6847.70 5930160.36 678989.22 GCT-MS 11671.97 45 .90 262. 96 8764.20 8681. 90 -1285.32 -6869.40 5930157.29 678967.59 GCT-MS 11702.10 45 .42 263. 18 8785.26 8702: 96- -1287.92 -6890.79 5930154.16 678946.27 GCT-MS 11732.17 45 .18 263. 54 8806.41 8724. 11 -1290.39 -6912.02 5930151.17 678925.11 GCT-MS 11762.08 44 .30 264. 08 8827.65 8745. 35 -1292.66 -6932.95 5930148.38 678904.25 GCT-MS 11792.13 44 .12 264. 46 8849.19 8766. 89 -1294.75 -6953.80 5930145.78 678883.46 GCT-MS 11822.57 43 .75 265. 33 8871.12 8788. 82 -1296.63 -6974.84 5930143.38 678862.47 GCT-MS 11851.00 43 .53 265. 58 8891.69 8809. 39 -1298.18 -6994.40 5930141.34 678842.96 MWD 11883.03 34 .54 280. 26 8916.60 8834. 30 -1297.41 -7014.41 5930141.62 678822.93 MWD 11912.89 26 .89 305. 64 8942.36 8860. 06 -1291.94 -7028.31 5930146.75 678808.91 MWD 11946.28 20 .87 349. 48 8973.11 8890. 81 -1281.61 -7035.59 5930156.90 678801.37 MWD 11979.58 30 .02 24. 52 9003.31 8921. 01 -1268.09 -7033.20 5930170.47 678803.43 MWD ~ 12007.44 43 .24 19. 13 9025.62 8943. 32 -1252.66 -7027.15 5930186.04 678809.10 MWD 12040.15 59 .59 15. 79 9045.96 8963. 66 -1228.34 -7019.59 5930210.55 678816.06 MWD 12069.70 74 .44 8. 94 9057.48 8975. 18 -1201.84 -7013.87 5930237.18 678821.12 MWD 12102.65 88 .94 6. 65 9062.23 8979. 93 -1169.62 -7009.47 5930269.49 678824.72 MWD 12137.34 95 .27 4. 37 9060.95 8978. 65 -1135.14 -7006.15 5930304.04 678827.20 MWD 12173.22 98 .88 11. 05 9056.53 8974. 23 -1099.88 -7001.38 5930339.41 678831.10 MWD 12208.31 98 .96 15. 97 9051.09 8968. 79 -1066.18 -6993.28 5930373.29 678838.36 MWD 12244.71 98 .17 20. 54 9045.66 8963. 36 -1032.01 -6982.01 5930407.73 678848.79 MWD 12278.66 97 .56 23. 35 9041.02 8958. 72 -1000.82 -6969.44 5930439.22 678860.58 MWD 12310.34 93 .87 32. 49 9037.85 8955. 55 -973.00 -6954.70 5930467.38 678874.64 MWD 12350.65 97 .82 35. 48 9033.75 8951. 45 -939.76 -6932.29 5930501.17 678896.22 MWD 12380.24 97 .47 37. 24 9029.81 8947. 51 -916.15 -6914.90 5930525.20 678913.02 MWD 12406.05 96 .63 40. 32 9026.64 8944. 34 -896.18 -6898.86 5930545.55 678928.56 MWD 12433.79 96 .68 46. 91 9023.43 8941. 13 -876.24 -6879.87 5930565.95 678947.06 MWD 12466.17 97 .47 47. 61 9019.44 8937. 14 -854.44 -6856.27 5930588.33 678970.12 MWD 12495.22 96 .06 52. 18 9016.01 8933. 71 -835.86 -6834.21 5930607.45 678991.71 MWD 12532.62 95 .80 59. 21 9012.15 8929. 85 -814.91 -6803.50 5930629.15 679021.89 MWD 12565.46 95 .71 66. 59 9008.85 8926. 55 -800.03 -6774.43 5930644.73 679050.58 MWD 12601.60 96 .33 67. 65 9005.06 8922. 76 -786.06 -6741.32 5930659.51 679083.34 MWD 12631.67 95 .27 64. 84 9002.02 8919. 72 -774.01 -6713.94 5930672.23 679110.41 MWD 12661.98 95 .27 62. 02 8999.23 8916. 93 -760.51 -6686.95 5930686.39 679137.06 MWD Halliburton Global Company: BP Amoco Date: 1/9/2006 Time: 19:24:41 Page: 11 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 13-31, True N orth j .Site: PB US 13 Vertica l (TVD) Refe rence: 46 ; 31 4/2/1994 00 :00 82.3 Well: t3- 31 Section {VS) References Well (O:OON,O.OOE,40.OOAzi) Wellpath: 13- 31A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool !~ ~ ft deg deg ft ft ft ft ft ft ', 12698.97 96.50 53. 59 8995. 43 8913.13 -740.93 -6655.84 5930706. 73 679167.68 MWU 12733.96 98.35 50. 60 8990 .91 8908.61 -719.62 -6628.47 5930728. 71 679194.51 MN/U l 12761.29 96.85 44. 45 8987 .29 8904.99 -701.33 -6608.50 5930747. 48 679214.03 MWC' ~ 12782.56 95.81 40. 02 8984 .95 8902.65 -685.68 -6594.29 5930763. 47 679227.84 MWU i 12817.30 98.26 43. 39 8980 .69 8898.39 -659.94 -6571.36 5930789. 77 679250.13 MWD I 12852.58 97.65 35. 66 8975 .80 8893.50 -633.01 -6549.14 5930817. 23 679271.68 MWU 12881.76 96.85 27. 57 8972 .11 8889.81 -608.38 -6533.98 5930842. 23 679286.22 MWD 12917.43 97.56 24. 05 8967 .64 8885.34 -576.53 -6518.58 5930874. 45 679300.84 M~JD j 12945.64 100.11 27. 22 8963 .31 8881.01 -551.40 -6506.52 5930899. 86 679312.27 MV?~~ 12983.20 99.58 33. 37 8956 .88 8874.58 -519.47 -6487.86 5930932. 25 679330.14 MWU 13018.26 96.85 39. 00 8951 .86 8869.56 -491.48 -6467.38 5930960. 73 679349.92 MWU 13048.39 94.96 41. 88 8948 .76 8866.46 -468.67 -6447.94 5930984. 01 679368.79 MVO%~~ 13087.09 92.11 45. 50 8946 .38 8864.08 -440.75 -6421.27 5931012. 57 679394.77 MWU 13117.22 89.91 51. 30 8945 .85 8863.55 -420.76 -6398.75 5931033. 11 679416.79 MWG 13152.84 87.19 57. 98 8946 .75 8864.45 -400.17 -6369.73 5931054. 41 679445.29 MWf1 13187 96 82.70 60. 97 8949 .84 8867.54 -382.40 -6339.61 5931072. 91 679474.97 MWD . 13228.64 84.81 59. 04 8954 .27 8871.97 -362.19 -6304.59 5931093. 98 679509.47 MWU 13265 99 84.20 62. 02 8957 .84 8875.54 -343.90 -6272.23 5931113 .06 679541.38 MWU . l ~ 13299.60 82.97 69. 05 8961 .60 8879.30 -330.07 -6241.85 5931127 .63 679571.40 MWi:7 i 13328.26 83.14 71. 34 8965 .07 8882.77 -320.43 -6215.08 5931137 .92 679597.92 MWU 13363.72 83.06 78. 72 8969 .34 8887.04 -311.35 -6181.10 5931147 .84 679631.67 MWC? 13391:15 82.97 84. 17 8972 .67 8890.37 -307.30 -6154.19 5931152. 55 679658.47 MV1+n 13420.02 83.59 84. 64 8976 .05 8893.75 -304.50 -6125.65 5931156 .05 679686.93 MWI7 13442.50 83.14 89. 27 8978 .65 8896.35 -303.32 -6103.36 5931157. 78 679709.18 MWU 13473.43 82.97 89. 45 8982 .39 8900.09 -302.97 -6072.66 5931158 .88 679739.87 MWU 13505.72 83.50 95. 60 8986 .20 8903.90 -304.39 -6040.64 5931158 .26 679771.91 MWU 13530.24 83.14 99. 47 8989 .05 8906.75 -307.58 -6016.50 5931155 .66 679796.12 MWU 13559.20 81.39 100. 52 8992 .95 8910.65 -312.56 -5988.24 5931151 .38 679824.49 MWC) 13594.72 79.89 95. 42 8998 .73 8916.43 -317.42 -5953.55 5931147 .37 679859.29 MWU 13634 39 81.91 90. 50 9005 .01 8922.71 -319.44 -5914.44 5931146 .32 679898.43 MWD . 13669.77 81.91 86. 63 9009 .99 8927.69 -318.56 -5879.43 5931148 .06 679933.40 MWU 13710.57 82.70 80. 83 9015 .46 8933.16 -314.14 -5839.26 5931153 .46 679973.45 MWU 13741.40 84.64 75. 38 9018 .86 8936.56 -307.83 -5809.29 5931160 .51 680003.26 MWU 13775.67 82.70 72 .57 9022 .64 8940.34 -298.43 -5776.56 5931170 .71 680035.75 MWU I 13803 33 81.83 68 .53 9026 .36 8944.06 -289.31 -5750.72 5931180 .47 680061.35 MWU . 13840.72 81.74 60 .97 9031 .71 8949.41 -273.53 -5717.27 5931197 .06 680094.40 MWD ~ 13872.80 83.14 57 .80 9035 .93 8953.63 -257.34 -5689.91 5931213 .92 680121.35 MWD 13904.42 85.69 53 .94 9039 .01 8956.71 -239.68 -5663.87 5931232 .21 680146.95 MWD 13928.00 85.69 53 .94 9040 .78 8958.48 -225.84 -5644.86 5931246.51 680165.61 MWD TREE = 4-1/6" CM/ 5M WELLHEAD- FMC A ~TUATOR BAKER C KB. ELEV..- 82 BF. ELEV KOP = __ 1449' Max Angle = 100 @ 12946' -Datum MD = 11838' Datum TV D = 8800' SS • ~4-1/2" TBG, 12.6#, L-80 TCII, .0152 bpf, ID = 3.958" ~~ 9-518" CSG, 40#, NT-80, ID = 8.835" 3527' Minimum ID =1.731" @ 11701' SEAL ASSY w/NO GO PERFORATION SUMMARY REF LOG: MWD ON 04/14/94 A NGLE AT TOP PERF: 83 @ 13310' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 1-9/16" 6 13310 - 13350 O 12/24!05 1-9/16" 6 13390 - 13670 O 12/24/05 3-1/2" TBG, 9.3#, L-80 TCII, .0087 bpf, ID = 2.992" 11725' COC (12/09105) 11866' PBTD 12060' 5-1/2" CSG, 17#, L-80, ID = 4.892" 12137' NOTES: 13 -31 A ''~~~ 4-1 /2" X 3-1 /2" XO, ID = 2.992" --~3-1/2" WLEG: ID = 2.992" (BE]-IIND PIPE) MILLOtlT WINDOW (13-31 A) 11854' -11860' PBTD 13893' 2-318" LNR, 4.7#, L-80 STL, .0039 bpf, ID = 1.995" --~' DATE REV BY COMMENTS DATE REV BY COMMENTS 04/17/94 ORIGINAL COMPLETION 12l04t05 N4E5 RWO (PRE CTD SDTRCK) 12/12/05 NORDIC1 CTD SIDETRACK(13-31A) 01/02/06 KSB/TLH DRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL 13-31A PERMfI- No: 2051600 API No: 50-029-22459-01 SEC 14, T10N, R14E, 3341.52' FEL & 5014.3' FNL BP Exploration (Alaska) 2409' I~ 3-1/2" HES X NIP, ID = 2.813" 7998' -~5-1/2" PARKER SWS NIP, MILLm ID = 4.75" 89~ 5-1/2" OTIS XN NIP, M ILLED ID = 4.75" 11570' -j 3-1/2" HES X NIP, ID = 2.813" 11591' BKR KBH-22 ANCHOR SEAL ASSY, ID = 2.98" 11592' 5-1/2" X 3-1/2" BKR SABL-3 PKR, ID = 2.78" 116 3-1/2" HES X NIP, ID = 2.75" 11698' I-~KB LNR TOP PKR, ID = 1.810" 11701' SEAL ASSY w/NOGO, ID = 1.731" 117 2.70" BKR DEPLOY SLV, ID = 2.25" • • 12-Jan-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 13-31A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. ao~ - - ~ o Tie-on Survey: 11,822.57' MD Window /Kickoff Survey: 13,904.42' MD (if applicable) Projected Survey: 13,928.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ,~~ ~ ~ ;, 4~ ~~ ~ ;~ ~~ y, ~ ~ ~~ ~ ~ is r ~,,y ' ~~ ~ ~~~ ~ 1 ~ ~ ~~ ~"°`~~ ;~ '__9 ~.. ., ~~-~,, a ~ FRANK H. MURKOWSKI, GOVERNOR ~~ ~~ ~~ ~~++ ~ t~~ /fit ~ ~+ f dilt>•-7~ OI~ ~ z7ray7 ` 333 W. 7TM AVENUE. SUITE 100 COI~TSERQA'1`IO1Q COMhIISSIOI~T ~~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27&7542 Barbara Holt CT Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: PBU 13-31A BP Exploration (Alaska), Inc. Permit No: 205-160 Surface Location: 1579' FSL, 1423' FEL, SEC. 14, T10N, R14E, UM Bottomhole Location: 1410' FSL, 1762' FEL, SEC. 15, T10N, R14E, UM Dear Ms. Holt: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). DATED this~day of November, 2005 cc: Department of Fish 8s Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. Chairman STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION COM SSION PERMIT TO DRILL ~1C7f~ ti ~q jZ~P .'~~.. ~~,_ 20 AAC 25.005 ~K ~~~s~s .3 ,_.~x ~ ~,.~>;,. a,~~±~'.~ , ~r. 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Oil ~ le Zone ^ Stratigraphic Test ®Service ^ Development Gas ~Sir~gle Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 13-31A ,e(/s/o~; 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13975 TVD 8960ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1579' FSL 1423' FEL SEC 14 T10N R14E UM 7. Property Designation: ADL 028314 Pool , , . , , , Top of Productive Horizon: 272' FSL, 3218' FEL, SEC. 15, T10N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: December 5, 2005 Total Depth: 1410' FSL, 1762' FEL, SEC. 15, T10N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 9400' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 685803 - 5931612 Zone- ASP4 10. KB Elevation (Height above GL): 82,3' feet 15. Distance to Nearest Well Within Pool 1200' to 14-09A 16. Deviated Wells: Kickoff Depth: 11855 feet Maximum Hole Angle: 99 de rees 17. Maximum Anticipated Pressures in psig (see 20 AA 35) Downhole: 3600 Surtace: 72 is. ing rogram: Size Specifications Setting Depth To Bottom ua o ement cf. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# L-80 STL 2275' 11700' 8701' 13975' 8960' 3 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed #or Redrill AND Re-entry Operations) Total Depth MD (ft): 12150 Total Depth TVD (ft): 9109 Plugs (measured): None Effective Depth MD (ft): 12062 Effective Depth TVD (ft): 9045 Junk (measured): None Casin Len th Size Cement Volume MD TVD r r on u 80' 20" 60 sx Arcticset A rox. 112' 112' 3494' 9-5/8" 80 sx Coldset III, 375 sx 'G', 250 sx CS II 3527' 3244' Pr i n 12105' S-1 t2" 21 sx Class 'G' 12137' 9100' Perforation Depth MD (ft): 11974' - 12060' Perforation Depth TVD (ft): 8981' -9044' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Barbara Holt, 564-5126 Printed Name Barbara Holt Title CT Drilling Engineer Prepared By Name/NUmber: Si nature Phone 564-5516 pate Z ~ eyrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: API Number: 50-029-22459-01-00 Permit Appr al Date: • See cover letter for other requirements Conditions of Approval: Sampl equired i- Yes ~No Mud Log Required ^ Yes ~No Hyd gen ulfide Measures 'Yes ^ No Directional Survey Required ,'Yes ^ No Other: t ~?, /±. p J t y `> ~ ~t' J S c ~~`-' f%,~,~ . /~ ~ ~ ~"""y.,~ t ~t +u t ~ i ~ ~ ~ ~ ~ ~ ~ ~ 'l.! !'- O t 1 ~ v~T A~~ ~/l. ~v1 rte, ~/' ~ ~~ ~.a t ~'~`t .~z.z--f ~~~-6u ~ ad ,~.U~~~z''4i{ y r.~.t J APPROVED BY ~/ O A roved '; ,""~ THE COMMISSION Date Form 10-401 R>~iB~d 0 ooa ~~ _,,,~,i I I ~ /-~ L Subrhit In Duplicate To: Winton Aubert, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Barbara M. Holt, CTD Engineer Date: October 24, 2005 Re: 13-31A CTD Sidetrack Permit to Drill The sidetrack, 13-31A, is scheduled to be drilled by Nordic 1 during the second week of December, following a RWO for P&A and tubing swap. The plan calls for setting a whipstock for an exit into the Sag, targeting Zone 4 injection. CTD Sidetrack Summary Rig Work: 1. MIRU Nordic 1 and test BOPE to 250 psi low and 3500 psi high. 2. Mi112.74" window at 11,855' MD (8895' ss) in the Sag River. 3. Drill approximately 2120' of horizontal sidetrack into Zone 4 target with Resistivity memory logging to 13,975' MD. Bit selection size will be 3" bicenter. 4. Run 2-3/8" solid lin OL at 11,700' MD (8703'ss). 5. Cement liner with 5 is 15.8 ppg cement to place top of cement at TOL. 6. Cleanout liner an st to 3000 psi. 7. Log memory CNL/GR/CCL from above TOL to PBTD. 8. Perforate liner as per Asset instructions, approximately 600' of perforations expected. 9. Freeze protect well and RDMO. Mud Program: • Well kill: 8.5 ppg brine • Milling/drilling: .6~ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Casing Program: • 2 3/8" fully cemented liner • A minimum of 15 bbls 15.8 ppg cement will be used for liner cementing. ~` Casin finer Infor n ~~ OD Grade Wei ht Burst Colla se 9-5/8" L-80 40# 5750 si 3090 si 5-1/2" L-80 17# 7740 si 6280 si 2-3/8" L-80 4.6 # 11,200 si 11,780 si 3" O en hole Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. ~ • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 99.3 deg at 12,375' MD. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 9,400 ft to Unit Boundary to SW. • Distance to nearest well within pool - 1200 ft to 14-09A at TSAD. Logging • MWD directional, Gamma Ray, and Memory Resistivity will be run over all of the open hole section. • Log memory CNL/GR/CCL from the tubing tail to PBTD. Hazards • DS 13 is an H2S pad. The highest H2S reading o 200,~pm was in wells 13-04 and 13-05. The latest H2S reading was in well 13-08 of 120 p m on O1/15/O5. • Lost circulation risk is high. The well is planned to avoid a 75' throw fault near landing. Reservoir Pressure • Res. press. is estimated to be 3600 psi at 8800'ss (7.9 ppg EMW). • Maximum surface pressure with gas (0.10 psi/ft) to surface is 2720 psi. f -~ 1//////y/ r t0'yl„F ~~/ v _~.. ~. ~!. ~ /c. ~ ~/f ~/t' ~ e`er. ~, iREE _ _~ KB. ELEV = 82' BF. ELEV = KOP = 1449' Max Angle = 53 C~ 6233' Datum MD = 11838' Datum TV D = 8800' SS 9-5/8" CSG, 40#, NT-80, ID = 8.835" H 3527' Minimum ID = 2.25" @ 9003' 2-7/8" OTIS XN NIPPLE 2-7/8" TBG, 6.5#, L-80, .0056 bpf, 1D = 2.441" ~-~ 9009' PERFORATION SUMMARY REF LOG: MWD ON 04/14/94 ANGLE AT TOP PERF: 43 C~3 11974' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 4 11974 - 11986 O 09/02/99 2-1/8" 4 11990 - 12002 O 09/02/99 2-1/8" 4 12006 - 12014 O 09/02/99 2-1/8" 4 12022 - 12034 O 09/02/99 3-3/8" 6 12040 - 12060 O 09/02/99 IPBTD ri 12060' 5-1 /2" CSG, 17#, L80, ID = 4.892" 12137' 13-31 I 3095' H3-1/2" CAM DS SSSV NIP, ID = 2.812" 7998' H5-1/2" PARKER SWS NIP, ID= 4.562" 8974' N3-1/2" OTIS XN NIP, ID= 2.75" 8975' 3-1/2" X 2-7/8" XO, ID = 2.44" 8976' H5-1/2" OTIS XN NIP, ID = 4.455" WITH XN LOCK MANDREL 8978' ~--STOP OF SBE, ID = 3.0" 8985' H2-7/8" MULESHOE, ID = 2.375" $988' 3-1 /2" X 2-7/8" XO, ID = 2.44" 9003' ~2-7/8" OTIS XN NIP, ID= 2.25" 9009' 2-7/8" MULESHOE WLEG, ID=2.44" ELMD TT NOT LOGGED SAFETY NOTES: ***RAPID T X IA COMM *** PWI INJ ECTION ONLY DATE REV BY COMMENTS DATE REV BY COMMENTS 04/17/94 ORIGINAL COMPLETION 05/24/01 RWTP CORRECTIONS 02/11/03 JP/tlh WAIVERSAFETY NOTE 01/11/04 TJPTLP WANERSAFETY NOTE 07/26/05 RPWPJC WANERCANCELLED PRUDHOE BAY UNIT WELL: 13-31 PERMIT No: #1940400 API No: 50-029-22459-00 SEC 14, T10N, R14E, 3341.52' FEL & 5014.3' FNL BP Exploration (Alaska) TREE _ WELLHEAD= CIW ACTUATOR= BAKERC KB. ELEV = 82' BF. EL KOP= Max A Datum Datum .. PropOSd CTC3 Sidetrack DATE REV BY COMMENTS DATE REV BY COMMENTS 04/17/94 ORIGINAL COMPLETION 05/24/01 RWTP CORRECTIONS 02/11/03 JP/tlh WANERSAFETY NOTE 01/11/04 TJPTLP WANERSAFETY NOTE 07/26/05 RPH/PJC WANERCANCELLED PRUDHOE BAY UNIT WELL: 13-31 PERMIT No: 1940400 API No: 50-029-22459-00 SEC 14, T10N, R14E, 3341.52' FEL & 5014.3' FNL BP Exploration (Alaska) ' ~ • ConocoPhillips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~t~~ ~~ INTEQ Company: BP Amoco Date: 10/6/2005 Time: 11:00:37 Page: 1 Field: Prudhoe Bay Co-ordiDate(NE) Reference: Well: 13-31, True North Site: PB D513 Vertical (1'VDj Reference: 46:31 4/2/t994 00:00 82.3 Well: 13-31 SectioD (VS) References Well (O.OON,O.OOE,40.OOAzi) We1lDath: Plan 4. 13-31A c~~r.,p., rAt~.~~An..„ wrarh...r• ~IBIRII ifl'L CIIN•J}Ilro r•M n~9(`IP Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB DS 13 TR-10-14 UNITED STATES :North Slope Site Position: Northing: 5932645.45 ft Latitude: 70 13 15.444 N From: Map Essting: 685828.44 ft Longitude: 148 30 2.303 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.41 deg Well: 13-31 Slot Name: 31 13-31 Well Position: +N/-S -1033.35 ft Northing: 5931611.22 ft Latitude: 70 13 5.281 N +E/-W -51.05 ft Easting : 685802.86 ft Longitude: 148 30 3.786 W Position Uncertainty: 0.00 ft Wellpath: Plan 4, 13-31A Drilled From: 13-31 Tie-on Depth: 11852.86 ft Current Datum: 46:31 4/2/1994 00:00 Height 82.30 ft Above System Datum: Mean Sea Level Magnetic Data: 7/5/2005 Declination: 24.93 deg Field Strength: 57606 nT Mag Dip Angle: 80.85 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.30 0.00 0.00 40.00 Plan: Plan 4, 13-31A Date Composed: 7/5/2005 Version: 19 Principal: Yes Tied-to: From: Definitive Path Targets Natne I)escriptioD 1)ip. Dir.:. 'TVD ft +N/-S ft" -- +E/-W ft Map Northing ft Map Eastiag ft <- Latitude -> Deg Min Sec <- Longitude -> Deg Min Sec 13-31A Polygon 82.30 170.81 -5767.75 5931640.00 680033.00 70 13 6.939 N 148 32 51.269 W -Polygon 1 82.30 170.81 -5767.75 5931640.00 680033.00 70 13 6.939 N 148 32 51.269 W -Polygon 2 82.30 -379.41 -7188.81 5931055.00 678626.00 70 13 1.516 N 148 33 32.518 W -Polygon 3 82.30 -1404.34 -7085.00 5930033.00 678755.00 70 12 51.436 N 148 33 29.476 W -Polygon 4 82.30 -386.79 -5426.35 5931091.00 680388.00 70 13 1.458 N 148 32 41.344 W 13-31A Fault 1 82.30 -1368.53 -7117.13 5930068.00 678722.00 70 12 51.788 N 148 33 30.410 W -Polygon 1 82.30 -1368.53 -7117.13 5930068.00 678722.00 70 12 51.788 N 148 33 30.410 W -Polygon 2 82.30 -419.65 -7341.86 5931011.00 678474.00 70 13 1.118 N 148 33 36.961 W 13-31A Fault 3 82.30 -1476.01 -5880.33 5929991.00 679961.00 70 12 50.742 N 148 32 54.501 W -Polygon 1 82.30 -1476.01 -5880.33 5929991.00 679961.00 70 12 50.742 N 148 32 54.501 W -Polygon 2 82.30 -1495.55 -6996.21 5929944.00 678846.00 70 12 50.540 N 148 33 26.896 W 13-31 A Fault 2 82.30 -184.10 -5248.30 5931298.00 680561.00 70 13 3.452 N 148 32 36.178 W -Polygon 1 82.30 -184.10 -5248.30 5931298.00 680561.00 70 13 3.452 N 148 32 36.178 W -Polygon 2 82.30 240.66 -5475.92 5931717.00 680323.00 70 13 7.628 N 148 32 42.796 W -Polygon 3 82.30 628.91 -5399.34 5932107.00 680390.00 70 13 11.447 N 148 32 40.581 W '~ -Polygon 4 82.30 240.66 -5475.92 5931717.00 680323.00 70 13 7.628 N 148 32 42.796 W 13-31A Target 2 8920.30 -360.05 -6227.98 5931098.00 679586.00 70 13 1.715 N 148 33 4.621 W 13-31A Target 3 9042.30 -158.22 -5608.79 5931315.00 680200.00 70 13 3.704 N 148 32 46.646 W 13-31A Target 1 9090.30 -1165.07 -7011.09 5930274.00 678823.00 70 12 53.790 N 148 33 27.337 W ~ • ConocoPh~llips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ^ iNr>~~ Company:... BP AmOCA Dste: 10/6/2005 Time: 11:00:37 Page: 2 Field: Prudhoe Bay - Co-ordinate(NE) Reference: Well: 13-31, True North Site:. PB DS 13 Vertical (1'VD) Reference: 4 6:31 4!2/1994 00:00 82.3 Well: 1 3-31 Section (VS) Reference: Well (O.OON,O.OOE,40.OOAzi) Wellpath:: Plan 4,13-31A Survey CslculaBon Method: Minimum Curvature Db: O racle Annotation MD TVD ft ft 11852.86 8893.04 TIP 11855.00 8894.59 KOP 11875.00 8909.31 End of 9°/100' DLS 11955.00 8979.19 4 12005.00 9025.12 5 12158.25 9088.50 End of 45°/100' DLS 12508.25 9033.37 7 12833.25 8983.20 8 13108.25 8943.63 9 13308.25 8930.16 10 13408.25 8939.43 11 13658.25 8984.47 12 13975.00 0.00 TD Plan Section Information MD Inc! Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg ; deg ft ft ft deg/100ft deg/100ft' deg/100ft deg 11852.86 43.52 265.60 8893.04 -1298.28 -6995.67 0.00 0.00 0.00 0.00 11855.00 43.51 265.60 8894.59 -1298.40 -6997.14 0.47 -0.47 0.00 180.01 11875.00 41.71 265.60 8909.31 -1299.43 -7010.64 .9.00 -9.00 0.00 180.00 11955.00 19.50 327.29 8979.19 -1289.93 -7045.55 45.00 -27.76 77.12 150.00 12005.00 29.44 18.43 9025.12 -1271.00 -7046.18 45.00 19.88 102.27 90.00 12158.25 98.40 18.43 9088.50 -1148.16 -7005.24 45.00 45.00 0.00 0.00 12508.25 98.90 60.93 9033.37 -888.17 -6789.65 12.00 0.14 12.14 86.00 12833.25 98.16 21.49 8983.20 -651.29 -6582.34 12.00 -0.23 -12.14 272.00 13108.25 97.92 54.82 8943.63 -440.31 -6416.57 12.00 -0.09 12.12 88.00 13308.25 89.70 77.44 8930.16 -360.34 X235.35 12.00 -4.11 11.31 109.00 13408.25 79.66 84.05 8939.43 -344.31 -6137.26 12.00 -10.04 6.61 147.00 13658.25 80.06 53.57 8984.47 -256.42 -5910.70 12.00 0.16 -12.19 268.00 13975.00 79.73 92.20 9042.17 -166.42 -5618.68 12.00 -0.10 12.20 94.00 Survey MD Inc! Azim SSTVD N/S rE/W " MapN MapE ' 'DLS VS TFO Tool ft - deg deg ft ft ` ' ft ft ft deg/100ft; ft' deg 11852.86 43.52 265.60 8810.74 -1298.28 -6995.67 5930141.22 678841.69 0.00 -5491.27 0.00 MWD 11855.00 43.51 265.60 8812.29 -1298.40 -6997.14 5930141.07 678840.22 0.47 -5492.30 180.01 MWD 11875.00 41.71 265.60 8827.01 -1299.43 -7010.64 5930139.70 678826.75 9.00 -5501.78 180.00 MWD 11889.15 36.31 270.97 8838.00 -1299.72 -7019.53 5930139.19 678817.87 45.00 -5507.71 150.00 13-31A 11900.00 32.37 276.10 8846.96 -1299.36 -7025.64 5930139.40 678811.76 45.00 -5511.36 145.82 MWD 11925.00 24.47 293.12 8868.97 -1296.61 -7037.09 5930141.87 678800.24 45.00 -5516.61 141.58 MWD 11950.00 19.81 320.66 8892.18 -1291.28 -7044.56 5930147.01 678792.64 45.00 -5517.34 126.56 MWD 11955.00 19.50 327.29 8896.89 -1289.93 -7045.55 5930148.34 678791.62 45.00 -5516.93 100.95 MWD 11975.00 21.40 352.68 8915.66 -1283.48 -7047.82 5930154.72 678789.19 45.00 -5513.46 90.00 MWD 12000.00 27.82 15.16 8938.43 -1273.30 -7046.87 5930164.93 678789.89 45.00 -5505.04 66.17 MWD 12005.00 29.44 18.43 8942.82 -1271.00 -7046.18 5930167.24 678790.52 45.00 -5502.84 45.65 MWD 12025.00 38.44 18.43 8959.40 -1260.42 -7042.65 5930177.91 678793.79 45.00 -5492.47 360.00 MWD 12025.77 38.79 18.43 8960.00 -1259.96 -7042.50 5930178.37 678793.93 45.00 -5492.02 360.00 13-31A 12050.00 49.69 18.43 8977.33 -1243.95 -7037.17 5930194.50 678798.87 45.00 -5476.33 0.00 MWD 12075.00 60.94 18.43 8991.54 -1224.48 -7030.68 5930214.13 678804.88 45.00 -5457.24 0.00 MWD 12100.00 72.19 18.43 9001.46 -1202.76 -7023.44 5930236.02 678811.58 45.00 -5435.94 360.00 MWD 12125.00 83.44 18.43 9006.73 -1179.61 -7015.73 5930259.35 678818.72 45.00 -5413.25 360.00 MWD 12150.00 94.69 18.43 9007.14 -1155.93 -7007.84 5930283.21 678826.02 45.00 -5390.05 0.00 MWD 12158.25 98.40 18.43 9006.20 -1148.16 -7005.24 5930291.05 678828.42 45.00 -5382.43 0.00 MWD 12175.00 98.54 20.46 9003.73 -1132.54 -6999.73 5930306.80 678833.55 12.00 -5366.91 86.00 MWD 12200.00 98.72 23.49 8999.98 -1109.62 -6990.48 5930329.94 678842.23 12.00 -5343.41 86.30 MWD 12225.00 98.87 26.52 8996.16 -1087.23 -6980.04 5930352.58 678852.12 12.00 -5319.55 86.75 MWD 12250.00 99.01 29.55 8992.27 -1065.43 -6968.44 5930374.65 678863.18 12.00 -5295.39 87.22 MWD 12275.00 99.12 32.59 8988.33 -1044.29 -6955.70 5930396.10 678875.39 12.00 -5271.01 87.69 MWD Conoco/Phillips • Baker Hughes INTEQ Baker Hughes INTEQ Planning Report LNTE(2 Company: $P Amoco Dste:. 10/6/2005 Time: 11:00:37 Page: 3 Field: Prudhoe Bay Co-ordiaate(NE) Reference: Well: 13-31, True North Site: PB D513 Vertical (TVI)) Reference: 46:31 4/2/1994 00:00 82.3 Well: 13-31 Sectlou (VS) Reference: Well (O.OON,O.OOE,40.OOAzi) Wellpatb: Plan 4, 13-31A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Intl Aztm SS TVD N/S E/W MapN MspE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/10pft ft deg 12300.00 99.20 35.63 8984.35 -1023.86 -6941.86 5930416.87 678888.72 12.00 -5246.46 88.17 MWD 12325.00 99.26 38.66 8980.34 -1004.19 -6926.96 5930436.89 678903.13 12.00 -5221.82 88.65 MWD 12350.00 99.29 41.70 8976.31 -985.34 -6911.04 5930456.13 678918:58 12.00 -5197.15 89.14 MWD 12375.00 99.30 44.74 8972.28 -967.37 -6894.15 5930474.51 678935.03 12.00 -5172.52 89.63 MWD 12400.00 99.28 47.78 8968.24 -950.31 -6876.32 5930492.00 678952.43 12.00 -5148.00 90.12 MWD 12425.00 99.23 50.82 8964.22 -934.22 -6857.62 5930508.54 678970.73 12.00 -5123.65 90.61 MWD 12450.00 99.16 53.86 8960.22 -919.15 -6838.08 5930524.09 678989.89 12.00 -5099.54 91.10 MWD 12475.00 99.07 56.90 8956.26 -905.13 -6817.77 5930538.61 679009.84 12.00 -5075.75 91.58 MWD 12500.00 98.95 59.93 8952.35 -892.20 -6796.74 5930552.05 679030.55 12.00 -5052.32 92.07 MWD 12508.25 98.90 60.93 8951.07 -888.17 -6789.65 5930556.25 679037.54 12.00 -5044.69 92.54 MWD 12525.00 98.97 58.90 8948.46 -879.88 -6775.33 5930564.89 679051.64 12.00 -5029.13 272.00 MWD 12550.00 99.04 55.86 8944.55 -866.57 -6754.54 5930578.70 679072.10 12.00 -5005.57 271.68 MWD 12575.00 99.09 52.83 8940.61 -852.18 -6734.48 5930593.58 679091.80 12.00 -4981.65 271.21 MWD 12600.00 99.12 49.79 8936.65 -836.75 -6715.22 5930609.48 679110.68 12.00 -4957.45 270.73 MWD 12625.00 99.12 46.75 8932.69 -820.32 -6696.80 5930626.36 679128.69 12.00 -4933.02 270.25 MWD 12650.00 99.09 43.71 8928.73 -802.94 -6679.28 5930644.16 679145.77 12.00 -4908.45 269.77 MWD 12675.00 99.04 40.67 8924.79 -784.65 -6662.70 5930662.85 679161.90 12.00 -4883.78 269.29 MWD 12700.00 98.97 37.64 8920.88 -765.51 -6647.11 5930682.37 679177.01 12.00 -4859.09 268.81 MWD 12725.00 98.87 34.60 8917.00 -745.56 -6632.55 5930702.67 679191.07 12.00 -4834.46 268.33 MWD 12750.00 98.75 31.57 8913.17 -724.86 -6619.07 5930723.70 679204.04 12.00 -4809.93 267.86 MWD 12775.00 98.60 28.54 8909.40 -703.47 -6606.69 5930745.38 679215.88 12.00 -4785.59 267.40 MWD 12800.00 98.43 25.51 8905.70 -681.45 X595.46 5930767.67 679226.57 12.00 -4761.50 266.94 MWD 12825.00 98.23 22.48 8902.08 -658.86 -6585.40 5930790.51 679236.07 12.00 -4737.73 266.49 MWD 12833.25 98.16 21.49 8900.90 -651.29 -6582.34 5930798.15 679238.94 12.00 -4729.96 266.05 MWD 12850.00 98.23 23.52 8898.51 -635.97 -6576.00 5930813.62 679244.90 12.00 -4714.15 88.00 MWD 12875.00 98.30 26.55 8894.92 -613.55 -6565.53 5930836.28 679254.81 12.00 -4690.25 88.29 MWD 12900.00 98.36 29.58 8891.30 -591.73 -6553.90 5930858.39 679265.91 12.00 -4666.06 88.73 MWD 12925.00 98.39 32.61 8887.65 -570.55 -6541.13 5930879.87 679278.15 12.00 -4641.62 89.16 M W D 12950.00 98.40 35.64 8884.00 -550.08 -6527.25 5930900.67 679291.52 12.00 -4617.02 89.61 MWD 12975.00 98.39 38.68 8880.35 -530.37 -6512.32 5930920.74 679305.96 12.00 -4592.33 90.05 MWD 13000.00 98.35 41.71 8876.71 -511.48 -6496.36 5930940.02 679321.45 12.00 -4567.59 90.49 MWD 13025.00 98.29 44.74 8873.10 -493.46 -6479.42 5930958.45 679337.94 12.00 -4542.90 90.93 MWD 13050.00 98.21 47.77 8869.51 -476.35 -6461.55 5930975.99 679355.39 12.00 -4518.31 91.37 MWD 13075.00 98.10 50.80 8865.96 -460.21 -6442.79 5930992.59 679373.74 12.00 -4493.89 91.81 MWD 13100.00 97.97 53.82 8862.47 -445.08 -6423.20 5931008.20 679392.94 12.00 -4469.71 92.24 MWD 13108.25 97.92 54.82 8861.33 -440.31 -6416.57 5931013.13 679399.46 12.00 -4461.79 92.66 MWD 13125.00 97.27 56.74 8859.11 -430.98 -6402.84 5931022.80 679412.96 12.00 -4445.81 109.00 MWD 13150.00 96.27 59.59 8856.17 -417.88 -6381.75 5931036.41 679433.71 12.00 -4422.23 109.25 MWD 13175.00 95.25 62.43 8853.66 X05.83 -6360.00 5931048.99 679455.16 12.00 -4399.01 109.59 MWD 13200.00 94.23 65.25 8851.59 -394.85 -6337.64 5931060.52 679477.25 12.00 -4376.22 109.87 MWD 13225.00 93.19 68.08 8849.97 -384.97 -6314.73 5931070.96 679499.90 12.00 -4353.93 110.11 MWD 13250.00 92.15 70.89 8848.81 -376.22 -6291.34 5931080.28 679523.06 12.00 -4332.20 110.29 MWD 13275.00 91.10 73.70 8848.10 -368.62 -6267.54 5931088.46 679546.67 12.00 -4311.07 110.42 MWD 13300.00 90.05 76.51 8847.85 -362.19 -6243.38 5931095.48 679570.66 12.00 -4290.63 110.50 MWD 13308.25 89.70 77.44 8847.86 -360.34 -6235.35 5931097.54 679578.65 12.00 -4284.04 110.53 MWD 13325.00 88.02 78.54 8848.20 -356.85 -6218.97 5931101.42 679594.94 12.00 -4270.84 147.00 MWD 13350.00 85.50 80.18 8849.61 -352.24 -6194.44 5931106.64 679619.34 12.00 -4251.54 146.98 MWD 13375.00 82.99 81.83 8852.12 -348.35 -6169.87 5931111.13 679643.80 12.00 -4232.77 146.89 MWD 13400.00 80.49 83.49 8855.71 -345.19 -6145.34 5931114.89 679668.25 12.00 -4214.58 146.72 MWD 13408.25 79.66 84.05 8857.13 -344.31 -6137.26 5931115.97 679676.30 12.00 -4208.71 146.48 MWD 13425.00 79.60 82.01 8860.15 -342.31 -6120.91 5931118.38 679692.60 12.00 -4196.67 268.00 MWD 13450.00 79.53 78.96 8864.68 -336.24 -6096.66 5931123.04 679716.74 12.00 -4177.97 268.37 MWD ~' ~ • ConocoPhillips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ^ __ INTEtt Company: BP Amoco Dater 10/6/2005 Time:.. 11:00:37 Page: 4 Field: Prudhoe Bay Co-ordiaate(NE) Reference: Well: 13-31, True North Site: PB DS 13 Vertical (TVD) Reference: 46:31 4/2!1994"00:00 82.3 We14, 13-31 Section (VS) Reference: .Well (O.OONO.OOE,40.OOAzi) Wellpath: Plan 4, 13-31A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inc! ft deg 13475.00 79.48 13500.00 79.47 13525.00 79.49 13550.00 79.53 13575.00 79.61 13600.00 79.71 13625.00 79.84 13650.00 80.00 13658.25 80.06 13675.00 79.93 13700.00 79.75 13725.00 79.60 13750.00 79.48 13775.00 79.39 13800.00 79.33 13825.00 79.30 13850.00 79.30 13875.00 79.33 13900.00 79.38 13925.00 79.47 13950.00 79.58 13975.00 79.73 Azim SS TVD N/S E/W deg ft ft ft 75.91 8869.23 -332.89 -6072.67 72.86 8873.80 -326.28 -6049.00 69.80 8878.36 -318.41 -6025.72 66.75 8882.92 -309.31 -6002.89 63.70 8887.44 -299.01 -5980.56 60.66 8891.93 -287.54 -5958.82 57.61 8896.37 -274.92 -5937.70 54.57 8900.74 -261.19 -5917.27 53.57 8902.17 -256.42 -5910.70 55.60 8905.08 -246.86 -5897.25 58.64 8909.49 -233.50 -5876.59 61.69 8913.97 -221.27 -5855.26 64.74 8918.51 -210.19 -5833.31 67.79 8923.10 -200.30 -5810.82 70.84 8927.71 -191.62 -5787.83 73.89 8932.35 -184.18 -5764.42 76.95 8936.99 -178.00 -5740.65 80.00 8941.63 -173.09 -5716.59 83.05 8946.25 -169.47 -5692.29 86.10 8950.84 -167.15 -5667.82 89.15 8955.38 -166.13 -5643.27 92.20 8959.87 -166.42 -5618.68 MapN MapE DIS VS ft ft deg/100ft ft 5931128.97 679740.59 12.00 -4158.45 5931136.17 679764.08 12.00 -4138.17 5931144.61 679787.17 12.00 -4117.17 5931154.26 679809.77 12.00 -4095.53 5931165.11 679831.83 12.00 -4073.29 5931177.12 679853.29 12.00 -4050.52 5931190.25 679874.08 12.00 -4027.28 5931204.48 679894.16 12.00 -4003.63 5931209.41 679900.62 12.00 -3995.75 5931219.29 679913.83 12.00 -3979.79 5931233.15 679934.15 12.00 -3956.27 5931245.91 679955.18 12.00 -3933.19 5931257.52 679976.84 12.00 -3910.60 5931267.96 679999.08 12.00 -3888.56 5931277.20 680021.85 12.00 -3867.14 5931285.22 680045.06 12.00 -3846.39 5931291.98 680068.67 12.00 -3826.37 5931297.48 680092.61 12.00 -3807.14 5931301.70 680116.81 12.00 -3788.75 5931304.62 680141.21 12.00 -3771.25 5931306.25 680165.73 12.00 -3754.68 5931306.56 680190.32 12.00 -3739.10 TRO Tool deg 268.92 MWD 269.48 MWD 270.03 MWD 270.59 MWD 271.15 MWD 271.70 MWD 272.25 MWD 272.79 MWD 273.32 MWD 94.00 MWD 93.65 MWD 93.11 MWD 92.56 MWD 92.01 MWD 91.45 MWD 90.89 MWD 90.32 MWD 89.75 MWD 89.19 MWD 88.62 MWD 88.06 MWD 87.51 MWD BP Amoco W61JAn1 uruu n.. 4, +sa+A ~Y°ArTM rm iiis:as ~r IIS1. DStuntl N r N 4rllI0M OOrW ea.a0rt V. ~ OrIMn OrYM NartlrrS IW Ua~ rr..r n1D -_. _. 40-00' 0.00 0.00 a0.a0 REFERENCE INFORMATION CooNinate (N/E) Retererice: Wet Centre: 13-31, True Nnrth Ver6ral D) Reference: System: Mean Sea Level Section (VS) Reference: Slot - 31 (O.OON,O.OOE) Measuretl Depm Reference: 46:31 4/2/1994 00:00 82.30 Calculation Memotl: Minimum CurveNre daerres uaxuu dw r0 w r ®rv0 .rue .0_w OW no va.. •~ •e.orAno°° •vo rdo ur.etder.. ano.~4 t+aS:.as ~r Mt12S "SSS.00 01 ~~~ _ ~ wr~~ un.o+ a>•e.oo e.d s°•noo- tas aaaasa ++asa.oo 4 aw.ax +xo4a.o4 a sode.:o +a+aaas ow r ds•noo• ou w„t M wu+:°.i m°0aem ~wsm ro„u .d. asa+.o>•+xaaa.xS .aoa.so +xsaa.a asd+.aa ta+e..2S w>'x +aaa.+. w wr.+a +adoa.ae „ uaa +aa>•e.oo to a d D d io ~~ ~~ N; d 3 H rr.^ BAKER ttu~HES - by 'C!\ LEGEND 13-31 (1}31) Plan d, l}31A Plan 4, 1}31A West(-)/East(+) [100ft/in] T Azimuths t0 True North Plan: Plan 4, 13-31A (13J7/Plan 4, 73-31A) M Magnetic North: 24.93° creates ey eio Midlaelson Data: 1a62o0s Magnetic Field --,,..,I, ~,.I p„~,,,naoon. Strength: 57606nT B,ll M¢haelson Dip Angle: 80.85° Direct: (907) 267-6624 Date: 7/5/2005 Cell: (907) 30t-73670 Model: bggm2005 E-mail: bin.michaelsonQinteq eo,n l I F~:t.- .~~tll 1~ ~'; :1:.. i:l ~: ~~1 ~~_ l~T ~~" r+ ~. i i!:: :Y -5000 AM • • Vertical Section at 40.00° [50ft/in] • ~~ by To: Winton Aubert, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Barbara M. Holt, CTD Engineer Date: November 3, 2005 Re: 13-31A CTD Sidetrack Area of Review ~~ The sidetrack, injection well 13-31A, is scheduled to be drilled by Nordic 1 during the second week of December, following a RWO for P&A and tubing swap. The plan calls for setting a whipstock for an exit into the Sag, targeting Zone 4 injection. Well 13-31A will penetrate Zone 4 at approximately 11,960' MD, with a TD of 13,975' MD. Wells within 1/a mile (1,320') from the wellbore include well 14-09A (1,212' ~ $p ~~7 away). 14-09A was abandoned with a cement retainer set at 10290' in the 9-5/8" with 300 sacks of cement squeezed below and 200 sacks of cement above the retainer. Estimated cement top 9730'. An Ultrasonic Imager cement evaluation was run on May 2°d, 1994. The log shows approximately 10 feet of cement at 11,838 - 11,852' MD (near the kick off point) in the Sag River. There is currently no indication of out of zone injection for the well 13-31; however, a log will be run post-rig to verify in-zone injection for the sidetrack 13-31A. ~ Please call if you would like further discussion on this matter. Regards, ~~~~~ Barbara M. Holt CTD Engineer Ph: 564-5126 TERRIE L RUBBLE ss-si,zez 230 BP EXPLORATION- AK INC "Mastercard Check" PO BOX 196612 MB 7-5 1~' ~S,US ANCHORAGE, AK 89519-6612 DATE PAY TO THE ~ `.Sr.--~? ~~ . ORDER OF ~. n ~ .. ~ ,. ~ / DOLLARS. First Plational Bank Alaska Anchorage, AK2 99501 , MEMO i ,~'~J ~: L 25 200060:99 L4~~~6 2 2?~~~ L 55611' 0 23D • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTTAL LETITER WELL NAME ,~ ~7 / ~ J~/ PTD# z,o ~ ~ ~ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of .the original API number stated I are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (pT~ 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). SPACING The permit is approved subject to full ~ EXCEPTION compliance with 20 AAC 25.055. Approval to ~ perforate and produce/infect is contingent upon issuance of a conservation order ! approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing I exception that may occur. DRY DITCH All dry ditch sample sets submitted to the ~ SAMPLE Commission must be in no greater than 30' I sample intervals from below the permafrost ~ or from where samples are first caught and 10' sample intervals through target zones. ~ Rev: 04/01/05 C\jody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 13-31A Program SER _- Well bore seg ^ PTD#:2051600 Company BP EXPLORATION (ALASKA) INC Initial ClasslType SER! 1WINJ GeoArea 890 Unit 11650 OnlOff Shore On Annular Disposal ^ Administration ` 1 Permit_feeattached________ _______________________ Yes_ _--_---- 2 Lease number appropriate____ ___________________________ _________Yes_ ____--_.----_---__ 3 Uniquewell_nameandnumber_____________________ _ ___-.__-. Yes _-___-__--_- 4 Well located in a-defnedpool----_______-___ ____-_ Yes- ----------------- 5 Well located properdistance_fromdrillingunit_boundary_______ ______ ____ ___ Yes_ __-_-----------_ ---._-.-. -_- 6 Well located properdistance_fromotherwells--_--__.--_-_--_---_ --_.-_-. Yes_ _____________-________---_ 7 Sufficientacreageayailablein_d_rillingunit_____________ ______ __ _________Yes- -_----.__._ 8 If deviated,is-wellboreplat_inclu_ded____________________ _____ _____ ___Yes- _-___.__-----__-._ 9 Operator only affected party__________ .Yes _------------------ - - 10 Operatorhas_appropriate-bond in force..--- -- - -- -...- - - Yes- ------ -- ---------- - - -- ---- -- ~- ~----- -- -- ------ - - 11 Permit_canbeissuedwithoutco_nservationorder_____ __________-_ -_-_---Yes_ _____________________ __ ____________-__---.--_--___---_-_________ __--_ Appr Date 12 Permit_can be issued without administrative_approyal - _ _ - - - - - - - - - - - - - - -- - - - - -Yes . . - - - - - -- - RPC 11!412005 13 Can permit be approved before 15•day wait Yes 14 Well located within area and_strataauthorized by-Injection Orde[ # (put 10# in-comments).(FQr- Yes - - - - . - - AIO-3 15 Allwells_within1/4_milearea_ofCeyiewidentified(Forservicewellonly)_--_ ._-.--__-Yes_ ___-__14-09A___________________________--_-.-_________-_- ------------------ 16 Pre-produced injector; duration of pre p[oduction less than 3 months_ (For service well only) - - NA_ - _ 17 ACMP-Finding of Consistency_hasbee_nissued_for_thisproject___________ _________ NA_. __-___----__-_-_-----.__ --_______________________--_._-.__.-_--____ ____ Engineering 18 Conductor string-provided_-__-.----__--..-..-__------- ---------NA__ ____-__---.__-_-_. 19 Surface casing.protects all_knpwn U$DWS - NA - - - - - - - - 20 CMT_v_ol_adequate_tocircul_ate_o_nconductor__&surf_csg__ ___ ________ _._-_-. NA- ___-._-___________ 21 CMT-vol adequate-to tie-in long string to surf csg_ _ _ _ _ _ _ _ _ _ NA_ _ _ - - - . _ 22 CMT-will coverall known-prgductiyehorizons_--____----.----___ ---__--__Yes_ ______Adequateexcess----------------------- --- ------------------------------- 1 23 Casing designs adequatefo[C,TB&-permafrost------------------ -- Yes- ---- --.--.----------------------------------------------------- -- ~ 24 Adequate tankage_or reserve pit - - - - - - - Yes CTDU. - - 25 If a_re-drill, has a 1.0-403 for abandonment been approved Yes _ - - _ _ - -10!13!2005. -- 26 Adequatewellboreseparation_p[oposed_ __ ~_ __ _ _ _ - _.__Yes_ ______ ___ ________,... _ _ ______ __ ___ ------------------- ~ 27 If diverterrequired,doesitmeetregulations______________________ __ ______NA__ --_-.-$idet[ack.____-- __--__ ______________.___-._--_--_----.-____________--. Appr Date 28 Drillingfluid-prpgramschematic&equiplistadequate_____ --------- Yes_ ------ --_---Max MW 8,6ppg.-_______-_-_----------------------------- --- WGA 11!4/2005 29 BOPEs,.do they meet_ regulation - - Yes - - - 30 BOPE_press rating appropriate; test to_(pu_t prig in comments)_ Yes . . - - - . - Test t_o 3500_ psi. _MSI? 2720 psi, - - 31 Choke_manifoldcomplieswlAPl_RP-53(M_ay84)------------------- _-__.-_-Yes_ -__________________-- -__----_---_---_- --_.-__ 32 Work will occur without operation shutdown---------------_----_ -___--__Yes_ __________-___-__--.,------___--_----_._-_-__________-_..-_--_ __-- -___ 33 Ispresence_ofH2Sgasprobable__----------------------_ _____Yes- 120_ppmonpad._-_-_--------____.-_____-------_---------. ---- 34 Mechanical-condition of wells within AOR yerifed GFor_seruice well only) - - - - - _ - . , . - - .Yes _ Records reviewed for all_AORwells.- - _ . . . . ......... . .. . - - . Geology 35 Permit_ can be issued w!o_ hydrogen_sulfide measures . . . . . . . . ...... . ... . . ... . No- - '36 Data_presented on-potential overpressure zones_ NA_ _ Appr Date 37 Seismicanalysisofshallowgas_zones___________________-_ -- --------. NA_- -_-__- -____ RPC 1013112005 ',,38 Seabed condition survey-(ifoff-shore)_______________________ _____ ___ NA.- __--__-__-._ _ __ _-.-- ~39 Conlack namelphone for weekly progress_reports [exploratory only]_ N_A_ Geologic Engineering Public Commissioner: Date: Commissioner: Date Co Date ~J Well History File APPENDIX Information of detailed nature that is not • particularly germane io the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • 13-31a.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Dec 18 11:52:21 2007 Reel Header Service name .............LISTPE Date . ...................07/12/18 0ri9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date . ...................07/12/18 0rigin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: 13-31A API NUMBER: 500292245901 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 18-DEC-07 JOB DATA MWD RUN 3 MWD RUN 4 MWD RUN 5 JOB NUMBER: MW0004094476 MW0004094476 MW0004094476 LOGGING ENGINEER: S. LATZ S. LATZ S. LATZ OPERATOR WITNESS: B. LAULE/R. B. LAULE/R. B. LAULE/R. MWD RUN 6 JOB NUMBER: MW0004094476 LOGGING ENGINEER: B. JAHN OPERATOR WITNESS: B. LAULE / R SURFACE LOCATION SECTION: 14 TOWNSHIP: lON RANGE: 14E FNL: FSL: 1579 FEL: 1423 FWL: Page 1 u=c ~oS -r~~ ~i5~3~ ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 13-31a.tapx 82.30 48.79 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.000 5.500 11851.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS). 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK POSITIONED IN THE 13-31 WELLBORE. THE TOP OF THE WHIPSTOCK WAS AT 11851'MD/8809'TVDSS. 4. MWD RUNS 3-6 COMPRISED DIRECTIONAL WITH NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. NO DATA ARE PRESENTED FOR MWD RUNS 1,2,7-9. UPHOLE SGRD TIE-IN DATA WERE MERGED WITH RUN 3 MWD DATA. 5. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO AN OPEN-HOLE GAMMA RAY RUN ON 12/15/2005 IN 13-31A. THESE LOG DATA WERE PROVIDED TO SDS BY D. DORTCH (SAIC/BP) ON 8/29/07, AS AUTHORIZED BY COLE ABEL (BP). LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 3-6 REPRESENT WELL 13-31A WITH API#: 50-029-22459-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13928'MD/8958'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED NATURAL GAMMA RAY. File Header Service name... .......STSLIB.001 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......07/12/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 Page 2 13-31a.tapx FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 11803.0 13909.0 ROP 11874.0 13933.0 BASELINE. CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 11803.0 11816.5 11820.0 11826.5 11830.0 11833.0 11835.0 11853.0 11859.5 11861.0 11865.5 11868.5 11878.5 11884.5 11889.0 11892.5 11897.0 11899.0 11903.5 11908.0 11912.5 11915.0 11916.5 11918.0 11923.0 11929.0 11933.0 11942.0 11943.0 11946.0 11949.0 11951.0 11960.0 11963.0 11965.0 11971.0 11993.5 11995.0 12002.5 12004.5 12006.0 12025.5 12043.0 12055.5 12062.0 12086.0 12120.0 12121.5 12134.0 12147.5 12175.0 12201.5 12210.0 11802.5 11816.0 11819.5 11827.0 11830.0 11832.0 11835.0 11853.5 11860.0 11861.5 11865.0 11869.0 11879.0 11884.0 11889.5 11892.5 11897.5 11899.5 11904.5 11908.0 11913.0 11915.5 11917.5 11918.5 11923.0 11928.0 11932.5 11942.0 11943.0 11945.5 11948.5 11950.5 11960.5 11962.5 11964.5 11970.5 11993.0 11995.5 12002.5 12004.5 12006.0 12024.5 12043.0 12054.5 12061.5 12087.5 12118.5 12121.5 12136.0 12148.5 12174.0 12201.5 12211.0 Page 3 12216.0 12237.5 12240.5 12244.5 12251.0 12260.0 12269.5 12283.0 12285.5 12288.0 12295.5 12305.5 12314.5 12330.5 12338.5 12347.5 12358.5 12372.5 12404.0 12409.0 12423.0 12426.0 12446.0 12452.0 13933.0 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD 12216.5 12235.0 12239.5 12244.0 12249.5 12260.0 12268.0 12281.0 12283.5 12286.0 12293.5 12303.0 12313.0 12327.5 12336.5 12345.0 12356.0 12370.0 12400.5 12405.0 12420.5 12425.0 12441.0 12447.5 13928.0 13-31a.tapx BIT RUN NO MERGE TOP 3 11802.5 4 12103.0 5 12470.0 6 12712.0 REMARKS: MERGED MAIN PASS. MERGE BASE 12103.0 12470.0 12712.0 13927.5 Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Ldst Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 11803 13933 12868 4261 11803 13933 GR MWD API 19.16 807.1 62.1636 4213 11803 13909 ROP MWD FT/H 0.16 1778.75 104.642 4119 11874 13933 Page 4 13-31a.tapx First Reading For Entire File..........11803 Last Reading For Entire File...........13933 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLi6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11802.5 12076.0 ROP 11874.5 12103.0 LOG HEADER DATA DATE LOGGED: 11-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 3.35 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12103.0 TOP LOG INTERVAL (FT): 11874.0 BOTTOM LOG INTERVAL (FT): 12103.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 20.9 MAXIMUM ANGLE: 74.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray 005 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.000 DRILLER'S CASING DEPTH (FT): 11851.0 Page 5 13-31a.tapx BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 9,0 MUD CHLORIDES (PPM): 23500 FLUID LOSS (C3): 5.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 116.4 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 ROP MwD030 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11802.5 12103 11952.8 602 11802.5 12103 GR MWD030 API 20.73 786.9 99.3144 548 11802.5 12076 ROP MWD030 FT/H 0.74 150.23 51.7449 458 11874.5 12103 First Reading For Entire File..........11802.5 Last Reading For Entire File...........12103 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/18 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Page 6 ~ ~ 13-31a.tapx Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12076.5 12446.0 ROP 12103.5 12470.0 LOG HEADER DATA DATE LOGGED: 11-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 3.35 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12470.0 TOP LOG INTERVAL (FT): 12103.0 BOTTOM LOG INTERVAL (FT): 12470.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.9 MAXIMUM ANGLE: 99.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray 016 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.000 DRILLER'S CASING DEPTH (FT): 11851.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 45000 FLUID LOSS (C3): 8.5 RESISTIVITY (OHMM) AT TEMPERATU RE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMP ERATURE: .000 116.4 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O Page 7 • 13-31a.tapx NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..... .....0 Data specification Block Type .....0 Logging Direction ............ .....DOwn Optical log depth units...... .....Feet Data Reference Point ......... .....undefined Frame Spacing....... ....... .....60 .lIN Max frames per record ........ .....undefined Absent value ................. .....-999 Depth units. .. .. ..... Datum Specification Block sub -type...0 Name service order units size N sam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD040 API 4 1 68 4 2 ROP MwD040 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12076.5 12470 12273.3 788 12076.5 12470 GR MwD040 API 21.2 173.67 45.6989 740 12076.5 .12446 ROP MWD040 FT/H 3.09 208.73 84.3165 734 12103.5 12470 First Reading For Entire File..........12076.5 Last Reading For Entire File...........12470 File Trailer Service name... .......STSLIB.003 service sub Level Name... Version Number. ........1.0.0 Date of Generation.......07/12/18 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.003 Page 8 13-31a.tapx Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12446.5 12687.0 ROP 12470.5 12712.0 LOG HEADER DATA DATE LOGGED: 12-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 3.35 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12712.0 TOP LOG INTERVAL (FT): 12470.0 BOTTOM LOG INTERVAL (FT): 12712.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 95.3 MAXIMUM ANGLE: 96.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray 005 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.000 DRILLER'S CASING DEPTH (FT): 11851.0 BOREHOLE CONDITIONS MUD TYPE: KCL/Flo Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3): 9.0 RESISTIVITY (OHMM) AT TEMPERATU RE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMP ERATURE: .000 142.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format specification Record Page 9 f ~ 13-31a.tapx Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ., ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 GR MwD050 API 4 1 68 4 2 ROP MWD050 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12446.5 12712 12579.3 532 12446.5 12712 GR MWD050 API 20.34 173.47 60.771 482 12446.5 12687 ROP MWD050 FT/H 1.46 343.75 68.5381 484 12470.5 12712 First Reading For Entire File..........12446.5 Last Reading For Entire File...........12712 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header service name... .......STSLI6.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12687.5 13904.0 ROP 12712.5 13927.5 Page 10 ~ ~ 13-31a.tapx LOG HEADER DATA DATE LOGGED: 14-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 3.35 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13928.0 TOP LOG INTERVAL (FT): 12712.0 BOTTOM LOG INTERVAL (FT): 13928.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 81.7 MAXIMUM ANGLE: 100.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER $CG Natural gamma ray 016 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.000 DRILLER'S CASING DEPTH (FT): 11851.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 45000 FLUID LOSS (C3): 9.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 139.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing ........ ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 Page 11 13-31a.tapx GR MWD060 API 4 1 68 4 2 ROP MWD060 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12687.5 13927.5 13307.5 2481 12687.5 13927.5 GR MWD060 API 19.16 807.1 58.9897 2434 12687.5 13904 ROP MWD060 FT/H 0.16 1778.75 127.9 2431 12712.5 13927.5 First Reading For Entire File..........12687.5 Last Reading For Entire File...........13927.5 File Trailer Service name... .......STSLI6.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/18 Maximum Physical Record..65535 File Type ................L0 Next File Name...........sTSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/12/18 Origin ...................sTs Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................sTS LIS Writing Library. Scientific Technical services Reel Trailer Service name .............LISTPE Date . ...................07/12/18 Ori 9in ...................sTS Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 12