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205-010
7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU I-100 Renew Well Suspension Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-010 50-029-23245-00-00 ADL 0047446 8140 Conductor Surface Intermediate Production Liner 6882 80 2592 8105 8047 20" 9-5/8" 7" 6809 30 - 110 30 - 2622 26 - 8131 30 - 110 30 - 2582 26 - 6875 None 470 3090 5410 None 1490 5750 7240 None 4-1/2" 12.6# L-80 24 - 4021N/A Structural No Packer No SSSV Installed Date: Torin Roschinger Operations Manager Oliver Sternicki oliver.sternicki@hilcorp.com 907.564.4891 Prudhoe Bay 9/9/2025 Current Pools: Schrader Bluff Oil, Orion Dev Area Proposed Pools: Schrader Bluff Oil, Orion Dev Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:58 am, Aug 27, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.08.26 21:32:35 - 08'00' Torin Roschinger (4662) 325-520 DSR-9/24/25 Suspension renewal approved given: 1) A 10-403 for a complete P&A, including surface, is submitted and approved by 12/31/27. 2) The well is P&A'd, including surface, by 6/30/2028, unless otherwise agreed by the AOGCC. JJL 9/24/25 No Form Required 6/30/2028 A.Dewhurst 07OCT25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.10.07 13:42:49 -08'00'10/07/25 RBDMS JSB 100825 Hilcorp North Slope, LLC Torin Roschinger, PBW Operations Manager 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 08/25/2025 Commissioners – Jesse Chmielowski, Greg Wilson Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Orion Well I-100 (PTD #205010) Application for Renewal of Existing Suspension (10-403) Dear Commissioner Chmielowski and Commissioner Wilson, An AOGCC witnessed suspended well inspection of Orion well I-100 was conducted on 07/04/2025 (20 AAC 25.110 (h)). The submitted suspended well inspection reflects the current condition of the well (reference 20 AAC 25.110 (f)) and supports the request for renewal of suspension. Recent events from this well indicate that this well is mechanically sound. Specific attachments include: x Suspended Well Site Inspection form documenting the site condition. x Wellbore diagram illustrating the current configuration of the well. Orion well I-100 was suspended on 04/17/2006 and has future utility as an exploration well tied to O-pad and I-pad development. The strata through which the well was drilled is neither abnormally geopressured nor depleted. The well is secured with unperforated casing and cement. The well is mechanically sound as proven by a pressure test of the 7” casing and cement on 4/16/2006 to 3500 psi. Based on these conditions and the inspection on 07/04/2025, Orion well I-100 meets the provisions required in 20 AAC 25.110 (a)(1). Hilcorp North Slope, LLC requests approval for renewal of the existing suspension status for this well. Attached is an Application for Sundry Approval (10-403) with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h)). In summary, Hilcorp believes Orion well I-100 is mechanically sound and secure and meets the requirements for renewal of suspended status. If you have any questions, please call me at 406-570-9630 or Oliver Sternicki at 907-564-4891. Sincerely, Torin Roschinger PBW Operations Manager Attachments Technical Justification 2025 Suspended Well Site Inspection Form Wellbore Schematic Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.08.25 15:59:33 - 08'00' Torin Roschinger (4662) Orion Well I-100 (PTD #205010) Technical Justification for Renewal of Suspended Status 08/25/2025 Well History and Status Orion well I-100 (PTD# 205010) was suspended on 04/17/2006 after being drilled from an ice pad as an appraisal well for the Schrader Bluff and Kuparuk accumulations. The surface location was originally selected based on a potential future gravel pad design just east of the Milne Point access road, The well was suspended per plan without being completed or perforated. It is secured with cemented casing and has no communication to the reservoir. A kill string was run to 4020', the well freeze protected and a BPV was set in the tubing hanger. There is a likelihood that this well will be used to collect fluid samples and/or additional subsurface data to assist our team in appraising the ongoing O-Pad and I-Pad development plan. The well future utility is as an exploration well candidate. In the current state the well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, is secure, safe and not a threat to public health. The strata through which the well was drilled is neither abnormally geo-pressured or depleted. Condition of the Wellhead and Surface Location Orion well I-100 is not located on a pad and is situated approximately 450’ east of the Milne Point access road on the tundra. The surrounding area is in good condition. There is no discoloration and no sheens around the well or on nearby water. The well pressure readings are not accessible due to VR plugs and a BPV installed. Request Hilcorp North Slope, LLC requests approval for renewal of the existing suspension status for I-100. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. PBU I-100 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-010 50-029-23245-00-00 8140 6882 80 2592 8105 8047 20" 9-5/8" 7" 6809 30 - 110 30 - 2622 26 - 8131 30 - 110 30 - 2582 26 - 6875 None None 1490 5750 7240 None 4-1/2" 12.6# L-80 24 - 4021 N/A No Packer No Packer Torin Roschinger Operations Manager Andrew Ogg andrew.ogg@hilcorp.com 907.659.5102 Prudhoe Bay, Schrader Bluff Oil, Orion Development Area ADL 0047446 24 - 3864 N/A N/A 0 0 0 0 0 0 0 0 0 0 N/A Schrader Bluff Oil, Orion Development Area No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.07.10 17:05:54 - 08'00' Torin Roschinger (4662) By Grace Christianson at 8:28 am, Jul 11, 2025 RBDMS JSB 071725 JJL 7/21/25 DSR-7/21/25 I-100 Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 08/05/2025 InspectNo:susGDC250704070635 Well Pressures (psi): Date Inspected:7/4/2025 Inspector:Guy Cook If Verified, How?Other (specify in comments) Suspension Date:4/17/2006 Tubing: IA: OA: Operator:Hilcorp North Slope, LLC Operator Rep:Andy Ogg Date AOGCC Notified:6/27/2025 Type of Inspection:Subsequent Well Name:PRUDHOE BAY UN ORIN I-100 Permit Number:2050100 Wellhead Condition Rusty, but in decent condition. A shipping cap installed on the SSV prevents it from closing. The conductor has an unplugged 4" tapped hole that is low enough to take in water from the cellar. Suface csg hanger flutes oare above the cellar preventing water entering the conductor. Surrounding Surface Condition Well guard around the well. Natural growth/tundra with no signs of hydrocarbons. Condition of Cellar Snow melt/rain water. No signs of hydrocarbons visible. Comments Well verified by map. Supervisor Comments Photos (7) Suspension Approval:Completion Report Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Tuesday, August 5, 2025 jbr 2025-0704_Suspend_PBU_I-100_photos_gc Page 1 of 4 Suspended Well Inspection – PBU I-100 PTD 2050100 AOGCC Inspection Rpt # susGDC250704070635 Photos by AOGCC Inspector G. Cook 7/4/2025 2025-0704_Suspend_PBU_I-100_photos_gc Page 2 of 4 Water in well cellar 2025-0704_Suspend_PBU_I-100_photos_gc Page 3 of 4 Unplugged 4-inch port on Conductor 2025-0704_Suspend_PBU_I-100_photos_gc Page 4 of 4 Shipping Cap installed on SSV Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:205-010 6.50-029-23245-00-00 Prudhoe Bay, Schrader Bluff Oil Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 8140 8047 6809 None None None NOne Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 30 - 110 30 - 110 1490 470 Surface 2592 9-5/8" 30 - 2622 30 - 2582 5750 3090 Intermediate Production 8105 7" 26# 26 - 8131 26 - 6875 7240 5410 Perforation Depth: Measured depth: None feet True vertical depth: N/A feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 24 - 4021 24 - 3864 Packers and SSSV (type, measured and true vertical depth) None Liner 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Suspended Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Andy Ogg PBFieldWellIntegrity@hilcorp.co Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907-659-5102 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP 5 SPLUG 16. Well Status after work:Oil Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured6882 Sundry Number or N/A if C.O. Exempt: No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Inspect Suspended Well Operations shutdown Change Approved Program 5 N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 047446 I-100 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations m By Samantha Carlisle at 1:11 pm, Aug 19, 2020 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.08.19 13:03:55 - 08'00' Stan Golis RBDMS HEW 8/19/2020 DSR-8/20/2020 SFD 8/19/2020MGR02SEP2020 ACTIVITY DATE SUMMARY 8/2/2020 T/I/O = BPV/VR plug/VR Plug. Suspended well inspection by AOGCC rep Matt Herrera. Daily Report of Well Operations PBU I-100 Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name:Prudhoe Bay Unit I-100 Field/Pool: Prudhoe Bay / Schrader Blf-Orion Permit # (PTD):2050100 API Number: Operator:Hilcorp North Slope LLC Date Suspended: 4/17/2006 Surface Location:Section: 20 Twsp: 12N Range: 11E Nearest active pad or road:MPS-Pad / MP Access Road Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Normal condition. Pad or location surface: Good. Location cleanup needed: No. Pits condition: N/A. Surrounding area condition: Good. Water/fluids on pad: Non pad. Discoloration, Sheens on pad, pits or water: None. Samples taken: None Access road condition: Milne access road in good condition. Photographs taken (# and description): No. Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Tree - Swab, Flow Cross with Wing, Surface Safety, Master. Wellhead - TBG spool with 2 casing valves, Starting head with 1 casing valve. Cellar description, condition, fluids: Snow/ice melt. Clean water. Fluid level in cellar below lowermost casing valve. Rat Hole: N/A Wellhouse or protective barriers: Yes, guard. Well identification sign: Yes. Tubing Pressure (or casing if no tubing): BPV/SSV closed. Annulus pressures: VR plugs in IA and OA. Wellhead Photos taken (# and description): Yes. (1) sign and wellhead/tree. Work Required: None Operator Rep (name and signature):Eric Dickerman AOGCC Inspector: Matt Herrera Other Observers: Inspection Date: 8/2/2020 AOGCC Notice Date: 7/31/2020 Time of arrival: 8:00am Time of Departure: 8:20am Site access method: Truck/Walk. 500292324500 Re-Inspection ' Suspended Well—Inspection Review Report |nspect0o: susMFH200804104425 Date Inspected: 8/2/2020 ' Inspector: Matt Herrera Type of I nspection VVeUName� PRUDHOEBAY UNBORE |'I0O � - Permit Number: _ 2050100 ' � _ SuypensionApprova|� Completion Report Suspension Date: 4/17/2006 � Location Verified? |fVerified, How? ' Other (specify incomments)Offsh,ore? El Subsequent Date A0G[[Notified: 7/31/I020 Operator: Hi|corpNorth Slope, LLC Operator Rep: EhcDickennan Wellbore Diagram Avail? Photos 'Taken? Well Pressures (psi): Tubing: Fluid in Cellar? |A: [) BPV|nstaUed? DA: 0 VRNug(s)Installed? El Wellhead Condition Access on tundra by foot. Wellhead in good condition . BPV Installed but annulus valves operational and fitted for digital ' gauge. Novisible leaks SSV still installed but capped. Condition ofCellar Some water in cellar but well below OA casing valve flange. Clean with no visible sheen. - Surrounding Surface Condition Novisible stains ortund/avegetation compromised. ' Comment-,, Location Verified Aerial Photo Map. Operator informed to update well sign information (company name). . Supewisor[omments Photos (9)include corrected well sign (8/4/202O) J�p 'b/zt;/ Monday, August l7'Z0ZO U O b N O W O O N O N N O 00 O O N O N • fr ti OF 71i, • re, I%% s, THE STATE Alaska Oil and Gas � � ofAS Conservation Commission TKA Witt 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALASY'P Fax: 907.276.7542 www.aogcc.alaska.gov CANE) '4v ` 2015 Ryan Daniel Alaska Wells Integrity& Compliance Team Leader BP Exploration(Alaska), Inc. ©� P.O. Box 196612 ©S Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Schrader Bluff Oil Pool,PBU BORE I-100 Sundry Number: 315-582 Dear Mr. Daniel: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Approval is granted contingent on development of a P&A plan for suspended wells with no future utility which brings these wells closer to abandonment prior to pad decommissioning. This plan must be developed and approved through the Commission by 12-31-2016. Failure to comply with this requirement will invalidate this sundry. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this2D day of October, 2015 Encl. RBDMS� MnV022015 RECEIVED a • STATE OF ALASKA SEP 2 1 2015 ALASKA OIL AND GAS CONSERVATION COMMI ON APPLICATION FOR SUNDRY APPROVALS 0-"C% W 20 AAC 25.280 ¢y� ' 'L7 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 ` 'Olins shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 5v5Pek SJR 19• ,trn, rthi!wit I 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 205-010 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development O. 99519-6612Stratigraphic 0 Service ❑ 6. API Number: 50-029-23245-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PRUDHOE BAY UN BORE 1-100 • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0047446• PRUDHOE BAY, 6cAst.AOt2 is,WFF OSL 11. PRESENT WELL CONDITION SUMMARY eac 142_15 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8140 • 6882 • 8047 6809 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 30-110 30-110 1490 470 Surface 2592 9-5/8"40#L-80 30-2622 30-2582 5750 3090 Intermediate Production 8105 7"26#L-80 26-8131 26-6875 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4-1/2"12.6#L-80 L-80 24-4021 Packers and SSSV Type: No Packer Packers and SSSV MD(ft)and TVD(ft): No Packer No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development 0 • Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended 0 • 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned 0 Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Daniel,Ryan Email Ryan.Daniel@bp.com Printed Name Daniel,Ryan Title Alaska Wells Integrity&Compliance Team Leader Signature Phone +1 907 564 5430 Date ? -5 /W 20/T— COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: ;(5'G112- Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other:4 pv-6 v4 / 15 c1 rq r, trd G Uv, 1--C.1---2 q tq f- n n. dtvt / d/� r,-i rh 1,' ° f /��tl `J ! fo f-- p t n cl rt,� ✓v e it 5 W o�t 61 1,10 /F,tv,,--e. v f-1�1 r' LA, 1-1 i`c l-� b r r`r1 c> 5 fi"i'z�-S�c wt1 5 CLb5t1' 7L-2 a bav,c(ov:><tiithf- Prior 1-0 ped c�lrcu w, is5f v"'"1'� p et, Ian o he dr veto pz �thd tc ro uveal 't-hp-otza ht _e, t, i lvrt to cowly�/ op _irks bn� v Yt s-vr.tYt�' W``6 fi b n v a it` SS r`o h �7 )2 j3. . Spacing Exception Required? Yes No I�1 Subseq nt orm Required � e 1 t-- -aO+n y.A. Tog APPROVED BYTHE Approved by:61/67 COMMISSIONER COMMISSION Date:M_a.•-/$ 1/TL- I6/a4// L- ORIGINAL RBDMS ltrrn► 0 2 2015 X/0 i✓r Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate MEE= 4-118OW • —SIC NOTES: ;Itha_LI-EAD= FMC I 00 ACTUATOR= N/A ELEV= 74-4 SUSPENDED 4/18/06 BF EIEV= 7165 KOP= 750' Max Angle= 44 @ 5051' Datum MD= 4858.46' Datum TVD= 4400'SS 1 009' 5/8-Tam Port Collar CONDUCTOR, ,1,14= - — ? 9-5/8-CSG,40#,L-80 BUTT,ID=8.835" — 2621' —A Minimum ID = 3.958" @ SURFACE -4000' 4-112" TUBING STRING 3884' --17-RA TAG / " EG " 4 1/2"TBG, 12.6#,L-80 IBT-M, 4020' 4020' —4 1/2 W ,,U=3 958 0152 bpf,ID=3.958" 4244' H7"RA TAG 7'Cog,26#,L-80 TC11 XO TO L-80 BTC — 6020' ' 7780' H7" MARKER JOINT w/RA TAG 4.4e,t,eizrue pe-rD — 804T 7"CSG,26#,L-80 BTC, .0383 bpi,ID=6.276" H 8130' DATE REV BY CONVENTS DATE REV BY COMAENTS LNT: ORION 04/18/06 BJB SUSPRCED CONFLETTON WELL 1-100 04/18/11 A43/JM) LEGEND CORRECTIONS FERMT No- 'N050100 0750/15 PJC CRAVVING CLEANUP AFI lb: 50-029-23245-00 SEC.20.T12N,R11E,2062'FTC&1335'AM_ BP Exploration(Alaska) • • bp BP Exploration (Alaska) Inc. Douglas A. Cismoski, P.E., BPXA Wells Intervention Manager Post Office Box 196612 Anchorage,Alaska 99519-6612 September 3, 2015 Ms. Cathy P. Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Orion Unit Well 1-100 (PTD # 2050100) Application for Renewal of Existing Suspension (10-403) Dear Ms. Foerster, BP Exploration (Alaska) Inc. completed an AOGCC witnessed suspended well inspection of Orion Unit well 1-100 on 6/15/2014 (20 AAC 25.110 (h). This recently submitted suspended well inspection reflects the current condition of the well (reference 20 AAC 25.110 (f)) and supports the request for renewal of suspension. Recent events indicate that this well is mechanically sound. Specific attachments include: • Wellbore diagram illustrating the current configuration of the well • Suspended Well Site Inspection form documenting the pressures and site condition Orion Unit well 1-100 was suspended on 4/17/2006. It is not located on a gravel pad and was drilled from an ice pad adjacent to the Milne Point access road. The strata through which the well was drilled is neither abnormally geopressured or depleted. The well is secured with unperforated casing and cement. The well is mechanically sound as proven by a pressure test after the cement was placed and the tree install. Based on these conditions and the inspection on 6/15/2014 Orion Unit well 1-100 meets the provisions required in 20 AAC 25.110 (a)(1). Based on this information, BPXA requests approval for renewal of the existing suspension status for this well. Attached is an Application for Sundry Approval (10-403) with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h) and (i)). In summary, BPXA believes Orion Unit well 1-100 is mechanically sound and secure and meets the requirements for renewal of suspended status. If you have any questions, please call me at 564-4303 or Whitney Pettus/ Kevin Parks at 659-5102. Sincerely, • • DougfaW. ismoski, P.E. BPXA Wells Intervention Manager Attachments Technical Justification 2014 Suspended Well Site Inspection form Wellbore Schematic Cc: Doug Cismoski Pettus/ Parks Ryan Daniel • • Orion Unit Weill-100 (PTD 2050100) Technical Justification for Renewal of Suspended Status September 3, 2015 Well History and Status Orion Unit well 1-100 (PTD 2050100) was suspended on 4/17/2006 after being drilled as an appraisal well for the Schrader Bluff and Kuparuk accumulations. The surface location was originally selected based on a potential gravel pad design and is positioned within the future row of wells based on that design. Future I Pad viscous oil development is subject to successful demonstration of sand control technology in the Schrader Bluff Formation. If a trial of sand control technology is successful, the learnings will be incorporated into development planning and I Pad will be re-evaluated at the prevailing market conditions. The well has potential future utility for surveillance, a pilot study or inclusion in a small satellite pad. The well was suspended per plan without being completed or perforated. It is secured with cemented casing with no communication to the reservoir. A kill string was run to 4020', the well was freeze protected and a BPV was set in the tubing hanger. In the current state the well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, is secure, safe and not a threat to public health The strata through which the well was drilled is neither abnormally geo-pressured or depleted. Condition of Wellhead and Surface Location Orion Unit well 1-100 is located on the tundra having been drilled from an ice pad. The surrounding area is in good condition, there is no discoloration and no sheen on the tundra or in nearby water. The wellhead is in good shape with no issues. The well pressure readings are T/I/O= NA/0/0 psi recorded on 6/15/2014 and are stable. Request BPXA requests approval for renewal of the existing suspension status for 1-100. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to remain as suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. • Suspended Well Site Inspection Form 10 Year inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Names 1-100 Field/Pool: Prudhoe Bay Field/SchraderBLF-Orion Permit#(PTD): 2050100 API Number: 50-029-23245-00 Operator: BP EXPLORATION(ALASKA)INC Date Suspenc 4/17/2006 Surface Location Section: 20 Twsp 12N Range' R-11E Nearest active pad or road MPS-Pad Take to Location (Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site Clearance documentation Pressure gauges,fillings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1)a description of the condition of the surface location,including discoloration,fluids or sheens visible On the ground or in any nearby water, 2)photographs showing the condition of the location surrounding the well General location condition: good normal Tundra conditions Pad or location surface. Good Location cleanup needed No Pits condition: N/A Surrounding area condition. Good Water/fluids on pad: No Discoloration,Sheens on part,pits or water: No sheens Samples taken: No Access road condition: Good graded smooth Photographs taken(#and description): No Condition of Wellhead AOGCC requires: 1)a description of the Condition of the wellhead.2)well pressure readings,where practicable, 3)photographs showing the wellhead condition Weilheadttreeivalve description,conthtion FMC wellhead CIW Tree No flowfine BPV in TBG IA and CA valves functioned Cellar description,condition, fluids snow meltilce clean Rat Hole. N/A Welthouse or protective barriers, yes Guard Well identification sign: yes Tubing Pressure(or casing if no tubing): BPV/SSV is dosed Annulus pressures: IA=0 psi OA=0 psi Wellhead Photos taken(#and description): yes (1)sign(5)wellhead/tree(1)cellar Work Required: None Operator Rep(name and signature): Jack Disbrow 0 AOGCC Inspector Bob Noble Ot -r 0 servers: Kewir Parks Inspection Date 6/1512014 As CI, Notice Date: 6/14/2014 Time of arrival: 2:20 PM Time of Departure 2:50 PM Site access method. Trt,cic/walk • • TREE- 41f6'CAN ..°1 SAFETY NOTES: FA WELLFEAD= C ACTUATOR= WA "F ELEV= 74.4 SUSPENDED 4/18/08 BF ELEV flEV= 7165 KCP= 750' litoc Angle= 44 @ B05,' IJu:um A4J= 4858-46' Durum TVD= 4400 SS CONDUCTOR #, 1009' 1'�',rtt'1.111)Wit Collar I0-518"CSG 4011 I-80 RIITT 1)=8 815" H 9491' Minimum ID=3.958"@ SURFACE -4000' 4-1/2" TUBING STRING • I 3884-i T RA TAG 4 11?TBG,12.6#,1-80 BT-M, --1 4020 j 4024' 4 112'W iG.ID.3 958`, .0152 bpf,D=3.958• • 4244 r RA TAG /'C g,260 r 8O tC11 XO If i_ BO HI( H 6020' 2—I 7280• H 7" MARKER.DONT w 1 RA TAG MID —I 804T AP 1106 [T CSG.26#,1-80 BTC,.0383 bpf,D=6,276"_I 8130' DATE REV BY COMMENTS DATE REV BY COINA T'S UNE ORLON 04/18/06 BAB SUSPEICEDC AEtEf1ON WELL 1,100 04/18/11 WB/M) LEWD CORFECTTJNS FUOVIT No: 1050100 07/30/15 PJC DRANK i CLEANUP API No. 50-029-23245-00 SEC.29,T12N,R11 E,206Z FM.&1335 EVIL BPExpbration(Allasa! • • Loepp, Victoria T (DOA) From: Daniel, Ryan <Ryan.Daniel@bp.com> Sent: Thursday, October 22, 2015 9:01 AM To: Loepp, Victoria T (DOA) Cc: Sternicki, Oliver R Subject: FW: PBU Suspension Renewal Wells Good Morning Victoria, Thanks for the conversation this morning. BPXA currently have 59 suspended status wells,of which many would not have *future utility today. My view for the business and from a risk perspective is to leave these wells "as is" until pad level decommissioning.The SU wells on pads with trees are monitored daily and pose minimum risk to our operations. Any wells,that are determined to have a higher risk associated with communication, re-pressurization etc will certainly be given priority for intervention and mitigation. *Additionally, as the business starts to realign from oil to gas over the next 10-15 years we would want to preserve various options(wells and surface locations)for the future. Let me know if you have any other questions Rgds Ryan From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, October 21, 2015 3:56 PM To: Sternicki, Oliver R Subject: RE: PBU Suspension Renewal Wells Oliver, At what point will these wells with no future utility be brought closer to abandonment?Approximately how many suspended wells are in this category? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppr alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov 1 • • Loepp, Victoria T (DOA) Subject: From: Daniel, Ryan [mailto:Ryan.Daniel©bo.com] Sent: Tuesday, October 20, 2015 4:25 PM To: Loepp, Victoria T(DOA); Sternicki, Oliver R Cc: Regg, James B (DOA); Julian, Jennifer Y; Bill, Michael L (ASRC) Subject: RE: PBU Suspension Renewal Wells Hello Victoria, Negative. BP and its working Interest owners are developing some longer term options for"decommissioning" work scope which includes some wells and surface kit.These are screening opportunities only(potential future activities)and still in the very early scoping stage. They are not funded or approved yet,and as such it would be premature for BPXA to comment any further. The Observation well P&A program which I discussed recently with Jim, and the Suspended well renewal applications submitted by Oliver are also separate (discrete and unrelated)activity plans for well stock management and as such have different timelines and rational. We are happy to discuss the Suspended wells further id necessary. If you could use Oliver as the single point of contact for this work that would be much appreciated. Thanks Ryan From: Loepp, Victoria T(DOA) [mailto:victoria.loeDDC�alaska.gov] Sent: Tuesday, October 20, 2015 2:16 PM To: Daniel, Ryan Subject: PBU Suspension Renewal Wells Ryan, Do you have any information to share with us on the sustained P&A program and where these suspension renewal wells fit in the program? Thanx, Victoria 1 • • From: Sternicki, Oliver R [mailto:Oliver.Sternicki@bp.con,] Sent: Thursday, October 08, 2015 4:03 PM To: Loepp, Victoria T(DOA) Cc: Daniel, Ryan Subject: PBU Suspension Renewal Wells Victoria, This is the response from Base Management for the 9 suspended wells renewals and if the fall under A or B of 20AAC 25.110(a)(2). 20 AAC 25.110(a)(2):the well (A) has future utility as an exploratory, development,or service well; (B) is a viable candidate for redrilling; or (C) is located on a pad or platform with active producing or service wells. WGI-01: no current sidetrack plans 02-30B: no current sidetrack plans G-13A: no current sidetrack plans, but may use surface equipment for another well V-201: no current sidetrack plans S-14A: no current sidetrack plans W-09A: no current sidetrack plans E-18B: evaluating several sidetrack options NK-14A: evaluating a sidetrack option Y-25A: no current sidetrack plans Let me know if you have any other questions. Regards, Oliver Sternicki w *Ws or/pm/oboe Well Integrity Engineer BP Exploration Alaska Office: 1 (907) 564 4301 Cell: 1 (907) 350 0759 oliver.sternicki(cr�.bp.com From: Loepp, Victoria T(DOA) [mailto:victoria.loepo@alaska.gov] Sent: Monday, September 28, 2015 3:10 PM To: Sternicki, Oliver R Subject: RE: PBU Suspension Renewal Wells So no well listed below,with the exception of 1-100 has future utility as an exploratory, development, or service well and no well listed below is a viable candidate for redrilling? I understand the wells are all located on active pads. Victoria Victoria Loepp Senior Petroleum Engineer 2 ` i • - State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppaalaska.00v CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepo@alaska.gov From: Sternicki, Oliver R [ .Oliver.Sternickabp.com] Sent: Monday, September 28, 2015 2:41 PM To: Loepp, Victoria T(DOA) Cc: AK, D&C Well Integrity Coordinator; Daniel, Ryan Subject: RE: PBU Suspension Renewal Wells Victoria, The below wells that you have listed fall under the category; (C) is located on a pad or platform with active producing or service wells. 1-100 which you did not list is the only well that BPXA sent for renewal of suspended status that falls under the category. (A) has future utility as an exploratory,development,or service well; no wells meet the (B)criteria. Regards, Oliver Sternicki w Well Integrity Engineer BP Exploration Alaska Office: 1 (907) 564 4301 Cell: 1 (907) 350 0759 oliver.sternicki(a�bp.com From: Daniel, Ryan Sent: Monday, September 28, 2015 9:26 AM To: Sternicki, Oliver R Cc: AK, D&C Well Integrity Coordinator Subject: FW: PBU Suspension Renewal Wells Oliver, Can you please reply to Victoria on this question, Copy me,or come and discuss if we have an issue. Thanks Ryan 3 • • From: Loepp, Victoria T(DOA) [mailto:victoria.loeppCa>alaska.gov] Sent: Monday, September 28, 2015 9:25 AM To: Daniel, Ryan Subject: PBU Suspension Renewal Wells Ryan, PBU 02-30B 200-126 PBU V-201 201-222 PBU E-18B 204-139 PBU G-13A 200-163 PBU S-14A 204-071 PBU W-09A 204-102 PBU WGI-01 179-031 PBU Y-25A 208-140 PBU NK-14A 206-031 20 AAC 25.110(a)(2):the well (A) has future utility as an exploratory, development,or service well; (B) is a viable candidate for redrilling;or (C) is located on a pad or platform with active producing or service wells. Which wells meet the criteria of(A)and/or(B)? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a alaska.Qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or .ia.Loepp@alaska.go, 4 STATE OF ALASKA ALASKAL AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Other Q INSPECT Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ WELL Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development❑✓ Exploratory ❑ \ 205 -0100 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 '-% 50- 029 - 23245 -00 -00 8. Property Designation (Lease Number) : ` 9. Well Name and Number: ADLO- 047446 PBU 1 -100 10. Field /Pool(s): PRUDHOE BAY FIELD /RbTORWS'Rf1FEl�POOL �� 6 B 11. Present Well Condition Summary: Total Depth measured 814 feet Plugs (measured) None feet true vertical 6881.95 feet Junk (measured) Non feet Effective Depth measured 8047 feet Packer (measured) true vertical 6809 feet (true vertical) Casing Length Size MD TVD Burst Collapse Structural Conductor 109 20" 91.5# H-40 SURFACE - 109 SURFACE - 109 1490 470 Surface 2621 9 -5/8" 40# L -80 29 - 2621 29 - 2582 5750 3090 Intermediate 8131 7" 26# L -80 26 - 8131 26 - 6875 7240 5410 Production Liner Liner MNF.E) NO 2010 Perforation depth: Measured depth: NONE - True Vertical depth: Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 SURFACE - 4020 SURFACE - 3864 Packers and SSSV (type, measured and true vertical depth) LVA VIN EIVE4 OCT 0 7 12. Stimulation or cement squeeze summary: �a r � Intervals treated (measured): ii ir7p� '�' 0.i, Treatment 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: SI Subsequent to operation: 14. Attachments: 15. Well Class after work: \ Copies of Logs and Surveys Run Exploratorf❑ % 9pye1opment ❑� Service ❑ Daily Report of Well Operations X 16. Well Status after woi ieSUSPENDED Oil Gas Lj WDSPL GSTOR ❑ WAG ❑ GINJ ❑ WINJ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Pone 564 4944 Date Form 10-404 Revised 7/2009 � ���ginal Only s � Prudhoe Bay Unit Bore 1 -100, PTD 2050100 Suspended Well Inspection Report BP Exploration (Alaska) Inc. (BPXA) completed a suspended well inspection of PBU Bore 1 -100 on 9/22/10. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). • Suspended Well Site Inspection form documenting the well pressures and site condition. AOGCC inspector John Crisp witnessed the inspection. • Wellbore diagram illustrating the current configuration of the well • There is one well located within one - quarter mile radius, PBU NWE 04 -01. See attached As Built survey. • Photographs showing the condition of the wellhead and the surrounding location Additional pertinent information: • PBU Bore 1 -100 was suspended on 04/17/06 after drilling and runni casing. • PBU Bore 1 -100 was drilled from an ice pad adjacent to the Milne Point road. • The strata through which the well was drilled is neither abnormally geo- pressured or depleted. • The well is secured with casing and cement. The well is not perforated. • The well is mechanically sound as proven by a pressure test after the casing was cemented. • During the inspection, it was noted that the well sign was missing. A new sign will be ordered and placed at the well. MLB 09/24/10 Suspended Well Site Inspection Form Notify AOGCC inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UN BORE 1 -100 Field /Pool: PRUDHOE BAY / ORION_S_Ct Permit # (PTD): 205 -010 API Number: 50029232450000 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 4/17/2006 Surface Location: Section: 20 Twsp: 12N Range: 11E Nearest active pad or road: Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit docurnentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Conditio of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface; Good Location cleanup needed: None Pits condition: NIA Surrounding area condition: Good Water /fluids on pad: None / cellar Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: N/A Photographs taken (# and description): 4; wellhead & cellar Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: i =MC; Good condition; IA & OA function good Cellar description, condition, fluids: Water / Froze Rat Hole: N/A Welihouse or protective b=sign Well identification sign: Tubing Pressure (or casin N/A Annulus pressures: IA = 0 psi / OA = 0 psi Wellhead Photos taken (# and description): 4; wellhead and cellar Work Required: Need sign Operator Rep (name and signature): Jerry Murphy y AOGCC Inspector: John Crisp Other Observers: Ryan oft Inspection Date: 9/22/2010 AOGCC Notice Date: 9/20/2010 Time of arrival: 9:45 AM Time of Departure: 10:00 AM Site access method: Drive / Walk 18 17 16 IS E2 0 —N— I NM u 19 20 21 22 —N— 30 0 29 0 a 28 27 5 a W y � �0 Of 32 3 3 ti V L � 34 2 3� I —PAD T12N g VICINITY MAP N.T.S. NWE 4-01 +I—loo LAKE • 2 D 30 ROP o ICE PAD q Puss 1top 9 ° ........................ °° Leonard J. 0 Hanle mss° 11386 taL ss�ta� LEGEND SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM + AS —BUILT CONDUCTOR PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN ■ THE EXISTING WELL THIS S P AT REPRESENTS THAT SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL NOTES CORRECT AS OF MARCH 11, DE TAILS ARE 1. DATE OF SURVEY: MARCH 11, 2006. 2. REFERENCE FIELD BOOK: W006 -03 (PGS. 16 -18). 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD '27. GEODETIC POSITIONS ARE NAD '27. 4. BASIS OF HORIZONTAL CONTROL IS GPS CONTROL POINT "NS96- 01 -30 ". 5. ELEVATIONS ARE BPX MEAN SEA LEVEL (M.S.L.) DATUM. 6. MEAN PAD SCALE FACTOR IS 0.999905923 LOCATED WITHIN PROTRACTED SEC. 20, T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES POSITION (DMS) POSITION(D.DD) BOX ELEV OFFSETS Y= 5,989,385.70 70'22'52.610" 70.3812806' 3,219' FSL 1-100 X 572,264.98 149'24'44.644" 149.4124011' 45 3,945' FEL F. jj$ DRAWN" KW CHECKED: ry cmC DATE 3/18/06 DRAWING: FRB06 W01 01 -00 WOA I —PAD SHEET: oe ND: WELL "I -100" 0 3 18 OB ISSUED FOR INFORMATION KMM -BUILT CONDUCTOR CMC SCALE: 1 OF 1 i - = 200 AS NO. OATS REVISION BY CHK Pad July 9, 2010 Approximate Scale: 1" =300' 2010- 19c -7 -36 AVRO-IWRK z } x ,i. t. 1 n' t F r i TREE = 4 -1/8" CIW W ELLHEAD = FMC O O SAFETY NOTES: Suspension Details AC TUATOR = N/A KB. ELEV = 74.4 BF. ELEV = 7165 SUSPENDED 4/18106 OP = 750' Max Angle = 7 44 - @505V Dat MD = 4858.46_' Datum TVD = 4400' SS 1009' 9 5/8" Tam Port Collar Minimum !D = 3.958" @ 4000' JEWELRY TYPE WLEG 9 -518" CSG, 40 #, L -80, ID = 8.835" 2621' 4 1/2" 12.6# L -80 IBT -M Tbg. 3.958" ID, .0152 bpf 4020' 3884' RA Tag 4020' 4 1/2" WLEG 4244' RA Tag 7" Csg, 26 #, L- 80,TC -11, ID = 6.276" 6020' 77$0' 1 7 . 26# L -80, ID = 6.276, Marker joint w /RA Tag PBTD $O4T 7" Csg, 26 #, L- 80,BTC, ID = 6.276° 8130' DATE I REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/18/06 BJB Original Drill & Complete WELL: 1 -100 PERMIT No: 205 -010 API No: 50 -029 -23245 SEC.20, T12N, R11E, UM BP Exploration (Alaska) �r '�� \ , �� ?\ ', `1 g '1 �► . ., �. . • ,. ''�1 I � - .. _ � l _. � � . ■ - .. - �.. 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C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2050100 Well Name/No. PRUDHOE BAY UN BORE I-100 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23245-00-00 MD 8140 TVD 6882 Completion Date 4/17/2006 Completion Status SUSP Current Status SUSP UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Ye DATA INFORMATION Types Electric or Other Logs Run: MWD / GR, MWD / GR / NEU /DEN /PWD, MWD / GR / RES /PWD, (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc Directional Survey Directional Survey EN~D D Asc Directional Survey ?'Rpt Directional Survey pt See Notes .wog 14159 Induction/Resistivity 25 Blu I~'~og 14159 InductionlResistivity 25 Blu C Lis 14159 Induction/Resistivity ~g 14160 Induction/Resistivity 25 Blu J {/Log 14160 Induction/Resistivity 25 Blu i VED C Lis 14160~nduction/Resistivity (/dog 14281 Induction/Resistivity 25 Blu i ~og 14281 Induction/Resistivity 25 Blu 0 8140 Open 5/19/2006 0 8140 Open 5/19!2006 0 11982 Open 5/18/2006 P61 0 11983 Open 5/18/2006 PB 1 0 0 Open Oil Viscosity Prediction vs. Depth in the 1-100 Well (Orion Field, North Slope, Alaska) Based on Gas Chromatographic Analysis of Sidewall Core Extracts OilTracers L.L.C. Dallas, TX 0 8140 Open 10/4/2006 TVD Vision Res Final 13- Apr-2006 0 8140 Open 10/4/2006 MD Vision Res Final 13- Apr-2006 0 0 Open 10/4/2006 FET, ROP, GR w/Graphics 0 11982 Open 10/4/2006 PB 1 TVD Vision Service Final 5-Apr-2006 0 11982 Open 10!4/2006 P8 1 MD Vision Service Final 5-Apr-2006 0 0 Open 10/4/2006 GR, ROP, FET, NPHI, w/Graphics 2621 8138 Open 12/7/2006 MD Platform Express, PEX, DSI, AIT, GPIT 13- Apr-2006 w/Graphics 2621 8138 Open 12/7/2006 TVD Platform Express, PEX, DSI, AIT, GPIT 13- Apr-2006 w/Graphics DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2050100 Well Name/No. PRUDHOE BAY UN BORE I-100 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23245-00-00 MD 8140 TVD 6882 Completion Date 4/17/2006 Completion Status SUSP Current Status SUSP UIC N C Lis 14281 nduction/Resistivity 0 0 Open 12/7/2006 LIS Veri, GR, CNTC, NCNT, NPHI, DRHO, RHOB, Well Cores/Samples Information: Interval Name Start Stop -- _ . ____ -- -- ', 0 0 ADDITIONAL INFORMATION Well Cored? '~/ N C W ~ ~ W~ Chips Received? -~F~Ffd"-'J ll Analysis `~ N Received? Comments: Compliance Reviewed By: i Sent Received Sample Set Number Comments Side Wall Core Analysis Daily History Received? ~ / N Formation Tops ~ N Date: Schlumberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 4065 Company: Alaska Oit 8 Gas Cons Comm Aftn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Orion Prudhoe Bay Date BL Color CD S-121 11366505 S-28B PB1 40008506 1.100 11216289 MEMORY PROD PROFILE OH EDIT OF MWD/LWD OH EDIT OF MWDILWD 11/06106 02/01103 04/13/06 1 2 2 1 1 L-212 L-212 P61 L-212 P82 40011870 40011870 40011670 OH EDIT OF MWD/LWD OH EDIT OF MWDILWD OH EDIT OF MWD/LWD 04/13/05 03/25105 04/O6I05 2 2 2 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99500-4254 Date Delivered: Schlumberg ~ ~\ ~, 2525 Gambe ~ --. ~~ Anchorage, ~8~` ATTN: Beth Received bv: i ~* -~~~" 4 ~~`yl~~~~ •t. oI 12/06/06 ~d~-Otte ~ ~ ~I~~SI 1olozlos Scbbuaberger Sehlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 3985 Company: Alaska Oil 8. Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion Borealis Date BL Color CD V-120 40010983 OH EDIT OF MWD/LWD 08127/04 2 1 V-115 40010304 OH EDIT OF MWD/LWD 03/31!04 6 1 V-115 PBt 40010304 OH EDIT OF MWDILWD 03/24!04 6 1 V-202 L1 40009877 OH EDIT OF MWDILWD 11/30/03 2 1 V-202 L2 40009877 OH EDIT OF MWDILWD 12/08103 2 1 I.100 40013292 OH EDIT OF MWDILWD 04/13106 2 1 I-100 P81 40013292 OH EDIT OF MWDILWD 04/05106 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvtl. Anchorage AK 99508-4254 Date Delivered: Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~~ ~6~ ~ i O ~ !y~ ~ ~ C~1 & Gas Ceps. Commissiat Andscrage STATE OF ALASKA RECEIVED ALA OIL AND GAS CONSERVATION C ISSION WELL C PLETION OR RECOMPLETION RE T AND LOG AUG 2 5 2006 Alaska Oil & Gas Cons. Commission 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ®Suspended ^ WAG zoAAC Zs.,os soAAC 2s.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions Zero Omer 1 b. Well C ~ orage ^ Development ®Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 4/17/2006 12. Permit to Drill Number 205-010 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 3/20/2006 13. API Number 50-029-23245-00-00 4a. Location of Well (Governmental Section): Surface: 3219' NSL 3945' WEL SEC 2 T 7. Date T.D. Reached 4/12/2006 14. Well Name and Number. PBU I-100 , , . 0, 12N, R11 E, UM Top of Productive Horizon: 3950' NSL, 3756' WEL, SEC. 20, T12N, R11 E, UM g. KB Elevation (ft): 74.4' 15. Field /Pool(s): Prudhoe Bay Field / Kuparuk RivE Pool Total Depth: 336' NSL, 1732' WEL, SEC. 17, T12N, R11 E, UM 9. Plug Back Depth (MD+TVD) 8047 + 6809 Ft 4b. Locati n of Well (State Base Plane Coordinates): Surface: x- 572265 y- 5989386 Zone- ASP4 10. Total Depth (MD+TVD) 8140 + 6882 Ft 16. Property Designation: ADL 047446 TPI: x- 572444 y- 5990120 Zone- ASP4 Total Depth: x- 574446 Y- 5991805 Zone- ASP4 11-Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Surve y ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD / GR, MWD / GR / NEU /DEN /PWD, MWD / GR / RES /PWD, PEX, USIT ASING, INER AND EMENTING ECORD CASING ETTING EPTF1 MD ETTING TVD ~~ OUNT SIZE WT. PER FT. GRADE OP TTOM OP TTOM SIZE CEMENTING RECORD PULLED 34" x 20" 91.5# H-40 Surface 109' Surface 109' 42" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 29' 2621' 29' 2582' 12-1 /4" 551 sx AS Lite. 211 sx Class'G', 497 sx AS Lite 7" 26# L-80 26' 8131' 26' 6875' 8-3/4" 356 sx LiteCrete, 173 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and " " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2", 12.6#, L-80 4020 None MD TVD MD TVD 25. AiCID, Fw-cTURE, CEMENT ~7tiVC~c, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protect w/ 91 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): WA Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure CALCUU-TEO 24-HouR RATE OIL$BL 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". Sidewal! Cores were takpen~. The final summary report shoul,(d be completed in about one month and will be forwarded upon receipt. I v~r v FORn 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ~~1GE~li~~ 28. GEOLOGIC 29. ~ FORMATION TESTS NAME I I mciuae aria oneny summarize test results. List intervals tested, MD TVD and attach detailed supporting data as necessary. If no tests were conducted state "None" Ugnu 2690' 2649' Ugna MA 3898' 3771, Ungu MB1 3901' 3773' Ugnu MB2 3984' 3837' Schrader Bluff NB 4102' 3925' Schrader Bluff NC 4150' 3960' Schrader Bluff NE 4163' 3969' Schrader Bluff NF 4236' 4023' Schrader Bluff OA 4291' 4063' Schrader Bluff OBa 4373' 4123' Schrader Bluff OBb 4446' 4176' Schrader Bluff OBc 4510' 4222' Schrader Bluff OBd 4581' 4274' Schrader Bluff OBe 4667' 4336' Schrader Bluff OBf 4722' 4376' Base Schrader Bluff OBf 4786' 4422' (Top Colville) NRZ 7080' 6086' Kalubik 7400' 6322' Kuparuk D 7688' 6537' Kuparuk C 7800' 6621 Kuparuk B 7915' 6708' 30. List of Attachments: Summary of Daily Drilling None ulagram, ,. , ~~c~cuy ~C~ ury uiat me roregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~Q /~ PBU I-100 205-010 Well Number Permit No. / Title Technical Assistant Date ~/~ 1 Prepared By Name/Number: Terrie Hubble, 564-4628 tVn OrillingEngineer: Phil Smith 5Rd_dR07 INSTRUCTIONS Ger~wu.: This form is designed for submitting a complete and correct well completion report and log on all types of lands and teases 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. frEM 4b: TPI (Top of Producing Interval). frets 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. frets 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). hEM 20: True vertical thickness. frErw 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). hErr 28: Method of Operation; Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). frF.rw 27: If no cores taken, indicate "None". frEw 29: Ust all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only SCHLUMBERGER Survey report Client .................... BP Exploration (Alaska) Inc. Field ..................... Borealis Well ...................... I-100 API number ................ 50-029-23245-00 Engineer .................. I. Hernandez Rig :...................... Nabors 9ES STATE :.................... Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS............ Mason & Taylor ----- Depth reference ---- Permanent datum........... Depth reference........... GL above permanent.......: KB above permanent.......: DF above permanent.......: ------------------ Mean Sea Level Driller's Pipe Tally 45.90 ft N/A (Top Drive) 74.40 ft ----- Vertical section origin---------------- Latitude (+N/S-).......... 0.00 ft Departure (+E/W-)......... 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-) ........ -999.25 ft Departure (+E/W-)......... -999.25 ft Azimuth from Vsect Origin to target: 46.63 degrees 13-Apr-2006 07:11:24 Page 1 of 4 Spud date ................. 20-Mar-06 Last survey date.......... 13-Apr-06 Total accepted surveys...: 87 MD of first survey.......: 0.00 ft MD of last survey........: 8140.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2005 Magnetic date ............. 20-Mar-2006 Magnetic field strength..: 57576.93 LAMA Magnetic dec (+E/W-).....; 24,26 degrees Magnetic dip .............. 80.86 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G . ............. H ............... Dip ............. of G............ of H............ of Dip.......... Criteria --------- 1002.68 meal 57577.00 LAMA 80.86 degrees (+/-) 2.50 meal (+/-)300.00 LAMA (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.26 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.26 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction d.~j ~. c~cv • SCHLUMBERGER Survey Report 13 -Apr-2006 07:11:24 Page 2 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +NJS- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 100.00 0.13 113.21 100.00 100.00 0.05 -0.04 0.10 0.11 113.21 0.13 GYR None 3 200.00 0.17 118.15 100.00 200.00 0.14 -0.16 0.34 0.37 115.16 0.04 GYR None 4 300.00 0.20 109.87 100.00 300.00 0.26 -0.29 0.63 0.70 114.47 0.04 GYR None 5 400.00 0.16 90.69 100.00 400.00 0.44 -0.35 0.94 1.00 110.45 0.07 GYR None 6 500.00 0.25 111.79 100.00 500.00 0.63 -0.43 1.28 1.35 108.66 0.12 GYR None 7 572.53 0.38 115.03 72.53 572.53 0.79 -0.59 1.65 1.75 109.82 0.18 MWD IFR MS None . 8 667.04 0.65 108.89 94.51 667.03 1.15 -0.90 2.44 2.60 110.26 0.29 _ MWD IFR _ MS None 9 759.14 0.62 33.11 92.10 759.13 1.88 -0.65 3.20 3.27 101.49 0.85 _ MWD IFR _ MS None 10 850.49 2.20 11.95 91.35 850.45 3.80 1.48 3.84 4.11 68.92 1.79 _ MWD IFR _ MS None 11 944.40 4.61 0.27 93.91 944.19 7.89 7.02 4.23 8.19 31.06 2.66 MWD IFR MS None 12 1039.97 5.11 1.96 95.57 1039.41 13.57 15.11 4.39 15.74 16.20 0.54 _ MWD IFR _ MS None 13 1129.57 6.18 359.87 89.60 1128.58 19.71 23.92 4..52 24.34 10.69 1.22 _ MWD IFR _ MS None 14 1222.82 6.93 357.23 93.25 1221.22 26.81 34.56 4.23 34.82 6.98 0.87 _ MWD IFR _ MS None 15 1314.94 10.08 0.41 92.12 1312.31 36.01 48.18 4.02 48.34 4.77 3.46 _ MWD IFR _ MS None 16 1408.68 10.50 0.33 93.74 1404.55 47.58 64.92 4.13 65.05 3.64 0.45 MWD IFR MS None 17 1501.63 12.19 357.06 92.95 1495.68 59.80 83.19 3.68 $3.27 2.53 1.94 _ MWD IFR _ MS None 18 1594.72 13.10 357.06 93.09 1586.51 73.02 103.54 2.63 103.58 1.45 0.98 _ MWD IFR _ MS None 19 1689.15 13.60 358.16 94.43 1678.39 87.32 125.33 1.72 125.34 0.79 0.59 _ MWD IFR _ MS None 20 1782.64 15.02 346.51 93.49 1768.99 100.64 148.10 -1.46 148.11 359.44 3.43 _ MWD IFR _ MS None 21 1875.46 15.18 332.92 92.82 1858.64 110.05 170.62 -9.80 170.90 356.71 3.81 MWD IFR MS None 22 1970.14 14.87 329.62 94.68 1950.08 116.25 192.14 -21.58 193.35 353.59 0.96 _ MWD IFR _ MS None 23 2061.54 14.09 323.66 91.40 2038.58 120.25 211.22 -34.11 213.96 350.83 1.84 _ MWD IFR _ MS None 24 2153.74 15.21. 314.54 92.20 2127.79 121.19 228.75 -49.38 234.02 347.82 2.78 _ MWD IFR _ MS None 25 2247.57 14.54 303.62 93.83 2218.50 118.08 243.91 -67.97 253.20 344.43 3.07 _ MWD IFR _ MS None 26 2340.81 13.54 286.45 93.24 2308.99 109.96 253.48 -88.19 268.38 340.82 4.58 MWD IFR MS None 27 2435.22 13.51 277.44 94.41 2400.79 97.43 258.04 -109.73 280.40 336.96 2.23 _ MWD IFR _ MS None 28 2528.21 13.41 279.99 92.99 2491.23 84.13 261.32 -131.12 292.37 333.35 0.65 _ MWD IFR _ MS None 29 2655.93 12.90 280.17 127.72 2615.60 66.82 266.40 -159.74 310.62 329.05 0.40 _ MWD IFR _ MS None 30 2758.00 10.30 296.86 102.07 2715.60 56.96 272.54 -179.10 326.12 326.69 4.13 _ MWD IFR _ MS None SCHLUMBERGER Survey Report 13-Apr-2006 07:11:24 Page 3 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 2853.76 8.37 310.51 95.76 2810..10 53.32 280.94 -192.04 340.30 325.64 3.05 MWD IFR MS None 32 2949.74 9.22 328.02 95.98 2904.97 54.10 292.00 -201.42 354.73 325.40 2.91 _ MWD IFR _ MS None 33 3045.11 10.67 348.82 95.37 2998.93 60.31 307.15 -207.19 370.49 326.00 4.03 MWD IFR MS None 34 3140.35 12.25 358.71 95.24 3092.28 71.78 325.90 -209.12 387.23 327.31 2.64 MWD IFR MS None 35 3235.45 15.01 10.51 95.10 3184.71 88.50 348.10 -207.10 405.05 329.25 4.11 _ MWD IFR _ MS None 36 3331.42 18.35 19.31 95.97 3276.64 111.97 374.59 -199.84 424.56 331.92 4.35 MWD IFR MS None 37 3427.41 21.85 27.45 95.99 3366.79 142.28 404.72 -186.60 445.66 335.25 4.66 _ MWD IFR _ MS • None 38 3523.10 25.50 33.28 95.69 3454.43 179.16 437.76 -167.08 468.56 .339.11 4.53 _ MWD IFR _ MS None 39 3617.39 29.46 39.65 94.29 3538.08 221.94 472.60 -141.13 493.22 343.37 5.23 MWD IFR MS None 40 3713.90 32.64 44.74 96.51 3620.76 271.54 509.37 -107.65 520.63 348.07 4.27 _ MWD IFR _ MS None 41 3809.74 35.33 50.25 95.84 3700.25 325.05 545.47 -68.14 549.71 352.88 4.26 MWD IFR MS None 42 3905.21 38.56 52.55 95.47 3776.54 382.21 581.22 -23.28 581.69 357.71 3.68 _ MWD IFR _ MS None 43 4000.58 41.49 53.46 95.37 3849.56 443.15 618.12 25.71 618.65 2.38 3.13 _ MWD IFR _ MS None 44 4095.80 42.78 54.13 95.22 3920.17 506.53 655.84 77.26 660.38 6.72 1.43 _ MWD IFR _ MS None 45 4191.39 42.99 54.95 95.59 3990.22 570.97 693.58 130.24 705.70 10.64 0.62 _ MWD IFR _ MS None 46 4287.61 43.34 55.45 96.22 4060.40 636.05 731.15 184.30 754.02 14.15 0.51 MWD TFR MS None 47 4380.37 43.33 55.57 92.76 4127.87 698.95 767.19 236.76 802.90 17.15 0.09. _ MWD IFR _ MS None 48 4476.79 43.31 55.50 96.42 4198.02 764.30 804.63 291.30 855.74 19.90 0.05 _ MWD IFR _ MS None 49 4572.22 43.35 55.10 95.43 4267.43 829.04 841.91 345.14 909.91 22.29 0.29 MWD IFR MS None 50 4668.00 43.57 52.63 95.78 4336.96 894.39 880.75. 398.34 966.64 24.34 1.79 _ MWD IFR _ MS None 51 4763.28 43.84 51.80 95.28 4405.84 959.91 921.09 450.37 1025.30 26.06 0.67 MWD IFR MS None 52 4859.81 44.00 51.90 96.53 4475.37 1026.59 962.45 503.02 1085.98 27.59 0.18 _ MWD IFR _ MS None 53 4955.00 44.11 50.03 95.19 4543.78 1092.58 1004.13 554.43 1147.03 28.91 1.37 MWD` IFR MS None 54 5051.47 44.14 48.68 96.47 4613.03 1159.67 1047.88 605.39 1210.19 30.02 0.97 MWD IFR MS None 55 5145.98 43.59 48.27 94.51 4681.17 1225.12 1091.30 654.42 1272.48 30.95 0.66 _ MWD IFR _ MS None 56 5242.03 43.75 47.83 96.05 4750.65 1291.43 1135.63 703.75 1336.01 31.79 0.36 MWD IFR MS None 57 5336.44 43.61 47.39 94.41 4818.93 1356.62 1179.59 751.91 1398.86 32.51 0.35 MWD~ IFR _ MS None 58 5428.43 43.33 47.34 91.99 4885.69 1419.90 1222.46 798.46 1460.12 33.15 0.31 MWD IFR MS None 59 5522.23 43.00 46.81 93.80 4954.10 1484.07 1266.16 845.45 1522.48 33.73 0.52 _ MWD IFR _ MS None 60 5615.73 43.57 47.36 93.50 5022.17 1548.17 1309.81 892.40 1584.92 34.27 0.73 _ MWD IFR _ MS None SCHLDMBERGER Survey Report 13-Apr-2006 07:11:24 Page 4 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 5709.15 43.94 48.71 93.42 5089.65 1612.75 1353.00 940.44 1647.74 34.80 1.07 MWD IFR MS None 62 5803.02 43.88 48.72 93.87 5157.27 1677.81 1395.96 989.36 1711.00 35.33 0.06 _ MWD IFR _ MS None 63 5896.70 43.77 47.88 93.68 5224.86 1742.65 1439.11 1037.79 1774.27 35.80 0.63 _ MWD IFR _ MS None 64 5991.49 43.41 48.52 94.79 5293.52 1807.99 1482.67 1086.51 1838.16 36.23 0.60 _ MWD IFR _ MS None 65 6087.02 43.72 49.42 95.53 5362.74 1873.77 1525.89 1136.18 1902.43 36.67 0.73 _ MWD IFR _ MS None 66 6183.11 43.54 49.86 96.09 5432.29 1939.98 1568.83 1186.70 1967.10 37.10 0.37 MWD IFR MS Non 67 6278.86 41.92 49.58 95.75 5502.62 2004.85 1610.83 1236.27 2030.55 37.51 1.70 _ MWD IFR _ MS e None 68 6373.89 42.29 51.12 95.03 5573.13 2068.43 1651.48 1285.32 2092.71 37.89 1.15 _ MWD IFR _ MS None 69 6469.84 42.50 51.14 95.95 5643.99 2132.92 1692.08 1335.69 2155.74 38.29 0.22 _ MWD IFR _ MS None 70 6565.22 42.15 51.02 95.38 5714.50 2196.95 1732.42 1385.66 2218.41 38.65 0.38 _ MWD IFR _ MS None 71 6660.91 43.78 51.55 95.69 5784.52 2261.95 1773.21 1436.55 2282.09 39.01 1.74 MWD IFR MS None 72 6756.63 44.28 51.67 95.72 5853.34 2328.23 1814.52 1488.69 2347.06 39.37 0.53 _ MWD IFR _ MS None 73 6852.89 43.95 50.84 96.26 5922.45 2395.01 1856.46 1540.95 2412.67 39.69 0.69 _ MWD IFR _ MS None 74 6948.22 43.76 51.27 95.33 5991.20 2460.87 1897.98 1592.32 2477.46 40.00 0.37 _ MWD IFR _ MS None 75 7044.14 43.69 51.08 95.92 6060.51 2526.96 1939.54 1643.97 2542,53 40.28 0.16 _ MWD IFR _ MS None 76 7140.17 43.08 50.93 96.03 6130.30 - 2592.73 1981.05 1695.24 2607.37 40.55 0.64 MWD IFR MS None 77 7234.93 42.76 50.29 94.76 6199.70 2657.10 2022.00 1745.11 2670.93 40.80 0.57 MWD IFR MS None 78 7330.99 42.21 49.78 96.06 6270.54 2721.86 2063.67 1794.84 2734.99 41.01 0.68 _ MWD IFR _ MS None 79 7427.09 41.83 49.76 96.10 6341.93 2786.09 2105.21 1843.95 2798.58 41.21 0.40 _ MWD IFR _ MS None 80 7521.94 41.83 50.13 94,85 6412..61 2849.25 2145.92 1892.37 2861.12 41.41 0.26 _ MWD IFR _ MS None 81 7618.98 41.77 50.83 97.04 6484.95 2913.78 2187.08 1942.26 2925.01 41.61 0.48 MWD IFR MS None 82 7714.59 41.19 51.11 95.61 6556.58 2976.93 2226.96 1991.45 2987.51 41.80 0.64 _ MWD IFR _ MS None 83 7809.51 41.18 51.25 94.92 6628.01 3039.23 2266.14 2040.15 3049.20 42.00 0.10 _ MWD IFR _ MS None 84 7905.54 40.57 51.52 96.03 6700.62 3101.86 2305.36 2089.25 3111.22 42.18 0.66 _ MWD IFR _ MS None 85 8001.07 39.36 51.52 95.53 6773.84 3163.00 2343.54 2137.29 3171.78 42.36 1.27 _ MWD IFR _ MS None 86 8066.82 38.77 51.97 65.75 6824.89 3204.27 2369.20 2169.82 3212.67 42.48 1.00 MWD IFR MS None 87 8140.00 38.77 51.97 73.18 6881.95 3249.89 2397.43 2205.92 3257.88 42.62 0.00 _ Projected to TD [(c)2006 IDEAL ID10 2C Ol] SCHLUMBERGER Survey report Client ...................: Field ....................: Well ...................... API number ...............: Engineer .................: Rig :.....................: STATE :...................: ----- Survey calculation m Method for positions.....: Method for DLS...........: BP Exploration (Alaska) Inc. Orion I-100PB1 50-029-23245-70 I. Hernandez Nabors 9ES Alaska ethods------------- Minimum curvature Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 45.90 ft KB above permanent.......: 0.00 ft DF above permanent.......: 74.40 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 78.05 degrees [(c)2006 IDEAL ID10 2C O1] 5-Apr-2006 03:05:24 Page 1 of 6 Spud date ................: 20-Mar-06 Last survey date.........: 05-Apr-06 Total accepted surveys...: 146 MD of first survey.......: 0.00 ft MD of last survey........: 11982.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2005 Magnetic date ............: 20-Mar-2006 Magnetic field strength..: 57576.93 LAMA Magnetic dec (+E/W-).....: 24.26 degrees Magnetic dip .............: 80.86 degrees ----- MWD survey Reference Reference G ..............: Reference H ..............: Reference Dip ............: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 meal 57577.00 GAMA 80.86 degrees (+/-) 2.50 meal (+/-)300.00 LAMA (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.26 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.26 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction ~ ~ ~`- oc® • • SCHLUMBERGER Survey Report 5-Apr-2006 03:05:24 Page 2 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 100.00 0.13 113.21 100.00 100.00 0.09 -0.04 0.10 0.11 113.21 0.13 GYR None 3 200.00 0.17 118.15 100.00 200.00 0.30 -0.16 0.34 0.37 115.16 0.04 GYR None 4 300.00 0.20 109.87 100.00 300.00 0.56 -0.29 0.63 0.70 114.47 0.04 GYR None 5 400.00 0.16 90.69 100.00 400.00 0.85 -0.35 0.94 1.00 110.45 0.07 GYR None 6 500.00 0.25 111.79 100.00 500.00 1.16 -0.43 1.28 1.35 108.66 0.12 GYR None 7 572.53 0.38 115.03 72.53 572.53 1.49 -0.59 1.65 1.75 109.82 0.18 MWD IFR MS None 8 667.04 0.65 108.89 94.51 667.03 2.20 -0.90 2.44 2.60 110.26 0.29 MWD_ IFR MS None 9 759.14 0.62 33.11 92.10 759.13 3.00 -0.65 3.20 3.27 101.49 0.85 MWD IFR _ MS None 10 850.49 2.20 11.95 91.35 850.45 4.06 1.48 3.84 4.11 68.92 1.79 _ MWD IFR _ MS None 11 944.40 4.61 0.27 93.91 944.19 5.59 7.02 4.23 8.19 31.06 2.66 MWD_ IFR MS None 12 1039.97 5.11 1.96 95.57 1039.41 7.42 15.11 4.39 15.74 16.20 0.54 MWD IFR _ MS None 13 1129.57 6.18 359.87 89.60 1128.58 9.37 23.92 4.52 24.34 10.69 1.22 MWD IFR MS None 14 1222.82 6.93 357.23 93.25 1221.22 11.30 34.56 4.23 34.82 6.98 0.87 MWD_ IFR MS None 15 1314.94 10.08 0.41 92.12 1312.31 13.91 48.18 4.02 48.34 4.77 3.46 MWD IFR _ MS None 16 1408.68 10.50 0.33 93.74 1404.55 17.48 64.92 4.13 65.05 3.64 0.45 MWD IFR MS None 17 1501.63 12.19 357.06 92.95 1495.68 20.82 83.19 3.68 83.27 2.53 1.94 MWD IFR MS None 18 1594.72 13.10 357.06 93.09 1586.51 24.01 103.54 2.63 103.58 1.45 0.98 _ MWD_ IFR _ MS None 19 1689.15 13.60 358.16 94.43 1678.39 27.64 125.33 1.72 125.34 0.79 0.59 MWD_ IFR _ MS None 20 1782.64 15.02 346.51 93.49 1768.99 29.24 148.10 -1.46 148.11 359.44 3.43 MWD IFR _ MS None 21 1875.46 15.18 332.92 92.82 1858.64 25.75 170.62 -9.80 170.90 356.71 3.81 MWD_ IFR MS None 22 1970.14 14.87 329.62 94.68 1950.08 18.67 192.14 -21.58 193.35 353.59 0.96 MWD_ IFR _ MS None 23 2061.54 14.09 323.66 91.40 2038.58 10.37 211.22 -34.11 213.96 350.83 1.84 MWD_ IFR _ MS None 24 2153.74 15.21 314.54 92.20 2127.79 -0.95 228.75 -49.38 234.02 347.82 2.78 MWD_ IFR _ MS None 25 2247.57 14.54 303.62 93.83 2218.50 -15.99 243.91 -67.97 253.20 344.43 3.07 MWD IFR _ MS None 26 2340.81 13.54 286.45 93.24 2308.99 -33.79 253.48 -88.19 268.38 340.82 4.58 MWD_ IFR MS None 27 2435.22 13.51 277.44 94.41 2400.79 -53.92 258.04 -109.73 280.40 336.96 2.23 MWD IFR _ MS None 28 2528.21 13.41 279.99 92.99 2491.23 -74.17 261.32 -131.12 292.37 333.35 0.65 _ MWD_ IFR _ MS None 29 2562.98 13.45 279.39 34.77 2525.05 -81.67 262.68 -139.08 297.22 332.10 0.42 MWD_ IFR _ MS None 30 2655.90 16.01 277.52 92.92 2614.91 -103.82 266.12 -162.45 311.78 328.60 2.80 MWD IFR _ MS None [(c)2006 IDEAL ID10 2C O1] SCHLUMBERGER Survey Report 5-Apr-2006 03:05:24 Page 3 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (f t) (deg) 100f) type (deg) 31 2690.82 18.34 274.45 34.92 2648.27 -113.64 267.17 -172.70 318.13 327.12 7.16 MWD_ IFR _MS None 32 2723.43 20.71 271.25 32.61 2679.00 -124.17 267.70 -183.58 324.60 325.56 7.97 MWD IFR MS None 33 2753.89 23.01 268.83 30.46 2707.27 -135.27 267.69 -194.92 331.14 323.94 8.11 _ MWD_ IFR _ _MS None 34 2786.64 25.52 266.81 32.75 2737.12 -148.53 267.17 -208.37 338.82 322.05 8.07 MWD IFR MS None 35 2818.05 28.04 266.04 31.41 2765.16 -162.53 266.28 -222.49 347.00 320.12 8.10 _ MWD IFR _ MS None 36 2849.33 30.50 265.93 31.28 2792.45 -177.68 265.21 -237.74 356.17 318.13 7.87 MWD IFR _MS None 37 2882.13 33.28 266.13 32.80 2820.29 -194.84 264.01 -255.03 367.07 315.99 8.48 _ MWD IFR MS None 38 2914.21 35.98 265.91 32.08 2846.69 -212.89 262.75 -273.21 379.05 313.88 8.43 _ MWD IFR _ MS None 39 2946.48 38.89 266.17 32.27 2872.31 -232.31 261.39 -292.78 392.49 311.76 9.03 MWD IFR _MS None 40 2978.08 41.94 266.56 31.60 2896.37 -252.58 260.10 -313.22 407,14 309.71 9.68 _ MWD IFR MS None 41 3010.64 44.64 268.41 32.56 2920.07 -274.60 259.13 -335.52 423.94 307.68 9.16 MWD_ IFR _MS None 42 3042.37 46.64 269.25 31.73 2942.25 -296.88 258.67 -358.20 441.83 305.83 6.58 MWD IFR MS None 43 3073.90 49.24 269.90 31.53 2963.37 -319.82 258.50 -381.61 460.92 304.11 8.39 _ MWD IFR _ MS None 44 3105.75 52.18 270.35 31.85 2983.54 -343.92 258.55 -406.26 481.55 302.47 9.30 MWD_ IFR _MS None 45 3137.56 54.92 271.44 31.81 3002.43 -368.86 258.96 -431.84 503.53 300.95 9.04 MWD IFR MS None 46 3168.91 57.65 272.60 31.35 3019.83 -394.16 259.88 -457.90 526.50 299.58 9.24 MWD IFR MS None 47 3200.60 60.39 273.31 31.69 3036.14 -420.41 261.28 -485.03 550.92 298.31 8.86 _ MWD_ IFR _ _MS None 48 3233.26 62.93 273.53 32.66 3051.65 -448.13 263.00 -513.72 577.13 297.11 7.80 MWD_ IFR _MS None 49 3264.72 65.44 273.12 31.46 3065.35 -475.45 264.64 -541.99 603.15 296.03 8.06 MWD_ IFR _MS None 50 3296.82 68.35 272.56 32.10 3077.94 -503.99 266.10 -571.47 630.39 294.97 9.21 MWD IFR MS None 51 3328.86 71.47 271.97 32.04 3088.95 -533.16 267.29 -601.54 658.25 293.96 9.89 MWD_ IFR _MS None 52 3360.38 74.45 272.00 31.52 3098.18 -562.40 268.33 -631.65 686.28 293.02 9.45 MWD IFR MS None 53 3392.06 77.08 272.32 31.68 3105.97 -592.18 269.49 -662.33 715.06 292.14 8.36 MWD_ IFR_ MS None 54 3424.86 77.83 274.20 32.80 3113.10 -623.07 271.31 -694.30 745.43 291.34 6.04 MWD_ IFR_ MS None 55 3442.67 77.51 275.16 17.81 3116.90 -639.75 272.73 -711.64 762.11 290.97 5.56 MWD IFR MS None 56 3537.91 77.75 275.40 95.24 3137.30 -728.60 281.29 -804.27 852.04 289.28 0.35 MWD IFR MS None 57 3632.33 77.34 275.05 94.42 3157.67 -816.69 289.69 -896.09 941.75 287.92 0.57 MWD IFR MS None 58 3728.28 75.49 276.46 95.95 3180.20 -905.53 299.03 -988.68 1033.10 286.83 2.40 _ MWD_ IFR_ _ MS None 59 3823.73 72.60 277.35 95.45 3206.44 -992.37 310.06 -1079.97 1123.60 286.02 3.16 MWD_ IFR_ MS None 60 3916.46 70.14 278.78 94.73 3236.70 -1076.71 322.64 -1168.84 1212.56 285.43 2.96 MWD IFR MS None • • [(c)2006 IDEAL ID10 2C O1] SCHLUMBERGER Survey Report 5-Apr-2006 03:05:24 Page 4 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (f t) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 4014.09 71.41 277.85 95.63 3268.19 -1161.41 335.70 -1258.19 1302.20 284.94 1.61 MWD _IFR _MS None 62 4110.21 74.59 279.79 96.12 3296.29 -1247.34 349.80 -1349.00 1393.62 284.54 3.83 MWD _IFR _MS None 63 4206.22 77.21 281.15 96.01 3319.68 -1333.41 366.73 -1440.56 1486.51 284.28 3.06 MWD _IFR _MS None 64 4302.12 76.68 280.23 95.90 3341.34 -1419.63 384.06 -1532.36 1579.75 284.07 1.09 MWD IFR MS None 65 4398.15 76.76 280.41 96.03 3363.40 -1506.12 400.80 -1624.31 1673.03 283.86 0.20 MWD IFR MS None 66 4493.31 77.23 279.50 95.16 3384.81 -1592.14 416.83 -1715.63 1765.54 283.66 1.05 MWD _IFR _MS None 67 4592.61 77.23 277.96 99.30 3406.76 -1682.74 431.53 -1811.35 1862.04 283.40 1.51 MWD - IFR - MS None . 68 4686.18 77.01 277.27 93.57 3427.62 -1768.69 443.62 -1901.76 1952.81 283.13 0.76 MWD _IFR _MS None 69 4779.57 76.93 275.14 93.39 3448.68 -1855.14 453.45 -1992.21 2043.16 282.82 2.22 MWD _IFR _MS None 70 4873.28 77.00 273.35 93.71 3469.82 -1942.81 460.21 -2083.25 2133.47 282.46 1.86 MWD IFR MS None 71 4966.10 76.48 272.06 92.82 3491.11 -2030.21 464.47 -2173.49 2222.56 282.06 1.46 MWD _IFR _MS None 72 5060.62 75.06 271.87 94.52 3514.34 -2119.14 467.62 -2265.05 2312.82 281.66 1.51 MWD _IFR _MS None 73 5153.40 74.67 272.61 92.78 3538.57 -2205.97 471.12 -2354.54 2401.21 281.31 0.88 MWD _IFR _MS None 74 5249.09 74.75 273.05 95.69 3563.80 -2295.22 475.67 -2446.73 2492.54 281.00 0.45 MWD _IFR _MS None 75 5344.62 74.47 274.04 95.53 3589.15 -2383.97 481.37 -2538.66 2583.90 280.74 1.04 MWD IFR MS None 76 5440.21 74.57 275.70 95.59 3614.67 -2472.15 489.19 -2630.45 2675.55 280.54 1.68 MWD _IFR _MS None 77 5536.13 74.32 276.27 95.92 3640.39 -2560.07 498.82 -2722.35 2767.67 280.38 0.63 MWD _IFR _MS None 78 5631.92 74.60 276.33 95.79 3666.06 -2647.71 508.95 -2814.08 2859.73 280.25 0.30 MWD _IFR _MS None 79 5727.00 74.52 275.38 95.08 3691.37 -2734.97 518.30 -2905.25 2951.12 280.12 0.97 MWD _IFR _MS None 80 5823.63 75.18 274.21 96.63 3716.62 -2824.29 526.09 -2998.19 3044.00 279.95 1.35 MWD IFR MS None 81 5918.74 74.76 272.68 95.11 3741.29 -2912.84 531.61 -3089.88 3135.28 279.76 1.62 MWD_ IFR _MS None . 82 6014.78 74.75 272.40 96.04 3766.54 -3002.56 535.72 -3182.45 3227.22 279.56 0.28 MWD IFR MS None 83 6110.66 74.46 273.44 95.88 3792.00 -3091.90 540.43 -3274.77 3319.06 279.37 1.09 MWD_ IFR MS ~ None 84 6205.95 73.48 272.52 95.29 3818.31 -3180.39 545.19 -3366.23 3410.09 279.20 1.39 MWD IFR MS ~ None 85 6301.69 73.12 272.37 95.74 3845.82 -3269.21 549.10 -3457.84 3501.17 279.02 0.40 MWD IFR MS None 86 6397.79 73.90 274.43 96.10 3873.10 -3358.06 554.57 -3549.82 3592.88 278.88 2.21 MWD_ IFR _MS None 87 6493.10 73.95 274.25 95.31 3899.49 -3445.97 561.50 -3641.14 3684.18 278.77 0.19 MWD _IFR MS ~ None 88 6588.21 74.92 274.36 95.11 3925.01 -3533.93 568.38 -3732.51 3775.53 278.66 1.03 MWD IFR MS None 89 6683.32 74.25 274.04 95.11 3950.30 -3622.00 575.10 -3823.95 3866.95 278.55 0.78 MWD_ IFR _MS None 90 6779.23 74.84 275.61 95.91 3975.85 -3710.50 582.87 -3916.06 3959.20 278.47 1.69 MWD IFR MS None [(0)2006 IDEAL ID10 2C O1] SCHLUMBERGER Survey Report 5-Apr-2006 03:05:24 Page 5 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 91 6875.67 74.97 274.51 96.44 4000.97 -3799.54 591.08 -4008.81 4052.15 278.39 1.11 MWD_ IFR _MS None 92 6971.36 74.77 275.03 95.69 4025.95 -3888.01 598.77 -4100.86 4144.34 278.31 0.56 MWD_ IFR _MS None 93 7066.49 73.75 274.37 95.13 4051.75 -3975.73 606.27 -4192.11 4235.72 278.23 1.26 MWD_ IFR _MS None 94 7162.24 74.80 275.24 95.75 4077.70 -4063.98 613.99 -4283.95 4327.73 278.16 1.40 MWD_ IFR _MS None 95 7257.89 74.44 274.43 95.65 4103.07 -4152.27 621.77 -4375.85 4419.80 278.09 0.90 MWD IFR MS None 96 7353.29 74.61 276.65 95.40 4128.53 -4239.96 630.64 -4467.35 4511.65 278.04 2.25 MWD IFR MS None 97 7448.23 75.54 277.05 94.94 4152.98 -4326.80 641.58 -4558.43 4603.36 278.01 1.06 -_ MWD - IFR MS None 98 7543.08 75.24 275.49 94.85 4176.91 -4413.98 651.61 -4649.66 4695.10 277.98 1.62 MWD IFR MS None 99 7636.82 74.15 274.81 93.74 4201.65 -4500.39 659.73 -4739.71 4785.41 277.92 1.36 _ MWD _ IFR MS None 100 7731.45 73.52 273.25 94.63 4228.00 -4587.77 666.11 -4830.37 4876.09 277.85 1.72 _ MWD _ IFR MS None 101 7824.44 73.61 272.83 92.99 4254.31 -4673.92 670.84 -4919.44 4964.97 277.77 0.44 MWD_ IFR MS None 102 7917.59 72.89 272.01 93.15 4281.15 -4760.33 674.61 -5008.55 5053.78 277.67 1.14 MWD _ IFR MS None 103 8011.46 71.81 270.63 93.87 4309.61 -4847.39 676.68 -5097.98 5142.69 277.56 1.81 _ MWD_ _ IFR_ MS None 104 8103.26 72.01 271.00 91.80 4338.12 -4932.49 677.92 -5185.23 5229.36 277.45 0.44 MWD_ IFR MS None 105 8196.91 72.27 270.68 93.65 4366.84 -5019.42 679.22 -5274.36 5317.91 277.34 0.43 MWD _ IFR MS None 106 8290.67 73.10 273.85 93.76 4394.75 -5106.17 682.77 -5363.78 5407.06 277.25 3.35 MWD IFR MS None 107 8384.76 72.05 277.95 94.09 4422.94 -5191.60 691.98 -5453.06 5496.79 277.23 4.30 _ MWD_ _ IFR MS None 108 8476.66 72.83 279.87 91.90 4450.67 -5273.47 705.56 -5539.61 5584.36 277.26 2.17 MWD IFR~ MS None 109 8570.55 77.44 279.04 93.89 4474.75 -5357.94 720.45 -5629.10 5675.02 277.29 4.98 MWD_ IFR MS None 110 8663.47 81.96 278.33 92.92 4491.36 -5443.47 734.25 -5719.45 5766.39 277.32 4.92 MWD IFR~ MS None 111 8755.98 86.10 277.85 92.51 4500.98 -5529.89 747.19 -5810.53 5858.37 277.33 4.50 MWD_ IFR MS None • 112 8849.29 90.64 277.02 93.31 4503.63 -5617.85 759.26 -5902.99 5951.62 277.33 4.95 MWD IFR~ MS None 113 8942.69 94.71 276.77 93.40 4499.27 -5706.13 770.46 -5995.59 6044.90 277.32 4.37 MWD_ IFR MS None 114 9036.83 98.18 275.71 94.14 4488.71 -5794.99 780.63 -6088.57 6138.41 277.31 3.85 MWD_ _ IFR MS None 115 9129.42 101.80 276.51 92.59 4472.65 -5881.67 790.33 -6179.22 6229.56 277.29 4.00 MWD _ IFR MS None 116 9222.67 101.86 276.49 93.25 4453.53 -5968.24 800.66 -6269.90 6320.82 277.28 0.07 MWD_ IFR MS None 117 9316.29 102.09 276.75 93.62 4434.11 -6055.06 811.22 -6360.88 6412.40 277.27 0.37 MWD _ IFR MS None 118 9408.46 101.60 276.54 92.17 4415.19 -6140.56 821.65 -6450.48 6502.60 277.26 0.58 MWD_ IFR MS None 119 9500.10 101.18 277.37 91.64 4397.09 -6225.54 832.53 -6539.65 6592.43 277.26 1.00 MWD _ IFR MS None 120 9592.46 101.19 277.24 92.36 4379.17 -6311.08 844.05 -6629.52 6683.04 277.26 0.14 _ MWD _ IFR MS None [(c)2006 IDEAL ID10 2C O1] SCHLUMBERGER Survey Report 5-Apr-2006 03:05:24 Page 6 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (f t) (ft) (ft) (deg) 100f) type (deg) 121 9684.00 101.25 277.52 91.54 4361.36 -6395.81 855.59 -6718.57 6772.83 277.26 0.31 MWD IFR MS None 122 9775.83 101.37 277.89 91.83 4343.35 -6480.61 867.66 -6807.80 6862.87 277.26 0.42 MWD _ IFR _ MS None 123 9867.67 101.33 278.28 91.84 4325.28 -6565.20 880.32 -6896.95 6952.90 277.27 0.42 MWD _ IFR _ MS None 124 9959.37 101.38 278.56 91.70 4307.22 -6649.49 893.49 -6985.89 7042.79 277.29 0.30 MWD _ IFR _ MS None 125 10051.58 101.18 278.97 92.21 4289.19 -6734.07 907.27 -7075.26 7133.19 277.31 0.49 MWD _ IFR _ MS None 126 10146.36 101.28 279.48 94.78 4270.73 -6820.76 922.17 -7167.02 7226.10 277.33 0.54 MWD IFR MS None 127 10239.57 101.28 279.43 93.21 4252.50 -6905.86 937.19 -7257.19 7317.45 277.36 0.05 MWD _ IFR MS None 128 10332.59 101.43 279.71 93.02 4234.18 -6990.70 952.35 -7347.12 7408.58 277.39 0.34 MWD - IFR - MS None 129 10426.19 101.46 279.98 93.60 4215.61 -7075.89 968.04 -7437.51 7500.24 277.42 0.28 MWD _ IFR _ MS None 130 10519.35 101.19 280.18 93.16 4197.31 -7160.56 984.02 -7527.44 7591.49 277.45 0.36 MWD IFR MS None 131 10612.67 101.08 280,69 93.32 4179.29 -7245.22 1000.61 -7617.49 7682.93 277.48 132 10705.56 101.15 281.23 92.89 4161.39 -7329.18 1017.94 -7706.97 7773.91 277.52 133 10798.26 101.56 281.63 92.70 4143.13 -7412.60 1035.95 -7796.06 7864.58 277.57 134 10892.16 101.12 281.97 93.90 4124.67 -7496.87 1054.77 -7886.18 7956.40 277.62 135 10985.52 101.16 281.37 93.36 4106.63 -7580.80 1073.30 -7975.88 8047.78 277.66 136 11078.73 101.11 280.20 93.21 4088.63 -7665.15 1090.42 -8065.72 8139.10 277.70 137 11172.41 101.08 279.49 93.68 4070.60 -7750.51 1106.13 -8156.30 8230.96 277.72 138 11265.04 101.88 279.34 92.63 4052.17 -7835.04 1120.98 -8245.85 8321.70 277.74 139 11357.20 101.78 279.70 92.16 4033.27 -7918.99 1135.90 -8334.81 8411.86 277.76 140 11450.02 101.60 279.84 92.82 4014.47 -8003.43 1151.33 -8424.39 8502.70 277.78 141 11543.13 101.67 280.36 93.11 3995.69 -8087.95 1167.32 -8514.17 8593.82 277.81 142 11637.30 101.14 280.56 94.17 3977.07 -8173.29 1184.08 -8604.95 8686.03 277.83 143 11731.72 100.24 281.38 94.42 3959.55 -8258.75 1201.73 -8696.03 8778.67 277.87 144 11824.40 99.22 282.02 92.68 3943.89 -8342.42 1220.26 -8785.48 8869.82 277.91 145 11917.03 100.60 282.87 92.63 3927.95 -8425.52 1239.92 -8874.58 8960.78 277.95 146 11982.00 100.60 282.87 64.97 3916.00 -8483.48 1254.15 -8936.83 9024.41 277.99 0.55 MWD_ IFR_ MS None 0.58 MWD_ IFR_ MS None 0.61 MWD_ IFR_ MS None 0.59 MWD_ IFR_ MS None 0.63 MWD_ IFR_ MS None 1.23 MWD_ IFR_ MS None 0.74 MWD_ IFR_ MS None 0.88 MWD_ IFR_ MS None 0.40 MWD_ IFR_ MS None 0.24 MWD IFR MS None 0.55 MWD_ IFR_ MS None 0.60 MWD_ IFR_ MS None 1.28 MWD_ IFR_ MS None 1.29 MWD_ IFR_ MS None 1.74 MWD IFR MS None 0.00 Projection to TD [(c)2006 IDEAL ID10 2C O1] STATE OF ALASKA ~ ALAS~IL AND GAS CONSERVATION COM1GriSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ®Suspended ^ WAG zoAACZS.,os ZoAAC2s.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions Zero Other 1 b. Well Class: ^ Development ®Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 4/17/2006 12. Permit to Drill Number 205-010 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 3/20/2006 13. API Number 50-029-23245-00-00 4a. Location of Well (Governmental Section): Surface: 321 ' NS 4 ' 7. Date T.D. Reached 4/12/2006 14. Well Name and Number: PBU I-100 9 L, 39 5 WEL, SEC. 20, T12N, R11 E, UM Top of Productive Horizon: 3950' NSL, 3756' WEL, SEC. 20, T12N, R11E, UM g. KB Elevation (ft): 74.4' 15. Field /Pool(s): Prudhoe Bay Field / Kuparuk Rive Pool Total Depth: 336' NSL, 1732' WEL, SEC. 17, T12N, R11 E, UM 9. Plug Back Depth (MD+TVD) 8047 + 6809 Ft 4b. Location of Wetl (State Base Plane Coordinates): Surface: x- 572265 y- 5989386 Zone- ASP4 10. Total Depth (MD+TVD) 8140 + 6882 Ft 16. Property Designation: ADL 047446 TPI: x- 572444 y- 5990120 Zone- ASP4 Total Depth: x- 574446 Y- 5991805 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Surve y ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD / GR, MWD / GR / NEU /DEN /PWD, MWD / GR / RES /PWD, PEX, USIT ASING, LINER AND EMENTING ECORD CASING ETTING H MD ETTING EPTH TVD HOLE OUNT $IZE WT. PER FT. GRADE OP TTOM OP OTTOM SIZE CEMENTING RECORD PULLED 34" x 20" 91.5# H-40 Surface 109' Surface 109' 42" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 29' 2621' 29' 2582' 12-1 /4" 551 sx AS Lite, 2,1 sx Class'G', 497 sx AS Litt 7" 26# L-80 26' 8131' 26' 6875' 8-3/4" 356 sx LiteCrete, 173 sx Class 'G' 23. Perforations open.to Production (MD +TVD of Top and " " 24. TUBING RECORD Bottom Interval, Slze and Number; if none, state none ): SizE DEPTH SEr (MD) PACKER SEr (M~) None 4-1/2", 12.6#, L-80 4020 None MD TVD MD TVD 25. Aao, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT He KIND OF MATERIAL USED Freeze Protect w/ 91 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO FIOw TUbing PfeSS. 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". Sidewall Cores were taken. The final summary report should be completed in about one month and will be forwarded upon receipt. ~~~5 (~~~- SAY ~ m' 2006 ~ ..,- - ,, Form 10-407 Revised 12/2003 NUED ON REVERSE SIDE ~~~ ,'~~~=~ X28. GEOLOGIC MARKS 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". Ugnu 2690' 2649' None Ugna MA 3898' 3771' Ungu M61 3901' 3773' Ugnu M62 3984' 3837' Schrader Bluff NB 4102' 3925' Schrader Bluff NC 4150' 3960' Schrader Bluff NE 4163' 3969' Schrader Bluff NF 4236' 4023' Schrader Bluff OA 4291' 4063' Schrader Bluff OBa 4373' 4123' Schrader Bluff OBb 4446' 4176' Schrader Bluff OBc 4510' 4222' Schrader Bluff OBd 4581' 4274' Schrader Bluff OBe 4667' 4336' Schrader Bluff OBf 4722' 4376' Base Schrader Bluff OBf 4786' 4422' (Top Colville) H RZ 7080' 6086' Kalubik 7400' 6322' Kuparuk D 7688' 653T Kuparuk C 7800' 6621 Kuparuk B 7915' 6708' 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. ~ c- Si ned U"'/1 ~ g Title Technical Assistant Date 1 lD Terrie Hubble PBU I-100 205-010 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Phil Smith, 564-4897 Permit No. / A royal No. INSTRUCTIONS GeNeRn~: 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). IreM 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". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only • • Schr~c~>~r Bluff l i~up~~uk ~Id~VIt~L4, ~C?R?;~LI~IS~II~I~RY ': BP EX`P[~t3RAT1(~N [-i oa a . s e walf;care depths ~orr~sp~r, d to ~ I~~>~.IQC~,d~pth, ,,fit ieasui~ed w le c#rli Ind depths. > ', :::::> ........... ~.::en hole to s,r~#1 ~~2u~ 6`.I~lf}.d. ! to L~VD io ~<. SWG f~lo. Farmatio~ Req fJepth Recover' CM Comments 1 Kuparuk Cia 7913 2.6 overpull 4x 2 Kuparuk C1a 7910 2.6 ok 3 Kuparuk Cia 7903 2.6 ok 4 Kuparuk C1 a 7894 2.6 ok 5 KuparukClb 7889 2.6 overpull 6x 6 Schrader Bluff OBf 4730 2.6 overpull 3x 7 Schrader Bluff OBe 4687 2.6 overpull 5x 8 Schrader Bluff OBd 4632 2.6 sli overpull 9 Schrader Bluff OBd 4617 3 ok 10 Schrader Bluff OBd 4595 2.6 ok 11 Schrader Bluff OBd 4583 3.2 ok 12 Schrader Bluff OBc 4521 3.2 sli overpull 13 Schrader Bluff OBc 4514 2.5 overpull 4x 14 Schrader Bluff OBb 4451 2.6 ok 15 Schrader Bluff OBa 4407 0 MISFIRE- No Recovery 16 Schrader Bluff OBa 4392 2.6 ok no pull 17 Schrader Bluff OBa 4383 2.6 ok 18 Schrader Bluff OBa 4375 2.6 ok NP 19 Schrader Bluff OA 4326 2.6 ok 20 Schrader Bluff OA 4319 2 ok 21 Schrader Bluff OA 4309 2.5 sli overpull 22 Schrader Bluff OA 4294 2.6 ok 23 Schrader Bluff Ne 4166 No Rec No pull Empty bullet, No Recovery 24 Schrader Bluff Nc 4152 1.3 no pull 25 Schrader Bluff Nb 4124 2.6 ok NP 26 Schrader Bluff Nb 4115 2.6 ok 27 Schrader Bluff Nb 4106 2.6 sli overpull 28 Ugnu Mb2 4063 2.6 ok sli overpull 29 Ugnu Mb2 4055 2.6 ok NP 30 Ugnu Mb2 4035 2.6 ok NP 31 Ugnu Mb1 3961 2.6 ok NP 32 Ugnu Mb1 3950 2.6 ok NP 33 Ugnu Mbi 3944 2.6 sli pull 34 Ugnu Mbi 3932 2.6 ok 35 Ugnu Mbi 3926 2.6 NP 36 Ugnu Mb1 3920 3 NP 37 Ugnu Mbi 3913 2.6 NP 38 Ugnu Mbi 3904 2.6 NP 39 Ugnu 1 3872 2 sli pull, ok 40 Ugnu 1 3838 2.6 sli pull OK 41 Ugnu 1 3822 2 sli pull 42 Ugnu 1 3803 2.6 NP 43 Ugnu 1 3760 2.6 NP 44 Ugnu 1 3687 3.5 NP 45 Ugnu 1 3546 3.5 sli pull 46 3546 NOTE: RECOVERED 43 OUT OF 45 CORE ATTEMPTS (95%) I-100 State Sidewall Core Summary.xls 1 of 1 BP Page l of 1 Leak-Off Test Summary- Legal Name: I-100 Common Name: I-100 Test Date Test'Type ; Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off. Pressure (BHP) EMW 3/28/2006 LOT 2,628.0 (ft) 2,588.0 (ft) 8.80 (ppg) 600 (psi) 1,783 (psi) 13.26 (ppg) 4/9/2006 LOT 2,621.0 (ft) 2,588.0 (ft) 8.90 (ppg) 580 (psi) 1,777 (psi) 13.21 (ppg) • Printed: 4/21/2006 11:58:09 AM gp Page 1 of 19 Operations Summary Report Legal Well Name: I-100 Common Well Name: I-100 Spud Date: 3/20/2006 Event Name: DRILL+COMPLETE Start: 3/19/2006 End: 4/17/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/17/2006 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/19/2006 00:00 - 08:00 8.00 MOB P PRE Move the pits away from the sub. Move the pits from L pad to I pad while bridling up the blocks and getting the rig floor ready for the derrick down rig move. Unpin and lower the cattle chute and the derrick. 08:00 - 18:00 10.00 MOB P PRE Move the sub from L pad to I pad. 18:00 - 20:30 2.50 RIGU N WAIT PRE Wait on security due to shortage in personnel 20:30 - 22:00 1.50 RIGU P PRE Install surface Hydril and Diverter. Lay mats and herculite. Move in and spot the sub over I-100. Put the riser in the cellar and close the doors. Accept the rig at 2200 hours due to waiting on security for 2.5 hours during the rig move. 22:00 - 00:00 2.00 RIGU P PRE Spot spot and level the pit complex. Raise and pin the derrick. Raise and pin the cattle chute. 3/20/2006 00:00 - 02:30 2.50 RIGU P PRE Unbridle the blocks and pin the top drive. RU the rig floor. 02:30 - 05:00 2.50 RIGU P PRE NU the 20 "diverter system, bell nipple and riser. Take on water and spud mud. Load and strap 4" DP in the pipe shed. 05:00 - 10:30 5.50 RIGU P PRE PU 57 joints of 4" HT40 DP and 24 joints of 4" HWDP and stand back in the derrick. 10:30 - 13:30 3.00 RIGU P PRE PU BHA components and bring them to the rig floor. Steam tools and load MWD tools. Ensure all walkways are clear, all handrails installed and berms are trimmed up. Changeout the quill. 13:30 - 14:00 0.50 RIGD P PRE Hold Pre-spud meeting with the rig team. 14:00 - 16:30 2.50 RIGU P PRE PJSM. MU BHA#1 - 12-1/4" surface hole. 16:30 - 17:00 0.50 RIGU P PRE Function test the diverter system. Witness of the test was waived by Lou Grimaldi of the AOGCC. 17:00 - 00:00 7.00 DRILL P SURF Fill the hole and test the lines. Drill from 108' to 355'. POH to the BHA and MU nm stab and jar stand. RIH to 355'. Continue to drill from 355' to 548' - 711 gpm, 1450 psi on, 1270 psi off, 80 rpm, 2.2k TO on, 1 k TO off, PU - 65k, SO - 65k, ROT - 65k, ART - 3.53 hours. 3/21/2006 00:00 - 01:15 1.25 DRILL P SURF Continue to drill 12-1/4" hole to 732'. Take Gyro survey to 500'. RD Gyrodata and HES a-line. 01:15 - 02:45 1.50 DRILL N RREP SURF Repair drag chain. 02:45 - 15:30 12.75 DRILL P SURF Continue to drill 12-1/4" hole from 732' to to 2,628' (TD) - PU - 106k, SO - 98k, ROT -103k, 3,110 psi on, 2,830 psi off, 2.9k TQ on, 1 k TO off, 80 rpm, AST - 3.37, ART - 6.33. Hydrates were managable and encountered intermittently from 1,750' to TD causing a 4" thick frothing of the mud coming across the shakers. The mud was treated with Lecithin prior to entering the hydrates. 15:30 - 17:00 1.50 DRILL P SURF Circulate 2.5 times a bottoms up - 711 gpm, 2,800 psi - observe some gravel and some coal in the returns. MW in - 9.5 ppg, MW out - 9.5 ppg 17:00 - 17:30 0.50 DRILL P SURF POH from 2,628' to 2,310' without problems, PU - 114k, SO - 96k. POH from 2,310' to 2,220' with 25k overpull. Attempt to work wpipe across zone -unable to get past 2,220'. 17:30 - 22:00 4.50 DRILL P SURF Work pipe back down to 2,310'. Screw in with the top drive and backream out of the hole from 2,310' to 1,380' - 700 gpm, 2,800 psi. Observed pea gravel and coal in the returns. Hole cleaned up a bit by 1,380'. Pump out of the hole from 1,380' to 172' - saw a decrease in the amount of gravel returned in the cuttings. 22:00 - 00:00 2.00 DRILL P SURF RIH from 172'. Hit an obstruction at 300'. Attempt to work past Printed: 4/21/2006 11:58:16 AM '$P Page2of19 Operations Summary Report Legal Well Name: I-100 Common Well Name: I-100 Spud Date: 3/20/2006 Event Name: DRILL+COMPLETE Start: 3/19/2006 End: 4/17/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/17/2006 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/21/2006 22:00 - 00:00 2.00 DRILL P SURF without pumps - no go. Ream down to 430' - 250 gpm, 30 rpm, 400 psi. Attempt to RIH without pumps to 460' and tagged up. Worked the pipe several times from 430' to 360' to try and get the hole to clean up -gravel and silt/sand across the shakers - 250 gpm, 400 psi, 30 rpm. Ream down at full drilling rate and make connection. 3/22/2006 00:00 - 01:00 1.00 DRILL P SURF Ream down from 430' to 600' - 700 gpm, 80 rpm, 1,200 psi. RIH without pumps or rotary from 600' to 925'. Work pipe without pumps from 925' to 1,100'. RIH without pumps to 2,300'. Ream down to TD as a precaution. 01:00 - 03:00 2.00 DRILL P SURF Circulate 3+ bottoms up staging up to 700 gpm and 100 rpm. Saw a lot of gravel and silt/sand come across the shakers as well as some frothed up mud, but no major hydrates. MW in - 9.5 ppg, MW out - 9.5 ppg. 03:00 - 07:00 4.00 DRILL P SURF POH from 2,628' to 1,000' without problems. At 1,000', hole started to pull tight. Screw in with the top drive and attempt to backream out of the hole -lost returns - 78 bbls of spud mud lost to the well. Run back in to 1,280' and get flow back. Backream out to 272'. 07:00 - 09:00 2.00 DRILL P SURF LD 12-1/4" BHA#1 from 272'. Clean and clear the floor. 12-1 /4" MXL-1 graded: 5-6-WT-A-E-1-CT-TD 09:00 - 12:00 3.00 CASE P SURF RU to run 9-5/8" 40# L-80 BTC casing - RU casing tool, stabbing board and fillup tool. Make a dummy run with the hanger and mark the landing joint. 12:00 - 15:00 3.00 CASE P SURF PU and RIH with 9-5/8" shoe track -joints 1-3 have been Bakerloc'd. Check the floats -holding. Continue RIH picking up 9-5/8" 40# L-80 BTC casing utilizing BOL 2000 NM thread lubricant and 8,600 ft-Ibs make up torque. Hit obstruction at 500' 15:00 - 18:00 3.00 CASE P SURF Worked the pipe down from 500' to 910' by working the pipe and pumping on it, staging the pumps up to 290 gpm, 440 psi. Hole trying to pack off -saw sand, wood and gravel returned to surface. 18:00 - 20:30 2.50 CASE P SURF Continue to work the pipe from 910' to 953' with considerable difficulty while varying the pump rate. Hole tried to pack off any time the rate was taken below 145 gpm. 20:30 - 23:00 2.50 CASE P SURF Continue to work the pipe at 953 without success. Conferred with town. Decision made to pull the casing back out for a cleanout run. Continue to work the pipe while readying the rig floor to pull casing out of the hole. MW in - 9.5 ppg, MW out - 9.5 PP9 23:00 - 00:00 1.00 CASE N DPRB SURF Hold PJSM with the rig team on laying down the 9-5/8" casing. Pump out and LD casing from 953' to 913' - 260 gpm, 450 psi. Lost 63 bbls of 9.5 ppg spud mud while trying to work the casing in the hole. 3/23/2006 00:00 - 10;30 10.50 CASE N DPRB SURF Pump out and LD casing from 913' to 300' - 260 gpm, 450 psi. POH without pumps from 300' to the shoe tract. Heat up the Bakerloc'd connections with a "rosebud" torch and break the connections. 10:30 - 12:00 1.50 CASE N DPRB SURF RD the casing running equipment and clear the floor. 12:00 - 13:00 1.00 CASE N DPRB SURF RU the rig floor to run back in the hole with 4" DP and cleanout assembly. Bring BHA components to the rig floor. Printed: 4/21/2006 11:58:16 AM ,~ $P Page 3 of 19 Operations Summary Report Lega! Well Name: I-100 Common Well Name: I-100 Spud Date: 3/20/2006 Event Name: DRILL+COMPLETE Start: 3/19/2006 End: 4/17/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/17/2006 Rig Name: NABORS 9ES Rig Number: Date. From -To Hours Task Code.-NPT Phase Description of Operations 3/23/2006 13:00 - 14:30 1.50 CASE N DPRB SURF MU cleanout BHA#2 to 195'. BHA#2 - 12-1/4" MXL-1 RR, near bit stabilizer with float, 3 x steel dc's, xo, 1 x 5" HWDP, jars, 1 x 5"HWDP, xo. 14:30 - 16:30 2.00 CASE N DPRB SURF Ream down from 200' to 1,100'. Hole was very tight from 527' to 1,100' - 600 gpm, 1,400 psi, 6k TO on, 100 rpm. Seeing a considerable amount of gravel and silt/sand coming across the shakers. 16:30 - 17:00 0.50 CASE N DPRB SURF Circulate a bottoms up below the trouble area of 1,100' - 600 gpm, 1,400 psi. Still seeing a lot of gravel with silt/sand across the shakers, but the amount seems to be diminishing. 17:00 - 20:30 3.50 CASE N DPRB SURF Ream down from 1,100' to 2,628'. Hole was much easier to ream through this interval than the one above 1,100' - 600 gpm, 1,400 psi, 4k TQ on, 100 rpm, PU - 96k, SO - 85k, ROT - 90k. Saw much less gravel and silt/sand coming across the shakers. Tight spots seen at 1,945', 2,000', 2,245', 2,391'. 20:30 - 22:00 1.50 CASE N DPRB SURF Circulate 3 times a bottoms up to ensure the hole is as clean as possible prior to short trip - 600 gpm, 2,120 psi. No hydrates seen in the returns and the hole looks to be very clean. MW in - 9.5 ppg, MW out - 9.5 ppg. 22:00 - 00:00 2.00 CASE N DPRB SURF Attempted to POH, but encountered -50k overpull at 2,600' without any tendancy to swab. Attempt to work past without pumps -unsuccessful. Screw in with the top drive and pump out one stand from 2,609' without any major overpull, but we appear to be pulling something up with us. Run back in the hole with stand to 2,609' without pumps and without problems. Attempt to POH without pumps -unsuccessful -pulled tight at the same spot as before. Backream out of the hole from 2,609' to 2,048' - 600 gpm, 2,200 psi, 100 rpm. Saw some considerable torque spikes while backreaming this interval. 3/24/2006 00:00 - 03:30 3.50 CASE N DPRB SURF Backream out of the hole from 2,048' to 465' - 600 gpm, 2,200 psi, 100 rpm -minor torque spikes seen and the shakers cleaned up very well. POH from 465' to 99' without pumps and without problems. 03:30 - 04:30 1.00 CASE N DPRB SURF RIH without pumps or rotary from 99' to 2,020'. 04:30 - 05:30 1.00 CASE N DPRB SURF Tag up at 2,020'. Attempt to work past without pumps or rotary - unsuccessful. Screw in with the top drive and pump and ream down to 2,628' - 600 gpm, 80 rpm, 2,120 psi, 5k TO. 05:30 - 07:00 1.50 CASE N DPRB SURF Circulate and condition the mud prior to trip out of the hole - 600 gpm, 2,120 psi, 90 rpm. 07:00 - 09:30 2.50 CASE N DPRB SURF Circulated some hydrates to surface which caused the released gas from the hydrates to be entrained in the mud and the pump efficiency to drop off. Dropped the rate, circulated and conditioned the mud by adding Screen Clean and some water to thin the mud and to allow the entrained gas to escape. 09:30 - 11:00 1.50 CASE N DPRB SURF Circulate 3 times bottoms up - 600 gpm, 2,080 psi, 90 rpm, PU - 90k, SO - 85k, ROT - 90k. 11:00 - 14:00 3.00 CASE N DPRB SURF Attempt to pull out of the hole without pumps or rotary - unsuccessful. Pump out of the hole from 2,628' to 700' - 600 gpm, 2,080 psi. 14:00 - 16:00 2.00 CASE N DPRB SURF POH without pumps or rotary from 700' to 194'. 16:00 - 17:00 1.00 CASE N DPRB SURF LD cleanout BHA#2 Clear and clean the rig floor. 17:00 - 19:00 2.00 CASE N DPRB SURF RU casing tools and rig floor to run 9-5/8" 40# L-80 BTC casing. Printed: 4/21 /2006 11:58:16 AM • gp Page 4 of 19 Operations Sulrnlrnary Report Legal Well Name: I-100 Common Well Name: I-100 Spud Date: 3/20/2006 Event Name: DRILL+COMPLETE Start: 3/19/2006 End: 4/17/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/17/2006 Rig Name: NABORS 9ES Rig Number: Date': From - Ta Hours Task Code NPT Phase Description of Operations 3/24/2006 19:00 - 21:15 2.25 CASE N DPRB SURF PU and RIH with 9-5/8" shoe track -joints 1-3 have been Bakerloc'd. Check the floats -holding. Continue RIH picking up 9-5/8" 40# L-80 BTC casing utilizing BOL 2000 NM thread lubricant and 8,600 ft-Ibs make up torque. Hit obstruction at 711', but was able to pump past with little problem. RIH with casing to 953'. 21:15 - 23:00 1.75 CASE P SURF Continue RIH with casing from 953' to 1.,980' -tag up at 1,980'. 23:00 - 00:00 1.00 CASE P SURF Pump down from 1,980' to 2,061' - 295 gpm, 530 psi, PU - 150k, SO - 100k 3/25/2006 00:00 - 02:30 2.50 CASE P SURF Pump and work the pipe down from 2,061' to 2,091' with difficulty - 295 gpm, 530 psi, PU - 150k, SO - 100k. Lost returns shortly after making a connection. Attempt to regain - unsuccessful. 02:30 - 03:00 0.50 CASE P SURF LD single joint of 9-5/8" casing. 03:00 - 04:30 1.50 CASE P SURF PU and re-establish circulation - 240 gpm, 250 psi. Circulate while reciprocating to ensure hole is clean. Lost 12 bbls of 9.5 ppg drilling fluid. 04:30 - 18:00 13.50 CASE P SURF Continue to pump and work the pipe down from 2,091' to 2,628' - hole trying to pack off - 327 gpm, 520 psi. LD fillup tool and MU hanger, landing joint and cement head. 18:00 - 21:30 3.50 CEMT P SURF Circulate and condition the mud while reciprocating - PU - 140k, SO - 110k, 420 gpm, 722 psi. Hold PJSM for the cement job and prime up the pump unit. 21:30 - 00:00 2.50 CEMT P SURF Line up to Schlumberger and pump 5 bbls of fresh water. Shut in and pressure test the lines to 3,500 psi -good. Shut down and batch up a tub of 10.2 ppg Mudpush II and pump 78 bbls. Attempted to reciprocate, but was unable, so we left the hanger on the ring throughout the entire cement job. While pumping the spacer, we varied the rate from 6.5 bpm to 4 bpm to get the rate lined out so that we were not losing any fluid, but we had partial losses -lost approximately 30 bbls while pumping the spacer. Shut down and dropped the bottom plug while hatching up a tub of the 10.7 ppg ArcticSet Lite lead cement. Pumped 437 bbls of lead cement. Continued to vary the rate in an attempt to reduce the losses -average rate was 5 bpm, 500 psi. Saw some hydrates circulate to surface after 250 bbls of lead pumped. Shut in and batch a tub of the 15.8 ppg Glass G +adds tail cement. Pumped 44 bbls of tail cement. Continued to vary the rate in an attempt to reduce the losses -average rate was 4.6 bpm, 690 psi - lost a total of 40 bbls while pumping the lead and the tail cement. Shut down and drop the j top plug. Kick out the plug with 10 bbls of fresh water. Line up to the rig to displace. 3/26/2006 00:00 - 01:00 1.00 CEMT P SURF Displaced with the rig using conditioned 9.5 ppg drilling fluid. Caught the cement after -14 bbls pumped. Continue to displace with the rig at 5 bpm - 650 psi, FCP - 820 psi with 151 bbls displaced. Reduce the rate to 4 bpm with 151 bbls pumped - 812 psi, then to 3 bpm with 165 bbls pumped - 750 psi, and finally to 2 bpm with 175 bbls pumped - 720 psi. Bumped the plug on calculated volume of 184 bbls with 3,500 psi - 96% efficiency. Lost --70 bbls of 9.5 ppg drilling fluid during the displacement -total losses to the well during the cement job was -140 bbls. CIP - 0030 3/26/06. Cement was Printed: 4/21/2006 11:58:16 AM ~' BP Page 5 of 19 Operations Summary Report Legal Well Name: I-100 Common Well Name: I-100 Spud Date; 3/20/2006 Event Name: DRILL+COMPLETE Start: 3/19/2006 End: 4/17/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/17/2006 Rig Name: NABORS 9ES Rig Number: Date From - To Hours .Task Cade <NPT Phase Description of Operations 3/26/2006 00:00 - 01:00 1.00 CEMT P SURF not circulated to surface. Checked the floats -holding. 01:00 - 02:30 1.50 CEMT P SURF RD the cement head and rig floor. LD top pup of the 9-5/8" split landing joint. Clear and clean the floor. RU to run the TAM port collar shifting tool. Have additional 10.7 ppg lead cement brought to the rig from Deadhorse. 02:30 - 04:30 2.00 CEMT P SURF MU TAM port collar combo tool and RIH on 4" HWDP and 4" DP to 1,010'. PU - 58k, SO - 55k. Open the TAM port collar. 04:30 - 11:00 6.50 CEMT P SURF Circulate and condition the drilling fluid through the port collar. Saw -25 bbls of cement in the returns after 4 bottoms up. Stage up the pumps to 10 bpm and circulate 3.5 times bottoms up, 1,065 psi - no losses. Drop the rate to 2 bpm. 11:00 - 13:30 2.50 CEMT N WAIT SURF Continue to circulate while waiting on Schlumberger crew to change out due to number of hours worked. 13:30 - 16:30 3.00 CEMT P SURF Line up to Schlumberger and pump 5 bbls of fresh water ahead. Pressure test the lines to 3,500 psi -good. Bleed off pressure and continue to pump 15 bbls additional fresh water at 6 bpm, 310 psi. Batched up a tub of 10.7 ppg ArcticSet Lite and pumped 394 bbls at 8 bpm, 500 psi. At -200 bbls away, dropped the rate to 5.4 bpm, 300 psi. At 300 bbls away, dropped the rate to 2 bpm due to clabbered up mud coming back to surface. While pumping, the last 94 bbls, the flutes in the hanger plugged up with gel/gravel balls and the pump was shut down to clear the flutes. Once the flutes were cleared, the cement job was restarted. Once cement was seen at the surface, the circulation fines were lined up to the rig for displacement - 11 bbls of 9.5 drilling mud ~10 bbls of cement returned to the surface - -625% excess was required. CIP 1630 3/26/2006 16:30 - 17:30 1.00 CEMT P SURF Close the TAM port collar. Pressure test to 1,000 psi to verify closure -closed. Rotate 1/4 turn to the right and pull up and out of the TAM port collar. Pressure test to 1,000 psi again to verify closure -closed. PU 10 ft and pressure up to 2,250 psi to shear the burst disc and circulate the 9-5/8" casing clean at 4 bpm, 450 psi. 17:30 - 20:00 2.50 CEMT P SURF RD the circulation lines on the rig floor. POH standing back the 4" DP and 4" HWDP from 1,010'. LD TAM combo tool, install top pup on the split landing joint, and LD the landing joint. Clean and clear the floor. 20:00 - 00:00 4.00 DIVRTR P SURF ND diverter. 3/27/2006 00:00 - 02:00 2.00 WHSUR P SURF MU base flange and tubing spool. Test the metal to metal seal to 1,000 psi for 10 minutes -good. 02:00 - 04:30 2.50 BOPSU P SURF NU the BOPE, MU turnbuckles and install riser. RU the rig floor for BOP test. 04:30 - 08:30 4.00 BOPSU P SURF Test the ROPE and all related valves to 250 psi low / 4,000 psi high. Test the Annular Preventer to 250 psi low / 3,500 psi high. There were no failures during the test. Winess of the test was waived by Jeff Jones of the AOGCC. Witness of the test was done by James Franks/Alan Madsen - BP and Brian Tiedemann/Kelly Kozby - NAD. 08:30 - 09:30 1.00 BOPSU P SURF RD the testing equipment and blow down all the surface lines. Install wear ring. 09:30 - 14:00 4.50 CASE P SURF PJSM for installing kelly hose. Install kelly hose. 14:00 - 18:30 4.50 CASE P SURF PU 4" DP 1 x 1 and RIH to 2,486'. Stand back in the derrick. Printed: 4/21/2008 11:58:16 AM BP Page 6 of 19 Operations Slummalty Report Legal Well Name: I-100 Common Well Name: I-100 Spud Date: 3/20/2006 Event Name: DRILL+COMPLETE Start: 3/19/2006 End: 4/17/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/17/2006 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT :Phase Description of Operations 3/27/2006 18:30 - 22:00 3.50 CASE P SURF PU 4" DP 1 x 1 and RIH to 2,486'. Stand back in the derrick. 22:00 - 00:00 2.00 CASE P SURF PU 4" DP 1 x 1 and RIH to 2,486'. 3/28/2006 00:00 - 02:15 2.25 CASE P SURF Continue to PU 4" DP 1 x 1. Stand back 4" DP in the derrick from 2,486'. 02:15 - 03:00 0.75 CASE P SURF PU 4" DP 1 x 1 and RIH to 375'. Stand back 4" DP in the derrick from 375'. 03:00 - 05:30 2.50 DRILL P PROD1 PJSM. MU and RIH with 8.75" build assembly, BHA#3 - 8.75" MXC-1, 6.75" PDM w/ 1.5 degree bend - 3 stg - 7/8 R/S, XO w/float, LWD/ARC, MWD, nm dc, nm stab, 2 x nm dc, saver sub, 1 x 5" HWDP, jars, 1 x 5" HWDP, xo, 24 x 4" HWDP. 05:30 - 08:15 2.75 DRILL P PROD1 RIH with BHA#3 picking up 4" DP 1 x 1 to 2,500' 08:15 - 09:45 1.50 DRILL P PROD1 Slip and cut 50' of drilling line. Clean under the drawworks, service the top drive and grease the crown. 09:45 - 10:45 1.00 CASE P PROD1 RU and pressure test the 9-5/8" 40# L-80 BTC casing to 3,500 psi, chart and hold for 30 minutes -good. Blowdown the surface lines. 10:45 - 12:30 1.75 DRILL P PROD1 Wash down and tag top of the 9-5/8" float collar at 2,538'. Drill float collar, cement, float shoe and rat hole down to 2,628' - 500 gpm, 1,740 psi, 60 rpm, 2.5k TO. 12:30 - 13:15 0.75 DRILL P PROD1 Displace the well over to 8.8 ppg LSND drilling fluid - 509 gpm, 1,600 psi. 13:15 - 13:45 0.50 DRILL P PROD1 Drill 20' of new hole to 2,648' and circulate cuttings up the hole. 13:45 - 14:15 0.50 DRILL P PROD1 Line up and perform LOT with 600 psi surface pressure, 8.8 ppg .fluid at 2,588' TVD - 13.26 ppg EMW. 14:15 - 14:30 0.25 DRILL P PROD1 Get ECD baseline values, CECD - 9.22 ppg EMW. 14:30 - 21:00 6.50 DRILL P PROD1 Drill 8-3/4" hole ahead directionally from 2,648' to 3,483' - 583 gpm, 1,490 psi on, 1,380 psi off, PU - 113k, SO - 94k, ROT - 101 k, 80 rpm, TO on - 4.2k, TO off - 3.2k, CECD - 9.48 EMW, AECD - 9.57 EMW, ART - 0.15, AST - 4.7. Pumped a high visc sweep while sliding at 3,100' - no additional cuttings seen. 21:00 - 22:00 1.00 DRILL P PROD1 Circulate a high visc sweep from surface to surface while rotating at 80 rpm - 580 gpm, 1,200 psi. Saw -30% more cuttings returned to surface. Circulate hole clean. PU - 110k, SO - 85k, MW in - 8.8 ppg, MW out - 8.8 ppg. 22:00 - 00:00 2.00 DRILL P PR001 POH standing back 4" DP and 4" HWDP from 3,483' to 259'. 3/29/2006 00:00 - 02:00 2.00 DRILL P PROD1 LD BHA#3 from 259'. Clear and clean the floor. 02:00 - 05:30 3.50 DRILL P PROD1 Bring BHA#4 tools to the rig floor. Hold PJSM for BHA and handling of nuclear source. MU BHA#4 and RIH - 8-3/4" RSX616M, 6-3/4" PowerDRIVE bras unit, control collar, receiver sub, flex dc, LWD/ARC, MWD, ADN, 2 x nm flex dc's, xo, 1 x 5" HWDP, jar, 1 x 5" HWDP, xo. 05:30 - 06:00 0.50 DRILL P PROD1 RIH with BHA#4 on 4" DP to 1,116'. Shallow test the MWD, 580 gpm, 960 psi. RIH to 2,552', PU - 83k, SO - 73k. 06:00 - 06:30 0.50 DRILL P PROD1 Service the top drive. 06:30 - 09:00 2.50 DRILL P PROD1 RIH and tag up at 2,822'. Ream down from 2,822' to 3,130' - 400 gpm, 780 psi, 60 rpm, 2k TO. Wipe across interval without pumps -good. Continue RIH to 3,412'. Precautionary wash down to 3,483'. 09:00 - 00:00 15.00 DRILL P PROD1 Drill 8-3/4" ahead directionally with the rotary steerable BHA from 3,483' to 5,314'. PU - 112k, SO - 79k, ROT - 93k, 580 gpm, 130 rpm, 2,040 psi on, 1,975 psi off, WOB - 10k, TO on - 4.5k, TQ off - 3.7k, ART - 9.69 hours, CECD - 9.77 EMW, AECD - 10.03 EMW. Weatherford ghost reamer inserted into Printed: 4/21/2006 11:58:16 AM a • BP Page 7 of 19 Operations Summary Report Legal Well Name: I-100 Common Well Name: I-100 Spud Date: 3/20/2006 Event Name: DRILL+COMPLETE Start: 3/19/2006 End: 4/17/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/17/2006 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/29/2006 09:00 - 00:00 15.00 DRILL P PROD1 the drill string at 4,559' MD. 3/30/2006 00:00 - 06:30 6.50 DRILL P PROD1 Drill 8-3/4" ahead directionally with the rotary steerable BHA 06:30 - 08:00 I 1.501 DRILL I P 08:00 - 13:00 I 5.001 DRILL I P 13:00 - 15:00 I 2.00 I DRILL I P 15:00 - 17:00 I 2.001 DRILL I P 17:00 - 18:00 I 1.001 DRILL I P 18:00 - 20:00 I 2.001 DRILL I P 20:00 - 00:00 I 4.001 DRILL I P 3/31/2006 00:00 - 00:30 0.50 DRILL P 00:30 - 12:00 11.50 DRILL P 12:00 - 00:00 12.00 DRILL P 14/1/2006 100:00 - 12:00 I 12.001 DRILL I P 12:00 - 00:00 I 12.001 DRILL I P 14/2/2006 100:00 - 02:00 I 2.00) DRILL I P from 5,314' to 5,786', PU - 114k, SO - 84k, ROT - 94k, 580 gpm, 130 rpm, 2,125 psi on, 2,115 psi off, WOB - 10k, TO on - 4.3k, TO off - 3.7k, ART - 6.11 hours, CECD - 9.9 EMW, AECD - 9.94 EMW. ROP decreased to <1 fph at 0415 hours. PROD1 MW in - 9.Oppg, MW out - 9.0 ppg, PU - 114k, SO - 86k. Monitor the well -stable. Trip out of the hole to look at the bit. Intermittent overpulls and swabbing -work pipe to 5,126'. PROD1 Backream out of the hole from 5,126' to 3,221' - 550 gpm, 80 rpm, 5.7k TO, 1,900 psi. Tried several times over this interval to pull without pumps or rotary without success. PROD1 Pump out of the hole from 3,221' to 2,620' - 580 gpm, 1,650 psi. POH to the top of the BHA at 257'. PROD1 PJSM. Handle BHA#4. Stand back the jar stand and LD the flex dc's. Remove the nuclear source and LD the ADN, MWD, LWD/ARC, and PowerDRIVE components. Breakout and LD the bit. 8-3/4" RSX616M graded: 2-2-BT-A-X-I-CT-PR PROD1 Clear and clean the floor. Monitor the well -stable. Service the top drive and lubricate the rig. PROD1 PJSM. MU BHA#5, load nuclear source and RIH to 257'. Change out the bit and the PowerDRIVE bias unit. BHA#5 8-3/4" RSX616M, 6-3/4" PowerDRIVE bias unit, control collar, receiver sub, flex dc, LWD/ARC, MWD, ADN, 2 x nm flex dc's, xo, 1 x 5" HWDP, jar, 1 x 5" HWDP, xo. PROD1 RIH with 4" DP from 257' to 1,213'. Shallow test the MWD - good. Continue to RIH to 5,697'. Worked tight spots from 3,100' to 3,310'. PROD1 Continue to RIH from 5,697'. Precautionary wash down to 5,786'. PROD1 Drill 8-3/4" ahead directionally with the rotary steerable BHA from 5,786' to 6,889', PU - 126k, SO - 81 k, ROT - 100k, 580 gpm, 130 rpm, 2,370 psi, WOB - 10k, TO on - 5k, TO off - 4k, ART - 9.35, CECD - 9.9 EMW, AECD - 9.69 EMW. Lower WOB and RPM when hard stringers are encountered. Pumped a weighted sweep at 6,765' with no visible addition to the returns. PROD1 Drill 8-3/4" ahead directionally with the rotary steerable BHA from 6,889' to 7,323', PU - 132k, SO - 76k, ROT - 100k, 580 gpm, 140 rpm, 2,275 psi, WOB - 10k, TO on - 6k, TO off - 5k, ART - 9.35, CECD - 9.83 EMW, AECD - 9.67 EMW. Lower WOB and RPM when hard stringers are encountered. PROD1 Drill 8-3/4" ahead directionally with the rotary steerable BHA from 7,323' to 8,076', PU - 140k, SO - 89k, ROT - 107k, 580 gpm, 140 rpm, 2,525 psi, WOB - 5-20k, TO on - 6k, TO off - 5k, ART - 9.15, CECD - 9.91 EMW, AECD - 9.92 EMW. Lower WOB and RPM when hard stringers are encountered. PROD1 Drill 8-3/4" ahead directionally with the rotary steerable BHA from 8,076' to 8,728', PU - 137k, SO - 80k, ROT - 103k, 580 gpm, 140 rpm, 2,800 psi, WOB - 5-20k, TO on - 8k, TO off - 6k, ART - 8.47, CECD - 10.19 EMW, AECD - 10.06 EMW. Lower WOB and RPM when hard stringers are encountered. PROD1 Drill 8-3/4" ahead directionally with the rotary steerable BHA Printed: 4/21/2006 11:58:16 AM BP Page 8 of 19 Operations Summary Report Legal Well Name: I-100 Common Well Name: I-100 Spud Date: 3/20/2006 Event Name: DRILL+COMPLETE Start: 3/19/2006 End: 4/17/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/17/2006 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT phase.:. Description of Operations 4/2/2006 00:00 - 02:00 2.00 DRILL P PROD1 from 8,728' to 8,850', PU - 137k, SO - 80k, ROT - 103k, 580 gpm, 140 rpm, 2,800 psi, WOB - 5-15k, TO on - 8k, TO off - 6k. Lower WOB and RPM when hard stringers are encountered. 03:00 - 12:00 9.00 DRILL P PROD1 Adjust time ahead 1 hour for Daylight Savings Time. Drill 8-3/4"ahead directionally with the rotary steerable BHA from 8,953' to 9,070', PU - 145k, SO - 83k, ROT - 103k, 580 gpm, 140 rpm, 3,060 psi, WOB - 5-15k, TO on - 8k, TQ off - 6k, ART - 8.07, CECD - 10,2 EMW, RECD - 10.2 EMW. Lower WOB and RPM when hard stringers are encountered. 12:00 - 00:00 12.00 DRILL P PROD1 Drill 8-3/4" ahead directionally with the rotary steerable BHA from 9,070' to 9,511', PU - 133k, SO - 79k, ROT - 97k, 580 gpm, 140 rpm, 3,330 psi, WOB - 5-15k, TO on - 7k, TO off - 6k, ART - 10.37, CECD - 10.13 EMW, AECD - 10.03 EMW. Lower WOB and RPM when hard stringers are encountered. 4/3/2006 00:00 - 12:00 12.00 DRILL P PROD1 Drill 8-3/4" ahead directionally with the rotary steerable BHA from 9,511' to 10,580', PU - 140k, SO - 81 k, ROT - 103k, 580 gpm, 140 rpm, 4,085 psi, WOB - 5-15k, TQ on - 8k, TQ off - 6k, ART - 9.62, CECD - 10.2 EMW, AECD - 10.51 EMW. Lower WOB and RPM when hard stringers are encountered. 12:00 - 22:45 10.75 DRILL P PROD1 Drill 8-3/4" ahead directionally with the rotary steerable BHA from 10,580' to 11,225', PU - 133k, SO - 65k, ROT - 96k, 580 gpm, 140 rpm, 3,950 psi, WOB - 5-15k, TO on - 8.6k, TO off - 6.5k, ART - 9.25, CECD - 10.24 EMW, AECD - 10.34 EMW. Lower WOB and RPM when hard stringers are encountered. Pumped a weighted sweep at 10,750' and saw --5% additional cuttings returned. 22:45 - 00:00 1.25 DRILL P PROD1 Swab went out on the #2 mud pump releasing -2 bbls of drilling mud onto the floor -notified non-emergency spill response x 5700. Replace the swab. Reciprocate the pipe and circulate while working on mud pump - 267 gpm, 1,052 psi. 4/4/2006 00:00 - 00:30 0.50 DRILL P PROD1 Continue circulating and reciprocating while changing swab on the mud pump @ 267 gpm, 1,050 psi. 00:30 - 04:00 3.50 DRILL P PROD1 Drill 8-3/4" ahead directionally with the rotary steerable BHA from 11,225' to 11,310, PU - 137k, SO - 67k, ROT - 101 k, 580 gpm, 140 rpm, 3,930 psi, WOB - 5-15k, TO on - 8.6k, TO off - 6.5k. CECD - 10.24 ppg, AECD - 10.24 ppg. Lower WOB and RPM when hard stringers are encountered. 04:00 - 05:30 1.50 DRILL P PROD1 Change failed swab and liner in #1 mud pump due to failure. Change other swabs and liners in # 1 mud pump due to hours. Circulate and reciprocate @ 269 gpm, 1,080 psi, 60 rpm, 5-6k TO. 05:30 - 13:00 7.50 DRILL P PROD1 Drill 8-3/4" ahead directionally with the rotary steerable BHA from 11,310', to 11,827'. PU - 144k, SO - 60k, ROT - 101 k, 573 gpm, 140 rpm, 4,100 psi, WOB - 5-15k, TO on - 9k, TO off - 8k. CECD - 10.24 ppg, AECD - 10.43 ppg. Lower WOB and RPM when hard stringers are encountered. 13:00 - 14:00 1.00 DRILL P PROD1 Change failed discharge valve in #1 mud pump. 14:00 - 15:30 1.50 DRILL P PROD1 Drill 8-3/4" ahead directionally with the rotary steerable BHA from 11,827', to TD @ 11,982' MD, 3,915' TVD. PU - 140k, SO - 50k, ROT - 93k, 580 gpm, 140 rpm, 4,100 psi, WOB - 5-15k, TO on - k, TO off - 7.5k. CECD - 10.32 ppg, AECD - 10.47 ppg. Lower WOB and RPM when hard stringers are encountered. ART - 8.92 hrs (from midnight) Printed: 4/21/2006 11:58:16 AM ~' gp Page 9 of 19 Operations Summary Report Legal Well Name: I-100 Common Well Name: I-100 Spud Date: 3/20/2006 Event Name: DRILL+COMPLETE Start: 3/19/2006 End: 4/17/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/17/2006 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase. Description of Operations 4/4/2006 15:30 - 16:30 1.00 DRILL P PROD1 Circulate bottoms up @ 580 gpm, 4,075 psi, 140 rpm, 7.1k TO. CECD - 10.32 ppg, AECD - 10.37 ppg. 16:30 - 00:00 7.50 DRILL P PROD1 Monitor well - OK. 9.2 ppg mud weight. PU - 147k, SO - 63k without pumps. Backream out of hole from 11,982' to 7,702'. 560 gpm, 3,700 psi, 100 rpm, 7.2k - 8.6k TQ. Torque spikes of 2-3k over and minimal packoffs through coal stringers. 4/5/2006 00:00 - 08:30 8.50 DRILL P PROD1 Backream out of hole from 7,702" to 3,603'. 575 gpm, 2,650 psi, 100 rpm, 5k - 3.5k TO, 107k rotating weight, CECD - 10.24 ppg, AECD - 9.26 ppg. Pump out without rotating from 3,603' to 2,552', 575 gpm, 1,600 psi. 08:30 - 09:30 1.00 DRILL P PROD1 Circulate bottoms up @ 2,552', 570 gpm, 1,400 psi, 65 rpm. Monitor well - OK. Pump dry job. 9.2 ppg mud weight. 09:30 - 11:30 2.00 DRILL P PROD1 POH from 2,522' to 257'. PU - 90k, SO - 85k @ shoe. Stand back jar and flex DC stand. 11:30 - 12:30 1.00 DRILL P PROD1 PJSM with SLB on nuclear source. Unload same and lay down BHA #5. 12:30 - 13:00 0.50 DRILL P PROD1 Clear and clean rig floor. 13:00 - 14:00 1.00 BOPSU P PROD1 Rig up to test BOPE 14:00 - 17:30 3.50 BOPSU P PROD1 Test BOPE to 250 psi low pressure, 4,000 psi high pressure. Test annular preventer to 250 low pressure, 3,500 psi high pressure. Witnessing of test waived by AOGCC rep Chuck Scheive. Test witnessed by BP WSL Brian Buzby, Nabors TP Bill Bixby, and pump operator / Driller Sean Holcolm. 17:30 - 18:30 1.00 BOPSU P PROD1 Rig down BOPE test equipment 18:30 - 20:00 1.50 CASE P ABAN Rig up to run 5.5" P&A string. 20:00 - 00:00 4.00 CASE P ABAN PJSM on running casing. Pick up, Baker Lok, and make up shoe joint, crossover, and joint #2. Attempt to check shoe float. Mud didn't drop out of joint. Pick up head pin to casing and pump through shoe to confirm circulation. Pressured up to 100 psi before circulating. Rig down head pin and check float - OK. Continue RIH with 5.5" 17# L-80 LTC/tBT casing to 1,200'. 4/6/2006 00:00 - 01:30 1.50 CASE P ABAN Continue RIH with 5.5" 17# L-80 LTC/IBT P&A casing from 1,200' to 2,600'. Lubricated threads with Best-O-Life 2000 NM, torqued to 4,000 fUlbs. Filling each joint and topping off every 5 joints 01:30 - 02:15 0.75 CASE P ABAN Rig up circulating equipment. Circulate pipe volume @ 191 gpm, 100 psi. Check circulating rates @ 30 spm, 73 gpm, 40 psi. 60 spm, 147 gpm, 70 psi. Rig down circulating equipment. Ran total of: 57 joints 5.5" 17# L-80 LTC casing 9 joints 5.5" 17# L-80 IBT casing 02:15 - 03:00 0.75 CASE P ABAN Pick up and make up last joint of casing plus Baker ECP Isozone packer and C2 setting sleeve. PU - 81 k, SO - 74k. 03:00 - 04:00 1.00 CASE P ARAN Rig down casing running equipment. Make up plug dropping head on single and lay back down on skate. 04:00 - 11:30 7.50 CASE P ABAN Continue RIH with 5.5" 17# L-80 LTC/IBT P&A casing on 4" drillpipe and HWDP from 2,687' to 11,956'. Fill and break circulation every 10 stands. 11:30 - 12:00 0.50 CASE P ARAN Pick up, make up single with cementing head and wash down from 11,956' to bottom @ 11,982'. 210 gpm, 755 psi, PU - Printed: 4/21/2006 11:58:16 AM ,i BP Page 10 of 19 Operations Summary Report Legal Well Name: I-100 Common Well Name: I-100 Spud Date: 3/20/2006 Event Name: DRILL+COMPLETE Start: 3/19/2006 End: 4/17/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/17/2006 Rig Name: NABORS 9ES Rig Number: Da#e From - To Hours Task Code NPT Phase 'Description of Operations 4/6/2006 11:30 - 12:00 0.50 CASE P ARAN 147k, SO - 70k. 12:00 - 14:30 2.50 CEMT P ARAN Circulate and condition mud. 210 gpm, 735 psi, PU - 137k, SO - 75k. Held PJSM on cement job while circulating. 14:30 - 16:00 1.50 CEMT P ABAN Sacrificial P&A cement job. Pump 10 bbls H2O. Pressure test lines to 3,500 psi - OK. Mix and. pump 157 bbls 15.8 ppg lead cement, followed by 60 bbls 12.5 ppg tail cement. Shut down, drop wiper plug and kick out with 5 bbls 12.5 ppg tail cement. Unable to continue pipe reciprocation after dropping wiper plug. Displace with Dowell pumping new 9.2 ppg LSND mud 81 bbls @ 5 bpm, 700 psi. Slow pumps to 3 bpm to 93 bbls, 2 bpm, 300 psi to 94 bbls to bump plug. Bumped plug with 1000 psi. CIP @ 16:00 hr. Had full returns during cement job and displacement. 16:00 - 16:30 0.50 CEMT P ARAN Set ECP packer. Stage up pressure in 500 psi increments to 2,500 psi. Observed packer inflating by seeing 1600 psi pressure loss to 900 psi. Bleed off pressure, check floats - OK. 16:30 - 17:00 0.50 CEMT P ABAN Slack off to 35k and rotate 20 turns to the right. Release torque, 5 turns back. Pick up to 115k, slack off to 35k. Rotate 5 turns to the right. Release torque, 1-1/2 turns back. Pressure up to 1,000 psi, pick up out of liner. Liner set @ 11,980' Top of liner @ 9,300' 17:00 - 19:00 2.00 CEMT P ABAN Displace well with new 9.2 ppg LSND mud @ 580 gpm, 1,800 psi. Continue circulating and reciprocating 40' strokes. slowed rate to 400 gpm to handle fluids at surface. Returned and dumped 20 bbls good cement and 64 bbls of contaminated mud. Circulated 3 X bottoms up. Saw a small amount of (base ball and golf ball sized) coal chunks come over shakers intermittently during the 3x bottoms up. 19:00 - 20:30 1.50 CEMT P ABAN Monitor well - OK. Lay down single joint with cement head, rig down cement line. POH from 9,277' to 8,619'. PU - 155k, SO - 85k. 20:30 - 00:00 3.50 CEMT P ABAN Pick up single with cement head, break connections and lay down same. Continue to POH from 8,619 to 3,000'. Started losing mud @ appx. 9 bph after 20 stands were pulled. Lost 18 bbls total. 4/7/2006 00:00 - 01:30 1.50 CEMT P ABAN Continue to POH from 3,000' to surface. Lay down running tool. Tool had cement build up on outside of tool. 01:30 - 02:00 0.50 CEMT P ABAN Clean and clear rig floor. 02:00 - 02:30 0.50 CEMT P ARAN Rig up to run 3.5" NSCT cement stinger string. 02:30 - 06:30 4.00 CEMT P ABAN PJSM on running tubing. Make up 3.5" mule shoe, crossover pup and RIH with 3.5" 9.2# L-80 NSCT tubing cement string. 28 bph loss rate. 06:30 - 07:00 0.50 CEMT P ABAN Rig down tubing running tools. 07:00 - 07:30 0.50 CEMT P ABAN RIH with cement string on 4" drillpipe from 1,895' to 2,565'. 07:30 - 08:30 1.00 CEMT P ABAN Cut and slip drilling line 46'. 08:30 - 09:00 0.50 CEMT P ARAN Service topdrive and crown. 09:00 - 12:00 3.00 CEMT P ABAN Continue RIH with cement string on 4" drillpipe from 2,565' to 4,055'. PU - 85k, SO- 65k @ shoe. Set down at 4,055', pick up to 3,970'. Make up topdrive and attempt to wash down from 3,979'. Unable to go down or up. Differentially sticking. Work string free with torque and slump. Stand back stand, make up Printed: 4/21/2006 11:58:16 AM gp Page 11 of 19 Operations Summary Report.. Legal Well Name: I-100 Common Well Name: I-100 Spud Date: 3/20/2006 Event Name: DRILL+COMPLETE Start: 3/19/2006 End: 4/17/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/17/2006 Rig Name: NABORS 9ES Rig Number: Date' From - To Hours Task Gode NPT Phase Description of Operations 4/7/2006 09:00 - 12:00 3.00 CEMT P ABAN topdrive. Stage up pump to 235 gpm, 250 psi and wash to 4,096'. Midnight to noon mud loss = 158 bbls. 10 bph static loss rate @ noon. 12:00 - 14:00 2.00 CEMT P ABAN Circulate bottoms up. 188 gpm, 225 psi, 22 rpm, 1 k TO. Large amounts of cement and polymer in returns. Dumped 25-30 bbls of solids. 14:00 - 14:30 0.50 CASE P ABAN Wash down from 4,096' to 4,574'. 201 gpm, 230 psi, 40 rpm, 1k TO, 84k rotating weight. 14:30 - 16:00 1.50 CEMT P ABAN Circulate bottoms up. 201 gpm, 230 psi, 40 rpm, 1 k TO, 84k rotating weight. 16:00 - 17:00 1.00 CEMT P ABAN RIH from 4,574' to 5,527'. Broke circulation @ 5,051' and washed stand down. 17:00 - 18:00 1.00 CEMT P ABAN Circulate bottoms up. 215 gpm, 330 psi, 30 rpm, 1.8k TO. 18:00 - 18:30 0.50 CEMT P ABAN RIH from 5,527' to 6,197'. Broke circulation @ 6,006' and washed stand down to 6,197'. PU - 115k, SO - 75k. 18:30 - 20:00 1.50 CEMT P ABAN Circulate bottoms up. 215 gpm, 370 psi, 30 rpm, 2.2k TO. 20:00 - 20:30 0.50 CEMT P ABAN RIH from 6,197' to 7,138'. Broke circulation @ 6,665' and washed stand down. 20:30 - 22:00 1.50 CEMT P ABAN Circulate bottoms up. 215 gpm, 440 psi, 30 rpm, 2.9k TO. 22:00 - 23:00 1.00 CEMT P ABAN RIH from 7,138' to 8,095'. Work through tight spots @ 7,300' and 7,480'. Broke circulation @ 7,480' and washed stand down. 23:00 - 00:00 1.00 CEMT P ABAN Circulate bottoms up. 215 gpm, 485 psi, 10 rpm, 3k TO. Noon to Midnight mud loss = 122 bbls Total mud loss for day = 280 bbls 4/8/2006 00:00 - 01:30 1.50 CEMT P ARAN Continue RIH with 3.5" cement string on 4" drillpipe from 8,095' to top of 5.5" liner @ 9,300'. Washed last stand down. 01:30 - 05:00 3.50 CEMT P ARAN Circulate 1 bottoms up @ 223 gpm, 565 psi, 10 rpm, 3.3k TO, PU 140k, SO - 90k, ROT - 100k. Circulate 2 x bottoms up @ 500 gpm, 1700 psi. Held PJSM while circulating. 05:00 - 06:30 1.50 CEMT P ABAN P&A plug #1. Rig up circulating head. Switch to Dowell and pump 5 bbls H2O. Test lines to 3,500 psi - OK. Pump remaining 15 bbls H2O followed by 109 bbls 15.8 ppg class "G" cement followed by 3 bbls H2O. Switch to rig pumps and displace cement with 71 bbls 9.2 ppg LSND mud @ 5 bpm, 825 psi maximum pressure. CIP @ 06:15 hr. Reciprocated pipe during entire cement job. 06:30 - 07:30 1.00 CEMT P ABAN POH from 9,300' to 8,175', 20 fpm. PU - 160k. No problems. 07:30 - 09:00 1.50 CEMT P ABAN Circulate 2 X bottoms up @ 550 gpm, 1,880 psi, 35 rpm, 4.4k TO, PU 108k, SO - 90k, ROT - 97k. Returned appx. 15 bbls cement. Held PJSM while circulating. 09:00 - 10:00 1.00 CEMT P ARAN P&A plug #2. Rig up circulating head. Switch to Dowell and pump 5 bbls H2O. Test lines to 3,500 psi - OK. Pump remaining 15 bbls H2O followed by 109 bbls 15.8 ppg class "G" cement followed by 3 bbls H2O. Switch to rig pumps and displace cement with 61 @ 6.5 bpm, 985 psi maximum pressure. CIP @ 09:52 hr. Reciprocated pipe during entire cement job. Started getting sticky last 10 bbls cement and throughout displacement. 10:00 - 11:00 1.00 CEMT P ABAN POH from 9,175' to 7,042', 20 fpm. PU - 150k. Intermittent Printed: 4!2112006 11:58:16 AM i gp Page 12 of 19 Operations Summary Report Legal Well Name: I-100 Common Well Name: I-100 Spud Date: 3/20/2006 Event Name: DRILL+COMPLETE Start: 3/19/2006 End: 4/17/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/17/2006 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/8/2006 10:00 - 11:00 1.00 CEMT P ABAN 50k over sticky spots. 11:00 - 12:00 1.00 CEMT P ARAN Circulate 2 X bottoms up @ 550 gpm, 1,535 psi, 38 rpm, 2.8k TO, PU 95k, SO - 85k, ROT - 90k. Returned appx. 15 bbls cement. Held PJSM while circulating. 12:00 - 12:30 0.50 CEMT P ABAN Drop drillpipe wiper plug and pump down same @ 543 gpm, 1,340 psi, 40 rpm, 2.7k TQ. 12:30 - 13:30 1.00 CEMT P ABAN P&A plug #3. Rig up circulating head. Switch to Dowell and pump 5 bbls H2O. Test lines to 3,500 psi - OK. Pump remaining 15 bbls H2O followed by 100 bbls 12.5 ppg extended cement followed by 3 bbls H2O. Switch to rig pumps and displace cement with 49 bbls 9.2 ppg LSND mud @ 6 bpm, 670 psi maximum pressure. CIP @ 13:26 hr. Reciprocated pipe during entire cement job. No sticky problems. 13:30 - 14:00 0.50 CEMT P ARAN POH from 7,042' to 6,006', 40 fpm. PU - 120k. SO - 80k. No problems. 14:00 - 15:30 1.50 CEMT P ABAN Circulate 2 X bottoms up @ 550 gpm, 1,285 psi, 40 rpm, 2k TO, PU 100k, SO - 75k, ROT - 88k. Retumed appx. 15 bbls cement. Held PJSM while circulating. 15:30 - 16:30 1.00 CEMT P ABAN P&A plug #4. Rig up circulating head. Switch to Dowell and pump 5 bbls H2O. Test lines to 3,500 psi - OK. Pump remaining 15 bbls H2O followed by 100 bbls 12.5 ppg extended cement followed by 3 bbls H2O. Switch to rig pumps and displace cement with 39 bbls 9.2 ppg LSND mud @ 6 bpm, 530 psi maximum pressure. CIP @ 16:16 hr. Reciprocated pipe during entire cement job. No sticky problems. 16:30 - 17:00 0.50 CEMT P ABAN POH from 6,006' to 4,956', 40 fpm. PU - 105k. SO - 80k. No problems. 17:00 - 21:30 4.50 CEMT P ABAN Circulate 2 X bottoms up @ 560 gpm, 1,675 psi, 40 rpm, 1.3k TQ, PU 92k, SO - 80k, ROT - 88k. Returned appx. 15 bbls cement. Drop drillpipe wiper plug and continue to circulate while waiting on thickening time confirmation. Held PJSM while circulating. 21:30 - 22:30 1.00 CEMT P ABAN Spot 17 ppg mud spacer. Rig up circulating head. Switch to Dowell and pump 5 bbls H2O. Test lines to 3,500 psi - OK. Pump remaining 15 bbls H2O followed by 141 bbls 17.0 ppg weighted spacer followed by 3 bbls H2O. Displace cement with 21 bbls 9.2 ppg LSND mud @ 5 bpm, 450 psi maximum pressure. Reciprocated pipe during entire job. No sticky problems. 22:30 - 23:00 0.50 CEMT P ABAN POH from 4,956' to 3,426', 90 fpm. PU - 90k. SO - 80k. No problems. 23:00 - 00:00 1.00 CEMT P ABAN Circulate 2 X bottoms up @ 500 gpm, 1,285 psi, 40 rpm, .6k TQ, PU - 80k, SO - 70k, ROT - 70k. Crew change. Held PJSM while circulating. Midnight to 05:00 hr = 50 bbls. No losses after 1st P&A plug. 4/9/2006 00:00 - 00:30 0.50 CEMT P ARAN Kick-off plug. Rig up circulating head. Switch to Dowell and pump 5 bbls H2O. Test lines to 3,500 psi - OK. Pump remaining 15 bbls H2O followed by 98 bbls 15.7 ppg class "G" cement followed by 3 bbls H2O. Switch to rig pumps and displace cement with 15 bbls 9.2 ppg LSND mud @ 5 bpm, 120 psi maximum pressure. CIP @ 00:30 hr. Reciprocated pipe during entire cement job. No sticky problems. Printed: 4/21/2006 11:58:16 AM BP Page 13 of 19 Operations Summary Report Legal Well Name: I-100 Common Well Name: I-100 Spud Date: 3/20/2006 Event Name: DRILL+COMPLETE Start: 3/19/2006 End: 4/17/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/17/2006 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase. Description of Operations 4/9/2006 00:30 - 01:30 1.00 CEMT P ABAN POH from 3,426' to 2,087', 40 fpm. PU - 75k. SO - 70k. No problems. 01:30 - 02:30 1.00 CEMT P ABAN Circulate 2 X bottoms up @ 550 gpm, 520 psi, 40 rpm, .5k TO, PU 75k, SO - 70k, ROT - 72k. Returned appx. 10 bbls cement. Drop drillpipe wiper dart and circulate out of pipe @ 502 gpm, 410 psi. 02:30 - 03:00 0.50 CEMT P ABAN Blow down surface lines. POH 2 stands to tubing. 03:00 - 03:30 0.50 CEMT' P ARAN Rig up to laydown 3.5" NSCT tubing. 03:30 - 06:30 3.00 CEMT P ABAN Laydown 3.5" NSCT tubing cement stinger. 06:30 - 07:00 0.50 CEMT P ABAN Rig down tubing equipment. Clean and clear rig floor. 07:00 - 07:30 0.50 CEMT P ABAN Flush BOP stack, function all rams and annular preventers. 07:30 - 10:00 2.50 CEMT P ABAN Service topdrive, change out and test lower well control valve, change out saver sub. 10:00 - 12:00 2.00 DRILL P PROD2 PJSM. Pick up, make up BHA #6. Change ABH to 1.15 deg. RIH with drill collar stand and jar stand. 12:00 - 12:30 0.50 DRILL P PROD2 RIH with 4" HWDP from 272 to 1,007'. 12:30 - 13:00 0.50 DRILL P PROD2 Shallow hole test MWD @ 575 gpm 1,120 psi - OK. 13:00 - 13:30 0.50 DRILL P PROD2 RIH with BHA #6 on 4" drillpipe from 1,007' to 1,964'. 13:30 - 14:00 0.50 DRILL P PROD2 Wash from 1,964' to 2,325' in soft cement. 14:00 - 16:00 2.00 DRILL P PROD2 Circulate out green cement until shakers cleaned up @ 400 gpm, 780 psi, 60 rpm, 1.2k TO. 16:00 - 16:30 0.50 DRILL P PROD2 Service drawworks and crown section. 16:30 - 17:00 0.50 DRILL P PROD2 Drill firm cement from 2,325' to 2,482'. 455 gpm, 900 psi off bottom, 1,200 psi on bottom, 50 rpm, 1.2k TO off bottom, 2.1k TO on bottom, 5-10k WOB, 95k RW. 17:00 - 19:30 2.50 DRILL P PROD2 Circulate due to large amount of cement in returns. 30 rpm, 1.2k TO. Stage up pumps from 75 gpm, 100 psi to full drilling rate. 19:30 - 20:30 1.00 DRILL P PROD2 Continue drilling cement from 2,482' to 2,648'. PU - 100k, SO - 90k, RW - 95k. 470 gpm, 1,130 psi off bottom, 1,350 psi on bottom, 50 rpm, 1.6k TO off bottom, 2.3k TQ on bottom, 5-10k WOB. 20:30 - 21:15 0.75 DRILL P PROD2 Kick-off plug from 2,648' to 2,660'. 21:15 - 21:30 0.25 DRILL P PROD2 Drill Directionally from 2,660' to 2,676'. 21:30 - 22:30 1.00 DRILL P PROD2 Displace well with new 8.9 ppg LSND mud @ 470 gpm, 1,050 psi, 50 rpm, 1.5k TQ. 22:30 - 23:00 0.50 DRILL P PROD2 Pull up into shoe and perform LOT. TVD - 2,588', 8.9 ppg MW, 580 psi - EMW of 13.21 ppg. 23:00 - 23:30 0.50 DRILL P PROD2 Obtain benchmark ECD's. 9.18 ppg without rotation, 9.19 ppg rotating. 23:30 - 00:00 0.50 DRILL P PROD2 Drill Directionally from 2,660' to 2,676'. PU - 100k, SO - 90k, ROT - 95k, WOB - 10k, 555 gpm, 1,060 psi off bottom, 1,220 psi on bottom. AST - 1.00 hr. CECD - 9.18 ppg, AECD - 9.2 PPg• 4/10/2006 00:00 - 11:00 11.00 DRILL P PROD2 Directionally drill 8.75" hole from 2,695' to 4,169'. PU - 125k, SO - 100k, RW - 103k 560 gpm, 1,740 psi on bottom, 1320 psi off bottom, 100 rpm, 5k TO on bottom, 4.5k TQ off bottom. CECD - 9.26 ppg, AECD - 9.22 ppg. 11:00 - 12:00 1.00 DRILL P PROD2 Circulate weighted sweep surface to surface @ drilling rate parameters. initial AECD - 9.22 ppg, final AECD - 9.07 ppg. Returned appx 10°!° increase in cuttings back to surface. 12:00 - 21:00 9.00 DRILL P PROD2 Continue directionally drill 8.75" hole from 4,169' to 5,560. PU - 153k, SO - 107k, RW - 126k 560 gpm, 2,540 psi on bottom, Printed: 4/21 /2006 11:58:16 AM BP Page 14 of 19 Operations Summary Report Legal Well Name: I-100 Common Well Name: I-100 Spud Date: 3/20/2006 Event Name: DRILL+COMPLETE Start: 3/19/2006 End: 4/17/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/17/2006 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Gode NPT Phase Description of Operations 4/10/2006 12:00 - 21:00 9.00 DRILL P PROD2 2,005 psi off bottom, 100 rpm, 7k TO on bottom, 6k TO off bottom. CECD - 9.54 ppg, AECD - 9.54 ppg. AST - 7.58 hrs., ART - 3.77 hrs. 21:00 - 21:30 0.50 DRILL P PROD2 Circulate 35 bbl weighted sweep surface to surface for ECD's @ drilling rate parameters. Packed off with sweep in casing. 21:30 - 22:00 0.50 DRILL P PROD2 Pick up to 25k over and free pipe. Establish circulation and rotation. Stage pumps up slowly on each upstroke back to drilling rate. No mud losses. ECD's @ 9.79 ppg. 22:00 - 00:00 2.00 DRILL P PROD2 Returning large amounts of cuttings back in sweep. Circulate until clean. Pump 25 bbls weighted sweep surface to surface @ drilling rate parameters. CECD - 9.54 ppg, initial AECD - 9.79 ppg, final AECD - 9.71 ppg. Returned appx 10% increase in cuttings back to surface. 4/11/2006 00:00 - 03:30 3.50 DRILL P PROD2 Continue directionally drill 8.75" hole from 5,560' to 6,100'. PU - 169k, SO - 110k, RW - 130k, 560 gpm, 2,900 psi on bottom, 2,400 psi off bottom, 100 rpm, 7k TO on bottom, 6k TO off bottom. CECD - 9.81 ppg, AECD - 10.67 ppg. Backream each stand, reduce pump rate on down stroke. 03:30 - 04:00 0.50 DRILL P PROD2 Circulate weighted sweep surface to surface @ drilling rate and parameters. Initial AECD - 10.67 ppg, final RECD - 10.31 ppg. Returned appx 10% increase in cuttings back to surface. 04:00 - 08:30 4.50 DRILL P PROD2 Continue directionally drill 8.75" hole from 6,100' to 6,386. PU - 174k, SO - 109k, RW - 133k 560 gpm, 3,005 psi on bottom, 2,625 psi off bottom, 100 rpm, 7-8k TO on bottom, 5-6k TO off bottom. CECD - 9.91 ppg, AECD - 10.43 ppg. Backream each stand, reduce pump rate on down stroke. 08:30 - 09:30 1.00 DRILL P PROD2 Circulate bottoms up with mud pump #1 while trouble shooting mud pump #2. 296 gpm, 960 psi, 30 rpm, 7.3k TO. 09:30 - 17:00 7.50 DRILL P PROD2 Backream from 6,386' to 2,538' while working on mud pump #2. Pot on mud end cracked and leaking, replaced same. 296 gpm, 1,140 psi, 90 rpm, 6.5k TO, PU - 131 k, SO - 124k, RT - 109k. From 4,100' to 3,700', had torque increase and small amount of mud loss. . 17:00 - 19:00 2.00 DRILL P PROD2 Backream from 3,700' to 2,538' at increased rate of 545 gpm. Both pumps back online. 1,950 psi, 40 rpm, 3k TO, 105k rotating weight. CECD - 9.81 ppg, AECD - 10.0 ppg. 19:00 - 20:30 1.50 DRILL P PROD2 Circulate bottoms up at shoe. 560 gpm, 1,740 psi, 60 rpm, 1.7k TQ. PU - 110k, SO - 85k. CECD - 9.81 ppg, AECD - 9.86 PPg• 20:30 - 21:00 0.50 DRILL P PROD2 Service drawworks and topdrive. 21:00 - 22:30 1.50 DRILL P PROD2 Run in hole from 2,538' to 6,352', no problems. 22:30 - 23:30 1.00 DRILL P PROD2 Circulate bottoms up for ECD's. 560 gpm, 2,545 psi, 100 rpm, 7k TQ. Initial ECD - 9.8 ppg, final ECD - 9.45 ppg. 23:30 - 00:00 0.50 DRILL P PROD2 Wash from 6,352' to 6,386'. Directionally drill 8.75" hole from 6,386' to 6,413'. PU - 174k, SO - 109k, RW - 140k, WOB - 5k, 560 gpm, 2,680 psi on bottom, 2,580 psi off bottom, 100% sliding. CECD - 9.81 ppg, AECD - 9.71 ppg. Total drilling time for day: AST - 1.8 hrs. ART - 3.65 hrs. 4/12/2006 00:00 - 03:00 3.00 DRILL P PROD2 Directionally drill 8.75" hole from 6,413' to 6,734'. PU - 186k, SO - 118k, RW - 142k, WOB - 5-20k, 560 gpm, 3,200 psi on bottom, 2,640 psi off bottom, 100 rpm, 8-9k TO on bottom, 7k TO off bottom .CECD - 9.81 ppg, AECD - 9.82 ppg. Started 40 bbl weighted sweep @ 6,638'. Printed: 4/21 /2006 11:58:16 AM BP Page 15 of 19 Operations Summary Report Legal Well Name: I-100 Common Well Name: I-100 Spud Date: 3/20/2006 Event Name: DRILL+COMPLETE Start: 3/19/2006 End: 4/17/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/17/2006 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/12/2006 03:00 - 04:00 1.00 DRILL P PROD2 Hole packed off with sweep @ calculated strokes to shoe. Reestablish circulation by rotating and staging pumps up to drilling rate. Returned 300% over normal cuttings back to surface. Circulate until shakers clean. 04:00 - 05:30 1.50 DRILL P PROD2 Directionally drill 8.75" hole from 6,734' to 6,926'. PU - 186k, SO - 122k, RW - 143k, WOB - 5-20k, 560 gpm, 3,350 psi on bottom, 2,870 psi off bottom, 100 rpm, 8-9k TO on bottom, 7k TO off bottom . MW - 10.2 ppg, CECD - 10.6 ppg, AECD - 10.71 ppg. 05:30 - 06:30 1.00 DRILL P PROD2 Hole packed off with no sweep in hole Reestablish circulation by rotating and staging pumps up to drilling rate. Returned 10% over normal cuttings back to surface on bottoms up. Circulate until shakers clean. 06:30 - 08:00 1.50 DRILL P PROD2 Directionally drill 8.75" hole from 6,926' to 7,188'. PU - 188k, SO - 121 k, RW - 144k, WOB - 15k, 560 gpm, 3,400 psi on bottom, 2,900 psi off bottom, 100 rpm, 9k TO on bottom, 7.5k TO off bottom . MW - 10.2 ppg, CECD - 10.72 ppg, AECD - 10.85 ppg. 08:00 - 09:30 1.50 DRILL P PROD2 Hole packed off with no sweep in hole Reestablish circulation by rotating and staging pumps up to drilling rate. Returned large amount of cuttings and soccer ball size clay balls back to surface on bottoms up. Circulate until shakers clean. Increased pump rate to 585 gpm, 3650 psi. Started adding "Screen Clean" to 1 % solution. 09:30 - 19:30 10.00 DRILL P PROD2 Directionally drill 8.75" hole from 7,188' to TD @ 8,140' TMD, 6,882 TVD. PU - 211 k, SO - 125k, RW - 158k, WOB - 15k, 585 gpm, 4,060 psi on bottom, 3,760 psi off bottom, 85 rpm, 9-10k TO on bottom, 8k TO off bottom . MW - 10.2 ppg, CECD - 10.78 ppg, AECD - 11.08 ppg. Total drilling hours = AST - 1.12 hrs., ART - 8.88 hrs. No problem since adding "Screen Clean and bringing up pump rate. 19:30 - 20:30 1.00 DRILL P PROD2 Circulate 40 bbl weighted sweep surface to surface @ 588 gpm, 3,850 psi, 100 rpm, 9k TO, 155k rotating weight. CECD - 10.78 ppg, initial AECD - 11.01 ppg, final AECD - 10.88 ppg, MW - 10.2 ppg. No significant increase in cuttings returned with sweep. 20:30 - 00:00 3.50 DRILL P PROD2 Backream from 8,140' to 6,638' without problems. 585 gpm, 3,695 psi, 100 rpm, Sk TQ, 135k rotating weight. AECD - 11.24 PP9• 4/13/2006 00:00 - 06:00 6.00 DRILL P PROD2 Backream from 6,638' to 2,621' without problems. 585 gpm, 3,360 psi, 100 rpm, 6.5k TQ, 135k rotating weight. CECD - 10.74 ppg, AECD - 10.78 ppg. 06:00 - 07:00 1.00 DRILL P PROD2 Circulate bottoms up @ shoe. 585 gpm, 2175 psi, 100 rpm, 1.8k TO, PU - 90k, SO - 88k, RT - 88k. Monitor well - OK. Pump dry job. 07:00 - 08:00 1.00 DRILL P PROD2 POH from 2,621' to 272'. 08:00 - 09:30 1.50 DRILL P PROD2 PJSM. Stand back drill collars, laydown remaining BHA #6. 09:30- 10:00 0.50 DRILL P PROD2 Clear and clean rig floor. 10:00 - 11:00 1.00 EVAL P PROD2 Rig up Schlumberger wire line. 11:00 - 19:30 8.50 EVAL P PROD2 PJSM. Pick up, calibrate, and load nuclear source in logging tools. RIH with Pex/Dipole Sonic logging tools to bottom @ 8,140'. Log up from bottom to shoe @ 2,621'. POH. 19:30 - 21:00 1.50 EVAL P PROD2 Unload nuclear source. Laydown tools. Printed: 4/21/2006 11:58:16 AM gP Page 16 of 19 ,Operations Summary Report Legal Well Name: I-100 Common Well Name: I-100 Spud Date: 3/20/2006 Event Name: DRILL+COMPLETE Start: 3/19/2006 End: 4/17/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/17/2006 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/13/2006 21:00 - 22:00 1.00 EVAL C PROD2 Test fire and calibrate tools on ground. 22:00 - 22:30 0.50 EVAL C PROD2 PJSM on Sidewall Core guns, pick up same. 22:30 - 00:00 1.50 EVAL C PROD2 RIH with Sidewall Coring tools to 1,500'. 4/14/2006 00:00 - 02:30 2.50 EVAL C PROD2 Continue RIH with Sidewall coring WL tools and position tools for bottom core sample @ 7,913' and topcore sample @ 3,546'. Fire guns and POH. Extract samples, laydown tools. 02:30 - 03:00 0.50 EVAL C PROD2 Rig down Schlumberger WL. Misfire @ 4,407', no recovery @ 4,166' (empty bullet). All other cores recovered. 03:00 - 03:30 0.50 BOPSU P PROD2 Rig up to test BOPE. 03:30 - 07:30 4.00 BOPSU P PROD2 Test ROPE to 250 psi low pressure, 4,000 psi high pressure. Test annular preventer to 250 psi low pressure, 3,500 psi high pressure. Perform Accumulator test (D4). Witnessing of test waived by AOGCC rep. John Spaulding. Test witnessed by BP WSL's R. French, B. Buzby, NAD TP's R. Hunt, K. Cozby. 07:30 - 08:30 1.00 BOPSU P PROD2 Rig down BOPE test equipment. 08:30 - 09:30 1.00 EVAL P PROD2 Cut and slip drilling line 85'. Inspect drawworks brakes. 09:30 - 10:00 0.50 EVAL P PROD2 Service topdrive, crown section and drawworks. 10:00 - 11:30 1.50 EVAL P PROD2 Make up cleanout assembly BHA #7. NB STB, STB 60' up on dumb iron. Run in BHA on 4" HWDP. 11:30 - 15:00 3.50 EVAL P PROD2 Run in hole with BHA #7 on 4" drillpipe from 906' to 8,140'. No problems 15:00 - 16:30 1.50 EVAL P PROD2 Circulate 12.2 ppg weighted sweep surface to surface @ 585 gpm, 3,530 psi, 150 rpm, 8.5k TO. PU - 205k, SO - 120k, RT - 145k. No significant increase in cuttings returned with sweep. 10.2 ppg mud weight. 16:30 - 18:00 1.50 EVAL P PROD2 Monitor well - OK. POH from 8,140' to tight spot @ 7,530', pulled 25k over. Pump out from 7,530' to 7,391'. 295 gpm, 1,030 psi. PU - 205k, SO - 110k. Monitor well - OK. Pump dry job. 18:00 - 21:00 3.00 EVAL P PROD2 POH from 7,391' to BHA. No problems. 21:00 - 21:30 0.50 EVAL P PROD2 Lay down BHA #7. 21:30 - 22:00 0.50 EVAL P PROD2 Clear and clean rig floor. 22:00 - 22:30 0.50 BOPSU P RUNPRD Pull wear bushing, install test plug. 22:30 - 23:30 1.00 BOPSU P RUNPRD Change upper variable bore rams to 7" rams. 23:30 - 00:00 0.50 BOPSU P RUNPRD Test 7" ram door seals to 3,500 psi - OK. Pull test plug. 4/15/2006 00:00 - 01:30 1.50 CASE P RUNPRD Make dummy run with 7" hanger. Rig up to run 7" liner. 01;30 - 06:30 5.00 CASE P RUNPRD PJSM. Pick up, make up 7" 80' shoe track with Baker Lok. Check floats - OK. Continue RIH with total of 50 jts 7" 26# L-80 BTC casing to 2,110'. Change to TCII equipment, rig up torque-turn. BTC-M make up torque - 8,600 fUlbs, lubricated with Best-O-Life 2000 NM. 06:30 - 08:00 1.50 CASE P RUNPRD Continue RIH with 7" 26# L-80 BTC/TCII casing to shoe @ 2,621. Torque-Tum TCII connections to 10.1k ft/Ibs torque. Lubricated connections with Jet Lube Sealguard. Fill every joint, break circulation every 10 joints with casing fill up tool. 80 fpm running speed. 08:00 - 08:30 0.50 CASE P RUNPRD Circulate bottoms up. Stage pumps up to 6 bpm, 280 psi. Lost 5 bbls during circulation. 08:30 - 12:00 3.50 CASE P RUNPRD Continue RIH with 7" 26# L-80 BTC/TCII casing from 2,621' to 3,645'. Fill every joint, break circulation every 10 joints, circulate down every 15 joints for 10 minutes with casing fill up tool. 30 fpm running speed. Started losing displacement but still able to circulate with full returns. Printed: 4/21/2006 11:58:16 AM gp Page 17 of 19 - Operations Summary Report Legal Well Name: I-100 Common Well Name: I-100 Spud Date: 3/20/2006 Event Name: DRILL+COMPLETE Start: 3/19/2006 End: 4/17/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/17/2006 Rig Name: NABORS 9ES Rig Number: Date.. From - To Nours Task Code NPT Phase Description of Operations 4/15/2006 08:30 - 12:00 3.50 CASE P RUNPRD Midnight to Noon mud losses = 21 bbls 10.2 ppg LSND mud. 12:00 - 17:00 5.00 CASE P RUNPRD Continue RIH with 7" 26# L-80 BTC/TCII casing from 3,645' to 5,887'. Fill every joint, break circulation every 10 joints, circulate down every 15 joints for 10 minutes with casing fill up tool. 30 fpm running speed. Started losing displacement but still able to circulate with full returns. Last good circulation @ 5,887'. 17:00 - 20:30 3.50 CASE P RUNPRD Attempt to circulate @ 5,887' without success. POH 10 joints from 5,887' to 5,488'. Attempt circulation without success. Losing 3 bbls for every 3.5 bbls pumped and returning 10.6 - 10.7 ppg mud to surface. POH 5 joints from 5,488', to 5,288'. Attempt circulation with same results. POH from 5 joints from 5,288' to 5,091'. Attempt circulation with same results. Partial returns with 10.2 ppg back to surface. 20:30 - 00:00 3.50 CASE P RUNPRD RIH with casing from 5,091' to 6,486'. Fill every joint, circulate down every 10 joints with casing fill up tool. 30 fpm running speed. No displacement, partial returns when breaking circulation. Noon to Midnight losses = 394 bbls 10.2 ppg LSND mud. 4/16/2006 00:00 - 03:00 3.00 CASE P RUNPRD RIH with casing from 6,486' to 8,102'. Fill every joint, circulate down every 10 joints with casing fill up tool. 30 fpm running speed. No displacement, partial returns when breaking circulation. 03:00 - 03:30 0.50 CASE P RUNPRD Pick up landing joint with hanger and land casing on depth at 8,131'. Shoe @ 8,131' Tops: Float Collar @ 8,047' RA Tag @ 7,780' RA Tag @ 4,244' RA Tag @ 3,884' 110 Total 7-1/8" x 8-1/4" x 8" Rigid Centralizers run 03:30 - 08:00 4.50 CEMT P RUNPRD Pump and spot 140 bbl 10.2 ppg, 10 ppb LCM pill out of 7" shoe @ 3 bpm, 310 psi. minimal returns. Started regaining circulation when LCM pill started around shoe. Full returns at 3 bpm, increase to 4 bpm with partial returns. Held PJSM with Dowell while circulating. Reciprocated casing during entire circulation. PU - 260k, SO - 145k. Lost 327 bbls of mud from Midnight to 08:00 hr. 08:00 - 10:30 2.50 CEMT P RUNPRD Switch over to Dowell. Pump 5 bbls H2O @ 2 bpm, 172 psi, pressure test lines to 4,000 psi - OK. Pump 50 bbls 11.1 ppg MudPush @ 5 bpm, 350 psi. Drop bottom plug. Batch mix and pump 142 bbls, 798 sx, 12.0 ppg LiteCrete lead cement with 2 ppg CemNET LCM @ 4.7 bpm, 318 psi ICP, 140 psi FCP. Batch mix and pump 37 bbls, 205 sx, 15.8 ppg Class "G" cement @ 4.9 bpm, 185 psi ICP, 160 psi FCP. Shut down and wash up lines to cement head, switch over to rig pumps. Release top plug and kick out same with 10.2 ppg LSND mud @ 7.5 bpm avg for first 288 bbls, 200 psi ICP, 1,200 psi FCP, slow pump to 3 bpm for final 23 bbls for 311 bbls total with 920 Printed: 4/21/2006 11:58:16 AM BP Page 18 of 19- Operations .Summary Report Legal Well Name: I-100 Common Well Name: I-100 Spud Date: 3/20/2006 Event Name: DRILL+COMPLETE Start: 3/19/2006 End: 4/17/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/17/2006 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/16/2006 08:00 - 10:30 2.50 CEMT P RUNPRD psi ICP, 1000 psi FCP. Bump plug with 1,500 psi @ calculated displacement of 95%. CIP @ 10:00 hr. Bleed off pressure, check floats - OK. Reciprocated casing throughout cement job until) last 20 bbls when casing was set on casing head. PU - 218k, SO - 120k. Had full returns throughout cementing and displacement. 10:30 - 12:00 1.50 CEMT P RUNPRD Rig down cementing and casing running equipment. 12:00 - 12:30 0.50 BOPSU P RUNPRD Flush BOP stack and function rams. 12:30 - 13:00 0.50 WHSUR P RUNPRD Install 7" X 9 5/8" pack-off. Test same to 5,000 psi - 10 minutes - OK. 13:00 - 14:00 1.00 BOPSU P CLEAN Change top rams from 7" to 3.5" x 6" VBR's. Test door seals to 3,500 psi - OK. 14:00 - 14:30 0.50 BOPSU P CLEAN Pull test plug and install wear bushing. 14:30 - 15:00 0.50 CLEAN P CLEAN Pick up, make up 6 1!8" bit and casing scraper. 15:00 - 18:00 3.00 CLEAN P CLEAN Run in hole with bit and casing scraper to 7,993'. Wash down from 7,993' to landing collar on depth @ 8,047' 18:00 - 19:00 1.00 CLEAN P CLEAN Circulate bottoms up @ 580 gpm, 3,000 psi, 80 rpm, 6.5k TO, PU - 195k, SO - 105k, RT - 123k. 19:00 - 20:00 1.00 CLEAN P CLEAN Pressure test 7" casing to 3,500 psi - 30 min - 0 psi loss. 20:00 - 21:30 1.50 CLEAN P CLEAN Displace well from 10.2 ppg LSND mud to 9.0 ppg brine @ 345 gpm, 1,800 psi, 80 rpm, 8.8k TO, PU - 200k, SO - 105k, RT - 123k. Displace until brine returned to surface. 21:30 - 23:00 1.50 CLEAN P CLEAN Cut and slip drilling line 52' and service rig and topdrive while cleaning mud pits. 23:00 - 00:00 1.00 CLEAN P CLEAN Continue clean mud pits and surface mud equipment. Bullhead 80 bbls 10.2 ppg mud followed by 64 bbls dead crude down 7" x 9 5/8" annulus. Broke down @ 520 psi and injection rate of 2.5 bpm 400 psi. Dead crude was pumped @ 2 bpm ICP 325 psi, FCP 650 psi. 4/17/2006 00:00 - 00:30 0.50 CLEAN P CLEAN Pump 216 bbls clean filtered 9.0 ppg brine with corrosion inhibitor followed by 80 bbls untreated brine @ 247 gpm, 680 psi, 80 rpm, 10k TQ. 00:30 - 08:00 7.50 CLEAN P CLEAN POH laying down drill pipe from 8,047' to casing scraper. Lay down scraper and bit. 08:00 - 09:30 1.50 CLEAN P CLEAN Run in hole with remaining 4" drill pipe to 3,822'. 09:30 - 12:00 2.50 CLEAN P CLEAN POH laying down drill pipe from 3,822' to surface. 12:00 - 12:30 0.50 BUNCO RUNCMP Pull wear bushing, make dummy run with tubing hanger. 12:30 - 13:30 1.00 BUNCO RUNCMP Rig up to run 4.5" kill string. 13:30 - 16:00 2.50 BUNCO RUNCMP PJSM. Pick up WLEG and 96 joints of 4.5" 12.6# L-80 IBT-M R3 tubing to 3,993'. 16:00 - 17:00 1.00 BUNCO RUNCMP Make up tubing hanger and land same with WLEG @ 4,020'. PU - 82k, SO - 75k (with blocks). Lay down landing joint, install 2-way check valve and test to 1,000 psi below hanger. 17:00 - 17:30 0.50 BUNCO RUNCMP Rig down tubing running equipment and clear floor. 17:30 - 19:00 1.50 BOPSU P WHDTRE PJSM. Nipple down BOPE. 19:00 - 21:00 2.00 WHSUR P WHDTRE Nipple up tree adapter. Test adapter to hanger seal and metal to metal seal to 5,000 - 10 minutes - OK. Nipple up production tree and test same to 5,000 psi - 10 minutes - OK. 21:00 - 21:30 0.50 WHSUR P WHDTRE Rig up Drill Site Maintenance lubricator and pull 2-way-check valve. 21:30 - 22:00 0.50 WHSUR P WHDTRE Rig up Little Red Hot Oil Services for freeze protection. Pressure test lines to 3,000 psi - OK. 22:00 - 23:30 1.50 WHSUR P WHDTRE PJSM. Freeze protect well. Reverse circulate 91 bbls 90 Printed: 4/21/2006 11:58:16 AM BP Page 19 of 19 Operations Summary Report Legal Well Name: I-100 Common Well Name: 1-100 Spud Date: 3/20/2006 Event Name: DRILL+COMPLETE Start: 3/19/2006 End: 4/17/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/17/2006 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task Code -NPT Phase. Description of Operations 4/17/2006 22:00 - 23:30 1.50 WHSUR P WHDTRE degree diesel @ 3 bpm, 490 psi FCP. U-tube diesel back to tubing. SIP - 75 psi. Install BPV and test to 1,000 psi from below. 'Final pressures on well: 4.5" tubing - 75 psi 7" casing - 75 psi 9 5/8" x 7" annulus - 0 psi. 23:30 - 00:00 0.50 WHSUR P WHDTRE Secure tree, clean cellar. Release rig from operations on I-100 @ 23:59 hr. 4/17/2006 for move to L-2131. Printed: 4/21 /2006 11:58:16 AM Il . lu~ae -~s; ~, : I-100PB1 Survey Report Report Date: 5-Apr-O6 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 278.050° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure /Slot: I•Pad / I.14 TVD Reference Datum: Rotary Table Well: I-100 TVD Reference Elevation: 74.40 ft relative to MSL Borehole: I-t00PB1 Sea Bed/Ground Level Elevation: 45.90ft relative to MSL UWI/API#: 500292324570 Magnetic Declination: 24.248° Survey Name /Date: I-t00PB1 /April 5, 2006 Total Field Strength: 57576.859 nT Tort /AHD / DDI / ERD ratio: 222.173° / 9214.12 ft / 6.736 / 2.046 Magnetic Dip: 80.865° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: March 27, 2006 Location LaULong: N 7022 52.610, W i49 24 44.644 Magnetic Declination Model: BGGM 2005 Location Grid NIE Y/X: N 5989385.700 ftUS, E 572264.9801tUS North Reference: True North Grid Convergence Angle: +0.55348969° Total Corr Mag North -> True North: +24.248° Grid Scale Factor: 0.99990593 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude. Depth Section Departure ft de de ft ft ft n n ft ft de 100 ft ftUS ftUS I"{ I t U.UU U.UU U.UU -/4.4V U.VV V.UV V.UU U.VV V.UV U.VV U.VV O`J6~360./V O/LL04,y0 IV /V LL ~L.O I V VV 14y L4 44,044 GYD GC MS 100.00 0.13 113.21 25.60 100.00 -0.11 0.11 0.11 -0.04 0.10 0.13 5989385.66 572265.08 N 70 22 52.609 W 149 24 44.641 200.00 0.17 118.15 125.60 200.00 -0.36 0.38 0.37 -0.16 0.34 0.04 5989385.54 572265.32 N 70 22 52.608 W 149 24 44.634 300.00 0.20 109.87 225.60 300.00 -0.67 0.70 0.70 -0.29 0.63 0.04 5989385.42 572265.62 N 70 22 52.607 W 149 24 44.625 400.00 0.16 90.69 325.60 400.00 -0.98 1.01 1.00 -0.35 0.94 0.07 5989385.36 572265.92 N 70 22 52.606 W 149 24 44.616 Last GYD GC MS 500.00 0.25 111.79 425.60 500.00 -1.33 1.36 1.35 -0.43 1.28 0.12 5989385.28 572266.26 N 70 22 52.606 W 149 24 44.606 MW D+IFR+MS 572,53 0.38 115.03 498.13 572.53 -1.71 1.76 1.75 -0.59 1.65 0.18 5989385.12 572266.63 N 70 22 52.604 W 149 24 44.596 667.04 0.65 108.89 592.63 667.03 -2.54 2.61 2.60 -0.90 2.44 0.29 5989384.82 572267.42 N 70 22 52.601 W 149 24 44.573 759.14 0.62 33.11 684.73 759.13 -3.26 3.49 3.27. -0.65 3.20 0.85 5989385.08 572268.19 N 70 22 52.603 W 149 24 44.550 850.49 2.20 11.95 776.05 850.45 -3.59 5.72 4.11 1.48 3.84 1.79 5989387.22 572268.80 N 70 22 52.624 W 149 24 44.532 944.40 4.61 0.27 869.79 944.19 -3.20 11.28 8.19 7.02 4.23 2.66 5989392.76 572269.14 N 70 22 52.679 W 149 24 0 1039.97 5.11 1.96 965.01 1039.41 -223 19.38 15.74 15.11 4.39 0.54 5989400.85 572269.22 N 70 22 52.758 W 149 24 1129.57 6.18 359.87 1054.18 1128.58 -1.12 28.19 24.34 23.92 4.52 1.22 5989409.66 572269.26 N 70 22 52.845 W 149 24 2 1222.82 6.93 357.23 1146.82 1221.22 0.65 38.83 34.82 34.56 423 0.87 5989420.30 572268.88 N 70 22 52.950 W 149 24 44.520 1314.94 10.08 0.41 1237.91 1312.31 2.76 52.45 48.34 48.18 4.02 3.46 5989433.91 572268.54 N 70 22 53.084 W 149 24 44.526 1408.68 10.50 0.33 1330.15 1404.55 5.00 69.20 65.05 64.92 4.13 0.45 5989450.65 572268.48 N 70 22 53.248 W 149 24 44.523 1501.63 12.19 357.06 1421.28 1495.68 8.01 87.47 83.27 83.19 3.68 1.94 5989468.92 572267.85 N 70 22 53.428 W 149 24 44.536 1594.72 13.10 357.06 1512.11 1586.51 11.90 107.85 103.58 103.54 2.63 0.98 5989489.25 572266.61 N 70 22 53.628 W 149 24 44.567 1689.15 13.60 358.16 1603.99 1678.39 15.84 129.66 125.34 125.33 1.72 0.59 5989511.03 572265.49 N 70 22 53.842 W 149 24 44.593 1782.64 15.02 346.51 1694.59 1768.99 22.18 152.69 148.11 148.10 -1.46 3.43 5989533.76 572262.09 N 70 22 54.066 W 149 24 44.687 1875.46 15.18 332.92 1784.24 1858.64 33.59 176.76 170.90 170.62 -9.80 3.81 5989556.20 572253.54 N 70 22 54.288 W 149 24 44.931 1970.14 14.87 329.62 1875.68 1950.08 48.28 201.30 193.35 192.14 -21.58 0.96 5989577.60 572241.54 N 70 22 54.500 W 149 24 45.276 2061.54 14.09 323.66 1964.18 2038.58 63.35 224.14 213.96 211.22 -34.11 1.84 5989596.56 572228.84 N 70 22 54.687 W 149 24 45.642 SurveyEditor Ver SP 1.0 Bld( doc40x_56) I-14\I-100\I-100P61\I-100PB1 Generated 5/11/2006 1:18 PM Page 1 of 5 Comments Measured Inclination Azimuth SulrSea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude longitude Depth Section Departure ft de de ft n n n n n n de 00 ft nUS ftUS L15:1./4 15.Ll ;114.54 LUS;i.;1y 'Ll'L/./`J t1U. y:i 'L4 /.41 L34.VL L'Lt1./5 -4y.;itS 'L./t5 5`Jtlybl:l.y4 5/LL1:i.4U IV /U LL 54.i1t)U VY 14y L4417.U23`J 2247.57 14.54 303.62 2144.10 2218.50 101.45 271.43 253.20 243.91 -67.97 3.07 5989628.91 572194.67 N 70 22 55.009 W 149 24 46.633 2340.81 13.54 286.45 2234.59 2308.99 122.82 293.89 268.38 253.48 -88.19 4.58 5989638.29 572174.35 N 70 22 55.103 W 149 24 47.225 2435.22 13.51 277.44 2326.39 2400.79 144.78 315.92 280.40 258.04 -109.73 2.23 5989642.64 572152.78 N 70 22 55.148 W 149 24 47.856 2528.21 13.41 279.99 2416.83 2491.23 166.42 337.57 292.37 261.32 -131.12 0.65 5989645.71 572131.36 N 70 22 55.180 W 149 24 48.482 2562.98 13.45 279.39 2450.65 2525.05 174.49 345.64 297.22 262.68 -139.08 0.42 5989646.99 572123.39 N 70 22 55.193 W 149 24 48.715 2655.90 16.01 277.52 2540.51 2614.91 198.11 369.26 311.78 266.12 -162.45 2.80 5989650.21 572099.99 N 70 22 55.227 W 149 24 49.399 2690.82 18.34 274.45 2573.87 2648.27 208.41 379.57 318.13 267.17 -172.70 7.16 5989651.17 572089.72 N 70 22 55.237 W 149 24 49.699 2723.43 20.71 271.25 2604.60 2679.00 219.26 390.47 324.60 267.70 -183.58 7.97 5989651.59 572078.84 N 70 22 55.243 W 149 24 50.017 2753.89 23.01 268.83 2632.87 2707.27 230.49 401.81 331.14 267.69 -194.92 8.11 5989651.47 572067.50 N 70 22 55.243 W 149 24 50.349 2786.64 25.52 266.81 2662.73 2737.13 243.73 415.26 338.82 267.17 -208.37 8.07 5989650.82 572054.06 N 70 22 55.237 W 149 24 2818.05 28.04 266.04 2690.76 2765.16 257.59 429.42 347.00 266.28 -222.49 8.10 5989649.80 572039.95 N 70 22 55.229 W 149 24 2849.33 30.50 265.93 2718.05 2792.45 272.54 444.71 356.17 265.21 -237.74 7.87 5989648.58 572024.71 N 70 22 55.218 W 149 24 51.603 2882.13 33.28 266.13 2745.90 2820.30 289.49 462.03 367.07 264.01 -255.03 8.48 5989647.21 572007.44 N 70 22 55.206 W 149 24 52.109 2914.21 35.98 265.91 2772.29 2846.69 307.31 480.26 379.05 262.75 -273.21 8.43 5989645.77 571989.27 N 70 22 55.194 W 149 24 52.641 2946.48 38.89 266.17 2797.91 2872.31 326.50 499.88 392.49 261.39 -292.78 9.03 5989644.23 571969.72 N 70 22 55.181 W 149 24 53.214 2978.08 41.94 266.56 2821.97 2896.37 346.56 520.36 407.14 260.10 -313.22 9.68 5989642.73 571949.29 N 70 22 55.168 W 149 24 53.812 3010.64 44.64 268.41 2845.67 2920.07 368.50 542.68 423.94 259.13 -335.52 9.16 5989641.55 571927.00 N 70 22 55.158 W 149 24 54.465 3042.37 46.64 269.25 2867.85 2942.25 390.90 565.37 441.83 258.67 -358.20 6.58 5989640.87 571904.33 N 70 22 55.154 W 149 24 55.128 3073.90 49.24 269.90 2888.97 2963.37 414.05 588.77 460.92 258.50 -381.61 8.39 5989640.47 571880.93 N 70 22 55.152 W 149 24 55.814 3105.75 52.18 270.35 2909.14 2983.54 438.46 613.42 481.55 258.55 -406.26 9.30 5989640.29 571856.28 N 70 22 55.153 W 149 24 56.535 3137.56 54.92 271.44 2928.03 3002.43 463.85 639.01 503.53 258.96 -431.84 9.04 5989640.45 571830.70 N 70 22 55.157 W 149 24 57.284 3168.91 57.65 272.60 2945.43 3019.83 489.78 665.08 526.50 259.88 -457.90 9.24 5989641.12 571804.64 N 70 22 55.166 W 149 24 58.046 3200.60 60.39 273.31 2961.74 3036.14 516.84 692.25 550.92 261.28 -485.03 8.86 5989642.26 571777.50 N 70 22 55.179 W 149 24 58.841 3233.26 62.93 273.53 2977.25 3051.65 545.49 720.99 577.13 263.00 -513.72 7.80 5989643.70 571748.80 N 70 22 55.196 W 149 24 59.680 3264.72 65.44 273.12 2990.95 3065.35 573.71 749.31 603.15 264.64 -541.99 8.06 5989645.07 571720.51 N 70 22 55.212 W 149 25 0.508 3296.82 68.35 272.56 3003.54 3077.94 603.11 778.83 630.39 266.10 -571.47 9.21 5989646.24 571691.02 N 70 22 55.227 W 149 25 1.37t 3328.86 71.47 271.97 3014.55 3088.95 633.04 808.92 658.25 267.29 -601.54 9.89 5989647.14 571660.95 N 70 22 55.238 W 149 25 2.251 3360.38 74.45 272.00 3023.78 3098.18 663.00 839.05 686.28 268.33 -631.65 9.45 5989647.89 571630.83 N 70 22 55.249 W 149 2 3392.06 77.08 272.32 3031.57 3105.97 693.55 869.76 715.06 269.49 -662.33 8.36 5989648.75 571600.14 N 70 22 55.260 W 149 2 ~ 3424.86 77.83 274.20 3038.70 3113.10 725.45 901.77 745.43 271.31 -694.30 6.04 5989650.26 571568.16 N 70 22 55.278 W 149 25 4.966 3442.67 77.51 275.16 3042.50 3116.90 742.82 919.17 762.11 272.73 -711.64 5.56 5989651.52 571550.81 N 70 22 55.292 W 149 25 5.474 3537.91 77.75 275.40 3062.90 3137.30 835.74 1012.20 852.04 281.29 -804.27 0.35 5989659.18 571458.10 N 70 22 55.376 W 149 25 8.185 3632.33 77.34 275.05 3083.27 3157.67 927.82 1104.40 941.75 289.69 -896.09 0.57 5989666.69 571366.22 N 70 22 55.458 W 149 25 10.872 3728.28 75.49 276.46 3105.80 3180.20 1021.01 1197.66 1033.10 299.03 -988.88 2.40 5989675.14 571273.36 N 70 22 55.550 W 149 25 13.588 3823.73 72.60 277.35 3132.04 3206.44 1112.75 1289.42 1123.60 310.06 -1079.97 3.16 5989685.28 571182.17 N 70 22 55.658 W 149 25 16.255 3918.46 70.14 278.78 3162.30 3236.70 1202.51 1379.18 1212.56 322.64 -1168.84 2.96 5989697.01 571093.19 N 70 22 55.782 W 149 25 18.856 4014.09 71.41 277.85 3193.79 3268.19 1292.80 1469.48 1302.20 335.70 -1258.19 1.61 5989709.20 571003.73 N 70 22 55.910 W 149 25 21.471 411021 74.59 279.79 3221.89 3296.29 1384.70 1561.38 1393.62 349.80 -1349.00 3.83 5989722.42 570912.79 N 70 22 56.049 W 149 25 24.130 4206.22 77.21 281.15 3245.28 3319.68 1477.72 1654.49 1486.51 366.73 -1440.56 3.06 5989738.46 570821.08 N 70 22 56.215 W 149 25 26.809 SurveyEditor Ver SP 1.0 Bld( doc40x_56) I-14\I-100\I-100P61\I-t00P61 Generated 5/11/2006 1:18 PM Page 2 of 5 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure n de de n n n n n n n de o0 ft ftUS nUS 4302.12 76.68 280.23 3266.94 3341.34 1511.04 1747.91 1519./5 384.06 -1532.36 7.05 5989/54.90 5/0/29.13 N /U 22 511.385 W 149 25 "L9.49/ 4398.15 76.76 280.41 3289.00 3363.40 1664.43 1841.38 1673.03 400.80 -1624.31 0.20 5989770.76 570637.03 N 70 22 56.550 W 149 25 32.188 4493.31 77.23 279.50 3310.42 3384.82 1757.10 1934.09 1765.54 416.83 -1715.63 1.05 5989785.90 570545.57 N 70 22 56.707 W 149 25 34.861 4592.61 77.23 277.96 3332.37 3406.77 1853.93 2030.94 1862.04 431.53 -1811.35 1.51 5989799.67 570449.72 N 70 22 56.852 W 149 25 37.663 4686.18 77.01 277.27 3353.22 3427.62 1945.14 2122.15 1952.81 443.62 -1901.76 0.76 5989810.88 570359.21 N 70 22 56.970 W 149 25 40.310 4779.57 76.93 275.14 3374.28 3448.68 2036.07 2213.14 2043.16 453.45 -1992.21 2.22 5989819.84 570268.68 N 70 22 57.067 W 149 25 42.957 4873.28 77.00 273.35 3395.42 3469.82 2127.16 2304.43 2133.47 460.21 -2083.25 1.86 5989825.72 570177.59 N 70 22 57.133 W 149 25 45.622 4966.10 76.48 272.06 3416.71 3491.11 2217.11 2394.78 2222.56 464.47 -2173.49 1.46 5989829.11 570087.32 N 70 22 57.175 W 149 25 48.263 5060.62 75.06 271.87 3439.94 3514.34 2308.22 2486.40 2312.82 467.62 -2265.05 1.51 5989831.37 569995.73 N 70 22 57.205 W 149 25 50.944 5153.40 74.67 272.61 3464.17 3538.57 2397.32 2575.96 2401.21 471.12 -2354.54 0.88 5989834.00 569906.22 N 70 22 57.240 W 149 25 53.563 5249.09 74.75 273.05 3489.40 3563.80 2489.24 2668.26 2492.54 475.67 -2446.73 0.45 5989837.67 569814.00 N 70 22 57.284 W 149 25 5344.62 74.47 274.04 3514.76 3589.16 2581.06 2760.36 2583.90 481.37 -2538.66 1.04 5989842.48 569722.03 N 70 22 57.340 W 149 25 5440.21 74.57 275.70 3540.27 3614.67 2673.03 2852.49 2675.55 489.19 -2630.45 1.68 5989849.41 569630.18 N 70 22 57.416 W 149 26 1.639 5536.13 74.32 276.27 3565.99 3640.39 2765.38 2944.89 2767.67 498.82 -2722.35 0.63 5989858.16 569538.20 N 70 22 57.511 W 149 26 4.329 5631.92 74.60 276.33 3591.66 3666.06 2857.62 3037.18 2859.73 508.95 -2814.08 0.30 5989867.40 569446.38 N 70 22 57.610 W 149 26 7.014 5727.00 74.52 275.38 3616.97 3691.37 2949.20 3128.83 2951.12 518.30 -2905.25 0.97 5989875.86 569355.14 N 70 22 57.702 W 149 26 9.683 5823.63 75.18 274.21 3642.22 3716.62 3042.32 3222.10 3044.00 526.09 -2998.19 1.35 5989882.76 569262.13 N 70 22 57.778 W 149 26 12.404 5918.74 74.76 272.68 3666.89 3741.29 3133.88 3313.96 3135.28 531.61 -3089.88 1.62 5989887.39 569170.41 N 70 22 57.832 W 149 26 15.088 6014.78 74.75 272.40 3692.14 3766.54 3226.11 3406.62 3227.22 535.72 -3182.45 0.28 5989890.60 569077.81 N 70 22 57.872 W 149 26 17.797 6110.66 74.46 273.44 3717.60 3792.00 3318.18 3499.06 3319.06 540.43 -3274.77 1.09 5989894.42 568985.46 N 70 22 57.918 W 149 26 20.500 6205.95 73.48 272.52 3743.91 3818.31 3409.40 3590.64 3410.09 545.19 -3366.23 1.39 5989898.30 568893.97 N 70 22 57.964 W 149 26 23.177 6301.69 73.12 272.37 3771.42 3845.82 3500.67 3682.34 3501.17 549.10 -3457.84 0.40 5989901.33 568802.33 N 70 22 58.002 W 149 26 25.858 6397.79 73.90 274.43 3798.70 3873.10 3592.50 3774.49 3592.88 554.57 -3549.82 2.21 5989905.90 568710.31 N 70 22 58.056 W 149 26 28.551 6493.10 73.95 274.25 3825.09 3899.49 3683.90 3866.07 3684.18 561.50 -3641.14 0.19 5989911.95 568618.93 N 70 22 58.123 W 149 26 31.224 6588.21 74.92 274.36 3850.61 3925.01 3775.32 3957.69 3775.53 568.38 -3732.51 1.03 5989917.95 568527.52 N 70 22 58.191 W 149 26 33.898 6683.32 74.25 274.04 3875.90 3950.30 3866.80 4049.38 3866.95 575.10 -3823.95 0.78 5989923.78 568436.02 N 70 22 58.256 W 149 26 36.575 6779.23 74.84 275.61 3901.46 3975.86 3959.09 4141.82 395920 582.87 -3916.0(1 1.69 5989930.66 568343.85 N 70 22 58.332 W 149 26 39.271 6875.67 74.97 274.51 3926.57 4000.97 4052.08 4234.93 4052.15 591.08 -4008.81 1.11 5989937.98 568251.04 N 70 22 58.413 W 149 26 41.986 6971.36 74.77 275.03 3951.55 4025.95 4144.30 4327.31 4144.34 598.77 -4100.86 0.56 5989944.77 568158.92 N 70 22 58.488 W 149 26 7066.49 73.75 274.37 3977.35 4051.75 4235.70 4418.87 4235.72 606.27 -4192.11 1.26 5989951.39 568067.61 N 70 22 58.561 W 149 26 7162.24 74.80 275.24 4003.30 4077.70 4327.72 4511.03 4327.73 613.99 -4283.95 1.40 5989958.22 567975.71 N 70 22 58.636 W 149 26 50.041 7257.89 74.44 274.43 4028.67 4103.07 4419.80 4603.26 4419.80 621.77 -4375.85 0.90 5989965.11 567883.75 N 70 22 58.712 W 149 26 52.731 7353.29 74.61 276.65 4054.13 4128.53 4511.65 4695.20 4511.65 630.64 -4467.35 2.25 5989973.10 567792.17 N 70 22 58.799 W 149 26 55.409 7448.23 75.54 277.05 4078.58 4152.98 4603.36 4786.93 4603.36 641.58 -4558.43 1.06 5989983.16 567701.00 N 70 22 58.906 W 149 26 58.075 7543.08 75.24 275.49 4102.51 4176.91 4695.10 4878.72 4695.10 651.61 -4649.66 1.62 5989992.30 567609.69 N 70 22 59.004 W 149 27 0.746 7636.82 74.15 274.81 4127.25 4201.65 4785.39 4969.13 4785.41 659.73 -4739.71 1.36 5989999.55 567519.57 N 70 22 59.083 W 149 27 3.382 7731.45 73.52 273.25 4153.60 4228.00 4876.06 5060.02 4876.09 666.11 -4830.37 1.72 5990005.06 567428.86 N 70 22 59.146 W 149 27 6.036 7824.44 73.61 272.83 4179.91 4254.31 4964.91 5 i 49.21 4964.97 670.84 -4919.44 0.44 5990008.93 567339.77 N 70 22 59.192 W 149 27 8.643 7917.59 72.89 272.01 4206.75 4281.15 5053.67 5238.40 5053.78 674.61 -5008.55 1.14 5990011.84 567250.62 N 70 22 59.228 W 149 2711.252 8011.46 71.81 270.63 4235.22 4309.62 5142.50 5327.85 5142.69 676.68 -5097.98 1.81 5990013.04 567161.19 N 70 22 59.248 W 149 27 13.869 SurveyEditor Ver SP 1.0 Bld( doc40x_56) I-14\I-100\I-100PB1\I-100P61 Generated 5/11/2006 1:18 PM Page 3 of 5 Comments Measured Inclination Azimuth SulrSea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 00 ft ftUS ftUS 731U:i.1Ei /1.U7 1/1.UU 41tii./1 433tf.11 5115.U/ 5415.11 51'15.:iEi (i//.51 -bltSb.l:i U.44 b55UUl;i.44 5ti/U/:i.54 N /U 1155."155 W 145 L/ lti.413 8196.91 72.27 270.68 4292.44 4366.84 5317.50 5504.25 5317.91 679.22 -5274.36 0.43 5990013.88 566984.81 N 70 22 59.272 W 149 27 19.032 8290.67 73.10 273.85 4320.35 4394.75 5406.54 5593.76 5407.07 682.77 -5363.78 3.35 5990016.56 566895.37 N 70 22 59.306 W 149 27 21.650 8384.76 72.05 277.95 4348.54 4422.94 5496.23 5683.53 5496.79 691.98 -5453.06 4.30 5990024.91 566806.02 N 70 22 59.396 W 149 27 24.263 8476.66 72.83 279.87 4376.27 4450.67 5583.83 5771.15 5584.36 705.56 -5539.61 2.17 5990037.65 566719.34 N 70 22 59.529 W 149 27 26.797 8570.55 77.44 279.04 4400.35 4474.75 5674.53 5861.87 5675.02 720.45 -5629.10 4.98 5990051.68 566629.72 N 70 22 59.675 W 149 27 29.417 8663.47 81.96 278.33 4416.96 4491.36 5765.92 5953.27 5766.39 734.25 -5719.45 4.92 5990064.60 566539.25 N 70 22 59.810 W 149 27 32.062 8755.98 86.10 277.85 4426.58 4500.98 5857.91 6045.26 5858.37 747.19 -5810.53 4.50 5990076.66 566448.06 N 70 22 59.936 W 149 27 34.728 8849.29 90.64 277.02 4429.23 4503.63 5951.15 6138.50 5951.62 759.26 -5902.99 4.95 5990087.83 566355.50 N 70 23 0.054 W 149 27 37.435 8942.69 94.71 276.77 4424.87 4499.27 6044.41 6231.78 6044.90 770.46 -5995.59 4.37 5990098.13 566262.80 N 70 23 0.164 W 149 27 40.146 9036.83 98.18 275.71 4414.31 4488.71 6137.89 6325.31 6138.41 780.63 -6088.57 3.85 5990107.40 566169.74 N 70 23 0.263 W 149 27 9129.42 101.80 276.51 4398.25 4472.65 6229.01 6416.48 6229.56 790.33 -6179.22 4.00 5990116.23 566079.01 N 70 23 0.357 W 149 27 9222.67 101.86 276.49 4379.13 4453.53 6320.24 6507.75 6320.82 800.66 -6269.90 0.07 5990125.68 565988.24 N 70 23 0.458 W 149 27 48.176 9316.29 102.09 276.75 4359.71 4434.11 6411.80 6599.34 6412.40 811.22 -6360.88 0.37 5990135.36 565897.18 N 70 23 0.561 W 149 27 50.840 9408.46 101.60 276.54 4340.79 4415.19 6501.98 6689.54 6502.60 821.65 -6450.48 0.58 5990144.93 565807.49 N 70 23 0.663 W 149 27 53.463 9500.10 101.18 277.37 4322.69 4397.09 6591.80 6779.38 6592.43 832.53 -6539.65 1.00 5990154.95 565718.22 N 70 23 0.770 W 149 27 56.073 9592.46 101.19 277.24 4304.77 4379.17 6682.39 6869.98 6683.04 844.05 -6629.52 0.14 5990165.60 565628.25 N 70 23 0.882 W 149 27 58.704 9684.00 101.25 277.52 4286.96 4361.36 6772.18 6959.77 6772.83 855.59 -6718.57 0.31 5990176.27 565539.11 N 70 23 0.995 W 149 28 1.311 9775.83 101.37 277.89 4268.95 4343.35 6862.22 7049.82 6862.87 867.66 -6807.80 0.42 5990187.48 565449.77 N 70 23 1.113 W 149 28 3.923 9867.67 101.33 278.28 4250.88 4325.28 6952.27 7139.86 6952.90 880.32 -6896.95 0.42 5990199.28 565360.51 N 70 23 1.236 W 149 28 6.533 9959.37 101.38 278.56 4232.82 4307.22 7042.17 7229.77 7042.79 893.49 -6985.89 0.30 5990211.58 565271.46 N 70 23 1.365 W 149 28 9.137 10051.58 101.18 278.97 4214.79 4289.19 7132.59 732020 7133.19 907.27 -7075.26 0.49 5990224.50 565181.97 N 70 23 1.500 W 149 28 11.754 10146.36 10128 279.48 4196.33 4270.73 7225.54 7413.16 7226.10 922.17 -7167.02 0.54 5990238.51 565090.07 N 70 23 1.646 W 149 28 14.440 10239.57 101.28 279.43 4178.10 4252.50 7316.92 7504.57 7317.45 937.19 -7257.19 0.05 5990252.66 564999.77 N 70 23 1.792 W 149 28 17.080 10332.59 101.43 279.71 4159.78 4234.18 7408.09 7595.77 7408.58 952.35 -7347.12 0.34 5990266.95 564909.71 N 70 23 1.941 W 149 28 19.713 10426.19 101.46 279.98 4141.21 4215.61 7499.78 7687.51 7500.24 968.04 -7437.51 0.28 5990281.76 564819.18 N 70 23 2.094 W 149 28 22.359 10519.35 101.19 280.18 4122.92 4197.32 7591.07 7778.86 7591.49 984.02 -7527.44 0.36 5990296.87 564729.11 N 70 23 2.250 W 149 28 24.992 10612.67 101.08 280.69 4104.89 4179.29 7682.55 7870.42 7682.93 1000.61 -7617.49 0.55 5990312.59 564638.91 N 70 23 2.413 W 149 28 27.629 10705.56 101.15 281.23 4086.99 4161.39 7773.58 7961.57 7773.91 1017.94 -7706.98 0.58 5990329.05 564549.27 N 70 23 2.582 W 149 28 10798.26 101.56 281.63 4068.73 4143.13 7864.31 8052.45 7864.59 1035.95 -7796.06 0.61 5990346.20 564460.03 N 70 23 2.758 W 149 28 10892.16 101.12 281.97 4050.27 4124.67 7956.18 8144.52 7956.40 1054.77 -7886.18 0.59 5990364.15 564369.74 N 70 23 2.943 W 149 28 35.496 10985.52 101.16 281.37 4032.23 4106.63 8047.60 8236.12 8047.78 1073.30 -7975.89 0.63 5990381.81 564279.87 N 70 23 3.124 W 149 28 38.122 11078.73 101.11 280.20 4014.23 4088.63 8138.95 8327.58 8139.10 1090.42 -8065.72 1.23 5990398.05 564189.87 N 70 23 3.291 W 149 28 40.753 11172.41 101.08 279.49 3996.20 4070.60 8230.83 8419.50 8230.96 1106.13 -8156.30 0.74 5990412.89 564099.16 N 70 23 3.445 W 149 28 43.405 11265.04 101.88 279.34 3977.77 4052.17 8321.58 8510.28 8321.70 1120.98 -8245.85 0.88 5990426.88 564009.48 N 70 23 3.590 W 149 28 46.027 11357.20 101.78 279.70 3958.87 4033.27 8411.75 8600.48 8411.86 1135.90 -8334.81 0.40 5990440.93 563920.39 N 70 23 3.736 W 149 28 48.631 11450.02 101.60 279.84 3940.07 4014.47 8502.60 8691.38 8502.70 1151.33 -8424.39 0.24 5990455.49 563830.67 N 70 23 3.886 W 149 28 51.254 11543.13 101.67 280.36 3921.29 3995.69 8593.74 8782.57 8593.82 1167.32 -8514.17 0.55 5990470.61 563740.75 N 70 23 4.043 W 149 28 53.883 11637.30 101.14 280.56 3902.67 3977.07 8685.97 8874.88 8686.03 1184.08 -8604.95 0.60 5990486.49 563649.82 N 70 23 4.206 W 149 28 56.541 11731.72 100.24 281.38 3885.15 3959.55 8778.63 8967.67 8778.67 1201.73 -8696.03 1.28 5990503.27 563558.58 N 70 23 4.379 W 149 28 59.208 SurveyEditor Ver SP 1.0 Bld( doc40x_56) I-14\I-100\I-100P61\I-100P61 Generated 5/11/2006 1:18 PM Page 4 of 5 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 00 ft ftUS ftUS 11t5L4.4U yy.L1 L2fL.VG 3i5by.4y 3y4:3.t5y t5t5t7`J./y yVby.Ul ifiSby.tfC lL'N.Yb -i5/i5b.425 l.Ly byyVS[V.y[ Last MWD+IFR+MS 11917.03 100.60 282.87 3853.55 3927.95 8960.77 9150.26 8960.78 1239.92 -8874.58 1.74 5990539.72 TD (Projected) 11982.00 100.60 282.87 3841.60 3916.00 9024.40 9214.12 9024.41 1254.15 -8936.84 0.00 5990553.34 Survey Type: Definitive Survey NOTES: GYD-GC-MS - (Gyrodata -gyro compassing m/s -- Older Gyrodata gyro multishots-plus all battery/memory tool surveys (RGS-BT). Replaces ex-BP "Gyrodata multishot into open hole" model. Not to be run above 70 degrees inclination.. ) MWD + IFR + MS - (In-field referenced MWD with mutt-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 3217 FSL 3945 FEL S20 T12N R11 E UM 5989385.70 572264.98 BHL : 4466 FSL 2777 FEL S24 T12N R10E UM 5990553.34 563317.30 5b:i4b75. `J/ IV /U L3 4.bbU VV 14`J C`J I.2SL/ 563379.69 N 70 23 4.753 W 149 29 4.436 563317.30 N 70 23 4.892 W 149 29 6.259 • SurveyEditor Ver SP 1.0 Bld( doc40x_56) I-14\I-100\I-100P61\I-100P61 Generated 5/11/2006 1:18 PM Page 5 of 5 tt ~ Schl~mber e ,,~ , _~ 1- rv 1 u e 00 S Y R rt o e p Report Date: 13-Apr-06 Survey /DLS Computation Method: Minimum Curvature! Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 278.050° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure /Slot: I-Pad / I-14 ND Reference Datum: Rotary Tabfe Well: I-100 ND Reference Elevation: 74.40 ft relative to MSL Borehole: I-100 Sea Bed /Ground Level Elevation: 45.90 ft relative to MSL UWIIAPI#: 500292324500 Magnetic Declination: 24.233° Survey Name /Date: I-100 /April 13, 2006 Total Field Strength: 57576.949 nT Tort /AHD / DDI / ERD ratio: 116.507° / 3655.15 ft / 5.702 / 0.531 Magnetic Dip: 80.865° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: April 11, 2006 Location LaUlong: N 70 22 52.610, W 149 2444.644 Magnetic Declination Model: BGGM 2005 Location Grid NIE Y/X: N 5989385.700 ftUS, E 572264.980 itUS North Reference: True North Grid Convergence Angle: +0.55348969° Total Corr Mag North -> True North: +24.233° Grid Scale Factor: 0.99990593 Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure it de de n n n ft n n n de 00 n ftUS nUS N I t U.UU U.UU U.UU -/4.4U U.UU U.UU U.UV U.UU U.VV V.UU V.VV b`Jt5`JJtSb./V 5/ZYb4.`JO IV / V ZZ bL.b I V VV 14`J Z4 44.b44 GYD CT DMS 100.00 0.13 113.21 25.60 100.00 -0.11 0.11 0.11 -0.04 0.10 0.13 5989385.66 572265.08 N 70 22 52.609 W 149 24 44.641 200.00 0.17 118.15 125.60 200.00 -0.36 0.38 0.37 -0.16 0.34 0.04 5989385.54 572265.32 N 70 22 52.608 W 149 24 44.634 300.00 0.20 109.87 225.60 300.00 -0.67 0.70 0.70 -0.29 0.63 0.04 5989385.42 572265.62 N 70 22 52.607 W 149 24 44.625 400.00 0.16 90.69 325.60 400.00 -0.98 1.01 1.00 -0.35 0.94 0.07 5989385.36 572265.92 N 70 22 52.606 W 149 24 44.616 MW D+IFR+MS 500.00 0.25 111.79 425.60 500.00 -1.33 1.36 1.35 -0.43 1.28 0.12 5989385.28 572266.26 N 70 22 52.606 W 149 24 44.606 572.53 0.38 115.03 498.13 572.53 -1.71 1.76 1.75 -0.59 1.65 0.18 5989385.12 572266.63 N 70 22 52.604 W 149 24 44.596 667.04 0.65 108.89 592.63 667.03 -2.54 2.61 2.60 -0.90 2.44 0.29 5989384.82 572267.42 N 70 22 52.601 W 149 24 44.573 759.14 0.62 33.11 684.73 759.13 -3.26 3.49 3.27 -0.65 3.20 0.85 5989385.08 572268.19 N 70 22 52.603 W 149 24 44.550 850.49 2.20 11.95 776.05 850.45 -3.59 5.72 4.11 1.48 3.84 1.79 5989387:22 572268.80 N 70 22 52.624 W 149 24 44.532 944.40 4.61 0.27 869.79 944.19 -3.20 11.28 8.19 7.02 4.23 2.66 5989392.76 572269.14 N 70 22 52.679 W 149 24 0 1039.97 5.11 1.96 965.01 1039.41 -2.23 19.38 15.74 15.11 4.39 0.54 5989400.85 572269.22 N 70 22 52.758 W 149 24 1129.57 6.18 359.87 1054.18 1128.58 -1.12 28.19 .24.34 23.92 4.52 1.22 5989409.66 572269.26 N 70 22 52.845 W 149 24 2 1222.82 6.93 357.23 1146.82 1221.22 0.65 38.83 34.82 34.56 4.23 0.87 5989420.30 572268.88 N 70 22 52.950 W 149 24 44.520 1314.94 10.08 0.41 1237.91 1312.31 2.76 52.45 48.34 48.18 4.02 3.46 5989433.91 572268.54 N 70 22 53.084 W 149 24 44.526 1408.68 10.50 0.33 1330.15 1404.55 5.00 69.20 65.05 64.92 4.13 0.45 5989450.65 572268.48 N 70 22 53.248 W 149 24 44.523 1501.63 12.19 357.06 1421.28 1495.68 8.01 87.47 83.27 83.19 3.68 1.94 5989468.92 572267.85 N 70 22 53.428 W 149 24 44.536 1594.72 13.10 357.06 1512.11 1586.51 11.90 107.85 103.58 103.54 2.63 0.98 5989489.25 572266.61 N 70 22 53.628 W 149 24 44.567 1689.15 13.60 358.16 1603.99 1678.39 15.84 129.66 125.34 125.33 1.72 0.59 5989511.03 572265.49 N 70 22 53.842 W 149 24 44.593 1782.64 15.02 346.51 1694.59 1768.99 22.18 152.69 148.11 148.10 -1.46 3.43 5989533.76 572262.09 N 70 22 54.066 W 149 24 44.687 1875.46 15.18 332.92 1784.24 1858.64 33.59 176.76 170.90 170.62 -9.80 3.81 5989556.20 572253.54 N 70 22 54.288 W 149 24 44.931 1970.14 14.87 329.62 1875.68 1950.08 48.28 201.30 193.35 192.14 -21.58 0.96 5989577.60 572241.54 N 70 22 54.500 W 149 24 45.276 2061.54 14.09 323.66 1964.18 2038.58 63.35 224.14 213.96 211.22 -34.11 1.84 5989596.56 572228.84 N 70 22 54.687 W 149 24 45.642 SurveyEditor Ver SP 1.0 Bld( doc40x_56) I-14\I-100\I-100\I-100 Generated 5/11/2006 1:18 PM Page 1 of 3 Comments Measured Inclination Azimuth SulrSea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 00 ft ftUS ftUS 2153.74 15.21 314.54 L053.39 2127.79 80.93 247.41 Z34.UZ 228.75 -49.38 L. /8 5989613.94 5/LL13.4U N 7U 22 54.860 W 149 24 48.089 2247.57 14.54 303.62 2144.10 2218.50 101.45 271.43 253.20 243.91 -67.97 3.07 5989628.91 572194.67 N 70 22 55.009 W 149 24 46.633 2340.81 13.54 286.45 2234.59 2308.99 122.82 293.89 268.38 253.48 -88.19 4.58 5989638.29 572174.35 N 70 22 55.103 W 149 24 47.225 2435.22 13.51 277.44 2326.39 2400.79 144.78 315.92 280.40 258.04 -109.73 2.23 5989642.64 572152.78 N 70 22 55.148 W 149 24 47.856 Tie-In Survey 2528.21 13.41 279.99 2416.83 2491.23 166.42 337.57 292.37 261.32 -131.12 0.65 5989645.71 572131.36 N 70 22 55.180 W 149 24 48.482 MW D+IFR+MS 2655.93 12.90 280.17 2541.20 2615.60 195.47 366.63 310.62 266.40 -159.74 0.40 5989650.52 572102.69 N 70 22 55.230 W 149 24 49.319 2758.00 10.30 296.86 2641.20 2715.60 215.50 387.02 326.12 272.54 -179.10 4.13 5989656.47 572083.27 N 70 22 55.290 W 149 24 49.886 2853.76 8.37 310.51 2735.70 2810.10 229.49 402.48 340.30 280.94 -192.04 3.05 5989664.74 572070.25 N 70 22 55.373 W 149 24 50.265 2949.74 9.22 328.02 2830.57 2904.97 240.33 417.04 354.73 292.00 -201.42 2.91 5989675.71 572060.76 N 70 22 55.482 W 149 24 50.540 3045.11 10.67 348.82 2924.53 2998.93 248.16 433.34 370.49 307.15 -207.19 4.03 5989690.80 572054.86 N 70 22 55.631 W 149 24 50.708 3140.35 12.25 358.71 3017.88 3092.28 252.70 452.22 387.23 325.90 -209.12 2.64 5989709.54 572052.74 N 70 22 55.815 W 149 24 3235.45 15.01 10.51 3110.31 3184.71 253.81 474.55 405.05 348.10 -207.10 4.11 5989731.75 572054.54 N 70 22 56.033 W 149 24 3331.42 18.35 19.31 3202.24 3276.64 250.32 502.04 424.56 374.59 -199.84 4.35 5989758.31 572061.55 N 70 22 56.294 W 149 24 50.493 3427.41 21.85 27.45 3292.39 3366.79 241.44. 534.98 445.66 404.72 -186.60 4.66 5989788.56 572074.50 N 70 22 56.590 W 149 24 50.106 3523.10 25.50 33.28 3380.03 3454.43 226.73 573.37 468.56 437.76 -167.08 4.53 5989821.78 572093.70 N 70 22 56.915 W 149 24 49.534 3617.39 29.46 39.65 3463.68 3538.08 205.92 616.83 493.22 472.60 -141.13 5.23 5989856.87 572119.30 N 70 22 57.258 W 149 24 48.775 3713.90 32.64 44.74 3546.36 3620.76 177.92 666.58 520.63 509.37 -107.65 4.27 5989893.96 572152.42 N 70 22 57.619 W 149 24 47.795 3809.74 35.33 50.25 3625.85 3700.25 143.85 720.12 549.71 545.47 -68.14 4.26 5989930.43 572191.58 N 70 22 57.974 W 149 24 46.638 3905.21 38.56 52.55 3702.14 3776.54 104.44 777.49 581.69 581.22 -23.28 3.68 5989966.62 572236.09 N 70 22 58.326 W 149 24 45.325 4000.58 41.49 53.46 3775.16 3849.56 61.10 838.82 618.65 618.12 25.71 3.13 5990003.98 572284.72 N 70 22 58.689 W 149 24 43.891 4095.80 42.78 54.13 3845.77 3920.17 15.34 902.70 660.38 655.84 77.26 1.43 5990042.20 572335.89 N 70 22 59.060 W 149 24 42.382 4191.39 42.99 54.95 3915.82 3990.22 31.83 967.75 705.70 693.58 130.24 0.62 5990080.44 572388.51 N 70 22 59.431 W 149 24 40.831 4287,61 43.34 55.45 3986.00 4060.40 -80.09 1033.57 754.02 731.15 184.30 0.51 5990118.52 572442.19 N 70 22 59.801 W 149 24 39.249 4380.37 43.33 55.57 4053.47 4127.87 -127.00 1097.23 802.90 767.19 236.76 0.09 5990155.07 572494.30 N 70 23 0.155 W 149 24 37.713 4476.79 43.31 55.50 4123.62 4198.02 -175.76 1163.38 855.74 804.63 291.30 0.05 5990193.03 572548.47 N 70 23 0.523 W 149 24 36.117 4572.22 43.35 55.10 4193.03 4267.43 -223.84 1228.86 909.91 841.91 345.14 0.29 5990230.82 572601.94 N 70 23 0.890 W 149 24 34.541 4668.00 43.57 52.63 4262.56 4336.96 -271.08 1294.74 966.64 880.75 398.34 1.79 5990270.17 572654.76 N 70 23 1.272 W 149 24 32.984 4763.28 43.84 51.80 4331.44 4405.84 -316.94 1360.57 1025.30 921.09 450.37 0.67 5990311.01 572706.39 N 70 23 1.668 W 149 24 31.461 4859.81 44.00 51.90 4400.97 4475.37 -363.29 1427.53 1085.98 962.45 503.02 0.18 5990352.87 572758.63 N 70 23 2.075 W 149 24 4955.00 44.11 50.03 4469.38 4543.78 -408.35 1493.72 1147.03 1004.13 554.43 1.37 5990395.05 572809.63 N 70 23 2.485 W 149 24 5051.47 44.14 48.68 4538.63 4613.03 -452.68 1560.88 1210.19 1047.88 605.39 0.97 5990439.28 572860.16 N 70 23 2.915 W 149 24 26. 22 5145.98 43.59 4827 4606.77 4681.17 -495.15 1626.37 1272.48 1091.30 654.42 0.66 5990483.16 572908.77 N 70 23 3.342 W 149 24 25.487 5242.03 43.75 47.83 467625 4750.65 -537.78 1692.70 1336.01 1135.63 703.75 0.36 5990527.97 572957.66 N 70 23 3.778 W 149 24 24.043 5336.44 43.61 47.39 4744.53 4818:93 -579.31 1757.90 1398.86 1179.59 751.91 0.35 5990572.39 573005.38 N 70 23 4.211 W 149 24 22.633 5428.43 43.33 47.34 4811.29 4885.69 -619.41 1821.18 1460.12 1222.46 798.46 0.31 5990615.69 573051.52 N 70 23 4.632 W 149 24 21.270 5522.23 43.00 46.81 4879.70 4954.10 -659.81 1885.35 1522.48 1266.16 845.45 0.52 5990659.84 573098.08 N 70 23 5.062 W 149 24 19.894 5615.73 43.57 47.36 4947.77 5022.17 -700.19 1949.46 1584.92 1309.81 892.40 0.73 5990703.94 573144.60 N 70 23 5.491 W 149 24 18.520 5709.15 43.94 48.71 5015.25 5089.65 -741.70 2014.06 1647.74 1353.00 940.44 1.07 5990747.59 573192.22 N 70 23 5.916 W 149 24 17.113 5803.02 43.88 48.72 5082.87 5157.27 -784.12 2079.17 1711.00 1395.96 989.36 0.06 5990791.01 573240.71 N 70 23 6.338 W 149 24 15.681 5896.70 43.77 47.88 5150.46 5224.86 -826.04 2144.03 1774.27 1439.11 1037.79 0.63 5990834.63 573288.72 N 70 23 6.763 W 149 24 14.263 5991.49 43.41 48.52 5219.12 5293.52 -868.18 2209.39 1838.16 1482.67 1086.51 0.60 5990878.66 573337.02 N 70 23 7.191 W 149 24 12.837 SurveyEditor Ver SP 1.0 Bld( doc40x_56) I-14\I-100\I-100\I-100 Generated 5/11/20061:18 PM Page 2 of 3 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS bVC/.U'L 4J./'L 4y.4L 5[1818.:14 b:SbL./4 -`J11.3U 'L'L/b.L:S 1`JUL.43 15Lb.t5`J 11:Sb.ltf U./J 5`J`JU`JLL.:iS 5/:i:iiSb.Lb IV /UL:f /.blb VV 14yL411.:Si53 6183.11 43.54 49.86 5357.89 5432.29 -955.31 2341.53 1967.10 1568.83 1186.70 0.37 5990965.76 573436.36 N 70 23 8.038 W 149 24 9.903 6278.86 41.92 49.58 5428.22 5502.62 -998.51 2406.50 2030.55 1610.83 1236.27 1.70 5991008.24 573485.51 N 70 23 8.451 W 149 24 8.452 6373.89 42.29 51.12 5498.73 5573.13 -1041.39 2470.21 2092.71 1651.48 1285.32 1:15 5991049.36 573534.17 N 70 23 8.851 W 149 24 7.016 6469.84 42.50 51.14 5569.59 5643.99 -1085.58 2534.91 2155.74 1692.08 1335.69 0.22 5991090.44 573584.14 N 70 23 9.250 W 149 24 5.541 6565.22 42.15 51.02 5640.10 5714.50 -1129.40 2599.13 2218.41 1732.42 1385.66 0.38 5991131.26 573633.71 N 70 23 9.647 W 149 24 4.078 6660.91 43.78 51.55 5710.13 5784.53 -1174.08 2664.34 2282.09 1773.21 1436.55 1.74 5991172.53 573684.19 N 70 23 10.048 W 149 24 2.588 6756.63 44.28 51.67 5778.95 5853.35 -1219.92 2730.87 2347.06 1814.52 1488.69 0.53 5991214.35 573735.93 N 70 23 10.454 W 149 24 1.061 6852.89 43.95 50.84 5848.06 5922.46 -1265.80 2797.88 2412.67 1856.46 1540.95 0.69 5991256.78 573787.78 N 70 23 10.866 W 149 23 59.531 6948.22 43.76 51.27 5916.80 5991.20 -1310.84 2863.93 2477.46 1897.98 1592.32 0.37 5991298.78 573838.74 N 70 23 11.274 W 149 23 58.027 7044.14 43.69 51.08 5986.12 6060.52 -1356.17 2930.23 2542.53 1939.54 1643.97 0.16 5991340.84 573889.98 N 70 23 11.683 W 149 23 7140.17 43.08 50.93 6055.91 6130.31 -1401.11 2996.19 2607.37 1981.05 1695.24 0.64 5991382.84 573940.84 N 70 23 12.091 W 149 23 7234.93 42.76 50.29 6125.30 6199.70 -1444.76 3060.72 2670.93 2022.00 1745.11 0.57 5991424.26 573990.31 N 70 23 12.494 W 149 23 53.553 7330.99 42.21 49.78 6196.14 6270.54 -1488.16 3125.59 2734.99 2063.67 1794.84 0.68 5991466.41 574039.63 N 70 23 12.904 W 149 23 52.097 7427.09 41.83 49.76 6267.53 6341.93 -1530.97 3189.92 2798.58 2105.21 1843.95 0.40 5991508.43 574088.33 N 70 23 13.312 W 149 23 50.659 7521.94 41.83 50.13 6338.21 6412.61 -1573.21 3253.18 2861.12 2145.92 1892.37 0.26 5991549.59 574136.35 N 70 23 13.712 W 149 23 49.241 7618.98 41.77 50.83 6410.55 6484.95 -1616.85 3317.86 2925.01 2187.08 1942.26 0.48 5991591.23 574185.84 N 70 23 14.117 W 149 23 47.780 7714.59 41.19 51.11 6482.18 6556.58 -1659.97 3381.19 2987.51 2226.96 1991.45 0.64 5991631.58 574234.64 N 70 23 14.509 W 149 23 46.339 7809.51 41.18 51.25 6553.61 6628.01 -1702.70 3443.69 3049.20 2266.14 2040.15 0.10 5991671.23 574282.95 N 70 23 14.894 W 149 23 44.913 7905.54 40.57 51.52 6626.23 6700.63 -1745.83 3506.53 3111.22 2305.36 2089.25 0.66 5991710.91 574331.67 N 70 23 15.280 W 149 23 43.475 8001.07 39.36 51.52 6699.44 6773.84 -1788.04 3567.89 3171.78 2343.54 2137.29 1.27 5991749.55 574379.33 N 70 23 15.655 W 149 23 42.068 Last MWD+IFR+MS 8066.82 38.77 51.97 6750.49 6824.89 -1816.67 3609.33 3212.67 2369.20 2169.82 1.00 5991775.52 574411.61 N 70 23 15.907 W 149 23 41.116 TD (Projected) 8140.00 38.77 51.97 6807.55 6881.95 -1848.46 3655.15 3257.88 2397.43 2205.92 0.00 5991804.10 574447.43 N 70 23 16.185 W 149 23 40.059 Survey Type: Definitive Survey NOTES: GYD-GC-M S - (Gyrodata -gyro compassing m/s -- Older Gyrodata g yro multishots-plus all battery/memory tool surveys (RGS-BT). Replaces ex-BP "Gyrodata multishot into open hole" model. Not to be run above 70 degrees inclination.. ) MWD +IFR + MS - (In-field referenced MWD w ith mutt-station analysis and correction applied in post-processing. Assumes a BHA sag correction is appl ied to enhance inclination accuracy. ) Legal Description: Northi ng (Y) [ftUS] Easting (X) [ftUS] , Surface : 3217 FSL 3945 FEL S20 T12N R11 E UM 5989385.70 572264.98 BHL : 335 FSL 1731 FEL S17 T12N R11 E UM 5991804.10 574447.43 SurveyEditor Ver SP 1.0 Bld( doc40x_56) I-14\I-100\I-100\I-100 Generated 5/11/2006 1:18 PM Page 3 of 3 TREE _ 4-1/R" C:IW WELLHEAD = FMC ACTUATOR = N/A KB. ELEV = 74.4 BF. ELEV = 7165 KOP = 750' Max Angle = 44 @ 5051' Datum MD = 4858.46' Datum TVD = 4400' SS ~ I-100 SUSPENDED 4/18106 Minimum ID = 3.958" @ 4000' JEWELRY TYPE WLEG CSG, 40#, L-80. ID = 8.835" ~~ 2621' 4 1/2" 12.6# L-80 IBT-M Tbg. 3.958" ID, .0152 bpf H 4020 S TES: Suspension Details 1009' 9 5/8" Tam Port Collar 3884' RA Tag 4020 4 1/2" WLEG 4244' I-i ~ Tag 7" Csg, 26#, L-80,TC-II, ID = 6.276" 6020 7" 26# L-80, !D = 6.276, Marker joint wlRA Tag PBTD 8047' 7" Csg, 26#, L-80,BTC, ID = 6.276" 8130 BP Exploration (Alaska} PRUDHOE BAY UNIT WELL: 1-100 PERMIT No: 205-010 API No: 50-029-23245 SEC.20, T12N, R11E, UM • • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: AOGCC -Librarian Well No I-100PB1 Date Dispatched: 8-May-O6 Installation/Rig Nabors 9ES Dispatched By: Mauricio Perdomo LWD Log Delivery V1.1,10-02-03 Data No Of Prints No of Floppies Surveys 2 1 Please sign and return to: James H. Jonnson ReCelved By: BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-i) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address: johnsojhC~bp.com ~~~ ~ V ~' • • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Well No I-100 Dispatched To: Helen Warman (AOGCCI Date Dispatched: 28-Apr-06 Installation/Rig Nabors-9ES Dispatched By: Mauricio Perdomo Data No Of Prints No of Floppies Surveys 2 1 Please sign and return to: James H. Jonnson ReCelved By: -(~(z BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-i) C~ M~ ~ (4~ I . 900 E. Benson Blvd. r -_ , ~ I p Anchorage, Alaska 99508 ) ~ v Fax:907-564-4005 e-mail address: johnsojh4~bp.com LWD Log Delivery V1.1,10-02-03 ~O) ~- D to I-100 abandonment Subject: I-100 abandonment From: "Smith, Phil G (ASRC)" <PhiLG.Smith@bp.com> Date: Wed, 29 Mar 2006 13:31:26 -0900 To: Winton Aubert <Winton_aubert@admin.state.ak.us> Winton, I would like to get some clarification regarding the cement plugging of the Schrader interval on I-100. We are currently planning the following: 5-1 /2" sacrificial liner placed in the 2300' lowermost section (inverted) fulty cement~l, inside and aut, cement held in place with an ECP. 3~-each, 1000-ft balanced plugs dinsctly on top of one another beginning at the top of the aforementioned liner, ending a minimum of 100-ft above the uppermost HC bearing zone. 16.0 ppg mud spacer to 800' from the surface shoe Final cement plug from 800` below the shoe to 200' inside the shoe. The final cement plug will be used as a kick off plug from the surface shoe to access the Kuparuk target. The reg's are unclear if we have to tag each plug in succession or if the kick-off plug alone would be adequate. We are planning to tag only the kick-off plug unless otherwise required. Please advise. Thanks, Phil Smith Operations Drilling Engineer 564-4897 1 of 1 3/29/2006 1:45 PM ~ • ~. ~~ ~ ~ ~~ 1 ~ ~ FRANK H. MURKOWSKI, GOVERNOR Ailt-~~-t7~~1a~T Qii~ A1sD i7r0a7 333 W. 7"' AVENUE, SUITE 100 COI~SERQ~ii~a` CQ~IISS'I0~ ANCHORAGE, ALASKA 99501-3539 Lowell Crane PHONE (907) 279-1433 Senior Drilling Engineer FAx (so7~ 27s-7542 BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: PBU I-100 BP Exploration (Alaska), Inc. Permit No: 205-010 Surface Location: 3218' NSL, 3945' WEL, Sec. 20, T12N, R1 lE, UM Bottomhole Location: 632' NSL, 1382' WEL, Sec. 17, T12N, R11E, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals 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. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name PBU I-100 PH and API number 50-029-23245-70 from records, data and logs acquired for well PBU I-100. 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 m result in the revocation or suspension of the permit. Please provide at least twenty-four (24) our notice for a representative of the Commission to witness any required test. Contact the Co~si 's petroleum field inspector at (907) 659-3607 (pager). ~---X~ C. N Chai DATED this day of January, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION ~JIMISSION PERMIT TO DRILL 20 AAC 25.005 ~ ~14r~ I (19 ~2~'° S 1a. Type of work ®Drill ^ Redrill ^ Re-Entry 1b. Current Well Class ®Exploratory ^ Development Oil ^ Multiple Zone ^ Stratigraphic Test ^ Service ^ Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 2S100302630-277 11. Well Name and Number: PBU I-100 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 8346 TVD 6834 12. Field /Pool(s): Prudhoe Bay Field / Orion 4a. Location of Well (Governmental Section): Surface: 3218' NSL 3945' WEL SEC. 20 T12N R11E UM (Planrred) 7. Property Designation: ADL 047446 Undefined , , , , , Top of Productive Horizon: 494' NSL, 1547' WEL, SEC. 17, T12N, R11E, UM 8. Land Use Permit: 13. Approximate Spud Date: February 15, 2005 Total Depth: 632' NSL, 1382' WEL, SEC. 17, T12N, R11E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 4500' 4b. Location of Well (State Base Plane Coordinates): Surtace: x-572265 -5989386 Zone-ASP4 10. KB Elevation Planned (Height above GL): 74.5 feet 15. Distance to Nearest Well Within Pool NWE 4-01 is 38' away at 840' MD 16. Deviated Wells: Kickoff Depth: 750 feet Maximum Hole Angle: 100 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3421 Surface: 2762 te. as ng rogram: Siz Specifications Setting Depth To Bottom uantity o ement c.f. or sacks Hole Casin Wei ht Grade Cou iin Len th MD TVD MD TVD includin sta a data 42" 34" x 20" 91.5# H-40 Weld 80' Surface Surface 110' 110' 60 sx Arctic Set A rox. 12-1/4" 9-5/8" 40# L-80 BTC 2474' Surface Surtace 2474' 2444' 60 sx Articset Lite, 207 sx Class 'G' 8-3/4" 7" 26# L-80 BTC-M " 8345' Surtace Surtace 8345' 6833' 36 sx LiteCrete, 145 sx Class 'G' 19. PRESENT WELL CONDITION SUMM ARY (To be completed for Redrill AND Re=e ntry Operatwns) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured): Casin Len th Size Cement Volume MD TVD r r n r P in , 4',. ~ t~ e Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ 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 Neil Magee, 564-5119 Printed Name L ~~II Crane Title Senior Drilling Engineer ,~ Prepared By NameMumber. Si natur !~':~ Phone 564-4089 Date ?-v,~"~ Terrie Hubble, 564-4628 Commission Use Only Permit To rill Number: _ API Number: ~ ` 50- Z - Z 2 7 Permit Approval Date: See cover letter for other requirements Conditions of Approval: Sam es equired ^ YesNo Mud Log Required ^ Yes ~No H r Sulfide Measures ^ Yes No i Directional SurveypRequired ~es ^ No Other: Tf S - ~!~!~ © f0 S t , c~ ~ ~ ~~~- dc~ ' f 'p s ~` tY~°~ ~~J d ~ ~ ~ ~ ~ APPROVED BY A roved B ~ ~ E ' ~ t k THE COMMISSION Date Form 10-401 Rewsed O6 ubmi Duplicate • Well Name: I-100 Permit Discussion Waiver of Required Mud Log and Cuttings Samples For drilling operations on I-100 appraisal well BP requests a waiver to AOGCC Regulations section 20 AAC 25.071 requiring a complete mud log and cuttings samples. The data is not required by BP and is not seen as information that will "significantly add to the geologic knowledge of the area". The proposed I-100 location lies between the ongoing Schrader Bluff and Kuparuk development at Milne Point S Pad and Borealis /Orion L and V Pad. Immediate offset penetrations include NWE 2-01, Texaco Prudhoe -0, NWE 4-01 and NW Eileen-1. Based on the close proximity of the data obtained in the offset wells, along with the extensive logging program planned for this well, it is believed that additional mud logging data is not critical to the geologic knowledge of the area. Proposed Suspension Condition I-100 is being drilled as an appraisal well for the Schrader Bluff and Kuparuk accumulations. Information gathered from this well will help determine the reservoir's future development requirements. The well is being planned as a "keeper" and is part of the future development plan. The surface location was selected based on the potential gravel pad design and is positioned within a future row of wells based on that design. The well location is immediately offset to well NWE 4-01 drilled in early 2002. As outlined in the Drill and Complete Summary, the base plan is to suspend the well without perforating or completing the well. A kill string will be run below the Permafrost and the wellhead secured for suspension. (See attached schematic fro additional details.) If the well fails to encounter any hydrocarbon reserves that justify future development plans, the well will be plugged and abandoned as per AOGCC regulations. I-100 Drilling Permit • Drill and Complete Plan Summary T e of Well service / roducer / in'ector : Appraisal/Delineation Surface Location: X = 572,264.87' Y = 5,989,385.56' Pro osed 3217' FSL, 3945' FEL, Sec. 20, T12N, R11 E Target Location: X = 574,629.00' Y = 5,991,965.00' Ku aruk 494' FSL, 1547' FEL, Sec. 17, T12N, R11 E Bottom"No Location: X = 574,792.98' Y = 5,992,104.32' u aru 631' FSL, 1382' FEL, Sec. 17, T12N, R11 E ~ t Location: X = 567,400.00' Y = 5,990,000.00' Schrader Oa 3877' FSL, 3522' FEL, Sec.19, T12N, R11 E Bottom Ho a Location: X = 563,610.00' Y = 5,990,525.00' chrade D 4435' FSL, 2484' FEL, Sec. 24, T12N, R10E AFE Number: BR 5M417 Ri Nabors 7ES i Estimated Start Date: 2/15/2005 O eratin da s to com lete: 30.0 Well Desi n conventional, slimhole, etc.: Ultra Slimhole Ob'ective: Schrader Bluff and Kuparuk Appraisal The cased Kuparuk interval of I-100 is 5050' MD away from the suspended NWE 2-01 TKUP C wellbore and 11,440' MD away from producing well L-122 at TKUP C. The abandoned Schrader interval of I-100 is 2400' MD away from the suspended NWE 4-01 Schrader Na and 9800' MD away from producing well L-211 at top Schrader Na. The well approaches within 4500' of the nearest Prudhoe Bay property line. Schrader TD: 11654' MD / 3964' TVD Ku aruk TD: 8345' MD /6833' TVD Casing/Tubing Program: RT/G L: 28.5' Hole Size Csg/ Tb O.D. Wt/Ft Grade Conn Length Top MD/TVD Btm MDlTVD bkb 42" 34" OD Insulated 20" 91.5# H-40 ~ W ~ 80' GL 110/110 12 '/a" 9 5/8" 40# L-80 BTC 2474' G L 2474'/2444' 8 3/a" 7" 26# L-80 BTC-m 8345' GL 8345'/6833' Tubin 41/2" 12.6# L-80 IBT-M 4000' GL 4000'/4000' 9-5/8" burst 5750 psi, collapse 3,090 psi 7" burst 7,240 psi, collapse 5,410 psi I-100 Drilling Permit • Mud Program: 12'/a" Surface Hole (0-2474'): Fresh Water Surface Hole Mud Density Viscosity seconds Yield Point Ib/100ft~ API FL mis/30min PH Initial 8.8 - 9.2 250-300 45 - 70 NC 9.0 - 9.5 Base PF to to SV 9.0 - 9.6 200-200 35 - 45 < 8 9.0 - 9.5 SV toTD 9.6 max 150-200 25 - 35 < 8 9.0 - 9.5 8 3/a" Schrader Appraisal Hole (2474' -11654'): LSND Interval Density YP PV pH API (ppg) Filtrate Upper 9.2 -9.4 25-35 10-15 9.0-9.5 6-8 Interval 8 3/a" Kuparuk Appraisal Hole (2474' - 8345'): LSND Interval Density YP PV pH API (ppg) Filtrate Upper 9.4 25-35 10-15 9.0-9.5 6-8 Interval Top of HRZ 10. - 22-32 10-15 9.0-9.5 4-5.5 to TD ~:* Directional: Ver. I-100 PB1 (Schrader P6), (Kuparuk P5) KOP: 750' Maximum Hole An le Schrader : 100 deg at 9,055' MD Close Approach Wells: All wells pass major risk criteria. NW E 4-01 38' C«~ 840' IFR-MS corrected surveys will be used for survey validation. Logging Program: Surface Drilling: MWD / GR Open Hole: None Cased Hole: None Schrader Appraisal Drilling: MWD/GR/NEU/DEN/PW D Open Hole: Case Hole: None Kuparuk Appraisal Drilling: MWD/GR/RES/PWD Open Hole: PEX-Triple Combo. (Dipole sonic in expert mode across Kuparuk Cased Hole: USIT Post Ri I-100 Drilling Permit • Formation Markers I-100 PB1 P6 Formation To s TVDss Comments SV6 835 SV5 1425 SV4 1550 Base ermafrost 1645 SV3 .1800 Possible H drates SV2 1955 Possible H drates SV1 2270 Possible H drates UG4 2610 UG4A 2645 UG3 2945 Fault No.1 3350 UG1 3505 H drocarbon bearin , 8.8 EMW Ma 3740 H drocarbon bearin , 8.8 EMW Mb1 3770 H drocarbon bearin , 8.8 EMW Mb2 3835 H drocarbon bearin , 8.8 EMW Fault No.2 3905 Mb2 Re eat 3990 Not h drocarbon bearin Na 4050 Not h drocarbon bearin Nb 4075 H drocarbon Bearin , 8.8 EMW Nc 4115 H drocarbon Bearin , 8.8 EMW Oa 4180 H drocarbon Bearin , 8.8 EMW OBa 4235 H drocarbon Bearin , 8.8 EMW OBb 4275 H drocarbon Bearin , 8.8 EMW OBc 4305 H drocarbon Bearin , 8.8 EMW OBd 4345 H drocarbon Bearin , 8.8 EMW OBe 4395 H drocarbon Bearin , 8.8 EMW TD 3890 Formation Markers I-100(P5): Formation To s TVDss Comments UG4 2605 UG4A 2640 UG3 2945 UG1 3460 H drocarbon bearin , 8.8 EMW Fault 3600 H drocarbon bearin , 8.8 EMW Ma 3610 H drocarbon bearin , 8.8 EMW Na 3875 H drocarbon bearin , 8.8 EMW Oa 4015 H drocarbon bearin , 8.8 EMW OBd 4225 H drocarbon bearin , 8.8 EMW CM2 5020 CM1 5342 THRZ 6000 K-1 6260 TKUP 6260 TKC 6495 H drocarbon Bearin , 3200 si, 9.6 EMW ~, 2 ~' ~~ , ~, I-100 Drilling Permit r TKB 6595 H drocarbon Bearin , 3421 si 10.0 EMW Ku aruk A6 6810 Miluveach 6890 TD Criteria 150' MD below TKB Integrity Testing: Test Point Depth Test Type EMW Surface Casing Shoe 20' min from LOT 12.9 ppg EMW Target Based on surface shoe Ku aruk Formation Pressure Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as a contingency if cement is not circulated to surface. Casina Size 19-5/8" Surface Basis: Lead: Based on conductor set at 110', 1620' of annulus in the permafrost C 250% excess and 244' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface Tail: Based on 500' MD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At 1974' MD ,--~ Total Cement Volume: Lead 363 bbl / 2036 f ' sks of Dowell ARTICSET Lite at 10.7 and .4 k. Tail 43 bbl / 24? -sks of Dowell Premium `G' at 15.8 The 7" roduction casin will be cemented across the Kuparuk through the UG1 as follows: Casing Size 7" Production Longstring Basis: Tail: Based on TOC 500' above top of Kuparuk formation + 30% excess + 80' shoe Cement Placement: From shoe to 7,545' MD Lead: Based on TOC 500' MD above top of the UG1 +30% excess volume Cement Placement: From 7,545' MD to 3700' MD 500' MD above UG1 sand Total Cement Volume: Lead 134 bbls / 752 ft / 336 sks of Dowell LiteCrete at 12.0 j and 2.24 cf/sk Tail 31 bbls / 174 ft / 145 sks of Dowell G at 15.8 ppg and /` 1.20cf/sk I-100 Drilling Permit r Well Control: Surface hole will be drilled with a diverter. The intermediate/production hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the planned casing test of 3500 psi for casing integrity considerations, the BOP equipment will be tested to 4000 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • Planned completion fluid: Disposal: 3421 psi C«? 6595' TVDss - Kuparuk B 2762 psi C~ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) 4000 psi (The casing will be tested to 3500) 9.0 ppg filtered brine / 6.8 ppg diesel • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. I-100 Drilling Permit • DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor is scheduled for installation. 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. Install two side outlet valves. Rig Operations: 1. MIRU Nabors 7ES. 2. Nipple up and function test diverter system~PU 4" DP as required and stand back in derrick. 3. MU 12 ~/a" drilling assembly with MWD/LWD (page 4) and directionally drill surface hole to approximately 100' TVD below the SV1 .Sands. 4. Run and cement the 9-5/8", 40# surface casing back to surface. Bump plug with 3500 psi and ~'' hold/chart for 30 minutes. Note - A Tam port collar will be run as a contingency if surface drilling is problematic. 5. ND riser spool and NU casing /tubing head. NU BOPE and test to 4000 psi. 6. MU 8-3/4"drilling assembly with MWD/LWD (page 4) and RIH to float collar. 7. Drill out shoe joints and displace well to 9.2 ppg LSND drilling fluid. Drill new formation to 20' below /` 9-5/8" shoe and perform Leak Off Test. 8. Drill ahead as per directional plan. Plans are to evaluate the heel of the Schrader interval and if productive continue on to the end of the polygon. Should the Schrader penetration be wet, the Asset Team will likely want to plug back the well and either drill a sidetrack to a target to the South West / (Well Plan PB2) or continue on with the Kuparuk leg of the well. 9. Assuming drilling will continue to the Kuparuk leg, the Schrader interval will be plugged back. In the case of the shortened Schrader wellbore, a cement plug will be placed across the open Schrader interval and immediately below the surface casing shoe for a Kuparuk kick-off. If the entire Schrader interval is drilled, it may be necessary to run a scab 5-1/2" liner (plop and drop) through the interval in ~ order to secure Schrader isolation due to the geometry of the interval. Afterwards a cement plug will be set below the surface casing shoe for a Kuparuk kick-off. 10. Kick of well and drill to +/-100' above the HRZ. Weight up mud from 9.4 ppg to 10.2 ppg. Ensure Pre-~~ Reservoir meeting is held highlighting kick tolerance and detection prior to entering HRZ. 11. Drill ahead to production TD at approximately 150' MD' below top Kuparuk B6 sand in order to evaluate entire Kuparuk D through B7 interval. (TD estimated at 8345' MD). ~" 12. Run PEX/Dipole Sonic in expert mode from TD to surface casing shoe. 13. Run and cement the 7" production casing. Test casing to 3500 psi. 14. Freeze protect the 7" x 9-5/8" annulus as required. Record formation breakdown pressure on the Morning Report. ~,, 15. Run a 4-1/2", 12.6#, IBT-Mod, L-80 suspension string to 4000' 16. Install TWC and test to 1000 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 17. RU hot oil truck and freeze protect well to approximately 2700' by pumping diesel down backside and allow to equalize. 18. Rig down and move off. Post-Rig Operations: 1. Clean-up location as required. Complete a post rig inspection with the HSE Representative. I-100 Drilling Permit • 1-100 Drilling Program Job 1: MIRU Hazards and Contingencies - The area surrounding the NWE4-01 well and the surrounding ice pad is not designated as an H2S site. As a precaution however Standard Operating Procedures or H2S precautions should be followed at all times. - The rig move will involve no surface close approach hazards with adjacent wells. Appraisal well NWE4-01 is approximately 38' to the South West of the proposed I-100 conductor. - Check the landing ring height on I-100. The BOP nipple up may need review for space out. Reference RPs • "Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" Job 2: Drilling Surface Hole - Hydrates were observed in the closest offset well, NWE4-01 well drilled in 2002. Background gas averaged 500 units from 2000' to TD in the SV-1 sand and connection gas averaged 2500 units in this interval. Final MW for the drilled interval was 9.9 ppg. - No fault crossings are expected in the surface hole. - There are no close approach issues along the I-100 well path. The offset well NWE 4-01 is offset 38' at 840' however should not pose a close approach concern. Reference RPs • "Prudhoe Bay Directional Guidelines" • "Well Control Operations Station Bill" Job 3: Install Surface Casing Hazards and Contingencies - It is critical that cement is circulated to surface for well integrity. 250% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. A 9-5/8" port collar will be available as a contingency if surface hole drilling is problematic. If used the port collar will be positioned at ±1000'MD to allow remedial cementing. - "Annular Pumping Away' criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement 2. Cement -Top of tail >500' TVD above shoe using 30% excess. 3. Casing Shoe Set approximately 100'TVD below SV-1 sand. Reference RPs • "Casing and Liner Running Procedure" I-100 Drilling Permit • • "Sun`ace Casing and Cementing Guidelines" • "Sun`ace Casing Port Collar Procedure" Job 7: Drilling Schrader Hole Hazards and Contingencies - I-100 is expected to cross two faults in the Schrader hole section. The approximate location of the first fault is 3350'TVD ss (+/- 200') and has an estimated throw of 30'. Lost circulation is considered a minimum risk. The second fault is at 3905'TVD ss (+/- 150') in the Ugnu M sands and has an estimated throw of 100'. Lost circulation is considered a risk as neither fault has been penetrated previously. If losses/breathing is encountered, consult the Lost Circulation Decision Tree regarding LCM treatments and procedures and adjust drilling practices to reduce losses. - KICK TOLERANCE: In the ca scenario of 8.8 ppg pore pressure at the top Schrader target depth, gauge hole, a fra gr dient of 12.0 ppg at the surface casing shoe, 9.4 ppg mud in the hole the kick tolerance ' 47 Is. (LOT achieved on offset well NEW 4-01 was 13.6 ppg EMW.) The Kuparuk appraisal will see a formation pressure of 3421 psi at 6595' TVDss. This equates an MW of 10.0 ppg. A leak off of 12.9 ppg at the surface casing shoe will be required to allow a 2 bbl kick tolerance with 10.3 ppg mud in the wellbore. (There is a 100 psi surface pressure qty factor built into this LOT requirement.) Contact the Drilling Manager if LOT is less than 12.9 ppg (25 bbl kick tolerance). - There are no close approach issues with the Schrader hole interval of I-100. Reference RPs • Standard Operating Procedure for Leak-off and Formation Integrity Tests • Prudhoe Bay Directional Guidelines • Lubricants for Torque and Drag Management. • ERD Recommended Practice Section 5.2 "Operating Practices" Planned Schrader Plug Back: The Schrader interval will be fully plugged back to comply with the requirements of AOGCC 20 AAC25.112. Depending on the total depth and geometry of the Schrader section drilled, the wellbore will either be plugged by multiple cement plugs covering all hydrocarbons and fresh water strata or by running and cementing a scab liner across the Schrader interval. The latter /~ will be accomplished by running either a 4-1/2" or 5-1/2" liner through the open Schrader interval, cementing the interval and releasing via a "plop and drop" system. Following the plugging of the Schrader portion a cement kick-off plug will be set immediately below the surface casing shoe to facilitate kicking off the Kuparuk section of the wellbore. I-100 Drilling Permit • Job 7: Drilling Kuparuk. Hole Hazards and Contingencies - I-100 is expected to cross one fault in the Kuparuk hole section. The approximate location of the fault is 3600'TVD ss (+/- 150') and has an estimated throw of 95'. Lost circulation is considered a minimum risk as NWE 4-01 crossed this fault without experiencing losses. - KICK TOLERANCE: See requirement detailed in Schrader section above regarding minimum LOT requirement. - There are no close approach issues with the Kuparuk hole interval of I-100. Reference RPs • Prudhoe Bay Directional Guidelines • Lubricants for Torque and Drag Management. • "Shale Drilling- Kingak & HrZ" Job 8: Log Kuparuk Interval Hazards and Contingencies - Ensure the hole is in optimal condition prior to logging to ensure a successful logging program. Review the use of lubricant pill across logging interval. - If logging time is excessive or hole conditions dictate, perform a clean out run prior to running the 7" longstring casing. Reference RPs • Follow Schlumberger logging practices and recommendations. • Wireline Pressure Control Job 9: Case & Cement Production Hole Hazards and Contingencies - The interval is planned to be cemented with a lead and tail slurry. The lead slurry will cover from 500' above the Kuparuk to 500' above the UG1 and the tail will cover from the shoe to 500' above the top of Kuparuk interval. - A casing running program will be jointly issued by the ODE and Drilling Supervisor detailing circulating points and running speed. In addition a LCM pill composed of "G Seal" may be placed across the Schrader and Ugnu to help arrest mud dehydration if losses were experienced while drilling this interval. - Ensure a minimum hydrostatic equivalent of 10,2 ppg on the HRZ during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. - Ensure the lower production cement has reached at least a 706C thickening value prior to freeze protecting. Pump approximately'h volume of casing-casing annulus prior to freeze. After freeze protecting the 7" x 9-5/8" casing outer annulus with 55 bbls of dead crude (2035' MD, 2026'TVD), I-100 Drilling Permit r the hydrostatic pressure will be 7.9 ppg vs 8.6 ppg EMW of the formation pressure immediately below the shoe. Ensure adouble-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be 110 psi underbalance to the open hole. (Approximately 25 bbls of 12.5 ppg mud ahead of the diesel would be required to balance this pressure.) Reference RPs • "Intermediate Casing and Cementing Guidelines" • "Freeze Protecting an Outer Annulus" Job 12: Run Completion Hazards and Contingencies - Watch hole fill while running the completion and verify proper safety valves are on the rig floor. The well will be underbalanced if there is a casing integrity problem. Reference RPs • Completion Design and Running • Freeze Protection of Inner Annulus Job 13: ND/NU/Release Rig Hazards and Contingencies - No hazards specific to this well have been identified for this phase of the well constructions Reference RPs • Freeze Protection of Inner Annulus I-100 Drilling Permit // // ' // // // ~~- / %' ~%'~ l/ / / ,' / / // // ~/ r <o / / // .~ / / \~o / / ~/ // // / / // // // / / // / / / / / / / ~~ / / / /~ ~ / Ice Pad / Access Road ~~~ ~ / Approx. 265' / / / / / / / / / / // / Winds PCe~a~\~n9 Ice Pad Access Road Approx. 270' 400' 0 Cr BP EXPLORATION (ALASKA) INC. PRUDHOE BAY UNIT PROPOSED I - 100 WELL CONCEPTUAL ICE PAD LAYOUT 0 J h p pit imps ~ - Existing Well This Project NWE 4-01 Proposed ~ I-100 Well DATE: SCALE: FIGURE: September 2004 1" = 150 Feet 4 ip149791o.dgn TREE ` 4-1 /8" CNV WELLHEAD= FMC ACTUATOR = N/A KB. ELEV..- BF. EI ~" _ __ KOP= ..Max / Datun Datun '-~ O O NOTES: Suspension Details # DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNfr 1/6/2005 NM Proposed Wellbore WELL: 1-100 PERMff No: API No: 50-??? SEC 2Q, T12N, R11 E, ???? BP 6cploration (Alaska) T' G9",--~ ~#, L~ ~fiD6' I-100PB1 (P6 Schlumberger Report Date: December 17, 2004 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 278.050° Field: Prudhoe Bay Unit - WOA Structure /Slot: I-Pad / I-14 ® Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table Well: Plan I-100 • ® Borehole: Plan I-100PB1 TVD Reference Elevation: 74.50 ft relative to MSL Sea Bed 1 Ground Level Elevation: 47.41 ft relative to MSL UWIIAPg1: 50029 Magnetic Declination: 24.493° Survey Name 1 Date: I-100PB1 (P6) /December 17, 2004 Total Field Strength: 57605.998 nT Tort I AHD 1 DDI 1 ERD ratio: 121.081 ° / 8907.71 ft / 6.449 / 2.247 Magnetic Dip: 80.821 ° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: March 31, 2005 Location LatlLong: N 70.38128014, W 149.41240200 Magnetic Declination Model: BGGM 2004 Location Grid NIE YIX: N 5989385.560 ftUS, E 572264.870 ftUS North Reference: True North Grid Convergence Angle: +0.55348884° Total Corr Mag North a True NoRh: +24.493° Grid Scale Factor: 0.99990593 Local Coordinates Referenced To: Well Hr"ad • Comments Measured Inclination Azimuth Sub-Sea TVD TVD Verbwl Along Hole NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Departure ft de de k ft ft ft ft it de 1100 ft de de 1100 ft de 100 ft ftUS ftUS RTF n nn n nn n nn ~n ~n n nn - ~• ~~ ~~~~ ~•~ - ~• ~~ ~ v.vv v.v~ v.vv v.vvm v.VV V.VV tlytlyJ80 Atl D/GLtl4 .t3/ N /U .S25lZtlVl4 VV 74`J. 47Z4UZUU Gl 339. 50 0.00 0.00 265. 00 339.50 0.00 0.00 0.00 0.00 0.00 O.OOM 0.00 0.00 5989385. 56 572264. 87 N 70. 38128014 W 149. 41240200 KOP Bld 1.51100 750. 00 0.00 0.00 675. 50 750.00 0.00 0.00 0.00 0.00 0.00 O.OOM 0.00 0.00 5989385 .56 572264 .87 N 70 .38128014 W 149. 41240200 800. 00 0.75 0.00 725. 50 800.00 0.05 0.33 0.33 0.00 1.50 O.OOM 1.50 0.00 5989385 .89 572264 .87 N 70 .38128103 W 149. 41240200 900. 00 2.25 0.00 825. 46 899.96 0.41 2.94 2.94 0.00 1.50 O.OOM 1.50 0.00 5989388 .50 572264 .84 N 70 .38128818 W 149. 41240200 SV6 904. 54 2.32 0.00 830. 00 904.50 0.44 3.13 3.13 0.00 1.50 O.OOM 1.50 0.00 5989388. 69 572264. 84 N 70. 38128868 W 149. 41240200 1000. 00 3.75 0.00 925. 32 999.82 1.15 8.18 8.18 0.00 1.50 O.OOM 1.50 0.00 5989393 .74 572264 .79 N 70 .38130248 W 149. 41240200 1100. 00 5.25 0.00 1025. 01 1099.51 2.24 16.02 16.02 0.00 1.50 O.OOG 1.50 0.00 5989401 .58 572264 .72 N 70 .38132391 W 149. 41240200 1200. 00 6.75 0.00 1124. 46 1198.96 3.71 26.48 26.48 0.00 1.50 O.OOG 1.50 0.00 5989412 .03 572264 .61 N 70 .38135247 W 149. 41240200 1300. 00 8.25 0.00 1223. 60 1298.10 5.54 39.53 39.53 0.00 1.50 O.OOG 1.50 0.00 5989425 .08 572264 .49 N 70 .38138813 W 149. 41240200 1400. 00 9.75 0.00 1322. 37 1396.87 7.73 55.17 55.17 0.00 1.50 O.OOG 1.50 0.00 5989440 .72 572264 .34 N 70 .38143086 W 149. 41240200 1500. 00 11.25 0.00 1420. 69 1495.19 10.28 73.39 73.39 0.00 1.50 O.OOG 1.50 0.00 5989458 .94 572264 .16 N 70 .38148064 W 149. 41 SV5 1509. 49 11.39 0.00 1430. 00 1504.50 10.54 75.26 75.26 0.00 1.50 O.OOG 1.50 0.00 5989460. 81 572264. 14 N 70. 38148574 W 149. 2 412 1600. 00 12.75 0.00 1518. 50 1593.00 13.19 94.19 94.19 0.00 1.50 O.OOG 1.50 0.00 5989479 .73 572263 .96 N 70 .38153744 W 149. 41240 0 SV4 1632. 33 13.23 0.00 1550. 00 1624.50 14.21 101.45 101.45 0.00 1.50 O.OOG 1.50 0.00 5989487. 00 572263. 89 N 70. 38155730 W 149. 41240200 1700. 00 14.25 0.00 1615. 74 1690.24 16.46 117.53 117.53 0.00 1.50 O.OOG 1.50 0.00 5989503 .07 572263 .73 N 70 .38160122 W 149. 41240200 Base Perm 1730. 22 14.70 0.00 1645. 00 1719.50 17.52 125.08 125.08 0.00 1.50 O.OOG 1.50 0.00 5989510. 63 572263. 66 N 70. 38162186 W 149. 41240200 End Bld 1750. 00 15.00 0.00 1664. 12 1738.62 18.23 130.15 130.15 0.00 1.50 O.OOG 1.50 0.00 5989515 .70 572263 .61 N 70 .38163570 W 149. 41240200 Crv 31100 1800. 00 15.00 0.00 1712. 41 1786.91 20.04 143.09 143.09 0.00 0.00 -131.01G 0.00 0.00 5989528 .63 572263 .49 N 70 .38167106 W 149 ,41240200 SV3 1890. 34 13.38 351.13 1800. 00 1874.50 24.72 165.19 165.11 -1.61 3.00 -122.41G -1.80 -9.82 5989550. 63 572261. 66 N 70. 38173121 W 149. 41241510 1900. 00 13.22 350.06 1809 .41 1883.91 25.38 167.42 167.31 -1.97 3.00 -121.37G -1.58 -11.07 5989552 .82 572261 .28 N 70 .38173720 W 149 .41241806 2000 .00 11.93 337.58 1907 .02 1981.52 34.16 189.11 188.13 -7.89 3.00 -109.19G -1.29 -12.48 5989573 .59 572255 .16 N 70 .38179409 W 149 .41246618 SV2 2049. 00 11.53 330.62 1955. 00 2029.50 39.71 199.06 197.08 -12.23 3.00 -102.37G -0.82 -14.21 5989582. 50 572250. 74 N 70. 38181855 W 149. 41250144 2100. 00 11.30 322.97 2004. 99 2079.49 46.35 209.15 205.52 -17.74 3.00 -94.87G -0.45 -14.99 5989590 .88 572245 .15 N 70 .38184159 W 149 41254625 2200. 00 11.44 307.73 2103. 05 2177.55 61.91 228.75 219.41 -31.49 3.00 -79.93G 0.14 -15.24 5989604 .64 572231 .26 N 70 . .38187955 W 149. 41265804 WeIlDesign Ver 3.1RT-SP3.03-HF5.00 Bld( do31rt-546) I-14\Plan I-100\Plan I-100P61\I-100P61 (P6) Generated 12/17/2004 10:49 AM Page 1 of 3 Comments Measured Inclination Azimuth SulrSea TVD TVD Vertical Along Hole NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Departure ft de de ft fl h fl R ft de 1100 k de de 1100 k de 1100 h ftUS ftUS G3UV .UU lG .3L Z`JJ ./5 LLUU .`J3 zuo .4s ts0.tt0 "149.24 229. It3 -49.10 3.00 -66.25G 0.88 -13.98 5989614. 83 572213 .55 N 70 .38190787 W 149.41280123 SV1 2370. 83 13. 32 285. 28 2270. 00 2344. 50 96.17 264. 93 234. 97 -63. 89 3.00 -57.98G 1.41 -11.96 5989619. 88 572198. 72 N 70. 38192206 W 149.41292145 2400 .00 13 .80 282 .17 2298 .36 2372 .86 102.97 271 .76 236. 59 -70 .53 3.00 -54.96G 1.66 -10.67 5989621. 44 572192 .06 N 70 .38192648 W 149.41297545 End Crv 2464 .87 15 .00 276 .00 2361 .19 2435 .69 119.07 287 .88 239. 10 -86 .44 3.00 O.OOG 1.85 -9.51 5989623. 79 572176 .13 N 70 .38193333 W 149.41310483 2473 .99 15 .00 276 .00 2370 .00 2444 .50 121.43 290 .24 239. 35 -88 .79 0.00 O.OOG 0.00 0.00 5989624. 01 572173 .78 N 70 .38193401 W 149.41312392 9-5/8" Csg Pt 2474. 00 15. 00 276. 00 2370. 01 2444. 51 121.44 290. 24 239. 35 -88. 79 0.00 O.OOG 0.00 0.00 5989624. 02 572173. 78 N 70. 38193401 W 149.41312394 Crv 6/100 2493 .99 15 .00 276. 00 2389 .32 2463 .82 126.61 295 .42 239. 89 -93 .94 0.00 -1.09G 0.00 0.00 5989624. 51 572168 .63 N 70 .38193548 W 149.41316577 2500 .00 15 .36 275. 97 2395 .12 2469 .62 128.18 296 .99 240. 05 -95 .51 6.00 -1.O6G 6.00 -0.43 5989624. 66 572167 .06 N 70 .38193593 W 149.41317850 2600 .00 21 .36 275. 67 2489 .99 2564 .49 159.64 328 .48 243. 23 -126 .83 6.00 -0.77G 6.00 -0.30 5989627. 53 572135 .71 N 70 .38194462 W 149.41343318 2700 .00 27 .36 275. 49 2581 .04 2655 .54 200.83 369 .70 247. 24 -167 .86 6.00 -0.61G 6.00 -0.18 5989631. 14 572094 .64 N 70. 38195555 W 149.413766 UG4 2732. 90 29. 33 275. 45 2610. 00 2684. 50 216.44 385. 32 248. 72 -183. 41 6.00 -0.57G 6.00 -0.13 5989632. 48 572079. 08 N 70. 38195962 W 149.413893 UG4A 2773. 55 31. 77 275. 40 2645. 00 2719. 50 237.07 405. 98 250. 68 -203. 98 6.00 -0.53G 6.00 -0.11 5989634. 23 572058. 50 N 70. 38196496 W 149.41406046 2800 .00 33 .36 275. 38 2667 .29 2741 .79 251.30 420 .22 252. 02 -218 .15 6.00 -0.51G 6.00 -0.10 5989635. 43 572044 .31 N 70. 38196861 W 149.41417570 2900 .00 39 .36 275. 29 2747 .79 2822 .29 310.49 479 .48 257. 52 -277 .15 6.00 -0.44G 6.00 -0.08 5989640. 37 571985 .27 N 70. 38198365 W 149.41465541 3000 .00 45 .36 275. 23 2821 .65 2896 .15 377.75 546 .83 263. 70 -344 .22 6.00 -0.40G 6.00 -O.OT, 5989645. 89. 571918 .15 N 70. 38200051 W 149.41520067 3100 .00 51 .36 275. 18 2888 .06 2962 .56 452.36 621 .52 270. 47 -418 .61 6.00 -0.36G 6.00 -0.05 5989651. 94 571843 .71 N 70. 38201899 VV 149.41580550 UG3 3170. 48 55. 59 275. 14 2930. 00 3004. 50 508.91 678. 14 275. 56 -475. 00 6.00 -0.34G 6.00 -0.05 5989656. 49 571787. 28 N 70. 38203289 W 149.41626399 3200 .00 57 .36 275. 13 2946 .31 3020 .81 533.49 702 .75 277. 76 -499 .51 6.00 O.OOG 6,00 -0.04 5989658. 46 571762 .75 N 70. 38203891 W 149.41646329 3300 .00 63 .36 275. 09 2995 .74 3070 .24 620.25 789 .63 285. 50 -586 .04 6.00 O.OOG 6,00 -0.04 5989665. 36 571676 .16 N 70. 38206003 W 149.41716682 3400 .00 69 .36 275. 06 3035 .82 3110 .32 711.69 881 .19 293. 60 -677 .25 6.00 O.OOG 6.00 -0.04 5989672. 57 571584 .88 N 70. 38208213 W 149.41790838 End Crv 3490 .88 74 .81 275. 03 3063 .77 3138 .27 798.01 967 .64 301. 19 -763 .36 6.00 O.OOG 6.00 -0.03 5989679. 34 571498 .71 N 70. 38210286 W 149.41860851 Fault Crossing 3629. 17 74. 81 275. 03 3100. 00 3174. 50 931.28 1101. 09 312. 89 -896. 30 0.00 O.OOG 0.00 0.00 5989689. 75 571365. 68 N 70. 38213477 W 149.41968941 UG1 5136. 82 74. 81 275. 03 3495. 00 3569. 50 2384.24 2556. 07 440. 38 -2345. 68 0.00 O.OOG 0.00 0.00 5989803. 22 569915. 27 N 70. 38248220 W 149.43147407 Ma 6052. 85 74. 81 275. 03 3735. 00 3809. 50 3267.05 3440. 11 517. 84 -3226. 32 0.00 O.OOG 0.00 0.00 5989872. 16 569034. 01 N 70. 38269293 W 149.43863457 Mb1 6167. 36 74. 81 275. 03 3765. 00 3839. 50 3377.40 3550. 62 527. 52 -3336. 40 0.00 O.OOG 0.00 0.00 5989880. 78 568923. 85 N 70. 38271925 W 149.43952964 M62 6415. 45 74. 81 275. 03 3830. 00 3904. 50 3616.49 3790. 05 548. 50 -3574. 91 0.00 O.OOG 0.00 0.00 5989899. 45 568685. 17 N 70. 38277626 W 149.44146897 Mc 6682. 63 74. 81 275. 03 3900. 00 3974. 50 3873.98 4047. 89 571. 10 -3831. 76 0.00 O.OOG 0.00 0.00 5989919. 56 568428. 14 N 70. 38283764 W 149.44355749 Fault Crossing 6835. 30 74. 81 275. 03 3940. 00 4014. 50 4021.11 4195. 23 584. 01 -3978. 54 0.00 O.OOG 0.00 0.00 5989931. 05 568281. 26 N 70. 38287270 W 149.44475094 Mc 6892. 56 74. 81 275. 03 3955. 00 4029. 50 4076.29 4250. 48 588. 85 -4033. 57 0.00 O.OOG 0.00 0.00 5989935. 36 568226. 18 N 70. 38288584 W 149.44519848 Na 7178. 82 74. 81 275. 03 4030. 00 4104. 50 4352.17 4526. 75 613. 06 -4308. 77 0.00 O.OOG 0.00 0.00 5989956. 91 567950. 79 N 70. 38295155 W 149.447 Nb 7293. 32 74. 81 275. 03 4060. 00 4134. 50 4462.52 4637. 25 622. 74 -4418. 85 0.00 O.OOG 0.00 0.00 5989965. 53 567840. 63 N 70. 4 38297783 W 149.44833 Nc 7465. 08 74. 81 275. 03 4105. 00 4179. 50 4628.05 4803. 01 637. 26 -4583. 97 0.00 O.OOG 0.00 0.00 5989978. 45 567675. 39 N 70. 38301724 W 149.44967395 I-100P61 Tgt 1 OA 7751 .34 74 .81 275. 03 4180 .00 4254 .50 4903.92 5079 .27 661. 47 -4859 .17 0.00 O.OOG 0.00 0.00 5990000. 00 567400 .00 N 70. 38308290 W 149.45191171 OA 7751. 38 74. 81 275. 03 4180. 01 4254. 51 4903.96 5079. 31 661. 47 -4859. 21 0.00 O.OOG 0.00 0.00 5990000. 00 567399. 96 N 70. 38308290 W 149.45191201 OBa 7961. 27 74. 81 275. 03 4235. 00 4309. 50 5106.23 5281. 86 679. 22 -5060. 99 0.00 O.OOG 0.00 0.00 5990015. 80 567198. 04 N 70. 38313103 W 149.45355274 OBb 8113. 94 74. 81 275. 03 4275. 00 4349. 50 5253.37 5429. 20 692. 13 -5207. 76 0.00 O.OOG 0.00 0.00 5990027. 29 567051. 17 N 70. 38316602 W 149.45474622 OBc 8228. 44 74. 81 275. 03 4305. 00 4379. 50 5363.72 5539. 71 701. 81 -5317. 84 0.00 O.OOG 0.00 0.00 5990035. 91 566941. 01 N 70. 38319226 W 149.45564134 OBd 8388. 75 74. 81 275. 03 4347. 00 4421. 50 5518.21 5694. 42 715. 37 -5471. 95 0.00 O.OOG 0.00 0.00 5990047. 97 566786. 79 N 70. 38322899 W 149.45689450 Crv 41100 8397 .34 74 .81 275. 03 4349 .25 4423 .75 5526.49 5702 .71 716. 10 -5480 .21 0.00 10.09G 0.00 0.00 5990048. 62 566778 .52 N 70. 38323096 W 149.45696165 8400 .00 74 .92 275. 05 4349 .94 4424 .44 5529.05 5705 .27 716. 32 -5482 .77 4.00 10.08G 3.94 0.73 5990048. 82 566775 .97 N 70. 38323157 W 149.45698244 8500 .00 78 .86 275. 76 4372 .63 4447 .13 5626.32 5802 .64 725. 50 -5579 .71 4.00 9.92G 3.94 0.71 5990057. 06 566678. 95 N 70. 38325643 W 149.45777071 8600 .00 82 .80 276. 45 4388 .57 4463 .07 5724.97 5901 .35 736. 00 -5677 .85 4.00 9.81G 3.94 0.69 5990066. 61 566580. 72 N 70. 38328492 W 149.45856876 8700 .00 86 .74 277. 14 4397 .69 4472 .19 5824.50 6000 .91 747. 78 -5776 .71 4.00 9.75G 3.94 0.68 5990077. 43 566481. 76 N 70. 38331690 W 149.45937270 90° Pt 8782. 80 90. 00 277. 70 4400. 04 4474. 54 5907.25 6083. 66 758. 46 -5858. 77 4.00 9.73G 3.94 0.68 5990087.32 566399. 61 N 70. 38334591 W 149.46004002 WeIlDesign Ver 3.1 RT-SP3.03-HF5.00 Bld( do31 rt-546) I-14\Plan I-100\Plan I-100PB1\I-100P61 (P6) Generated 12/17/2004 10:49 AM Page 2 of 3 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft de 1100 ft de de 1100 ft de 100 ft ftUS ftUS ......... .... ..., ..... ~, , .., ~ ~~:.~.~~ ~Y, Y .Yro „~~~ ..~ u iw .ov ~ vv. i o voi V.oc 8900. 00 94 .62 278 .49 4395.32 4469 .82 6024 .33 6200 .74 774.94 -5974.68 9000. 00 98 .56 279 .18 4383.83 4458 .33 6123 .64 6300 .06 790.19 -6072.82 End Crv 9055. 37 100 .75 279 .56 4374.55 4449 .05 6178 .20 6354 .63 799.07 -6126.67 OBd 9240. 66 100. 75 279. 56 4340.00 4414. 50 6360. 18 6536. 67 829.31 -6306.18 OBc 10018. 30 100. 75 279. 56 4195.00 4269. 50 7123. 91 7300. 68 956.20 -7059.57 OBb 10340. 08 100. 75 279. 56 4135.00 4209. 50 7439. 94 7616. 82 1008.71 -7371.32 Ot3a 10742. 30 100. 75 279. 56 4060.00 4134. 50 7834. 98 8011. 99 1074.34 -7761.00 OA 11080. 18 100. 75 279. 56 3997.00 4071. 50 8166. 81 8343. 93 1129.47 -8088.34 Nc 11251. 79 100. 75 279. 56 3965.00 4039. 50 8335. 36 8512. 54 1157.48 -8254.61 Nb 11546. 76 100. 75 279. 56 3910.00 3984. 50 8625. 05 8802. 34 1205.61 -8540.37 TD/Na 11654.02 ~" 100.75 279.56 3890.00 3964.50 8730.39 8907.71 1223.11 -8644.29 Leaal Description: Surface : 3217 FSL 3945 FEL S20 T12N R11E UM Target 1 OA : 3877 FSL 3522 FEL S19 T12N R11E UM TD / Na / BHL : 4435 FSL 2484 FEL S24 T12N R10E UM Northing (Yl fftUSl Eastina (Xl (ftUSI 5989385.56 572264.87 5990000.00 567400.00 5990525.00 563610.00 H .VV y.IJV J.~'1 V.bb 7yyUVby .4Lf bbb3t5L .b4 N /V..S75:S:SbLL"I VV "14`J.4bUl /tfbl 4 .00 9.76G 3.94 0.68 5990102 .68 566283 .56 N 70.38339068 W 149.46098257 4 .00 9.84G 3.94 0.69 5990116 .98 566185 .28 N 70.38343212 W 149.46178066 4 .00 O.OOG 3.94 0.70 5990125 .34 566131 .36 N 70.38345627 W 149.46221858 0. 00 O.OOG 0.00 0.00 5990153. 84 565951. 58 N 70.38353846 W 149.46367841 0. 00 O.OOG 0.00 0.00 5990273. 43 565197. 07 N 70.38388328 W 149.46980530 0. 00 O.OOG 0.00 0.00 5990322. 92 564884. 86 N 70.38402590 W 149.47234063 0. 00 O.OOG 0.00 0.00 5990384. 78 564494. 60 N 70.38420413 W 149.47550984 0. 00 O.OOG 0.00 0.00 5990436. 75 564166. 77 N 70.38435380 W 149.4781720 0. 00 O.OOG 0.00. 0.00 5990463. 14 564000. 26 N 70.38442981 W 149.47952 0. 00 O.OOG 0.00 0.00 5990508. 50 563714. 07 N 70.38456042 W 149.48184 0.00 O.OOG 0.00 0.00 5990525.00 563610.00 N 70.38460791 W 149.48269358 WeIlDesign Ver 3.1 RT-SP3.03-HF5.00 Bld( do31 rt-546) I-14\Plan I-100\Plan I-100P61\I-100P61 (P6) Generated 12/17/2004 10:49 AM Page 3 of 3 ~ ~ O O O O O W E 8 °n $ 4 ~ ~ t E ~~ O o O o z ,~ „^'^~ ~• p a g <8 ~ ~y O O O ~ n ~ m Q u"'i $ ~Yo O ~ $sLL in ~ ~ 9 - 3e ~~s ~ g~~ m ~ - ~ O O s $ L $ a ~_ @ Y & `o ~ M 8 ~$ 0 O O O N rro ~~ a $e `r o /~ W ~ ~ O o 0 ~ r 1 _ nR 8 ~ ~ ~ W 5 O o S o 0 0 O ~ N M V ilO O O B R i i i 1 IB tl IA 1 la EB B i~8 td1 tEBEE ;/ 1 t % 1 1 1 i %i 1 11 1~ # ' ~I BkP 41F£ ~ / t t% ! 1 P 3 ~1 # IA m B d .. .... it "T'1 Rttf / 1 !~ d 1 E # =1 t /A # E~ 1 tl tl B41 f 11ti t 1 % i 1 f ! %t 1 BI } 1 ik 1 le Itl Iift IRI B E- i i i 1 %B i li jt t= it t it £ sii& 1 F i i f t :i 1 BB t 1 p ` S>;: tl 1 I~A PIf #dit 1 f A 1 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U ... / IL c ..:..........<......,,,,e...,,..,.,.... 0 U 9 IL Q 0 w m a °o o° a z U Z U O C W i a i `N a ;i °o o° °o ° °o °o M N ~ ~ N «< N ~ll)OOOI~~ui)~ . a~eog g »> O O O ° 0 0 0 N ° ° ° M A A n W O ~ O O ~ O C o ~ 0 0 ~~ v O O O O O ° ° O O ao BP Alaska Anticollision Report ~, Company: BP Amoco Date: 12/17/2004 Time: 11:13:15 Page: 1 Field: Prudhoe Bay Reference Site: PB I Pad Co-ordinate(NE) Reference: Well: Plan I-100, True North Reference Well: Plan I-100 Vertical (TVD) Reference: I-100 Plan 74.5 Reference Wellpath: Plan I-100PB1 Db: Sybase NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 27.09 to 11654.02 ft Scan Method: Trav Cylinder North Maximum Radius:10000.00 ft Error Surface: Ellipse + Casing Survey Program for DeSnifive Wellpath Date: 12/9/2004 Validated: No Version: 4 Planned From To Survey Toolcode Tool Name ft ft 27.09 1400.00 Planned: Plan #6 V1 MWD MWD -Standard 27.09 11654.02 Planned: Plan #6 V1 MWD+IFR+MS MWD +IFR + Multi Station Casing Points M11D TVD Diameter HolcSize dame ft ft in in ~ -__ - _ - 2473.99 2444.50 9.625 12.250 9 5/8" _ 11654.02 3964.50 8.750 8.750 8-3/4" open Summary <---------------- Of[set Wellpath --------> Reference Offset Ctr-Ctr No-Go Allowable ~~ Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft NWE4-01 NWE4-01 NWE4-01 V18 840.26 850.00 37.69 13.23 24.46 Pass: Major Risk /~ 3 _._ 0 _ o 4 y _. _.. ~ 3 ` z ~~ -., ~ o ~ ~ W o0 a~^COo ~ 8 g ~ ~ ~ ~~ ~~ awwa ~~ b ~.. ~ v'3 ~ \ , .. ,. ~~ a I-100 (P5 Survey Name 1 Date: I-100 (PS) I December 17, 2004 Tort I AHD 1 DDI I ERD ratio: 99.308° / 6833.73 ft / 4007.417 10.586 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaULong: N 70.38128014, W 149.41240200 Location Grid NIE YIX: N 5989385.560 ftUS, E 572264.870 ftUS Grid Convergence Angle: +0.55348884° Schlumberger Report Date: December 17, 2004 Survey 1 DLS Computation Method: ---- Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 43.47° Field: Structure I Slot: Prudhoe Bay Unit - WOA I-Pad / I-14 ® Vertical Section Origin: TVD Reference Datum: N 0:000 ft, E 0:000 ft Rotary Table Well: Borehole: Plan I-100 w ®' Plan I-100 TVD Reference Elevation: Sea Bed 1 Ground Level Elevation: 74.50 ft relative to MSL 47.41 ft relative to MSL UWIIAPM: 50029 Magnegc Declination: 24 493° Total Field Strength: 57605.998 nT Magnetic Dip: 80.821 ° Declination Date: March 31, 2005 Magnetic Declination Model: BGGM 2004 North Reference: True North Total Corr Mag North -> True North: +24.493° Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole NS EW DLS Tool Face Build Rate Walk Rate Northing Easting Latitude Lon itude Depth Section Departure g ft de de k ft ft ft ft k de 1100 ft de de 1100 k de 100 ft ftUS ftUS KC1P f:n/ a/1M 9dtlZ ao 1 ~ nn ~~~ nn ~zao vo ona~ Qo ,nom n~ nn~ w ---~ -~- •-- •-°--° •~•-- -•~• ~~ ~~~~~ ~~ e~~~ •~~ ~~~• ~~ ~- - ~ v.v~ IYY.O/V V.VV V.VV oy0aOL4 AI O/L7 tl6 .tl3 N /U. SiSI`JSb4i5 VV 74y.47376b// 2500.00 14.79 276. 57 2395. 13 2469 .63 108. 53 296 .95 240. 06 -95 .48 4.20 144.32G -3.42 9.47 5989624. 66 572167 .09 N 70. 38193595 W 149.41317826 2600.00 11.64 288. 80 2492. 49 2566 .99 96. 65 319 .73 244. 77 -117 .72 4.20 132.41 G -3.16 12.23 5989629. 16 572144 .80 N 70. 38194882 W 149.41335910 2700.00 9.33 308. 28 2590. 84 2665 .34 91. 71 337 .76 253. 04 -133 .63 4.20 113.23G -2.31 19.49 5989637. 28 572128 .81 N 70. 38197142 W 149.41348852 2800.00 8.58 335. 10 2689. 67 2764 .17 93. 72 353 .05 264. 84 -143 .14 4.20 86.73G -0.75 26.81 5989648. 98 572119 .19 N 70. 38200364 W 149.41356581 2900.00 9.76 0. 65 2788. 43 2862 .93 102. 69 368 .73 280. 08 -146 .19 4.20 61.49G 1.18 25.56 5989664. 19 572116 .00 N 70. 38204529 W 149.41359058 3000.00 12.32 18. 21 2886. 59 2961 .09 118. 57 387 .73 298. 70 -142 .75 4.20 44.26G 2.56 17.55 5989682. 84 572119 .25 N 70. 38209616 W 149.41356267 3100.00 15.60 29. 16 2983. 64 3058 .14 141. 26 411 .79 320. 60 -132 .86 4.20 33.62G 3.28 10.95 5989704. 83 572128 .93 N 70. 38215597 W 149.41348225 3200.00 19.24 36. 23 3079. 05 3153 .55 170. 65 441 .68 345. 64 -116 .57 4.20 26.87G 3.63 7.07 5989730. 03 572144 .98 N 70. 38222440 W 149.41334975 3212.14 19.70 36. 91 3090. 50 3165 .00 174. 67 445 .73 348. 89 -114 .15 4.20 O.OOG 3.76 5.63 5989733. 30 572147 .36 N 70. 38223328 W 149.41333014 3212.59 19.70 36. 91 3090. 92 3165 .42 174. 82 445 .88 349. 01 -114 .06 0.00 O.OOG 0.00 0.00 5989733. 42 572147 .45 N 70. 38223360 W 149.41332941 3300.00 23.19 36. 91 3172. 27 3246 .77 206. 56 477 .83 374. 56 -94 .87 4.00 O.OOG 4.00 0.00 5989759. 15 572166 .39 N 70. 38230340 W 149.41317339 3400.00 27.19 36. 91 3262. 74 3337 .24 248. 84 520 .39 408. 59 -69 .32 4.00 O.OOG 4.00 0.00 5989793. 42 572191 .62 N 70. 38239636 W 149.41 3500.00 31.19 36. 91 3350. 02 3424 .52 297. 28 569 .15 447. 58 -40 .03 4.00 O.OOG 4.00 0.00 5989832. 69 572220 .52 N 70. 2 38250288 W 149.412 3600.00 35.19 36. 91 3433. 68 3508 .18 351. 66 623 .88 491. 34 -7 .16 4.00 O.OOG 4.00 0.00 5989876. 76 572252 .97 N 70. 38262244 W 149.4124 3700.00 39.19 36. 91 3513. 33 3587 .83 411. 70 684 .31 539. 67 29 .14 4.00 O.OOG 4.00 0.00 5989925. 43 572288 .79 N 70. 38275445 W 149.41216508 3800.00 43.19 36. 91 3588. 56 3663 .06 477. 12 750 .16 592. 32 68 .68 4.00 O.OOG 4.00 0.00 5989978. 45 572327 .82 N 70. 38289828 W 149.41184355 Fault Crossing 3828.99 44.35 36. 91 3609. 50 3684. 00 497. 04 770. 21 608. 35 80. 73 4.00 O.OOG 4.00 0.00 5989994. 61 572339. 71 N 70. 38294209 W 149.41174561 I-100 Tgt Ma 3829.69 44.38 36. 91 3610. 00 3684 .50 497. 53 770 .70 608. 74 81 .02 4.00 85.96G 4.00 0.00 5989995. 00 572340 .00 N 70. 38294316 W 149.41174322 3900.00 44.65 40. 90 3660. 14 3734 .64 546. 64 819 .98 647. 08 111 .97 4.00 83.12G 0.38 5.68 5990033. 63 572370 .57 N 70. 38304790 W 149.41149158 4000.00 45.26 46. 50 3730. 94 3805 .44 617. 24 890 .61 698. 11 160 .76 4.00 79.16G 0.62 5.59 5990085. 12 572418 .86 N 70. 38318730 W 149.41109486 End Crv 4067.58 45.83 50. 20 3778. 27 3852 .77 665. 29 938 .84 730. 15 196 .80 4.00 O.OOG 0.84 5.48 5990117. 51 572454 .59 N 70. 38327484 W 149.41080182 I-100 Tgt Kup 8045.69 45.83 50. 20 6550. 00 6624 .50 3499. 19 3792 .24 2556. 73 2389 .17 0.00 O.OOG 0.00 0.00 5991965. 00 574629 .00 N 70. 38826381 W 149.39297088 TD / 7" Csg Pt 8345.68 45.83 50. 20 6759. 02 6833 .52 3712. 90 4007 .42 2694. 47 2554 .50 0.00 O.OOG 0.00 0.00 5992104. 32 574792 .98 N 70. 38863997 W 149.39162585 Legal Description: Northing IYl fftUSl Easting fXl PftUSI Surface : 3217 FSL 3945 FEL S20 T12N R 11 E UM 5989385 .56 572264.87 I-100 Tgt Ma : 3826 FSL 3862 FEL S20 T12N R 11 E UM 5989995 .00 572340.00 I-100 Tgt Kup : 494 FSL 1547 FEL S17 T12N R1 1 E UM 5991965 .00 574629.00 BHL : 631 FSL 1382 FEL S17 T12N R1 1E UM 5992104 .32 574792.98 WeIlDesign Ver 3.1 RT-SP3.03-HF5.00 Bld( do31 rt-546) I-14\Plan I-100\Plan I-100\I-100 (P5) Generated 12/17/2004 11:40 AM Page 1 of 1 t- umd WELL I-100 (P5) FIELD Prudhoe Bay Unit - WOA STRUCNRE I-Pad MagneSC ParemeWrs Su Kam Locaem NA02] Nlaska State PMnes. Zone 04, US Feel Miamtlaneaus MoOel: BGGM 2001 Dip: 80.821° Date: Marcb 31, ZOD5 Lal: N)02252.808 NaMing'. 59693&5.56 XUS Grie Cmv: +0.55318 884° Sbt: L14 ND Re/: Rotary Table ()d SOft above MSL) Meg Dec: +24A93° F5: 5)606.0 nT Lon: W149 24 44 64] Easlin9: 5]2264.8]flUS Bmle Fad: 09999059323 Plan: 41001P5) Srvy Date: December t], 2004 0 600 1200 1800. 2400 3000 3600 2400 3000 F100PB1 0 0 c 3600 4200 N ~ 4800 0 5400 6000 6600 )0 )0 10 10 ~0 0 0 0 0 600 1200 1800 2400 3000 3600 Vertical Section (ft) Azim = 43.47°, Scale = 1(in):600(ft) Origin = 0 N/-S, 0 E/-W Sc rger WELL x.100 (P5) FIELD Prudhoe Bay Unit - WOA BTRDCTDRE I-Pad MaBnete Parameters Surtaca Loutbn NAD2] Rlaeka Stale Planes, Zone 04, US Feel Miscelleneaua Motlel: BGGM 2004 Dip: 80.921 ° Date: Merl 31,2005 Lal: N]0 22 62.fi08 NOMIne: 5909305.56 M1S Gritl Com: b 56340804° Sbt: 114 ND Rat Rotary Table ()d.50 k above b 9L) MaB Dec: X24.493° FS: 5)606.0 nT Lan'. W1492444.fi4] Eaating: 5]22648]%US Sule Feci'. 0.9899058323 PHn: I-100 (P6) Srvy Dale: Dezember l],2W4 -600 0 600 1200 1800 2400 3000 2400 n n 1800 z 0 0 c ~ 1200 c~ v v v 600 0 2400 1800 1200 600 0 • • -600 0 600 1200 1800 2400 3000 «< W Scale = 1(in):600(ft) E »> Plan I-100/Plan I-100 _- _ _ ', _ ~, __ _. _._ ~ ~. 00 ~ \ .. ~. ~. ~ / ~ _ ~. ~~:,. ~ 0 _ -- ~ ___ , ~ 0 ~__ -- _ _ __-~---- , 3 - \~ o 0 ___ , 5 ` , ~s ; , - oo , 0 ~. ~~ 6 _ _ 6000 ;, ,+SOO N ;,_ _ _ __ ~ _ _ ~ ~~0 q ~° ° ; ~ ~° o _ ' ~ ° o 0 - ~ 500 "-' ~ 0 ° o ---- NWE4-Ol(NWE4-0[) PlanI-100(PlanI-]OOPBI) PIanI-100 BP Alaska Anticollision Report Company: BP Amoco - - ---- Date: 12/17/2004 'l'ime: 11:59:16 Page: 1 Field: Prudhoe Bay Reference Site: PB 1 Pad Co-ordinate(NE) Reference: Well: Plan I-100, True North Reference Nell: Plan I-100 Vertic:il (TVD) Reference: I-100 Plan 74.5 Reference Welipath: Plan I-100 Db: Sybase - - - NO GLOBAL SCAN: Using user defined selection & scan criteria _-__ Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 2493.99 to 8345.68 ft Scan Method: Trav Cylinder North Maximum Radius: 10000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Welipath Date: 12/17/2004 .Validated: No Version: 4 Planned From To Survey Toolcode Tool Name ft ft 27.09 2493.99 Planned: Plan #6 V1 (0) MWD+IFR+MS MWD +IFR + Multi Station 2493.99 8345.68 Planned: Plan #5 V1 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diamctcr Hole Sizc Name ~~ ft ft in in 2473.99 2444.50 9.625 12.250 9 5/8" 8345.68 6833.52 7.000 8.750 7" Summary <-------------- Offset Welipath ----------> Reference Offset Ctr-Ctr No-Go Allowable Site Weil Welipath MD MD Distance Area Deviation Wareing ft ft ft ft ft , NWE4-01 NWE4-01 NWE4-01 V18 2784.14 3250.00 1310.04 43.31 1266.72 Pass: Major Risk ~ PB I Pad Plan I-100 Plan I-100PB1 V4 Plan: 2500.00 2500.00 0.03 36.72 -36.68 FAIL: Major Risk Field: Prudhoe Bay Site: PB I Pad Well: Plan I-100 Wellpath: Plan I-100 0 100 Travclling Cylinder Azirunth (TFO+pZI) [dcg] ve Centre [o Ccntrc Sepazation [100fi/in] • I-100 Well Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: • Gas hydrates may be encountered near the base of the Permafrost at 1730' MD and near the TD hole section as well. The closest offset well, NWE 4-01 encountered background gas of 500 units and connection gas of 2500 units while drilling below the Permafrost. • Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. Schrader Hole Section: • The closest offset well NWE 4-01 had a LOT of 13.6 ppg EMW at the surface casing shoe set just below the SV-1 sands. This gives a kick tolerance of 86 bbls with 9.4 mud in the wellbore while drilling the Schrader interval. We hope to achieve at least a 12.9 ppg LOT in this well to satisfy the 10.0 ppg EMW of Kuparuk B formation which will be drilled through on the second leg of the well. This will provide a 25 bbl kick tolerance for drilling this interval. • The Schrader hole section will be drilled with a recommended mud weight of 9.4 ppg to ensure hole stability in the 75-100 degree wellbore and to cover the Schrader 8.8+ ppg pore pressure. • Two faults will be penetrated in the Schrader wellbore. The first at 3350' TVDss has an estimated throw of 30' and the second at 3905' TVD ss has an estimated throw of 100'. Lost circulation is considered a minimum risk in this wellbore, however the Lost Circulation Decision Tree should be consulted should losses be encountered. Kuparuk Hole Section: • The Kuparuk hole section will be drilled with a recommended mud weight of 10.2 ppg once the HRZ horizon is penetrated. This mud weight is necessary to cover the expected 10.0 ppg EMW of the Kuparuk B formation which will be penetrated at the base of the wellbore. • One fault is expected to be crossed in the Kuparuk wellbore. This fault should be encountered at 3600' TVD ss. It was encountered in the offset well NWE 4-01 and no losses or operational problems were experienced. HYDROGEN SULFIDE - H2S f • This drill-site not designated as an H2S site. However as a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. Version 1.0 Rigsite Hazards and Contingencies w • ~ TRAANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~jQli/ I- /Od PTD# ~~.,a/a Development Service Exploration Stratigraphic CHECK WAAT ADD-OHS "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 are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(1), all (PH) records, data and logs acquired for the pilot bole must be clearly differentiated yin both ~S name name on permit plus Ply ~+~and API number (SO~cZ2. - 70/80) from records, data and logs acquired . for well (name on permit). SPACING The permit is approved subject •to full EXCEPTION compliance wish 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing ~ exception. (Company Hamel assumes the liability of any protest to ibe spacing .exception that may occur. DRY DITCH ~ All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 0' sample intervals through target zones. :szy,~ ~d .~~ ^^ N : : , m o a> d : : a N : ~ ~ ~ , L ~ ( , Q ~ ~ , , ~ ~ ~ ~ , O ~ , m ~ , o d , ~ ~ O a. ~, : O ~ ~ ~ 0: I o 'c O ~ ° a' 3 ~ °, d o' : w' °, r: Z ~, L ~ ~, ~ ° '9: - '- , } m o ~ ~ ~ ~ a ~ , O _ O, m' ~ , ~ ~, ~ N N. ~, a, d 0. ~ ~ o ~ m ~ N , m E, c n . ~ 3 , E ° rn ° ~ ~ W N O O- °o: O, uj Z • ~ ~ ~ 2. O. ~ v ~ N. ~, ~ 3 O. c. ~ ~ ~ Z. tl ~ ~ ~ ~ M. ~ Q, ~ ~ ~ Z. Z. ~~ ~~ Z, ~: N, } N, ~ N, N,~ ~~ N, N, N, N, ~ ~ >' ~ ~ ~ ~' N N, N, >~ ~ ~ N ~•• Q, Q, Q, Q,~ Z Z Z Z N, N, N, O, N, N, N, Q, N, N, N, O, N, N, N, O, Q. 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(O I~ O ~ O c- N M sf LO (O 1~ O O O M i ~ M M M M M M ~ O ~ - N M V ~ (O I~ W O ~ ~ ~ ~ ~ ~ ~ ~ ~ N N N N N N N N N N M M M _ o 0 0 ~ '~' N I +O.' N e0+ N U C Qr O O ~ O ~ O 0 O) 01 y Q r ~ I C .L ~ ~ O' J J N y c api CT7 '^ ~ V o ~. J ~# o E' Q a c 'a a~ ~ a s U ~1 w ~ o ~ a Q Q ~ w Q~ ~ Q~ i~J Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify rending 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. aos - ota Oil Viscosity Prediction vs. Depth in the I-100 Well (Orion Field, North Slope, Alaska) Based on Gas Chromatographic Analyses of Sidewall Core Extracts (OT Report No. 06-415) by Mark A. McCaffrey, Brooks A. Patterson, and Mark A. Beeunas OilTracers, L.L.C. Prepared for BP Exploration Alaska, Inc. CONFIDENTIAL May 30, 2006 OilTracers, L.L.C 3500 Oak Lawn, Suite 400 Dallas, TX 75219 Telephone: 214-584-9169 Fax:214-523-9695 e-mail: info@oiltracers.com OilTracers L.L.C. OBJECTIVES This project develops 18 mathematical equations (transforms) that relate oil viscosity to specific gas chromatography characteristics of oils in the Orion field. These transforms are then used to predict oil viscosity in frozen sidewall cores (SWC) from Well L- 100 from GC analyses of the SWC extracts. For the Ugnu, SB-Mbl, SB-Mb2, and SB-Nb sands, viscosity is predicted at 3 temperatures (95 °F, 85 °F, and 75 °F); for the SB-NC, SB-OA, SB-OBa, SB-OBb, SB-OBc, SB-OBD, SB-OBe, and SB-OBf sands, the viscosity is predicted at 1 temperature: (90°F) CONCLUSIONS The predicted viscosities of oil in the SWC from well I-100 are provided in Figure la (SB-Nc to SB-OBf sands @ 90°F) and Figures lb-lg (UG-3 to SB-Nb sands @ 95°F, 85°F, and 75°F). Numerical results are provided in Tables 4a-4d. For_ an~given sample, please note the RANGE of viscosity values predicted for that sample from the various transforms (Tables 4a- 4d), since that range provides one measure of the uncertainty associated with the predicted viscosity value for that sample. • Predicted viscosities of the extracted oil from the SWC's form two groups; i. a deep (> -3886 ft. TVDSS) low-viscosity group including SWC extracts from Nb through OBf sands and ii. a shallow (< -3867ft. TVDSS) high-viscosity group including SWC extracts from UG through Nb sands Note that the SWC extracts from Nb sands are listed in both groups since they appear transitional. However, significantly different viscosities are predicted for the Nb samples when they are included in the shallower vs. deeper groups (tables 4a and 4b). An argument for including them in the deeper groups is that all of the calibration oils from the shallower group are M sand oils. However, all three Nb extracts lack a significant light-end component (Appendix 1) suggesting that they may best fit in the shallower group. • Predicted oil viscosity in the deeper low-viscosity group of SWC's from the Nc through the OBf sands generally decreases with depth (Figure la). However, there are some excursions from this trend. Specifically - the lowest predicted viscosities (19-52 cSt @ 90 °F) occur in the OBb, lower OBd, and OBf sands, Oil Viscosity in the I-100 Well p. 2 OilTracers, LLC the highest predicted viscosity occurs in the Nc sand (188.8 cSt @ 90 °F), and intermediate viscosities (62-92 cSt @ 90 °F) occur in the OA, OBa, OBc, upper OBd, and OBe sands. Predicted oil viscosity in the shallow high-viscosity group of SWC's ranges from 4996 to 6742 cp @ 95°F (Figure lb). Oil in the SWC from the UG-3 sand has the highest predicted viscosity (6742 cp @ 95°F), whereas oil from the Nb sand has the lowest predicted viscosity (4996 cp @ 95°F). Even though the deepest SWC has the lowest viscosity there is not a distinct depth trend of decreasing viscosity in this group of SWC's, since predicted viscosities fluctuate above and below 6000 cp @ 95°F in all but one of the sands. Note that the units in which the Nc - OBf sand data are reported (cSt @ 90 °F) are different than the units in which the UG - Nb sand data are reported (cp @ 95°F, 85°F, and 75°F). The difference in units is due to differences in the viscosity data available for the OA-Nb calibration oils vs. the M sand calibration oils (Tables 2a-2b). In the deeper sands in the Orion field (e.g., Nc and O sands), the primary control on oil viscosity variations is variability in the relative abundance of a condensate-like secondary oil charge that reduces the viscosity of the primary, biodegraded charge of oil. This conclusion is suggested by the extremely high correlation (Figures 2-4) of Orion oil viscosity with GC parameters that are a ratio of a light-end component (n-octane or n-C8) and a heavy end component of the oil (as measured by the abundance of three aromatic compounds that elute from the GC in the C1~-CZO molecular weight range). In the shallower Ugnu, M, and Nb sands, the primary control on oil viscosity variations is variability in the extent of biodegradation of the primary oil charge. This conclusion is suggested by the high correlation for three M-sand oils of oil viscosity vs. 5 GC parameters that are ratios of biomarker compounds with differing susceptibilities to biodegradation (Figures 5-19). • Comparison of predicted viscosities from L-250 and L-218i SWC (OilTracers Reports OS-318 and 05-345, respectively) with data reported here for the I-100 SWC's indicates that: i. I-100 and L-2181 N and O sands contain oils with similar ranges of predicted viscosity (19-738 and 32-600 cSt @ 90 °F, respectively), which generally decrease with depth. L-250 N and O sand extracts have lower predicted viscosities (49-161 cSt @ 90 °F) and no apparent depth trend, since OA extracts predicted viscosities in that well are approximately equal to Nb extract viscosities (average viscosities = 160 and 141 cSt @ °90 F, respectively). Oil Viscosity in the I-100 Well p. 3 OilTracers, LLC ii. I-100 UG - M sand SWC extracts have a lower and more narrow range of viscosities (4996-6742 cp @ 95 °F) than either L-250 (4655-14191 @95 °F) or L-218i (range = 4683-15634 @ 95 °F, with all extracts except Ma having predicted viscosities > 10,000 cp @ 95 °F). iii. The I-100 profile of predicted viscosity does NOT show a decrease in viscosity as one moves from the Mbl to the unit right above it. In contrast, in both the L-218 and L-250 wells, there was a significant decrease in viscosity as one moves from the Mbl to the unit right above it. INTRODUCTION: Both Drozd (1995) and Smalley et al. (1996) have noted that the Schrader Bluff oils in the Milne Point field consist of a mix of biodegraded oil and a subsequently added, non- degraded secondary charge of condensate-like material. Similar observations have been made on the West Sak field to the southeast, where the secondary charge has been interpreted to be a retrograde condensate formed from condensate-rich gas leaking from the underlying Kuparuk accumulation (Masterson, 2001; Masterson, et al., 2001). Drozd (1995) and Smalley et al. (1996) noted that lateral and vertical variations in oil quality (viscosity, gravity) in the Milne Point field are controlled by two phenomena: (1) Lateral and vertical variations in the extent of oil biodegradation (a process that increases oil viscosity and decreases oil gravity), and (2) Lateral and vertical variations in the relative abundance of the secondary, condensate- like charge, a material that reduces the oil viscosity and raises the oil gravity. At Milne Point, the abundance of the secondary charge varies from 0-20 wt. % (Smalley et al., 1996). McCaffrey and Beeunas (2004) noted a similar two-stage charge history for Orion field oils and developed transforms that relate viscosity to the relative abundance of the secondary condensate-like charge that forms the light tends of many Orion oils. Prediction of Oil Viscosity from SWC Material The reason that fluid properties of oil in SWC material must be predicted geochemically and cannot be measured directly is that: Under most circumstances, insufficient oil can be centrifuged from either conventional core or sidewall cores to allow physical properties to be directly measured. Oil Viscosity in the I-100 Well p. 4 OilTracers, LLC • Evaporative loss oflow-molecular-weight hydrocarbons from SWC during handling and centrifugation would raise the apparent viscosity and lower the apparent gravity of oil centrifuged from the core. • Using solvent (in place of centrifugation) to extract oil from SWC will cause the extract to be of no use for direct gravity and viscosity measurements, since it is not possible to remove all the solvent from the extract without also losing much of the light ends of the oil. Therefore, oil properties must be inferred by using one or more transforms to convert a geochemical analysis of a core extract into a calculated gravity and/or viscosity value. Transforms were developed using a group of 13 oils from the Orion Field. The measured viscosities of these oils are listed in Table 2a and 2b. Ten of the oils have kinematic viscosity (cSt @ 90 °F), whereas 3 of the oil have dynamic viscosity (cp @ 75, 85, and 95 °F). Transforms were calculated by comparing a select group of gas chromatography ratios to the viscosity data (Figures 2-19). ANALYTICAL METHODS 38 SWC (Table 1) from the I-100 well were rigorously preserved following collection by: i. Immediately wrapping the SWC in tin foil after collection, and then placing them in sample bottles. ii. Immediately sealing the bottles with Teflon tape. iii. Immediately freezing the bottles, shipping them frozen, and then storing them in the lab frozen. The solvent extracts of the SWC were analyzed by Gas Chromatography (GC) at Baseline Resolution (Shenandoah, Texas) using a Hewlett Packard GC equipped with a 60 m DB-1 column (J&W Scientific); the injector was at 275°C, and the heating program was: 35°C (hold 5 minutes), 3°/min ramp to 320°C (hold for 20 minutes). The carrier gas was hydrogen. Solvent extracts of the core plugs were NOT blown to dryness, but rather were injected into the GC in solvent (carbon disulfide) to minimize the loss of light ends. RESULTS AND DISCUSSION One page plots of the GC traces of the SWC are reproduced in Appendix 1. One page plots of the GC traces of various the produced oils are reproduced in Appendix 2. The measured viscosities of the oils are listed in Tables 2a and 2b. In the deeper sands in the Orion field (e.g., Nc and O sands), the primary control on oil viscosity variations is variability in the relative abundance of a condensate-like secondary oil charge that reduces the viscosity of the primary, biodegraded charge of oil. This conclusion is suggested by the extremely high correlation (Figures 2-4) of Orion oil viscosity with GC parameters that are a ratio of a light-end component (n- Oil Viscosity in the I-100 Well p OilTracers, LLC octane or n-C8) and a heavy end component of the oil (as measured by the abundance of three aromatic compounds that elute from the GC in the C»-CZO molecular weight range). In the shallower Ugnu, M, and Nc sands, the primary control on oil viscosity variations is variability in the extent of biodegradation of the primary oil charge. This conclusion is suggested by the high correlation for three M-sand oils of oil viscosity vs. 5 GC parameters that are ratios of biomarker compounds with differing susceptibilities to biodegradation (Figures 5-19). The predicted viscosities of oil in the SWC from well I-100 are provided in Figure la (SB-Nc to SB-OBf sands @ 90°F) and Figure lb-lg (UG-3 to SB-Nb sands @ 95 °F, 85 °F, and 75 °F). Numerical results are provided in Tables 4a-d. For any liven sample, please note the RANGE of viscosity values predicted for that sample from the varioustransforms (Tables 4a-4d), since that range provides one measure of the uncertainty associated with the predicted viscosity value for that sample. Predicted viscosities of the extracted oil from the SWC's form two groups; iii. a deep (> -3886 ft. TVDSS) low-viscosity group including SWC extracts from Nb through OBf sands and iv. a shallow (< -3867ft. TVDSS) high-viscosity group including SWC extracts from UG through Nb sands Note that the SWC extracts from Nb sands are listed in both groups since they appear transitional. However, significantly different viscosities are predicted for the Nb samples when they are included in the shallower vs. deeper groups (tables 4a and 4b). An argument for including them in the deeper groups is that all of the calibration oils from the shallower group are M sand oils. However, all three Nb extracts lack a significant light-end component (Appendix 1) suggesting that they may best fit in the shallower group. Predicted oil viscosity in the deeper low-viscosity group of SWC's from the Nc through the OBf sands generally decreases with depth (Figure la). However, there are some excursions from this trend. Specifically - the lowest predicted viscosities (19-52 cSt @ 90 °F) occur in the OBb, lower OBd, and OBf sands, - the highest predicted viscosity occurs in the Nc sand (188.8 cSt @ 90 °F), and - intermediate viscosities (62-92 cSt @ 90 °F) occur in the OA, OBa, OBc, upper OBd, and OBe sands. Predicted oil viscosity in the shallow high-viscosity group of SWC's ranges from 4996 to 6742 cp @ 95°F (Figure lb). Oil in the SWC from the UG-3 sand has the highest predicted viscosity (6742 cp @ 95°F), whereas oil from the Nb sand has the lowest predicted viscosity (4996 cp @ 95°F). Even though the deepest SWC has the lowest viscosity there is not a distinct depth trend of decreasing viscosity in this group of SWC's as predicted viscosities fluctuate above and below 6000 cp @ 95°F Oil Viscosity in the I-100 Well p. 6 OilTracers, LLC in all but one of the sands. Note that the units in which the Nc - OBf sand data are reported (cSt @ 90 °F) are different than the units in which the UG - Nb sand data are reported (cp @ 95°F, 85°F, and 75°F). The difference in units is due to differences in the viscosity data available for the OA-Nb calibration oils vs. the M sand calibration oils (Tables 2a-2b). Comparison of predicted viscosities from L-250 and L-2181 SWC (OilTracers Reports OS-318 and OS-345, respectively) with data reported here for the I-100 SWC's indicates that: I-100 and L-218i N and O sands contain oils with similar viscosity ranges (19-738 and 32-600 cSt @ 90 °F, respectively), which generally decrease with depth. L- 250 Nand Osand extracts have lower predicted viscosities (49-161 cSt @ 90 °F) and no apparent depth trend as OA extracts are approximately equal to Nb extract viscosities (average viscosities = 160 and 141 cSt @ °90 F, respectively). ii. I-100 UG - M sand SWC extracts have a lower and more narrow range of viscosities (4996-6742 cp @ 95 °F) than either L-250 (4655-14191 @95 °F) or L- 218i (range = 4683-15634 @ 95 °F, with all extracts except Ma > 10,000 @ 95 ° F. iii. The I-100 profile of predicted viscosity does NOT show a decrease in viscosity as one moves from the Mbl to the unit right above it. In contrast, in both the L-218 and L-250 wells, there was a significant decrease in viscosity as one moves from the Mb 1 to the unit right above it. REFERENCES D. K. Baskin and M. A. McCaffrey (2003) Geochemical Evaluation of Core Extracts from Well V-111 PB1: Implications for Oil Quality Variations and Vertical Reservoir Continuity; OilTracers Report No. 03 142, September 14, 2003. Drozd, R. J. (1995) Preliminary geochemical assessment of sixteen Schrader Bluff oil, 1995 Sampling Program. Westport Technology Center International Report # WTCI-95-154 (September, 1995). Masterson, W. D., 2001, Petroleum Filling History of Central Alaskan North Slope Fields: Ph.D. thesis, University of Texas at Dallas, Dallas (May 2001), 159 p. Masterson, W. D., L. I. P. Dzou, A. G. Holba, A. L. Fincannon, and L. Ellis, 2001, Evidence for biodegradation and evaporative fractionation in West Sak, Kuparuk, and Prudhoe Bay field areas, North Slope, Alaska: Organic Geochemistry, v. 32, p. 411-441. McCaffrey M. A. (2003) Geochemical Characterization of Oil from S-33i Sidewall Cores, Milne Point Field, North Slope Alaska (OT Report No. 03-103, March 21, 2003). Oil Viscosity in the I-100 Well p. 7 OilTracers, LLC McCaffrey M. A. and M. A. Beeunas (2004) New Tools for Oil Viscosity Prediction in the Orion Field, North Slope, Alaska: Viscosity Transforms Based on Gas Chromatographic Analyses of Core Extracts (OT Report No. 04-171, February 25, 2004). Smalley, P. C., N. S. Goodwin, J. F. Dillon, C. R. Bidinger, and R. J. Drozd, 1996, New Tools Target Oil Quality Sweetspots in Viscous Oil Accumulations: Society of Petroleum Engineers, Paper # 36652, p. 911- 917. Oil Viscosity in the I-100 Well p OilTracers, LLC Table 1A: Summary of SWC collected from the I-100 Well Spl No. MD Depth TVDSS De th Sand Recovery (cm.) Comments 1 4729.93 -4307.00 sB_OBt 2.6 overpull 3x 2 4686.84 -4276.00 SB_OBe 2.6 overpull 5x 3 4631.91 -4236.00 sB_OBd 2.6 sli overpull 4 4616.97 -4225.00 SB_OBd 3 ok 5 4594.88 -4209.00 SB_OBd 2.6 ok 6 4583.03 -4200.00 SB OBd 3.2 ok 7 4521 -4155.00 SB_OBc 3.2 sli overpull 8 4514.08 -4150.00 s6_OBc 2.5 overpull 4x 9 4451.08 -4104.00 SB OBb 2.6 Ok 10 4392.04 -4061.00 sB_OBa 2.6 ok no pull 11 4383.08 -4055.00 SB_OBa 2.6 ok 12 4375.04 -4049.00 SB OBa 2.6 ok NP 13 4326.05 -4013.00 SB_OA 2.6 ok 14 4319.06 -4008.00 SB OA 2 Ok 15 4309.04 -4001.00 s6_OA 2.5 sli over ull 16 4294.04 -3990.00 SB OA 2:6 ok 17 4152.05 -3886.00 s6_Nc 1.3 no pull 18 .4124.03 -3866.00 SB_Nb 2.6 Ok NP 19 4115.03 -3859.00 SB Nb 2.6 ok 20 4106.04 -3853.00 s6_Nb 2.6 sli overpull 21 4063.06 -3821.00 uG_Mb2 2.6 ok sli overpull 22 4055.06 -3815.00 UG_Mb2 2.6 ok NP 23 4035.01 -3800.00 UG Mb2 2.6 ok NP 24 3961.07 -3745.00 UG Mb1 2.6 ok NP 25 3949.93 -3736.00 UG_Mb1 2.6 ok NP 26 3944.07 -3732.00 UG_Mb1 2.6 sli pull 27 3931.98 -3722.00 UG_Mb1 2.6 ok 28 3926.07 -3718..00 UG Mb1 2.6 NP 29 3920.07 -3713.00 UG Mb1 3 NP 30 3913.05 -3708.00 UG Mb1 2.6 NP 31 3903.97 -3700.00 UG_Mb1 2.6 NP 32 3872.04 -3675.00 UG1 2 sli ull, Ok 33 3837.96 -3647.00 UG1 2.6 sli pull OK 34 3822.03 -3635.00 UG1 2 sli pull 35 3803.06 -3620.00 UG1 2.6 NP 36 3759.98 -3584.00 UG1 2.6 NP 37 3686.95 -3522.00 UG1 3.5 NP 38 3546 -3400.00 UG3 3.5 Sli pull Table 2A: Oil samples and Kinematic viscosity data used to calibrate the GC-viscosity transforms shown in Figures 2-4. i' ~," ~ ,. V-100 1.02 BP005075 OA 5031 4463 4379.0 378.5 V-100 1.07 BP005076 OBd 5424 4706 4622.0 271.9 Z-39 1.01 BP005078 OBd 5016 4750 4668.0 227.2 NWE4-01 1.07 BP005080 OBa 5905 4248 4168.0 499.9 NWE4-01 1.06 BP005081 OBb soon 4298 4218.0 34.9 V-202 1.13 BP005083 OBa 5175 4453 4371.0 135.1 V-202 1.03 BP005088 OBc 5972 4522 4440.0 55.0 L-120 1.06 BP005092 OBa 6099 4488 4409.0 36.1 L-120 1.01 BP005094 OBc 6252 4581 4502.0 25.9 W-205 1.11 BP005096 OA 6795 4976 4895.0 908.9 Table 2B: Oil samples and Dynamic viscosity data used to calibrate the GC-viscosity transforms shown in Figures 5-19. - T ;; - ~ . 5-213A 1.11 BP011121 MC 5747 4858.0 4023.9 2296.2 1374.2 $-213A 1.12 BP011122 MB1 5531 4718.0 10168.0 5436.5 3073.1 L-211 BP011148 M61 6446 3391.0 44127* 22662 11654 5917 *Estimated from a best fit line thorugh the 85°, 95°, 105° data for this oil [log Viscosity = -0.0292(temp in °F) + 6.8347] '~•i••r••~~r•~~~•••!•~•••••••+!•~•••••••••••!i~! Table 3A: Measured viscosity data and raw GC data (three GC ratios: C"/nC8, D**/nC8, E***/nC8) for 10 oils used to construct the transforms in Figures 2-4. For comparison, the viscosity values CALCULATED for these samples using the transforms are also shown. .p.. q`. •'. .Y~.~. .. 4 y V-~ 00 i~~ ~~. ~ .,,;.'r; ~~~~~ 378.5 4.'~u s ui ! 3 'IG ~ 386.4 ~ 366.0 339.1 363.9 V-100 BP005076 oad 271.9 1.95 1.70 1.62 277.8 254.8 235.2 255.9 Z-39 BPOO5o7s osd 227.2 1.51 1.51 1.49 247.0 241.5 226.1 238.2 NWE4-01 BP005o80 OBa 499.9 8.45 7.77 7.68 544.9 520.3 508.3 524.5 NWE4-01 BP005081 oab 34.9 0.08 0.07 0.07 33.2 22.5 7.7 21.1 V-202 BPO05o83 OBa 135.1 0.41 0.34 0.34 136.5 124.2 117.6 126.1 V-202 ePOO5os8 oac 55.0 0.13 0.11 0.11 66.2 56.2 47.0 56.5 L-120 BPO05092 OBa 36.1 0.14 0.12 0.12 70.8 62.0 53.6 62.1 L-120 BP005094 oBc 25.9 0.08 0.07 0.07 33.2 22.5 7.7 21.1 W-205 BP005096 0,4 908.9 24.35 25.93 26.59 870.0 903.2 936.0 903.1 *Peak C = Phenanthrene **Peak D = 9-methylphenanthrene ***Peak E = 3,9-dimethylphenanthrene Table 3B: Measured viscosity data and raw GC data (five GC ratios: 1, 2, 3, 4, 5) for 3 oils used to construct the transforms in Figures 5- 9. For comparison, the viscosity values CALCULATED for these samples using the transforms are also shown. .: S-213A BPO11121 Mc 1374.2 1.25 1.32 0.97 0.52 0.53 1304 1225 1407 1514 1324 1354.6 S-213A BP011122 M61 3073.1 0.85 1.41 1.72 1.18 1.13 3110 3111 2578 2922 3119 2968.1 L-211 BP011148 M61 11654 0.24 1.81 7.41 5.28 3.98 11715 11551 11466 11672 11643 11609.4 Table 3C: Measured viscosity data and raw GC data (five GC ratios: 1, 2, 3, 4, 5) for 3 oils used to construct the transforms in Figures 10-14. For comparison, the viscosity values CALCULATED for these samples using the transforms are also shown. - -~,; - S-213A BPO11121 Mc 2296.2 1.25 1.32 0.97 0.52 0.53 2190 1987 2676 2451 2104 2281.6 S-213A BP011122 M61 5436.5 0.85 1.41 1.72 1.18 1.13 5506 5816 5007 5257 5669 5450.9 L-211 BP011148 M61 22662 0.24 1.81 7.41 5.28 3.98 22655 22591 22712 22687 22621 22653.2 Table 3D: Measured viscosity data and raw GC data (five GC ratios: 1, 2, 3, 4, 5) for 3 oils used to construct the transforms in Figures 15-19. For comparison, the viscosity values CALCULATED for these samples using the transforms are also shown. S-213A BP011121 Mc 4023.9 1.25 1.32 0.97 0.52 0.53 3936 3397 4752 4309 3626 4004.0 S-213A BP011122 Mel 10168.0 0.85 1.41 1.72 1.18 1.13 10213 10938 9344 9836 10650 10196.2 L-211 BP011148 MB1 44127* 0.24 1.81 7.41 5.28 3.98 44112 43984 44222 44173 44043 44106.9 `Estimated from a best fit line thorugh the 85°, 95°, 105° data for this oil [log Viscosity = -0.0292(temp in °F) + 6.8347] Table 4A: Dead oil viscosity values (@ 90 °F, VALUES in cSt) predicted for 20 of the I-100 SWC's from GC ratios (C*/nCB, D**/nCB, and E***/nCB) using the transforms in Figures 2-4. Values are shown for only 17 of the SWC because nCB is ABSENT from all of the other SWC, causing the GC ratios to be undefined. One sample (4729.9 ft. md) was analyzed in triplicate NON-CONSECUTIVE runs -one time after every 25 GC runs. 4106 -3853 SB Nb G6060652 3.91 10.68 14.08 382.4 603.8 688.4 558.2 4115 -3859 SB Nb G6060649 7.10 17.44 27.76 503.3 756.4 955.2 738.3 4124 -3866 SB Nb G6060648 5.61 15.89 20.91 451.7 725.1 834.7 670.5 4152 -3886 SB Nc G6060647 0.93 0.86 0.90 198.4 187.8 180.2 188.8 4294 -3990 SB OA G6060646 0.18 0.14 0.15 84.6 72.6 68.6 75.2 4309 -4001 SB OA G6060644 0.24 0.19 0.19 102.6 90.4 83.6 92.2 4319.1 -4008 SB OA G6060643 0.19 0.15 0.14 88.0 74.8 64.5 75.7 4326 -4013 SB OA G6060642 0.19 0.16 0.15 90.8 78.2 68.1 79.0 4375 -4049 SB OBa G6060641 0.45 0.39 0.37 142.9 132.9 122.3 132.7 4383.1 -4055 SB OBa G6060639 0.39 0.35 0.34 133.3 126.0 118.1 125.8 4392 -4061 SB OBa G6060638 0.42 0.37 0.37 138.5 129.6 121.8 129.9 4451.1 -4104 SB OBb G6060637 0.08 0.07 0.07 35.6 20.6 1.7 19.3 4514.1 -4150 SB OBc G6060636 0.29 0.20 0.18 115.1 92.9 80.4 96.1 4521 -4155 SB OBc G6060634 0.15 0.12 0.11 76.0 62.2 48.5 62.2 4583 -4200 SB OBd G6060633 0.23 0.18 0.18 100.0 86.2 79.4 88.6 4594.9 -4209 SB OBd G6060632 0.21 0.17 0.17 96.3 84.4 76.0 85.6 4617 -4225 SB OBd G6060631 0.09 0.08 0.08 44.6 29.4 15.5 29.8 4631.9 -4236 SB OBd G6060628 0.10 0.08 0.08 46.6 32.6 16.7 32.0 4686.8 -4276 SB OBe G6060629 0.13 0.16 0.16 66.1 79.4 73.9 73.2 4729.9 -4307 SB OBf G6060626 0.11 0.08 0.08 54.0 37.6 23.0 38.2 4729.9 -4307 SB OBf G6060651 0.11 0.09 0.09 55.0 41.2 26.3 40.8 4729.9 -4307 SB OBf G6060697 0.14 0.08 0.12 71.4 34.3 51.0 52.3 *Peak C = Phenanthrene **Peak D = 9-methylphenanthrene ***Peak E = 3,9-dimethylphenanthrenc 3546 -3400 UG 3 G6060693 0.12 1.53 4.30 0.88 1.41 15307 5557 6606 2288 3950 6742 3687 -3522 UG 1 G6060692 0.24 1.54 3.43 1.22 1.71 11661 5894 5253 2999 4861 6134 3760 -3584 UG 1 G6060691 0.46 1.38 2.96 2.17 3.03 7304 2454 4508 5024 8807 5620 3803.1 -3620 UG 1 G6060690 0.39 1.46 3.04 1.41 2.39 8503 4247 4643 3419 6893 5541 3822 -3635 UG 1 G6060687 0.48 1.42 2.78 2.24 2.24 7019 3300 4241 5190 6427 5235 3838 -3647 UG 1 G6060686 0.36 1.57 3.15 1.57 1.86 8938 6469 4812 3750 5306 5855 3872 -3675 UG 1 G6060685 0.36 1.54 3.04 1.48 1.91 8951 5761 4642 3567 5441 5673 3904 -3700 SB Mb1 G6060684 0.31 1.54 3.07 1.57 1.85 10133 5958 4688 3748 5274 5960 3913 -3708 SB Mb1 G6060682 0.29 1.45 3.17 1.24 1.55 10597 4055 4840 3059 4366 5384 3920.1 -3713 SB Mb1 G6060681 0.30 1.68 3.52 0.89 1.51 10271 8740 5393 2307 4245 6191 3926.1 -3718 SB Mb1 G6060680 0.24 1.70 3.25 0.89 1.15 11693 9176 4973 2304 3187 6267 3932 -3722 SB Mb1 G6060678 0.22 1.67 3.54 0.75 1.49 12290 8514 5424 1998 4204 6486 3944.1 -3732 SB Mb1 G6060679 0.21 1.61 3.66 0.85 1.27 12390 7415 5612 2208 3540 6233 3949.9 -3736 SB Mb1 G6060658 0.23 1.72 0.34 0.64 1.31 11952 9692 425 1775 3645 5498 3961.1 -3745 SB Mb1 G6060657 0.22 1.64 3.39 0.76 1.42 12315 7911 5180 2021 3982 6282 4035 -3800 SB Mb2 G6060656 0.53 1.46 1.67 3.30 3.61 6181 4114 2493 7444 10530 6153 4055.1 -3815 SB Mb2 G6060654 0.42 1.49 2.05 2.40 2.81 7855 4874 3097 5525 8146 5899 4063.1 -3821 SB Mb2 G6060653 0.32 1.47 3.43 1.64 2.59 9836 4333 5253 3910 7477 6162 4106 -3853 SB Nb` G6060652 1.15 1.19 0.51 5.34 4.26 1633 -1626 688 11798 12487 4996 4115 -3859 SB Nb` G6060649 1.02 1.15 0.59 5.60 6.00 2138 -2452 819 12346 17692 6108 4124 -3866 SB Nb* G6060648 1.13 1.19 0.47 5.32 4.58 1687 -1585 632 11761 13440 5187 *Visc also calculated using phen/C8 ratios on Table 4A Table 4B: Dead oil viscosity values (@ 95 °F, VALUES in cp) predicted for 21 of the I-100 SWC's from GC ratios (Ratios 1, 2, 3, 4, 5) using the transforms in Figures 5-9. •~~tr~s~~~~~~~s~~~s~~~~~~~~~ss~~~~*~~~r~~~~~~~a 3546 -3400 UG 3 G6060693 0.12 1.53 4.30 0.88 1.41 30356 10505 13029 4002 7313 13041 3687 -3522 UG 1 G6060692 0.24 1.54 3.43 1.22 1.71 22679 11175 10335 5417 9126 11746 3760 -3584 UG 1 G6060691 0.46 1.38 2.96 2.17 3.03 13736 4333 8852 9448 16977 10669 3803.1 -3620 UG 1 G6060690 0.39 1.46 3.04 1.41 2.39 16167 7898 9120 6253 13168 10521 3822 -3635 UG 1 G6060687 0.48 1.42 2.78 2.24 2.24 13162 6014 8321 9778 12240 9903 3838 -3647 UG 1 G6060686 0.36 1.57 3.15 1.57 1.86 17055 12317 9457 6912 10011 11151 3872 -3675 UG 1 G6060685 0.36 1.54 3.04 1.48 1.91 17081 10910 9119 6549 10280 10788 3904 -3700 SB Mb1 G6060684 0.31 1.54 3.07 1.57 1.85 19509 11302 9212 6908 9947 11376 3913 -3708 SB Mb1 G6060682 0.29 1.45 3.17 1.24 1.55 20469 7517 9514 5537 8141 10236 3920.1 -3713 SB Mb1 G6060681 0.30 1.68 3.52 0.89 1.51 19793 16835 10614 4040 7900 11836 3926.1 -3718 SB Mb1 G6060680 0.24 1.70 3.25 0.89 1.15 22746 17703 9778 4034 5796 12011 3932 -3722 SB Mb1 G6060678 0.22 1.67 3.54 0.75 1.49 23992 16387 10675 3425 7818 12459 3944.1 -3732 SB Mb1 G6060679 0.21 1.61 3.66 0.85 1.27 24202 14199 11049 3843 6498 11958 3949.9 -3736 SB Mb1 G6060658 0.23 1.72 0.34 0.64 1.31 23285 18729 726 2982 6705 10486 3961.1 -3745 SB Mb1 G6060657 0.22 1.64 3.39 0.76 1.42 24045 15187 10191 3470 7376 12054 4035 -3800 SB Mb2 G6060656 0.53 1.46 1.67 3.30 3.61 11486 7634 4842 14263 20404 11726 4055.1 -3815 SB Mb2 G6060654 0.42 1.49 2.05 2.40 2.81 14850 9146 6044 10444 15661 11229 4063.1 -3821 SB Mb2 G6060653 0.32 1.47 3.43 1.64 2.59 18898 8070 10336 7230 14330 11773 4106 -3853 SB Nb' G6060652 1.15 1.19 0.51 5.34 4.26 2758 -3784 1248 22927 24298 9490 4115 -3859 SB Nb" G6060649 1.02 1.15 0.59 5.60 6.00 3682 -5427 1509 24016 34655 11687 4124 -3866 SB Nb' G6060648 1.13 1.19 0.47 5.32 4.58 2857 -3702 1137 22853 26196 9868 "Visc also calculated using phen/C8 ratios on Table 4A Table 4C: Dead oil viscosity values (@ 85 °F, VALUES in cp) predicted for 21 of the I-250 SWC's from GC ratios (Ratios 1, 2, 3, 4, 5) using the transforms in Figures 10-14. ~~~~~s~~~~~~~~~~~~~~is~~~~~~~~~~~~s~~~•~~~~s 3760 -3584 UG 1 G6060691 0.46 1.38 2.96 2.17 3.03 26290 8017 16919 18093 32925 20449 3803.1 -3620 UG 1 G6060690 0.39 1.46 3.04 1.41 2.39 31117 15040 17448 11800 25422 20165 3822 -3635 UG 1 G6060687 0.48 1.42 2.78 2.24 2.24 25155 11329 15872 18742 23594 18939 3838 -3647 UG 1 G6060686 0.36 1.57 3.15 1.57 1.86 32887 23745 18111 13097 19202 21409 3872 -3675 UG 1 G6060685 0.36 1.54 3.04 1.48 1.91 32938 20973 17446 12381 19733 20694 3904 -3700 SB Mb1 G6060684 0.31 1.54 3.07 1.57 1.85 37793 21745 17628 13090 19076 21866 3913 -3708 SB Mb1 G6060682 0.29 1.45 3.17 1.24 1.55 39717 14290 18223 10389 15519 19628 3920.1 -3713 SB Mb1 G6060681 0.30 1.68 3.52 0.89 1.51 38363 32644 20389 7439 15043 22776 3926.1 -3718 SB Mb1 G6060680 0.24 1.70 3.25 0.89 1.15 44295 34354 18742 7428 10898 23144 3932 -3722 SB Mb1 G6060678 0.22 1.67 3.54 0.75 1.49 46808 31761 20510 6229 14882 24038 3944.1 -3732 SB Mb1 G6060679 0.21 1.61 3.66 0.85 1.27 47233 27452 21247 7052 12281 23053 3949.9 -3736 SB Mb1 G6060658 0.23 1.72 0.34 0.64 1.31 45383 36376 911 5355 12691 20143 3961.1 -3745 SB Mb1 G6060657 0.22 1.64 3.39 0.76 1.42 46916 29398 19556 6318 14012 23240 4035 -3800 SB Mb2 G6060656 0.53 1.46 1.67 3.30 3.61 21850 14521 9020 27579 39675 22529 4055.1 -3815 SB Mb2 G6060654 0.42 1.49 2.05 2.40 2.81 28498 17498 11387 20055 30331 21554 4063.1 -3821 SB Mb2 G6060653 0.32 1.47 3.43 1.64 2.59 36568 15378 19842 13724 27711 22645 4106 -3853 SB Nb' G6060652 1.15 1.19 0.51 5.34 4.26 4996 -7971 1940 44646 47347 18192 4115 -3859 SB Nb' G6060649 1.02 1.15 0.59 5.60 6.00 6736 -11209 2453 46792 67747 22504 4124 -3866 SB Nb* G6060648 1.13 1.19 0.47 5.32 4.58 5181 -7810 1721 44501 51084 18936 "Visc also calculated using phen/C8 ratios on Table 4A Table 4D: Dead oil viscosity values (@ 75 °F, VALUES in cp) predicted for 21 of the I-100 SWC's from GC ratios (Ratios 1, 2, 3, 4, 5) using the transforms in Figures 15-19. Kinematic Viscosity @ 90°F (cSt) 0 200 400 600 800 -3800 -3850 -3900 -3950 ~ -4000 ~. ~ -4050 D H -4100 -4150 -4200 -4250 -4300 -4350 • OBf Figure 1A: Predicted kinematic viscosity @ 90 °F (cSt) of oil extracted from the I-100 frozen SWC from Nc, OA, OBa, OBb, OBc, OBd, OBe, and OBf sands. The data are from Table 4a. Values were predicted using the equations in Figures 2-4. ~ti~~~~~~~~~~~~~~~~~~~~~~w~~~s~~~~~~~-~~~~~~~s Dynamic Viscosity @ 95°F (cp) -3300 -3400 -3500 N -3600 D H -3700 -3800 -3900 Figure 1 B: Predicted dynamic viscosity @ 95 °F (cp) of oil extracted from the I-100 frozen SWC from the UG 3, UG 1, Mb1, Mb2, and Nb sands. The data are from Table 4b. Values were predicted using the equations in Figures 5-9. 0 2000 4000 6000 8000 10000 I - ~ O O Dynamic Viscosity at 95 °F (cp) 0 2000 4000 6000 8000 10000 GR Res. ~0° 3500 -3400 3550 -340Q UG3 -3450 3600 Note, Both dynamic and -3500 3650 -~ i kinematic viscosity 3550 3700 predictions are included ~ G ~ - "G' 3750 ' for N b extracts -3600 -3600 3800 -3650 3850 -60~ JIb1 3950 Mb1 -3750 Kinematic Viscosity @ 90 °F (cSt) 4000 nb2 3800 ~ Mbz 0 200 400 600 8( ' 5 405 _ D0~ 380 Nb3 3850 Nb -3900 -39(10 - ---. __. - --__ Nc Ne 4200 3soo N f - 425° -ass - } I -4000 4300 -4000 OA 4350 OA -4050 ) B a 4400 OBa )B b OBb )BC 4550 OBc 4600 ) B d -4250 4650 -425 OBd ~Ra -4300{ -435011 0 Figure 1 C: Well I-100 viscosity data from Figures 1A and 1 B plotted next to wireline log data for the well. C~ ~ , ~,,~ o .-. C. V LL 0 Lf'> >+ N O V N V .~ c~ C >+ D °o 0 0 0 °v 0 °o °o °o g °o c°o 0 °o O O O N 0 ~~11 SSaAl ~ ~ c ~ ~~ ~ ~ a~ ~. ~ o c o U ~ ~ ~~ m c ~ N N +L-+ O ~ ~ ~ O ~~ O ~ ~ ~ _ ~ ~ U O Q- ~ ~ ~ ~ °' 3 U ~ ~ ~ X ~ ~ (a ~ U O ~ ~~ ., co LL ~ ~ O ~~ V ~ L T ~ w ~ ~ U ~ ~_ ~ > ~ U ~- ~ ~ >, ~ ~ ~ ~~ ~z ~. U ~ ~ ~ L a N .~ ~ ~ L 1 1~ L.1. r r 0 0 °o S o 0 0 ~ ~ M M •••••~•••••••••s•••••••••••••••••••••••••••• I - 1 O 0 Dynamic Viscosity @ 85 °F (cp) 0 2000 4000 6000 8000 10000 12000 14000 16000 18000 G R ~+ Res . -3300 10 GAPI 110 SS MD 1 OHMM 20~ 3500 -3400 3550 -3400 UG3 -3450 3600 3650 Note, Both dynamic and -3500 -3soo kinematic viscosity -3550 3700 predictions are included JG~ ~7 uGt 3750 for Nb extracts -3600 -3600 3800 -3650 3850 -60' llbl 3950 Mb1 -37so Kinematic Viscosity @ 90 °F (cSt) 4000 0 200 4~0 ss00 81 llb2 -3eoo -3800 Mb2 -3800 405 001 850 4100 -3850 Nb Nb -3900 -39a~ -3900 Nc Ne 4200 - Nf 4250 -4000 4300 -4000 OA on 4350 ~Ba 4400 osa ~ - ~Bb oBb -~- - ~BC 4sso Oec 4soo ~Bd oed ~ -4250 4650 -4250 1Ra -4300 -4350 Figure 1 E: Well I-100 viscosity data from Figures 1A and 1 D plotted next to wireline log data for the well. ~p ~i~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~• Dynamic Viscosity @ 75°F (cp) -3300 -3400 -3500 .-. ..~ D ~ -3600 -3700 -3800 -3900 Figure 1 F: Predicted dynamic viscosity @ 75 °F (cp) of oil extracted from the I-100 frozen SWC from the UG 3, UG 1, Mb1, Mb2, and Nb sands. The data are from Table 4d. Values were predicted using the equations in Figures 15- 19. 0 5000 10000 15000 20000 25000 30000 35000 •••••••••••••••••••••••••••••••••••••••••••• I-100 GR Res. 10 GAPI 11D SS Mp 1 OHMM 2D0 Dynamic Viscosity @75°F (cp) 0 5000 10000 15000 20000 25000 30000 35000 -3300 r 3500 -3400 3550 -~ UG3 -3450 3600 -3500 3650 -3rd 3700 '~ Note Both dynamic J G 1 -3550 UG1 , and kinematic 3750 -3600 -3600 ~ viscosity predictions 3800 ' are included for Nb -3650 3850 extracts -60' 11 b1 3950 Mb1 -3750 Kinem atic Visco y @ 90 °F t) aooo 0 00 0 4 6 O 80 b 405 50 001 38 0 Nb 5 Nb -3900 -3900 3900 Nc Ne 4200 N f 4250 - ~ -4000 4300 -4000 OA ' OA 4350 )B a 4400 ', osa ~ )Bb - oBb )BC 4sso °Bo 4600 )Bd oed -4250 4650 -4250 ~Ra -4300 -4350 Figure 1 G: Well I-100 viscosity data from Figures 1A and 1 F plotted next to wireline log data for the well. •••••••••••••••••••••••••••••••e•••••••••••• Determination of Transforms Using Ratios of n-C$ and Phenanthrenes 1000 .- u_ 0 rn U .~ 0 U ~_ U i~ ^E rW L Y 800 600 • 400 200 0 5 10 15 20 25 30 C/n-C8 All Data (Blue Curve) y=y0+a`In(x)+b''(In(x))^2+c*(In(x))^3 y0: 205.0 a: 92.23 b: 21.41 c: 4.683 R2= 0.9980 Figure 2: Cross plot of measured viscosity at 90° F (in cSt) vs. a gas chromatography parameter (C/nC8) measured on 10 Orion oils. The raw data are provided in Table 3a. Compound "C" = Phenanthrene. Appendix 2 provides the GC traces for the oils. The best fit line is shown using all of the data (blue curve). A best fit line using all of the data EXCEPT the highest viscosity point was also calculated but did not plot significantly different than the blue curve; therefore we have used the fit that includes ALL of the data (blue curve) as the transform to calculate the viscosity of the I-100 SWC's in Table 4a. Asa check on the quality of this fit, using the equation for this curve, the viscosity value for each of these oils was calculated in Table 3a. Determination of Transforms Using Ratios of n-C$ and Phenanthrenes 1000 0 rn +. U ..~ ~. .~ 0 U _~ U :«r (0 E N C Y 0 5 10 15 20 25 30 D/n-C$ All Data (Blue Curve y=y0+a*I n (x)+b`(I n(x))^2+c'`(I n(x))^3 y0: 200.8 a: 88.73 b: 22.03 c: 5.219 R2= 0.9983 Figure 3: Cross plot of measured viscosity at 90° F (in cSt) vs. a gas chromatography parameter (D/nC8) measured on 10 Orion oils. The raw data are provided in Table 3a. Compound "D" = 9-methylphenanthrene. Appendix 2 provides the GC traces for the oils. The best fit line is shown using all of the data (blue curve). A best fit line using all of the data EXCEPT the highest viscosity point was also calculated but did not plot significantly different than the blue curve; therefore we have used the fit that includes ALL of the data (blue curve) as the transform to calculate the viscosity of the I-100 SWC's in Table 4a. Asa check on the quality of this fit, using the equation for this curve, the viscosity value for each of these oils was calculated in Table 3a. 800 600 400 200 ••••••••••••••••••e•••••••e•••••••s••••••••• .- u_ 0 rn U .~ 0 U U C6 E N C Y 0 10 15 20 E/n-C8 25 30 All Data (Blue Curve y=yo+a*In(x)+b*(~n(x))^2+c*(I n(x))^3 y0: 188.9 a: 83.21 b: 22.85 c: 6.464 R2= 0.9977 Figure 4: Cross plot of measured viscosity at 90° F (in cSt) vs. a gas chromatography parameter (E/nC8) measured on 10 Orion oils. The raw data are provided in Table 3a. Compound "E" = 3,9-dimethylphenanthrene. Appendix 2 provides the GC traces for the oils. The best fit line is shown using all of the data (blue curve). A best fit line using all of the data EXCEPT the highest viscosity point was also calculated but did not plot significantly different than the blue curve; therefore we have used the fit that includes ALL of the data (blue curve) as the transform to calculate the viscosity of the I-100 SWC's in Table 4a. Asa check on the quality of this fit, using the equation for this curve, the viscosity value for each of Determination of Transforms Using Ratios of n-C8 and Phenanthrenes 1000 800 600 400 200 these oils was calculated in Table 3a. •~~~~~~~~~~~~~~~~~~~~~~i~~~~~~~~~~~~~~~r~~~~ Determination of Transforms Using Biomarker Range Hydrocarbons y = 19740.5 * e^(-2.174x), R2= 0.99992 12000 10000 rn 8000 Q U a ~_ !~ 6000 O U ~_ ~~ 4000 co c ~ 2000 0 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 Value of Ratio 1 Figure 5: Cross plot of measured viscosity at 95° F (in cp) vs. a gas chromatography parameter "Ratio 1" measured on 3 Orion oils. The raw data are provided in Table 3b. The peaks in Ratio 1 are identified in Figure 20. Appendix 2 provides the GC traces for the oils. This transform is used to calculate the viscosity of the I-100 SWC's in Table 4b. As a check on the quality of this fit, using the equation for this curve, the viscosity value for each of these oils was calculated in Table 3b. I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~l~~~~~~~~~• Determination of Transforms Using Biomarker Range Hydrocarbons y= -26640+21100x, Rz=0.99957 12000 ,-. 10000 rn ~ 8000 n U ~_ ~ 6000 O U N •~ 4000 c~ c ~ 2000 0 1.2 1.4 1.6 1.8 Value of Ratio 2 Figure 6: Cross plot of measured viscosity at 95° F (in cp) vs. a gas chromatography parameter "Ratio 2" measured on 3 Orion oils. The raw data are provided in Table 3b. The peaks in Ratio 2 are identified in Figure 20. Appendix 2 provides the GC traces for the oils. This transform is used to calculate the viscosity of the I-100 SWC's in Table 4b. As a check on the quality of this fit, using the equation for this curve, the viscosity value for each of these oils was calculated in Table 3b. Determination of Transforms Using Biomarker Range Hydrocarbons y= -108.6+1562x, R2=0.9977 12000 .-, 10000 rn 8000 Q U .~ v~ 6000 O U ~_ .~ ~ 4000 c~ c ~ 2000 0 0 2 4 6 8 Value of Ratio 3 Figure 7: Cross plot of measured viscosity at 95° F (in cp) vs. a gas chromatography parameter "Ratio 3" measured on 3 Orion oils. The raw data are provided in Table 3b. The peaks in Ratio 3 are identified in Figure 20. Appendix 2 provides the GC traces for the oils. This transform is used to calculate the viscosity of the I-100 SWC's in Table 4b. As a check on the quality of this fit, using the equation for this curve, the viscosity value for each of these oils was calculated in Table 3b. Determination of Transforms Using Biomarker Range Hydrocarbons y= 404.2+2134x, R2=0.99930 12000 ,-. 10000 rn 8000 a U ~_ ~ 6000 O U ~_ ~~ 4000 cv c a ~ 2000 0 1 2 3 4 5 Value of Ratio 4 Figure 8: Cross plot of measured viscosity at 95° F (in cp) vs. a gas chromatography parameter "Ratio 4" measured on 3 Orion oils. The raw data are provided in Table 3b. The peaks in Ratio 4 are identified in Figure 20. Appendix 2 provides the GC traces for the oils. This transform is used to calculate the viscosity of the I-100 SWC's in Table 4b. As a check on the quality of this fit, using the equation for this curve, the viscosity value for each of these oils was calculated in Table 3b. Determination of Transforms Using Biomarker Range Hydrocarbons y= -261.3+2991x, R2=0.99993 12000 .-. 10000 rn 8000 n U ~_ N 6000 O U ~_ .~ ~ 4000 c4 c ~ 2000 0 Value of Ratio 5 Figure 9: Cross plot of measured viscosity at 95° F (in cp) vs. a gas chromatography parameter "Ratio 5" measured on 3 Orion oils. The raw data are provided in Table 3b. The peaks in Ratio 5 are identified in Figure 20. Appendix 2 provides the GC traces for the oils. This transform is used to calculate the viscosity of the I-100 SWC's in Table 4b. As a check on the quality of this fit, using the equation for this curve, the viscosity value for each of these oils was calculated in Table 3b. 0 1 2 3 4 5 Determination of Transforms Using Biomarker Range Hydrocarbons y = 39870 * e^(-2.330x), Rz= 0.99993 25000 ~-. ~ 20000 15000 +. .~ 0 U 10000 U .~ N C p 5000 0 Value of Ratio 1 Figure 10: Cross plot of measured viscosity at 85° F (in cp) vs. a gas chromatography parameter "Ratio 1" measured on 3 Orion oils. The raw data are provided in Table 3b. The peaks in Ratio 1 are identified in Figure 20. Appendix 2 provides the GC traces for the oils. This transform is used to calculate the viscosity of the I-100 SWC's in Table 4b. As a check on the quality of this fit, using the equation for this curve, the viscosity value for each of these oils was calculated in Table 3b. 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 I~~~s~~~ii~~~~~~~~~~~~~~~~~~~~~~~~ ~~~~~~~~• Determination of Transforms Using Biomarker Range Hydrocarbons y= -53538.1 +41969.5x, R2=0.9996 25000 .~ ~ 20000 Q. ~ 15000 a +. .~ 0 U 10000 U .~ N C p 5000 0 Value of Ratio 2 Figure 11: Cross plot of measured viscosity at 85° F (in cp) vs. a gas chromatography parameter "Ratio 2" measured on 3 Orion oils. The raw data are provided in Table 3b. The peaks in Ratio 2 are identified in Figure 20. Appendix 2 provides the GC traces for the oils. This transform is used to calculate the viscosity of the I-100 SWC's in Table 4b. Asa check on the quality of this fit, using the equation for this curve, the viscosity value for each of these oils was calculated in Table 3b. 1.2 1.4 1.6 1.8 I~~~~~~~~~a~~a~~r~~s~~~~~~~~~~~~~~~~~~~~-~~~~• Determination of Transforms Using Biomarker Range Hydrocarbons y= -336.7+3109.1x, R2=0.99862 25000 .-. ~ 20000 fl.. 15000 .~ 0 U 10000 U .~ (p C p 5000 Value of Ratio 3 Figure 12: Cross plot of measured viscosity at 85° F (in cp) vs. a gas chromatography parameter "Ratio 3" measured on 3 Orion oils. The raw data are provided in Table 3b. The peaks in Ratio 3 are identified in Figure 20. Appendix 2 provides the GC traces for the oils. This transform is used to calculate the viscosity of the I-100 SWC's in Table 4b. Asa check on the quality of this fit, using the equation for this curve, the viscosity value for each of these oils was calculated in Table 3b. 0 2 4 F A 1~~~~~~~~~~~~~~~~~~~~~~~~~i~i~~~~~~~~~~~~~• Determination of Transforms Using Biomarker Range Hydrocarbons y= 254.1 +4246.4x, R2=0.99976 25000 .-. u.. 20000 n ~ 15000 .~ 0 U 10000 U .~ (~ C p 5000 0 Value of Ratio 4 Figure 13: Cross plot of measured viscosity at 85° F (in cp) vs. a gas chromatography parameter "Ratio 4" measured on 3 Orion oils. The raw data are provided in Table 3b. The peaks in Ratio 4 are identified in Figure 20. Appendix 2 provides the GC traces for the oils. This transform is used to calculate the viscosity of the I-100 SWC's in Table 4b. As a check on the quality of this fit, using the equation for this curve, the viscosity value for each of these oils was calculated in Table 3b. 0 1 2 3 4 5 6 i•••••••••••••••••••••••i••••••••••••••••••• Determination of Transforms Using Biomarker Range Hydrocarbons y= -1065.9+5951.0x, R2=0.99961 25000 i 20000 ~" 15000 .~ 0 U '~ 10000 U .~ (0 C p 5000 0 Value of Ratio 5 Figure 14: Cross plot of measured viscosity at 85° F (in cp) vs. a gas chromatography parameter "Ratio 5" measured on 3 Orion oils. The raw data are provided in Table 3b. The peaks in Ratio 5 are identified in Figure 20. Appendix 2 provides the GC traces for the oils. This transform is used to calculate the viscosity of the I-100 SWC's in Table 4b. As a check on the quality of this fit, using the equation for this curve, the viscosity value for each of these oils was calculated in Table 3b. 0 1 2 3 4 5 Determination of Transforms Using Biomarker Range Hydrocarbons y = 79155.0 * e^(-2.410x), Rz= 0.99999 50000 ~ 40000 ti 30000 .~ 0 U 20000 U .~ (6 C p 10000 0 Value of Ratio 1 Figure 15: Cross plot of measured viscosity at 75° F (in cp) vs. a gas chromatography parameter "Ratio 1"measured on 3 Orion oils. The raw data are provided in Table 3b. The peaks in Ratio 1 are identified in Figure 20. Appendix 2 provides the GC traces for the oils. This transform is used to calculate the viscosity of the I-100 SWC's in Table 4b. Asa check on the quality of this fit, using the equation for this curve, the viscosity value for each of these oils was calculated in Table 3b. 0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 •~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~r~~~• Determination of Transforms Using Biomarker Range Hydrocarbons y= -105980.1+82673.7x, R2=0.99892 50000 LL. 40000 ti ~ 30000 .~ 0 U 20000 U .~ (~ C p 10000 0 Value of Ratio 2 Figure 16: Cross plot of measured viscosity at 75° F (in cp) vs. a gas chromatography parameter "Ratio 2" measured on 3 Orion oils. The raw data are provided in Table 3b. The peaks in Ratio 2 are identified in Figure 20. Appendix 2 provides the GC traces for the oils. This transform is used to calculate the viscosity of the I-100 SWC's in Table 4b. As a check on the quality of this fit, using the equation for this curve, the viscosity value for each of these oils was calculated in Table 3b. 1.2 1.4 1.6 1.8 Determination of Transforms Using Biomarker Range Hydrocarbons y= -1182.7+6124.9x, R2=0.99869 50000 ii 40000 ti n 30000 .~ 0 U 20000 U .~ (0 C p 10000 Value of Ratio 3 Figure 17: Cross plot of measured viscosity at 75° F (in cp) vs. a gas chromatography parameter "Ratio 3" measured on 3 Orion oils. The raw data are provided in Table 3b. The peaks in Ratio 3 are identified in Figure 20. Appendix 2 provides the GC traces for the oils. This transform is used to calculate the viscosity of the I-100 SWC's in Table 4b. Asa check on the quality of this fit, using the equation for this curve, the viscosity value for each of these oils was calculated in Table 3b. 0 2 4 6 8 •~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ l~~~~~~~~~~• Determination of Transforms Using Biomarker Range Hydrocarbons y= -18.4+8365.2x, R2=0.99979 50000 ii 40000 ti n ~ 30000 ~. .N 0 U 20000 U .~ f4 C p 10000 0 Value of Ratio 4 Figure 18: Cross plot of measured viscosity at 75° F (in cp) vs. a gas chromatography parameter "Ratio 4" measured on 3 Orion oils. The raw data are provided in Table 3b. The peaks in Ratio 4 are identified in Figure 20. Appendix 2 provides the GC traces for the oils. This transform is used to calculate the viscosity of the I-100 SWC's in Table 4b. As a check on the quality of this fit, using the equation for this curve, the viscosity value for each of these oils was calculated in Table 3b. 0 1 2 3 4 5 6 •••••••~•••••••••••••i••~••••••••••••••••••••• Determination of Transforms Using Biomarker Range Hydrocarbons y= -2618.0+11722.8x, R2=0.99957 50000 i 40000 ti a ~ 30000 .~ 0 U 20000 U .~ N C p 10000 Value of Ratio 5 Figure 19: Cross plot of measured viscosity at 75° F (in cp) vs. a gas chromatography parameter "Ratio 5" measured on 3 Orion oils. The raw data are provided in Table 3b. The peaks in Ratio 5 are identified in Figure 20. Appendix 2 provides the GC traces for the oils. This transform is used to calculate the viscosity of the I-100 SWC's in Table 4b. As a check on the quality of this fit, using the equation for this curve, the viscosity value for each of these oils was calculated in Table 3b. 0 1 2 3 4 °. '••••••••i••••••••••••••••••••••••••••••••••• ~,,,, ,~`. , ~ Biomarker Range Hydrocarbon Ratios 1 z o 0 0 • 25-Norhopanes (products of biodegradation of hopanes) G6060718 • Other biomarkers S-213A MC 1 1 0 0 0_ Ratio 3 Ratio 5 • •` ~ loooo_ ~, Ratio4 ~ „ • Ratio 1 ~. ,, -' ~h °~".v ~;.,,.~.,,.,,~,~~;'. Ratio 2 • ~ •' 1- °'''. --wv 9 0 0 0 _ ~ , ', .~ c,-l 4 " ~,~, ~ ~ ~ ~ -. i V. , ~~ d i 8000. .~ il~ ~~ ~ ~,~ - ~~ ~ ~ i ~u ~ f ~ I,~ h~.~.,.~ ~j l.~h .~ ivy ~ I ,~ ~I ~ 7000. 92 94 96 96 100 102 109 G6060720 13000- L-211 Ratio 1 MB-1 i z o 0 o Ratio 3 • Ratio 4 Ratio 5 • • ~ • I ,.,, i i o 0 0 • • ~ ~'~.r~ ~Irc .,+J yy,„ ~~..1~ ~~~ i Ratio 2 '',~,V' ",~,~.^~~„,r,M ..~.'~ ~, J r~M1 ti ~. w y , M r.,~ b 1•~.~ti, 8000 ~ `':~ v 9~2 ~ 9~4 96 98 - 1 0 1 d2 ~ ~ ~ 1 ~9 Figure 20: expanded view of 90-105 minute range of GC traces of S-213A MC Sand oil and L-211 MB-1 sand oil showing 5 GC ratios. Values for these 5 ratios (Tables 3b-3d and measured viscosity data (Figure 22) were used to construct the viscosity-GC transforms in Figures 6-20. •~~~~~~~s~~~~~~~~~~~~a~~~~~~~~~~~~~~~~~~s~~• y = -0.0292x + 6.834 ~\ • BP011121 (S-213A MC Sand) ^ BP011122 (S-213A MB1 Sand) BP011148 (L-211 MB1 Sand) -Linear (BP011122) -Linear (BP011148) -Linear (BP011121) 60 70 80 90 100 110 Temp, F Dynamic Visc. Kinematic Visc. Density Log (Vise) Sample ID Temp, F Temp, C mPa-s Mm2/s /g cm3 mPa-s BP011121 75 23.888 4023.9 4173.6 0.9641 3.604647 Well S-213A 85 29.44 2296.2 2390.1 0.9607 3.36101 MC Sand 95 35 1374.2 1435.0 0.9576 3.13805 BP011122 75 23.888 10168 10425 0.9754 4.007236 Well S-213A 85 29.44 5436.5 5593.3 0.9720 3.735319 M61 Sand 95 35 3073.1 3172.1 0.9688 3.487577 BP011148 75 23.888 Out of Valid Range of Instrument Well L-211 85 29.44 22662 41868 0.5413 4.355298 MB1 Sand 95 35 11654 21653 0.5382 4.066475 105 40.55 5917.2 10982 0.5388 3.772116 Figure 21: Measured viscosity values for 3 produced oils from the M sands. The data are expressed as both dynamic viscosity and kinematic viscosity. The kinematic viscosity values for the L-211 sample are suspect, since the reported density is unreasonable. The dynamic viscosity data for 95° F, 85° F, and 75° F were used in conjunction with the GC data to construct transforms in Figures 5-19. Appendix 1 Gas Chromatograms of the I-100 SWC Extracts Oil Viscosity in the I-100 Well p. 8 OilTracers, LLC N O O V C 7 x O O .--i O z 3 m 0 4 C C C e c ~ o ~ ° O ^~ L W ~-~~{{ r~ V V1 O O O O N O O O O O O O O O O O O O O O O O O O O O 00 ~ d-' N 0 0 x~ U ~~ ~o D I H 1-i ~~ ~~ •~ lON N lO •• ON ~ ~ O-r-I ~ E~ C7 W NN ~~ -rl b f~ Q •~~~~~~s~~~~~~s~~~~~~w~~~~~~~~~~~~~~~~~~~~a• Sample 4730 - - 100000 I 80000. 60000 40000 20000 (Duplicate Analysis) GC Run # : G6060651 Well No.: I-100 Depth: 4929.9 ft Reservoir: Schrader Bluff OBf Sample Type: SWC Extract >~ File: G6060651.D\FIDlA.CH Date & Time: 27-Apr-06, 14:17:22 100000 80000 60000 40000 20000. S amp l e 4 7 3 0 (Triplicate Analyses) ~~J 0 File: G6060697.D\FIDlA.CH Date & Time: 04-May-06, 09:39:01 GC Run # : G6060697 Well No.: I-100 Depth: 4730.0 n..,...__...__. o..~-_~_- n~__rr~rir Sample 4687 100000 GC Run # : G6060629 Well No.: I-100 80000 60000 40000 20000 20 40 6~0 8~0 100 ~0 File: G6060629.D\FIDIA.CH Date & Time: 25-Apr-06, 17:55:01 ~~•••••••••••••••••s••s••••••s••••••••••••••• Sample 4632 150000 120000 90000 60000 30000 GC Run # : G6060628 Well No.: I-100 0 File: G6060628.D\FIDlA.CH Date & Time: 25-Apr-06, 15:31:11 ••••••••!!•••••••••••••r•••••••a••••••••••i• Sample 4617 180000, GC Run # : G6060631 Well No.: I-100 150000 120000 90000 60000. 30000. Depth: 4617.0 ft ~U 4U 6U ~U 100 120 File: G6060631.D\FIDIA.CH Date & Time: 25-Apr-06, 21:06:30 •~~•••••••••••s•••••••i•s••••••••~•••~•••••• 140000 Sample 4595 GC Run # : G6060632 120000. 100000. 80000 60000 40000 20000. Well No.: I-100 2'0 4'0 File: G6060632.D\FIDIA.CH Date & Time: 25-Apr-06, 23:29:13 60 80 100 120 180000,Sample 4583 GC Run # : G6060633 Well No.: I-100 150000 120000 90000 60000 30000~I Depth: 4583.0 ft ~U 4U CCU ~U 100 120 File: G6060633.D\FIDlA.CH Date & Time: 26-Apr-06, 01:51:12 Reservoir: Schrader Bluff OBd 180000,Sample 4521 GC Run # : G6060634 Well No.: I-100 150000 120000 90000 60000 30000 Depth: 4521.0 ft ~U 4U ~U ~U lUU l~U File: G6060634.D\FIDIA.CH Date & Time: 26-Apr-06, 04:14:38 Reservoir: Schrader Bluff OBc I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~• Sample 4514 40000 30000 20000 100001 GC Run # : G6060636 Well No.: I-100 Depth: 4514.1 ft Reservoir: Schrader Bluff OBc 20 40 6~0 80 1b0 1~0 File: G6060636.D\FIDlA.CH Date & Time: 26-Apr-06, 07:27:28 Sample 4451 160000. GC Run # : G6060637 140000. 120000 100000_ 80000. 60000_ 40000. 20000_ Well No.: I-100 Depth: 4451.1 ft 2~0 4~0 6 0 8 0 1 0 12 0 File: G6060637.D\FIDlA.CH Date & Time: 26-Apr-06, 09:51:05 80000;Sample 4383 70000. 60000 50000 40000. 30000' 20000. 10000 GC Run # : G6060638 Well No.: I-100 Depth: 4392.0 ft 0 File: G6060639.D\FIDIA.CH Date & Time: 26-Apr-06, 14:36:11 ~ Reservoir: Schrader Bluff OBa •~~~~~~~~~~a~~~~~~s~~~~~~~~~~~~~s~~~~~~~~a~• 80000,Sample 70000 60000 50000 40000 30000 20000 10000 4383 GC Run # : G6060639 Well No.: I-100 Depth: 4383.1 ft Reservoir: Schrader Bluff OBa 0 File: G6060639.D\FIDIA.CH Date & Time: 26-Apr-06, 14:36:11 I~~~~~~~~~~~s~~~~~~~~~~~~~~~ ~~~~~~ss~~~~~~~~~ Sample 4375 40000 30000 20000 10000 GC Run # : G6060641 Well No.: I-100 Depth: 4375.0 ft 0 File: G6060641.D\FIDlA.CH Date & Time: 26-Apr-06, 17:49:01 Reservoir: Schrader Bluff OBa Sample 4326 100000 80000' 60000! 40000 20000 ~II GC Run # : G6060642 0 File: G6060642.D\FIDIA.CH Date & Time: 26-Apr-06, 20:10:32 0 ~y~ W O M N T',N U ~~ ,moo C] I i--i ~ Q iFC C] I N •~ MN Q' ~ .. ON ~~ O~rl ~o H C~ ~~ rl l~ ~ ~ f , Ll 0 Q ~ 0 0 ~ ~ ~ Q ~ Q 0 00 l~ LO ~ d-' M N ~I d o L j I~~~~~~~~~~~i~~~~~~~~~ ~~iw~~~~~~~a~~~~~~~~~~• Sample 4309 140000 120000_ 100000_ 80000 60000 40000_ 20000. GC Run # : G6060644 Well No.: I-100 no.,r1, • e 2no n fr 2~0 4~0 6~0 8~0 1 b 0 12 0 File: G6060644.D\FIDIA.CH Date & Time: 27-Apr-06, 00:51:39 0 N d-' W ~.l~ 0 ~a ~ ~ 4 ,~ G i ~ •• ~ C ~ e ~ O z s x ~ 3 c O O O O O O O O O O O O O O O O O O O O O O O O N O 00 ~ d'' N ~ ~ ~ ~, ~ M r-, 0 xo U ~~ .moo Q I H S-i ~~ Q~ •~ lON ~' ~.. O ~ ~ ~ O-rl ~H C~ N~ ~~ -~ ro wQ •~s~~r~~~~~~~~s~~ai~~s~~~~~~~~~~~~s~~~~~~~~~~ .~ 28000 24000 20000 16000 12000 8000 4000 n -i r n 2~0 4~0 6~0 8~0 1b0 120 File: G6060647.D\FIDIA.CH Date & Time: 27-Apr-06, 06:22:05 18000 Sample 4124 GC Run # : G6060648 15000 12000; 9000 6000 3000 20 40 File: G6060648.D\FIDlA.CH Date & Time: 27-Apr-06, 08:44:13 6~0 8~0 100 1~0 Well No.: I-100 N •~~~~~~~l~~~~~i~l~~~~~~~~~~~~~~~~~~~~~~~~~~• Sample 4115 24000 20000 16000 12000 8000 4000 GC Run # : G6060649 ° Well No.: I-100 c~ 'Z' T_-al_- A11~ n r~ 2~0 40 60 80 1 0 120 File: G6060649.D\FIDlA.CH Date & Time: 27-Apr-06, 11:05:37 •••••••• •••••••••••••••••••••••••••••i•••••• Sample 4106 210001 18000 15000 12000 9000. 6000 30001 GC Run # : G6060652 Well No.: I-100 nanth • dl n~ n 0 File: G6060652.D\FIDlA.CH Date & Time: 27-Apr-06, 16:39:56 I~~~~~a~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~• 60000 Sample 4063 ~~ U U z Contamination GC Run # : G6060653 Well No.: I-100 Depth: 4063.1 D .....,......:... iT.~.... AAL.'1 50000 40000 30000 20000 10000 0 File: G6060653.D\FIDIA.CH Date & Time: 27-Apr-06, 19:02:40 •••••••~•••s•••••••~•••••••••••••~•••••••~•• Sample 4055 18000 15000 12000 9000 6000 3000 0 File: G6060654.D\FIDIA.CH Date & Time: 27-Apr-06, 21:24:33 GC Run # : G6060654 Well No.: I-100 Contamination Depth: 4055.1 •s•••••••••••e•~•••••••••••••••••••••••••••• Sample 4035 30000: Contamination GC Run # : G6060656 Well No.: I-100 Depth: 4035.0 • _ iT-____ 1~T1_1 25000 20000 15000_ 100001 5000 File: G6060656.D\FIDIA.CH Date & Time: 28-Apr-06, 00:35:22 20 4'0 6~0 8~0 100 1~0 Sample 3961 24000 20000 16000 12000,; 8000 4000 GC Run # : G6060657 Well No.: I-100 Depth: 3961.1 File: G6060657.D\FIDIA.CH Date & Time: 28-Apr-06, 02:56:36 2 0 4~0 6~0 8~0 10 0 1~ 0 •~~~~~~~~l~~~~~~~~~~~~~~~~~~~~~~~~~r~~~~~~~~• Sample 3950 120000_ 100000 80000 60000. 40000. 20000. Contamination GC Run # : G6060658 Well No.: I-100 Depth: 3949.9 Reservoir: Ugnu Mbl Sample Type: SWC Extract File: G6060658.D\FIDIA.CH Date & Time: 28-Apr-06, 05:20:08 ~U 4U CCU ~U lUU 1~0 ~~~~~~~~~~~~~~~~i~~~!l~~~~~~~~~~~~~~~~~~~~~• Sample 3944 60000! 50000 40000 30000 20000 10000: ~~ U Z Contamination GC Run # : G6060679 Well No.: I-100 Depth: 3944.1 Reservoir: Ugnu Mbl 0 File: G6060679.D\FIDIA.CH Date & Time: 02-May-06, 13:26:27 60000. Sample 3932 ~~ U U z Contamination GC Run # : G6060678 Well No.: I-100 Depth: 3932.0 50000 40000 30000 20000 10000 0 File: G6060678.D\FIDIA.CH Date & Time: 02-May-06, 10:49:51 Sample 3926 70000 60000 50000 40000 30000 20000 10000 a ~ ~ ~ C~~ z `-1.u.,.~ull. 0 File: G6060680.D\FIDlA.CH Date & Time: 02-May-06, 15:50:23 Contamination GC Run # : G6060680 Well No.: I-100 Depth: 3926.1 n,.,.,.__.,.:... iT~_... n,r~~ I~~~~-~~~~s~~~~~~~~~~~~~~~~~~~~~~~~~~~s~~~~~• Sample 3920 50000 40000 30000' 20000 10000' ~U, ~ ~1~~1A Contamination GC Run # : G6060681 Well No.: I-100 Depth: 3920.1 Reservoir: Ugnu Mbl File: G6060681.D\FIDlA.CH Date & Time: 02-May-06, 18:12:18 20 4~0 6~0 810 100 120 ••••••••~••••••!••~~+!•!•~i••••~•••••••i•!•••• Sample 3913 Contamination 30000 20000. 10000 GC Run # : G6060682 Well No.: 1-100 Depth: 3913.0 2~0 4~0 6~0 8~0 1b0 120 File: G6060682.D\FIDIA.CH Date & Time: 02-May-06, 20:33:54 ••••••••••••••e•••••••••••••••• •••••e•e••••• Sample 3904 21000. 18000 15000_ 12000_ 9000_ 6000_ 3000 GC Run # : G6060684 Well No.: I-100 Depth: 3904.0 T ________!___ iT.-__ A.iL7 File: G6060684.D\FIDIA.CH Date & Time: 02-May-06, 23:45:21 2~0 4~0 6~0 80 100 1~0 •~~~~~~~fw~~~~~~~~~~~~~~~~~i~~~~l~~~~~~i~~~• Sample 3872 24000 20000. 16000:~~ 12000 8000 4000 :xtract 2~0 4~0 6~0 8~0 1~0 120 File: G6060685.D\FIDlA.CH Date & Time: 03-May-06, 02:07:45 GC Run # : G6060685 Well No.: I-100 Depth: 3872.0 D..~.,.-.,..:... ~T...,., 1 I~~~~~~ ~~~~~~~~~~~~~~~~~~~~~s~~s~~i~~i Sample 3838 70000 60000 50000 40000 30000 200001 10000 U z 2~0 4~0 6~0 8~0 1b0 Fil G6060686 D\FIDlA CH e: . . Date & Time: 03-May-06 09:28:57 120 , Contamination GC Run # : G6060686 Well No.: I-100 Depth: 3838.0 T ________!___ iT-___ 1 •~~~~a ~~a~~~~~~~~~~~~~~~~a~~~~~~~s~~`~~~~~~~ Sample 3822 90000 800001 ~oooo 60000 50000! 40000 30000 20000 10000 U z, 20 4~0 6~0 80 100 1~0 File: G6060687.D\FIDlA.CH Date & Time: 03-May-06, 06:53:09 Contamination GC Run # : G6060687 Well No.: I-100 Depth: 3822.0 T ., .. ., ___..__-_ iT--__ 1 ••••••••••••••••~-•••!••~1•••••••••••••••••••• .~ ., ~ „ ~, 21000 18000 1500 1200 900 6000 3000 2~0 4~0 6~0 8~0 1b0 120 File: G6060690.D\FIDIA.CH Date & Time: 03-May-06, 12:28:04 I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~• 70000Sam 60000 50000 40000 30000 20000 10000 le 37 60 Contamination GC Run # : G6060691 Well No.: I-100 Depth: 3760.0 D .,~........:... i T...... 1 File: G6060691.D\FIDlA.CH Date & Time: 03-May-06, 14:51:41 2~0 4~0 6~0 8~0 1 ~ 0 1 ~ 0 •~~~~~~~~~~~r~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~• Sample 3687 40000 30000 20000 10000 U z Contamination GC Run # : G6060692 Well No.: I-100 Depth: 3687.0 T________!___ iT-___ 1 File: G6060692.D\FIDIA.CH Date & Time: 03-May-06, 17:13:47 20 40 0 80 1~0 120 •••••••••••••••••••••••••••••••••••••••••••• 21000Sample 3546 18000. 15000_ 12000 9000 6000. 3000 GC Run # : G6060693 Well No.: I-100 Depth: 3546.0 File: G6060693.D\FIDlA.CH Date & Time: 03-May-06, 19:36:55 - 20 40 60 8~0 100 120 I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~• 140000 120000 100000 80000' 60000 40000 20000 Sample I-100 MUD _~ File: G6060723.D\FIDIA.CH Date & Time: 08-May-06, 20:32:38 GC Run # : G6060723 Well No.: I-100 Date: nPnth 0 I~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~• Sample I-100 BASE OIL 500000_ 400000_ 300000_ 200000_ 100000 20 40 60 File: G6060724.D\FIDlA.CH Date & Time: 09-May-06, 09:02:46 GC Run # : G6060724 Well No.: I-100 Date: Depth: Reservoir: Sample Type: Base oil 80 100 120 Appendix 2 Gas Chromatograms of Produced Oils used to Calibrate the Various Viscosity Transforms 0 N O O ~ O O C '~ 4 •• r ~ C c o ~ ~ Z s s L73AG C~ O l~ W ~ r n Q Q D O~ ~ W I ^ u / N r-I ~I O O O ,~ d'' ".'. N M xN U ~~ rl0 QI H ~ O ~~ N Oi .~ NO O ~.. O ~ O-rl ~ E-~ ..~ NN rl l~ -~ ~ G~ Cl --_ ~_.. -. - -0 ~ 0 -- 0 0 N 01 LO C~ ~~~~~~~~~~s~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~• Sample V-100 14000: 12000 5424 GC Run # : G6060704 Well No.: V-100 Date: ,~ 10000': 8000 6000 40001 2000 20 40 6~0 8~0 100 1~0 File: G6060704.D\FIDIA.CH Date & Time: 05-May-06, 00:45:24 l~~~~~~i~~~~~~~~~~~~~~~i~lf~~~~~~~~~~i~~~~~• Sample NWE4-O1 5905 14000 12000 10000' 80001 60001 4000 z 20001 ~~~`,I ~ ~ll~ 2~0 4~0 6~0 8~0 1b0 120 File: G6060706.D\FIDIA.CH Date & Time: 05-May-06, 05:31:01 GC Run # : G6060706 Well No.: NWE4-O1 Date: •~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~w~~~~,~~~~~• Sample NWE4-01 6000 160000 GC Run # : G6060707 Well No.: NWE4-O1 14n(~n(1 Date: •s~~~~~~~~~~~~~~~~~s~~~~~~~s~~~~~~~~~~~s~~~• Sample V-202 5175 40000 GC Run # : G6060708 Well No.: V-202 Date: Sample V-102 90000 80000,, 70000 60000 50000 40000. U ~ z 30000~~~ 2 20000~~ 10000 5972 GC Run # : G6060710 Well No.: V-202 Date: 0 File: G6060710.D\FIDIA.CH Date & Time: 05-May-06, 13:27:55 0 rl O ~ O O N ~ `"~ •• a C C p V ~z ; x ~; ~~~ ~3A~ rn rn 0 O' N ~I .--I ~~ ~' O O O O N O O O O O O O O O O O O O O O O O O O O O 00 ~ d-' N O l~ 0 0 ~o o ,~ ~ M r-, x~ ~~ ~o o~ H r~ O /~ .~, N Q~ ~o ~.. o~ ~~ o-~ ~~ .. `" ~~ ~~ ~~ ro w ca ~' o U j •~~~l~~~~~~~~~~~~~~~~~~~~~~~~~~ l~~~~~~~~~~i• Sam le L-120 6252 120000 100000 80000 60000. V2 40000 20000 ~ File: G6060712.D\FIDIA.CH Date & Time: 05-May-06, 18:14:19 GC Run # : G6060712 Well No.: L-120 Date: Depth: 6252 ft Reservoir: Sample Type: 0 ••••••~!i•••••••i••~-••••ii••••••••i•••••••••• 14000 12000 10000 8000 6000 4000 2000 ~ r~ n n r r- ~ n r 0 File: G6060713.D\FIDIA.CH Date & Time: 05-May-06, 20:37:51 0 0 0 `i 0 W r~ V 1 0 0 ~o~ ..~o C O M ~z x_ ~~ ~3Ac 0 0 0 ~ ~: N x',N U ~~ ,moo OI H~ [*a rd i~ Q I •~ a' O ~.. O ~ ~~ O-ri ~o H C~ NN rl l~ _~ b [i, Q Q 00 LO d-' N Sample 1.11 12000 GC Run # : G6060718 Well No.: 5-213A Date: ilonrR• 10000 8000 60001 4000 20001 File: G6060718.D\FIDIA.CH Date & Time: 08-May-06, 10:12:51 2'0 4 0 6~0 8 0 ~ 12 0 0 N N O O O O ~Q O M ~p ~--~ N i *k ~ O ~ Z ~ ; ~, ~ s C7~A~ O O O O O O O O O O O O O O O O O O O O O O O O O O O O ~ LO ~ d-' (~ N ~I 0 O O -LO O di °.: M N ~" r-i U ~~ ~o of ~~ O wro ~~ Qi N •°' ~o ,~ .. o a~ ~~ o.~ ~~ c~ .. `~ ~~ ~~ -~ ro wo •~~~~~~~~~~~i~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~• 16OO0Sample L-211 G6060720.D\FIDlA.CH & Time: 08-May-06, 14:58:12 GC Run # : G6060720 Well No.: L-211 1 4 0 0 0 Date: T ....aL.
