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1REOH$2*&&5HSZLWQHVVHGFXWFDVLQJV3HUIRUPWRSMRERQ2$ZEEOVa RI$6FHPHQW'XPSEEOVRI$6FHPHQWLQ,$RXWRIFHPHQW5'02 3 $,Q3URJUHVV 3HUIRUPWRSMREZLWKEEOVa RI$6FHPHQWLQ7%* EEOVa RI$6FHPHQWLQ,$5'02 'DLO\5HSRUWRI:HOO2SHUDWLRQV 3%8'$ 3 $,Q3URJUHVV :HOGPDUNHUSODWHWRFDVLQJ%RE1REOH$2*&&5HS ZLWQHVVHGPDUNHUSODWHLQVWDOODWLRQ3KRWRGRFXPHQWFRQGLWLRQRIWRSMREDQGPDUNHU SODWH5'02 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg1 zI DATE: 12/15/2020 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Abandonment Inspector PBU D -27A Hilcorp North Slope, LLC PTD 2051930; Sundry 319-494 ' 12/11/2020: 1 traveled to Hilcorp's Prudhoe Bay Unit D -27A to do a pre -cement cut off inspection. I met with Hilcorp representative Robert Bryant. I watched as they strapped the voids. Cement in the tubing was 175 feet down, tubing -casing annulus (IA) was 60 feet down and the casing -casing annulus (OA) was 25 feet down. I told Robert to let us know when they had the voids full of good hard cement. 12/13/2020: 1 traveled back to PBU D -27A and met with Robert Bryant again. I inspected the marker plate and it had the proper identification information welded on it. ' The well was cut off 5'/2 feet below tundra grade. The marker plate was sized correct to the outer casing size. The plate was cut out of 3/8 -inch steel. Everything looked good so I told Robert they could proceed with welding the plate to the casing stub and back fill the hole. Attachments: Photos (3) 2020-1213—Surface—Abandon PBU D -27A bn.docx Pagel of 2 Surface Abandonment — PBU D -27A (PTD 2051930) Photos by AOGCC Inspector B. Noble 12/13/2020 2020-1213_Surface_Abandon_PBU_D-27A_bn.docx Page 2 of 2 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:205-193 6.50-029-21543-01-00 PRUDHOE BAY, PRUDHOE 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 11626 Surface Surface 8687 Surface 8199 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 32 - 112 32 - 112 Surface 2643 13-3/8" 32 - 2675 32 - 2675 5380 2670 Intermediate 8962 9-5/8" 29 - 8991 29 - 8483 6870 4760 Liner 706 7" 8756 - 9462 8263 - 8921 8160 7020 Perforation Depth: Measured depth: None feet True vertical depth: None feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 27 - 8808 27 - 8312 8687 8199Packers and SSSV (type, measured and true vertical depth) 4-1/2" TIW Packer Liner 2886 8740 - 11626 8248 - 9013 10160 10530 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: Ryan Holt ryan.holt@hilcorp.com 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 measured9013 Sundry Number or N/A if C.O. Exempt: N/A Junk Packer Printed and Electronic Fracture Stimulation Data 5 Suspended Well Inspect Operations shutdown Change Approved Program 5 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 028285 PBU D-27A 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 2-7/8" x 3-3/16" x 3-1/2" By Samantha Carlisle at 3:43 pm, Aug 04, 2020 g Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.08.04 14:18:17 - 08'00' Stan Golis SFD 8/5/2020MGR07AUG2020RBDMS HEW 8/5/2020 DSR-8/6/2020 ACTIVITYDATE SUMMARY 6/28/2020 T/I/O = Vac/0/0. Temp = SI. SU well inspection (AOGCC witnessed by Bob Noble). No AL, flowline or wellhouse. Pictures taken. SV = ? ASV = C. MV = O. IA, OA = OTG. 1130. Daily Report of Well Operations PBU D-27A Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name:D-27A Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD):2051930 API Number: Operator:BP EXPLORATION (ALASKA) INC Date Suspended: 9/23/2019 Surface Location:Section: 23 Twsp: 11N Range: 13E Nearest active pad or road:D 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, 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: Good Pad or location surface: Good Location cleanup needed: No Pits condition: Good Surrounding area condition: Good Water/fluids on pad: No Discoloration, Sheens on pad, pits or water: No Samples taken: None Access road condition: Good Photographs taken (# and description): 4 - Wellhead, tree & pits 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: FMC Wellhead McEvoy Tree Good condition Cellar description, condition, fluids: Wet Gravel Rat Hole: N/A Wellhouse or protective barriers: None Well identification sign: Good Tubing Pressure (or casing if no tubing): Vac Annulus pressures: IA - 0 psi OA - 0 psi Wellhead Photos taken (# and description): 3 wellhead, tree & cellar Work Required: None Operator Rep (name and signature):Ryan Holt AOGCC Inspector: Bob Noble Other Observers: Randy Mork Inspection Date: 6/28/2020 AOGCC Notice Date: 6/26/2020 Time of arrival: 11:20 AM Time of Departure: 11:30 AM Site access method: Drive 500292154301 Initial Inspection MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 7K�,, DATE: June 19, 2020 P. I. Supervisor l3� SUBJECT: Plug Verification PBU D -27A - FROM: Guy Cook BPXA Petroleum Inspector PTD 2051930; Sundry 319-494— Section: 19-494Section: 23 Township: 11N Range: 13E Meridian: Umiat Drilling Rig: NA Rig Elevation: NA Total Depth: 11626 ft MD Lease No.: ADL0028285 Operator Rep: Mark Spiller Depth Btm Depth To Suspend: Verified P&A: X - Retainer Casing/Tubing Data (depths are MD): 9.8 ppg - Wireline tag Casing Removal: Conductor: 20" O.D. Shoe@ 112 - Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 2675 - Feet Csg Cut@ Feet Intermediate: 9 5/8" O.D. Shoe@ 8991 Feet Csg Cut@ Feet Production: 7" O.D. Shoe@ 9462 Feet Csg Cut@ Feet Liner: O.D. Shoe@ Feet Csg Cut@ Feet Tubing: 4.5' O.D. Tail@ 8808 Feet Tbg Cut@ Feet Plugging Data: Test Data: Type Plug Founded on Depth Btm Depth To MW Above Verified Fullbore Retainer 2118 ft MD - 9.8 ppg - Wireline tag OA 27 27 27 . Initial 15 min 30 min 45 min Result Tubing 2793 2749 - 2731. IA 2780 2611 2545 P OA 27 27 27 . mitral lb min 3U min 45 min Result Tubing IA OA Remarks: The first cement tag was at 2118 ft MD. Schlumberger wireline captured a sample with a 2 ft by 3 inch drive down bailer. The sample was good cured cement. The CMIT TXIA was next and passed without issue. 2.75 bbls were pumped in and they got 2.75 bbls back after the test was complete. The second tag was run with the exact same tools and tagged at 2118 ft MD showing that the cement had not moved during the CMIT. Attachments: None i rev. 11-28-18 2020-0619_P l ug_Verification_PB U_D-27A—gc Suspended Well Inspection Review Report InspectNo: susRCN200630145531 Date Inspected: 6/28/2020 Inspector: Bob Noble Type of Inspection: Well Name: PRUDHOE BAY UNIT D -27A Permit Number: 2051930 Suspension Approval: Sundry N 319-114 _ Suspension Date: 9/23/2019 Location Verified? O If Verified, How? Other (specify in comments) Offshore? ❑ Initial Date AOGCC Notified: 6/28/2020 Operator: BP Exploration (Alaska) Inc. Operator Rep: Ryan Holt Wellbore Diagram Avail? O Photos Taken? Well Pressures (psi): Tubing: 0 Fluid in Cellar? ❑ IA: 0 BPV Installed? ❑ OA: 0 VR Plug(s) Installed? ❑ Wellhead Condition Wellhead in good condition. No flowline; all lines blinded with gauges; 2 SSVs. Condition of Cellar Good clean gravel Surrounding Surface Condition Good clean gravel Comments Location verified with a pad map. Supervisor Comments Photos(2)attached ' J-3C-71zlIZc>iu Tuesday, July 21, 2020 U b a THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Aras Worthington Senior Completions Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU D -27A Permit to Drill Number: 205-193 Sundry Number: 319-494 Dear Mr. Worthington: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 �.a ogc c.a I aska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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, 1� J Price Chair DATED this Y— day of November, 2019. IBDMS6J NOV 9 5 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED nrT Z i on1n 1. Type of Request: Abandon 0 0 Plug Perforations ❑ Fracture Stimulate ❑ Repair -Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Chan p eG rp C ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0 5. Permit to Drill Number: 205-193 3. Address: P.O. Box 196612 Anchorage, AK 99519-5612 Stretigraphic ❑ Service ❑ 6. API Number: 50-029-21543-01-00 7, If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU D -27A 9. Property Designation (Lease Number): 1 10. Field/Pools: ADL 028285 PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD:MPSP (psi): Plugs (MD): Junk (MD): 11626 9013 5096 4956 5096.8715.10994 None Casing Length Size MD TVD Burst Collapse Structurel Conductor 80 20" 32-112 32-112 Surface 2643 13-3/8" 32-2675 32-2675 5380 2670 Intermediate 1 8962 1 9-5/8" 29-8991 29 - 8483 6870 4760 Liner 706 7" 8756 - 9462 8263 - 8921 8160 7020 Liner 2886 3-1/2" x-3-3/1 5" x 2-7/8" 8740- 11626 1 8248-9013 Perforation Depth MD (ft): Perforation Depth TVD (ft): 1 Tubing Size: 1 Tubing Grade: Tubing MD (ft): h 4-1/2"12.6# L-80 1 27-8808 Packers and SSSV Type: 4-1/2" TIW Packer Packers and SSSV MD (ft) and TVD (ft): 8687/8199 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic RI 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: November 20, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Alvaro, Mike (Udelhoven) be deviated from without priorwritten approval. Contact Email: mike.aivano@bp.com Authorized Name: Worthington, Area J Contact Phone: +1 9075645475 Authonzed Title: Interventi & Integrk Engineer Authorized Signature: Date: 1,*13 67h j, COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity p�_ BOP Test ❑ hanical tegnty Test l MecQ� Location Clearance p/ Other: PLO -/—. a& 0 *V e w T (Z.1Led Post Initial Injection MIT Req'd? Yes El' No ❑/' 1BDMS_� NOV 0 5 2019 Spacing Exception Required? Yes ❑ No ($- Subsequent Form Required: ��1j �V6 f APPROVED BYTHE Approved by: \ COMMISSIONER COMMISSION Date:1` "I vU 'P / -c ii/i I Iel Form 10-403 Revised 04/2017 ORIGINALAA0 0101 rr' � 10/ Submit Form and Approved application is valid for 12 months from the date of approval. Attachments in Duplicate D-27 P&A Program - Upper Wellbore Abandonment Intervention Engineer Mike Aivano (907) 564-5475 / (907) 885-9190 Aras Worthington (907) 564-4102 Sundry Number: TBD History D -27A has multiple tubing leaks at 5063'& 5086' and PC leaks between 4946- 4955'. A releasable spear was stung into the liner top packer at 8739' to prep the well for a coil tubing side-track in 2014. The spear has not been able to be recovered by either slickline or coil efforts. The well was classified as Not Operable in May 2010 and has been recommended for P&A due to lack of value in its current state. Aug / Sept 2019, work completed under Sundry # 319-114: Punched tubing above 9-5/8" x 4-1/2" Production Packer and then set a cement retainer between the punches. CT was able to squeeze 24 bbls of cement below the retainer into the liner and lower completion section of the hole. Then 52 bbls of cement were laid in the tubing and 9-5/8" x 4-1/2" annulus. Proposed top of cement was —7957' md, but slickline later tagged up on cement well above the proposed TOC at 5096' slm (AOGCC Witnessed). It is believed that the cement did not go into the tubing backside, instead migrated up the tubing. Objective The objective of this procedure is to: Mill cement in the 4-1/2" tubing to verify the current TOC is not a bridge; Place a lateral cement barrier in the 4-1/2" tubing and 9-5/8" x 4-1/2" annulus to seal off the PC leak and to provide —575' overlap across the surface casing shoe; Place a lateral cement barrier in the 4-1/2" tubing and across all annuli from 1350' to surface. This P&A was designed to conform to BP Practice 100221: Zonal Isolation and BP Alaska's deviations captured in eMOC 10439. Procedural steps Note recording requirements in RP: Through Tubing Abandonments (section 5.9) that must be documented in AWGRS and the Wellfile. AOGCC Witness: All AOGCC witnessed operations require a minimum of 24 hour notice to AOGCC inspectors of the timing of the operation so they can be available. 1. CT Note: Objective is to prove competent cement in the tubing and the current cement top is not a bridge. A. Makeup mill and motor for milling cement inside 4-1/2" Tbg. B. RIH and dry tag top of cement. C. Mill cement • Mill cement at controlled rate D -27a P&A Upper Hole Abandonment • Circulate viscous sweeps as required for good hole cleaning. • Document areas of very soft cement or no cement. • If any significant voids in cement are found Circulate around viscous sweep dry tag top of cement and notify Town Engineer so information can be communicated with AOGCC • Mill for approximately 10 hrs or as directed by town engineer. (best guess would be approximately 200 to 300 ft in 10 hrs) D. Notify Town Engineer on condition of cement milled and new top of cement so that AOGCC can be informed. E. Circulate wellbore clean and POOH with motor and mill. F. Pick up tubing punches for 4-1/2" tubing. Punch tubing 5375' md. • 5 ft of punches, 4 spf, 0 degree phasing. G. Make up cementing BHA and RIH to top of cement H. Circulate around the following: • Pump down the CT x Tbg annulus and up the IA. • 50 bbls hot (-160 deg F) freshwater + surfactant; 2gal/mgal F103 and 2gal/mgal UO67 • followed by 360 bbls of 9.8 ppg brine I. Lay -in cement inside 4-1/2" tubing and 9-5/8" x 4-1/2" annulus from top of cement ( tbg punches) to 1800' md. Take returns off the IA and Tbg as required to get a balanced cemen lug. Cement from Tbg punches to 1800' md, approximately 242 bbls J. Pull up hole to surface after final cement is pushed through the nozzle. K. Bullhead down IA with 10 bbls of 50/50 to freeze protect. Bullhead down Tbg with 3 bbls of 9.8 ppg brine. • This will push the top of cement in the IA and Tbg down to 2000' md. L. Jet down to clear out tubing to 2000' md. M. POOH and freeze protect top 200' of tubing with 50/50. Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 800 and 110°F Fluid Loss: (20-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 8 hours Estimated BHST: Based on LDL 9/5/12 7600' MD / 7194' TVD -1530F assume base of Permafrost @ 2200' TVD 2. Fullbore A. CMIT TAA to 2500 psi - AOGCC Witnessed L-- 3. Slickline D -27a P&A_Upper Hole Abandonment A. D&T top of cement with bailer — AOGCC Witnessed B. Perforate tubing at 1350' and (can be perforated Relay / Slickline memory / Eline) • Perforate 1350-1360' md, 6 spf, 60 deg phasing. These perforations will punch through the tubing and 9-5/8" casing for circulating out the OA. • Perforations have been modeled with HES 2" Millennium, 6 spf, 60 deg phasing, centered. If using SLB, a model will need to be run to confirm which guns to use to obtain best performance. 4. Fullbore Note: Rig up in such a way that returns can be taken from the IA or OA independent from one another. This step is designed to prepare the annuli for cement, and then cement them to surface, circulating down the tubing. Note: The order of operations can be modified at WSL discretion for operational efficiency and risk reduction, provided the intent of removing Arctic Pack and or freeze protect from the annuli and surfactant washing all tubulars is achieved. A. Rig up to circulate down the tubing and take returns from the IA and the OA. B. Circulate down the tubing and up the OA to clean out crude freeze protect. Pump the following at max rate below 2500 psi. 1. 5 bbls McOH 2. 50 bbls hot (-160 deg F) freshwater + surfactant; 2gal/mgal F103 and 2gal/mgal U067 3. 110 bbls of 9.8 ppg NaCl Brine (60-100 deg F) 4. Freeze protect if required with 13 bbls of 50/50, U-tube freeze protect. C. OA Cement Plug. Pump down the tubing and take returns up the OA. Max pressure while pumping 2500 psi. • 5 bbls McOH (if required) • 10 bbls fresh water 115 bbls of Class G Cement as per design. (-15 bbls over calculated volume) ✓ If cement to surface on the OA is good, close in the OA then continue to the next step and cement the IA. D. IA Cement Plug. Pump down the tubing and take returns up the IA. Max pressure while pumping 2500 psi. • 88 bbls Class G Cement as per design. (-15 bbls over calculated volume) • Top of cement will be at surface in the tubing and IA, Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 800 and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 6 hours 5. DHD A. Assist Fullbore with cement job and pump N2 across the wellhead valves to remove cement, this will help when opening valves in later steps to check pressures. D -27a P&A Upper Hole Abandonment B. Bleed all wellhead pressures to 0 psi. C. Monitor wellhead pressures 24 hours after the pressures were bled to 0 psi. 6. Special Projects A. Excavate and Cut off all casings and wellhead 3' below original tundra level. Top job the conductor x 13-3/8" annulus and all other annuli and tubing with cement as needed. Photo document cement in wellbore prior to top job cement and after as well as Marker Plate installation. B. AOGCC witness cement tops in all annuli and installation of Marker Plate. f C. Marker Plate to meet requirements in RP: Through -Tubing Abandonment (Section 5.8) • Marker plate minimum W thick • Minimum of 18" diameter • Photo document well marker cap. D. Bead weld marker cap on outermost casing string (Conductor Pipe) to read as follows: BP Exploration Alaska, Inc. D -27a PTD # 205-193 API # 50-029-21543-01 D -27a P&A Upper Hole Abandonment 4 Original Wellbore Schematic p_27A SAFETY NO ANDSELASS.0A6909 670 -UP EAM� , mut 1 G(�1 AN03ELL0.33Y0t69P'E8fi7P'YgS Crude behind DPZ 1 2002 6148 ft 9-5/8,@surface-tP -- 207x• - 4yt a7�p®Eg, .rp D�asir 2151ftF4 NIA"IM "Ems OASIFTAMtDiM '' .aycc3Y.rn,caasms.D=fzsrr � Est Cm behind 4-5/8"@2151-2958ft I j Casing Leak@ 4945-4955ft Tubing Leak X5063-5086ft �bnYm ID m 2.38" � 8744• � � 8pT SEAL ASSY b LQCATOR €stTOC behind 9-518' @76mft I 7"Liner fullycemented _ Est TOC behind 3-3116" @ 9274ft D"2Q D, 961T ' W OVr YND01Yry-2rAj OLV- 940( BERKO 1 2 rcV tli f3]eb4Ni3 F44JUMC FAY LM i!f!: l.D KYSflFANlf+R3e TAll$ Y1flL. D27A —"_�.. V7/NCTJ PJC.SEitg,FgSA..E[EytylMi!) i6Mf W'2051990 _.-. AnW 504M2154301 E6:ZT. T11Yt Rt0', YY7Y FTh E 789: fiP D".0. tAYlYs7 D -27a P&A Upper Hole Abandonment 5 r + r D, 961T ' W OVr YND01Yry-2rAj OLV- 940( BERKO 1 2 rcV tli f3]eb4Ni3 F44JUMC FAY LM i!f!: l.D KYSflFANlf+R3e TAll$ Y1flL. D27A —"_�.. V7/NCTJ PJC.SEitg,FgSA..E[EytylMi!) i6Mf W'2051990 _.-. AnW 504M2154301 E6:ZT. T11Yt Rt0', YY7Y FTh E 789: fiP D".0. tAYlYs7 D -27a P&A Upper Hole Abandonment 5 Current Wellbore Schematic TRIM 4' CNV AC LATOR= AXELSON D -2 7 A AN SD EAL ASSY@ 8690' & 8670'MKB. ING 518" PKR KB. B.EV = -. 71.9' BF (HIEN 428'f]B 2073' 41/2. OOrsESS6V THIP, p=3.813' 3500 Max Angle = 101 @ 9795' 13-3fe• CSG, 2675' Datum ND 94()8 72#, LBO BTRS, Datum ND= 8800 D-12.347' PC LEA -4945' - 4955' - Tec CFA''- 5063' - 5086' TAG TBG TOC (09123/19) 5096' SLM- Minimum ID = 2.36" @ 8744' BOT SEAL ASSY & LOCATOR FlSH'. 15" BOWSPRING ECCENTRALQ RARM - FROM TBG PUNCH (09/04/19) _ JI LOP OF V\ CMT H 8725' 1 'TBG PUNCH (09/04/19) -8725'-8730' TOP OFT LN62 8756' 7" LNR 26#. L-80 WS, .0383 bpf, D = 6276" 8755• XO TO T LNR 29#. L-80 BTRS 3-12' LNR, 8.81#,L STL, 8797' 0087 bpf, D = 2.992' 41/2"TBG_12. SO L -A0. .0159 bnf n=aau^ nonan L FTOPOFCEMENT -- 9460' 1WPo5) -9459TBK2rw! RA TAG a 9469' _ -- - - -� PERFORA7ONSUMMARY REF LOG: SWS-MCNL/GR ON 01104106 ANGLE ATTOP PERF: 92" 0 9950' 6 110630 -10850 S 01/06/06 09/06!19 2" 6 71390 - 11550 j C 01Po6/O6 09/06/19 09/10/19 EPD/JMD TBG PUN 09110119 1 TFA/JMD TBGXIA 5 5063 485428 OLBO DW RM 0 04/21/10 -4 8480 6090 30 �OTT"8- -LBD DMY RM 0 1028/05 '3 T350 8889 22 OTIS-LBD DMY RA 0 1028/05 '2 8123 ]60] 24 OTIS-LBD DMY RA 0 10/28/05 8744' mm es D = 3.8" (12/17M5) (BEHIND P 7 879 3 p 2" ea/z3ie6 BEHIND CT LNR MLLOUTWINDOW(0-27A)9462'-9468' 10110' 3-3/16=X2-7/8' XO, D-2-41" .0076 bpf, p = 2.80" PBTD� 11589' 2-0/8' LNR, 6.te#, L-80 STL .0058 bpf ID = 22 LNR, #, 6TL .U058 bpf ID = 2 94f��11626'11626' COMMENTS PRUDHOEBAYUNR TAGGED TOC (09/13/19 WELL D -27A TAGGED TOC (0923/19) PERMIT No: 1051930 UPDATED CMT -TBG &PC LEAKS API No: 50-029-21543-01 SEC23,T11N,R13E 1606'FNL& 169ZFEL BP Exploration (Alaska) D -27a P&A Upper Hole Abandonment 6 Proposed Wellbore Schematic__ _ _ 0 AXELSON� CJM Tbg, IA and CA 719' -1500 fw to surF IEVCn29-5Mx13-318'=2151-295&Md E� Topof Cn2 9-518'= 7G80 -SAFETY CI -27A I AM SD EALL ASSYQ 8690' a 86 : WARNINQ 0 M UL PKR ` �eR Tbg&PCCsg L�'1506 rnC J4 If2' 0775 OBE SSSV W,, D-3.813" C&9cft Tbgand FCCsg to S375ando21000KI. WMTYO- Saw GATE T -- REV BY COMMENTS F03fOt/86 ORIGINAL COMPLETION _ v ST MO ' TVD oFV TYPE v V I ATC.H, Pm H DAW _ - 133l4•CoG. >2x,.eo 9TR6, 10-12.34]' 2676, RGT/PJC SET W1 EASABLE SPEAR 01113,06 KSS/PAG GLV CIO KSB/fLN DRLG DRAFT CORRECTIONS 09"EPDIA�q 0 6 .3002 2930 4 OTIS-LBD DMY RM 0 W2110�_. _ 01425%10 CJNAIJC SETCATVALVE/GLV C60 3 3083 483426 00 OM 1 •2 61231 40 8U] 30 22 OTISt@D OMY RM 0 W2UfR OTS -L80 DMY FW RA 0 0ML@D I x02605 PC Leah 49-05-55 mdtT Leak5963-eB rtq __ _ J DW RA 0 +4_IZ•HES E20RLL SY@CMT RETANER (L9N+1191.; 8715 �. IEISK IF BOWSPRN3 ECCENTRALMR ARM ILLLMTBG PUNCH tC9A<i19; rTBG PUNCH (OW419j j-,,8T25'4730't TOPCF r LNR 8758' r LN1Z 26#, L-50 WS, .0383 bpf, V-6,276* XO TO r LNR, 2A4, L•80 BTRS ___ . 3-17 LNR, SSI N, L-805TL, 8797' .0087 W. D = 2.992' . 4112• TBG, 12.0. L-80, .9152 bpf, D= 3959' 88118• -4"aB'CSG, 47x, L-8081775. D=eim 8991• FBKR VNiP5TOLIC ('2 1205) -9467^ • W f RA TAG a 84W' 7-LNP,291,4-WSTHS,.0371 VI, 0v6.184' �, ncr 4oc OWS MCNUcR ON01K4ow ANGLE AT TOP PEFF: 92° @ 9950' I NOW: RONr E1 Pmdcfi_an O6 WNsW cd ped data IISIZE'SPF P1713EVALL _gz�3_HOi 8OL 't 8 9950 tb•50 S 01A8O8 UOA61+9 2' 6 10630-10550 S 10 Z —Z01A)6)0612' 6 11390-11550 C @6)06I 05106F19 3.3/16^ LMT, B20, L -W TCI, 0076 bpi, D: 7, W -oro-A4-1r INV MR. D= 87M'�—+3_]0`BKR OERQY SLV.D=300' -87&4--3-12•fdR"COx NP,o-2.613•( L 8776' 41fr GT1J XN NP, 6LLED D = 3.8• (12J171D5) (B68ND PIPE) - 8791-—i31f2'X 3976 X0.1-2786' BEHIND CT LNR MLLOU'I WIN/0W(D-27Aj 9407-9t66� D=2441' pm - 11589' — �2-Tfd^LNR, E.1Ex, L-80 BTL, 005E 6Pi1 =2.441• -N62fi� DATE f;EY BY COMMENTS GATE T -- REV BY COMMENTS F03fOt/86 ORIGINAL COMPLETION _ v OSRif14 JMD WBS CLEANUP PER TALLjFrH �61/O7A8 NORDICI. CTO SIDETRACK -27A OOA4114 RGT/PJC SET W1 EASABLE SPEAR 01113,06 KSS/PAG GLV CIO KSB/fLN DRLG DRAFT CORRECTIONS 09"EPDIA�q 0 TBG PUNCHES, RETAN£R,�31f13l08 _1.___ NER, 19GXN TOC 0s+* ID „Q]r2gp0 POBM1'JC C/Pf PERT (0]/p9A91 01425%10 CJNAIJC SETCATVALVE/GLV C60 D -27a P&A_Upper Hole Abandonment PRIDHOE BAY UNIT WELL D -27A PEWU No'.'2051030 API NO: 5002921543-01 SP Exp1m0on (Adasl s) N STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended R1 - Well Class: 20AAC 25.105 20MC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero 11b. Development 0 Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or Aband.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 9/23/2019 ' 205-193 ' 319-114 3. Address: T Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 12/28/2005 50-029-21543-01-00 - 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: 1/2/2006 PBU D -27A Surface: 1606' FNL, 1692' FEL, Sec. 23, T11 N. R13E, UM 9 Ref Elevations KB 71 91 17. Field/Pool(s): Top of Productive Interval: 220' FSL, 3554' FEL, Sec. 14, T11 N, R13E, UM GL 41,51 ' BF 41.94 PRUDHOE BAY, PRUDHOE OIL Total Depth: 1341' FSL, 4970' FEL, Sec. 14, T11N, R13E, UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: • 5096'14956' ADL 026285 ' 41b. 41b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 653461 • y- 5959382 Zone - ASP 4 ' 11626'19013' • 91.32 TPI: x- 651560 y- 5961170 Zone - ASP 4 12. SSSV Depth (MD/TVD): 20 Thickness of Permafrost MDr VD: Total Depth: x- 650120 y- 5962262 Zone - ASP 4 None 1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13. Water Depth, if Offshore: 21, Re-drill/Lateral Top Wndow Submit electronic and printed information per 20 AAC 25.050MDf N/A (ft MSL) VD: 9462' / 8921' 22. Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and panted logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous otentlal, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, Acronyms may be used. Attach a separate page if necessary RECENED MWD /GR/EWR, MGR / CCL /CNL OCT 17 2019 23. CASING, LINER AND CEMENTING RECORD CASINGWf. PER PT GRADE SETTING DEPTHMD SETTING DEPTH TVD HOLE SIZENT a non CEMENTING RECORD PULLED TOP TOP BOTTOM 20" 32' 32' 112' 36" 8 cu yds Concrete 13-3/8" 72# L-80 32' 32 2675' 17-112" 3255 cu k PF'E', 465 cu ft PF 9-5/8" 47# L-80 29' r2575' 29' gg83' 12-1/4" 575 cu it Class'G' 7" 29# L-60 8756'8263' 8921' 8-1/2"340 cu ft Class'G' 3-12"x3-3/16" 8.81#16.2# L -8o 8740' 8248' 9013' 4-1/8"x33/4" 90 cu it Class 'G' x2-7/8" 6.16# s2+ 24. Open to production or injection? Yes ❑ No 0 • 25. TUBING RECORD If Yes, list each interval open (MD/ND of Top and Bottom; Perforation Size and Number; Date Perfd): GRADE DEPTH SET (MD) PACKER SET (MD/TV 4-1/2" 12.69 L-80 8806' 8687 / 8199' �S 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DTE Was hydraulic fracturing used during completion? Yes ❑ No 0 Per20 AAC 25.283 (i)(2) attach electronic and printed 1 information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED VEPIFIED See Attached 27. 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 Penod # Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size Gas -Oil Ratio: Flow Tubing Press Casing Press: Calculated 24 Hour Rate —.11i Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API loam; Forth 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only 1© 1171 RBDMS96" OCT 2 8 2019 ; s a 1u 50./b 1(1 28. CORE DATA Conventional Cores) Yes ❑ No 0 Sidewall Cores Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No 0 Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 9638' 9032' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. 23SB - Zone 2B 9472' 8930' 22TS 9539' 8983' 21TS-Zone 2A 9638' 9032' Formation at total depth: Zone 2A 9638' 9032' 31. List of Attachments: Summary of Daily Reports, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Aivano, Mike (Udelhoven) Authorized Title: SI peciali Contact Email: mike.aivano@bp.com YY11 j�I Authorized Signature: Date: `V �.� l ((� Contact Phone: +1 9075645475 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10407 well completion report and 10404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a. 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 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Reviewthe reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. 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 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only WELL NAME: D -27A 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 8660'- 8665' Tubing Punch 8725'- 8730' Tubing Punch 8715' Set Cement Retainer 5096' 76 Bbls Cement Daily Report of Well Operations PBU D -27A T/I/O = SSV/300/190. Temp = SI. Purge C&B / Chemical lines with hydraulic fluid. No AL, or flowline. Control line pressure = 500 psi, Balance line = 520 psi. Control line is @ 6 O'clock position, balance line @ the 12 O'clock position. Control line took 2 gallons of fluid and had good injectivity @ 2500 psi. Balance line took 2 gallons of fluid & had good injectivity @ 2900 psi. Tags hung. 8/5/2019 SV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. 11:00 T/I/O = SSV/300/200. Temp = SI. Cement C&B lines (P&A). No AL, or flowline. IA FL @ 30', OA FL @ surface. Balance line @ 150 psi.eA 2 `+ allnns ofcement down balance line and pressure up to 3500 psi then pressure fell off to 0 psi Tag hung on balance line. Final WHPs = SSV/300/200. 8/9/2019 SV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. 16:15 T/I/O = SSV/300/200. Temp = SI. Cement C & B lines (P&A). No AL, or flowline. Control line @ 340 psi. Pumped —2.5 gallons of cement down control line and pressured up to 2500 psi then pressure fell off to 0 psi. Tag hung on balance line. Final WHPs = SSV/300/200. 8/10/2019 SV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. 11:00 T/I/O = 140/340/210. Temp = SI. PT C & B lines (P&A). No AL or flowline. CLP = Vac, BLP = Vac. Pumped —1 gallon of hydraulic fluid down control line to pressure up to 2500 psi. Monitored 15 min. CLP decreased 33 psi. Repeat on balance line with 0.7 gal hydraulic fluid. BLP decreased 68 psi. Bled both lines back to 0 psi. Tag hung on balance line. 8/13/2019 SV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. 16:00. ****WELL S/I UPON ARRIVAL**** (Plug & abandonment) DRIFTED W/ 3.70" WRP DRIFT, 3.50" LIB TO LTP SPEAR @ 8,741' SLM (Impression of 4- 1/2" f/n) 8/16/2019 ****CONT JOB ON 8/17/19**** ****CONT. JOB FROM 8/16/19**** (Plug & abandonment) SLICKLINE SWCP #4522 RDMO 8/17/2019 ****WELL LEFT S/I & PAD -OP NOTIFIED OF STATUS UPON DEPARTURE**** T\I\O = 225\300\200. RD SV, RU TEMP #111. PT'd against SSV 350\5000 PSI (Pass) 8/18/2019 Charted and Retained. RDMO. ***Job Complete***. ***WELL SHUT IN ON ARRIVAL*** PUNCH TBG FROM 8,660'- 8 665' ELMD WITH TITAN 2" (CIR-2106-4T25) CHARGES. PUNCH TBG TAIL FROM 8 725 - 8 730' ELMD (missing bowspring eccentralizer arm). DRIFT TO 8,733' ELMD WITH JUNK BASKET, 3.65" GAUGE RING (no recovery). ***JOB CONTINUES ON 04 -SEP -19 WSR*** 9/3/2019 **FISH LIH - 15" OF BOWSPRING ECCENTRALIZER ARM.** ***CONTINUES FROM 03 -SEP -19 WSR*** PUNCH 4.5" TUBING FROM 8725-8730'. SET HES EZ DRILL CEMENT RETAINER AT 8715' 9/4/2019 ***WELL SECURED UPON DEPARTURE*** CTU #8 1.75" CT. Job Scope: Cement P&A. MIRU CTU. Perform Weekly BOP Test. MU & RIH w/ Halliburton cement retainer stinger. Stop at 8690'. Pump 11 bbls surfactant and 184 bbls 9.8 ppg brine down coil taking CTBS returns, IA shut in. Pump 46 bbls surfactant and 9.8 ppg brine down coil, taking IA returns, CTBS shut in. Continue pumping 9.8 brine. 9/5/2019 ***Job Continued on 9/6/19 WSR*** Daily Report of Well Operations PBU D -27A CTU #8 1.75" CT. Job Scope: Cement P&A. Continue pumping 9.8 ppg brine down coil, taking IA returns. Pump a total of 530 bbls 9.8 ppg brine up the IA. Sting in to cement retainer at 8719' CTM. Good injectivity test through cement retainer ( 1.5bpm at - 4100psi ). Rig up Cementers. Pump a total of 76 bbls of. Cement. After -13 bbls out of the stinger, noticed circ -pressure bump - Indication of squeezing into perfs. Able to Sqz 24 bbis below retainer. Unsting & lay in 52 bbls taking both Tbg & IA returns. Lay cement up to 7925'. Close choke & pooh pumping pipe displacement with 9.8ppg Brine. While laying in Cement got zero returns at surface initially due to Brine drinking thru PC -Leak. Returns were regained while laying in. Total of 21 bbls returned while laying in, 42% return rate. Freeze Protect Tbg w/ 2.5 bbls of 50/50 Meth (150') and Brine. Freeze Protect IA w/ 8 bbls 50/50 Meth (150') & Brine. Rig Down CTU. TOC in Tbg & IA at ^ 7925'. 9/6/2019 ***Job Complete*** ***WELL S/I ON ARRIVAL*** (P&A) DRIFT W/ 3.0" SAMPLE BAILER TO 5084' SLM (cement recovered). ATTEMPT TO BREAK THROUGH CEMENT BRID PLE BAILER AT 5086' SLIM. ATTEMPT TO BREAK THROUGH CEMENT BRIDGE W/ 5'x2.50" DRIVE DOWN BAILER AT 5086' SLM (recovered cement). ATTEMPT TO BREAK THROUGH CEMENT BRIDGE W/ 2.50" CENT AND 10'x1.75" DRIVE DOWN BAILER AT 5086' SLM (recovered cement). PERFORM STATE WITNESS TAG W/ 3.0" SAMPLE BAILER AT 5086' SLM (recovered runny cement) 9/13/2019***WELL TURNED OVER TO DSO*** ***WELL S/I ON ARRIVAL*** (P&A) TAG TOC AT 5 096' SLM W/ 3.00" SAMPLE BAILER (State witnessed by Matt Herrera). 9/23/2019 ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATER OF WELL STATUS*** TREE = 4" CNV WELLHEAD = FMC ACTLA )R = AXE LSON KB.ELEV= 71.9 BF. E LEV = 42.8' KOP= 3500' Max Angle = 101" @ 9795 Datum ND= 9409 Datum TVD = 8800' 13 -3/8 -CSG. —[7726775::7r 724, L80 STRS, D =12-347° PC LEAK 4946' - 4966' — TBG LEAK 60$3' - 6066' TAG TBG TOC (09/23/19) 509q' S Minimum ID = 2.36" @ 8744' BOT SEAL ASSY & LOCATOR D-2 7 A SAFETY AN SD EALL AY NOTES: 8690' & 8670- MKB. 5/8" PKR 2073' 4-1/2' 0T6 DBE SSS" NP, ID = 3.813" r4G I IPTUAMn0=1 c ST MD ND DEV TYPE VLV LATCH PORT DATE 6 3002 2930 4 OTIS-LBD DMY RM 0 0421/10 5 5063 4854 28 OTIS-L8D DMY RM 0042"10 8744' 3.70'BKR DEPLOYSLV,D=3.00" "4 6460 6090 30 OTIS-11SDMY RM 0 1028/05 "3 7350 6889 22 OTIS{BD DMY RA 0 110128M5 •2 8123 7607 24 OTS-LBD DMY RA 0 1028/05 "1 8545 7994 22 OTIS-LBD DMY RM 0 1028/05 4= BEHIND CEN 4-12" oTS XA 8672' —1TBG SEALASSY ES EZ DRILL SVB CMT RETAINER (09/04119) 8]15' ){:Y�? 868T 9-5/B"X4-12"TIW PKR, D=4.75" SH: 15'BOWSPRNGECCENTRALRERARM ANGLE ATTOP PERF: 92'@9957 $739' 2.813° RELEASABLESPEAR INTO PKR(05/14/1 ?OM TBG PUNCH (09/04/19) SIZE SPF TOP OF a CMT 8725° ` 873$' 4-12' OT6 X NP, D = 3.813' TBG PUNCH (09/04/19) 8726'-8730' 2' 8740' 4-12° KB LTP, D=2.38' (01/06/06) TOP OFT LNR 8766' ` 874.x• BOT SEAL ASSY&LOCATOR ID=2.36" 09/06/191 2" 8744' 3.70'BKR DEPLOYSLV,D=3.00" LNR, 26#, L-80 U4S, .0383 bpf, D = 6276' 8]66' 01/06/06 I TO 7" LNR 29#, L-80 BTRS 2' 6 11390-11550 C $764' 3-12'HOWCOX NP,D=2.813° 09106/19T 8775' 4-1/2" OTIS XN NP, MILLED 3-12" LNR, 8.81#, LA0 STL, 8797' D = 3.8' (12/17/05) (BE NNO PIPE) .0007 bpf, ID =2.992" $797' 3-1/2" X 33!16" XO, ID = 2.786" 2" TBG, 12.6#, L-80_0152 bpf, D = 3.958" 8$08' 8808' 4-12' WLEG, D = 3.958' 9-5/8" CSG, 47#, L-80 BTRS, D = 8.681" 8991' ® ELMD TT ON LOGGED 0323/86 BEHIND 9040' 7 MARKERJONT CT LNR TOP OF CEMENT --[ 9460' BKR WHIPSTOCK (12/12/05) ^•9459 RA TAG @ 9469' STRS, .0371 bpf, D = 6.184' I—F 97U PERFORATION SUMMARY DATE REV BY COMMENTS REF LOG: SWS-MCNL/GR ON 01/04 09/17/19 MTWJMD TAGGED TOC(09/13/19) ANGLE ATTOP PERF: 92'@9957 10/09/19 RCB/JMD TAGGED TOC (0923/19) Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL NS z SHOT SOZ 2' 6 9950-10150 S 01/06/06 09/06/191 2" 6 10630 -10850 S 01/06/06 09/06/191 2' 6 11390-11550 C 01/06/06 09106/19T 94¢T 7°MARKE(i JOM 60s"4 m • �• "1'1'1'1'1'U•1'w 11111111 1111111 11111111 ``. .1.1.1.1A.1.1.1 6- LNR, 6.2#, L-80 I 101 .0076 bpf, ID = 2.80" PBTD 11589' 2-7/8" LNR, 6.16#, LA0 STL, .0058 bpf, ID =2.441' 11626' DATE I REV BY I COMMENTS DATE REV BY COMMENTS 03N1B6 ORIGINALCOMPLETION 09/17/19 MTWJMD TAGGED TOC(09/13/19) 01/07/06 NORDICI CTD SIDETRACK (D -27A1 10/09/19 RCB/JMD TAGGED TOC (0923/19) 105f211141 JMD IWBS CLEANUP PER TALLIES 10/17/19 MA/JMD UPDATED CMT -TBG & PC LEAKS 06/04/14RCT/PJC SETRELEASABLE SPEAR(5/14/14) 09/10/19 EPD/JMD TBG PUNCHES, RETAINER, FISH 09/10/191 TFA/JMD ITBG X A TOC (09/06/19) WFD PRUDHOE BAY UNIT WELL: D -27A PERMIT No: 2051930 API No: 50-029-21543-01 SEC 23, TI I N, R1 3E, 1606' FNL & 1692' FEL BP Exploration (Alaska) MEMORANDUM TO: JimRegg!� I(IiQj tk P.I. Supervisor t FROM: Matt Herrera Petroleum Inspector Section: 23 Township: Drilling Rig: Rig Elevation: Operator Rep: Jeremy Grimes Casing/Tubing Data (depths are MD): Conductor: 20" -O.D. Shoe@ Surface: 13 3/8" . O.D. Shoe@ Intermediate: 9 5/8" - O.D. Shoe@ Production: Feet O.D. Shoe@ Liner: 7" O.D. Shoe@ Liner: 3.5"x27/8"-O.D. Shoe@ Tubing: 41/2" 'O.D. Tail@ Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: September 23, 2019 SUBJECT: Well Bore Plug & Abandonment PBU D -27A BPXA PTD 2051930; Sundry 319-114 11N Range: 13E Meridian: Umiat Total Depth: 11626 ft MD Lease No.: ADL 0028285 Suspend: X - P&A: 112 . Feet 2675 Feet 8991 Feet Csg Cut@ Feet 9457 Feet 11626 - Feet 8808 Feet Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Tubing Retainer 8715 ft MD 5096 ft MD- 9.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing IA OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Due to well PBU D -27A having multiple tubing and PC leaks attempt to prep well for coil tubing side track failed in 2014. The well has been classified as Non -Operable. A cement retainer was set at 8715 ft MD post tubing punch (8725 - 8730 ft MD). Injection established below retainer of 75 BBL's 15.8 ppg cement mixed and pumped for plug in tubing an tubing -casing annulus. Top of cement was tagged and verified by wireline and a sample brought to surface with AOGCC Inspector witness. No explanation offered as to why the tag was 2000 ft higher than planned. Attachments: none rev. 11-28-18 2019-0923_Plug_Verification_PBU_ D-27A_mh THE STATE °f.L A LASKAX GOVERNOR MIKE DUNLEAVY Aras Worthington Interventions & Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU D -27A Permit to Drill Number: 205-193 Sundry Number: 319-114 Dear Mr. Worthington: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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. I Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this Zoo day of March, 2019. V500SL4y 1010 % STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspends Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Soap Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0 5. Permit to Drill Number: 205-193 3, Address: P.O. Box 196612 Anchorage, AK 99519-8612Stretigrephic ❑ Service ❑ 6. API Number: 50-029-21543-01-00 1 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? e. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU D -27A 9. Property Designation (Lease Number): 10. Field/Pools: ADL 0028285 PRUDHOE BAY. PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (it): Total Depth TVD(h): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11626 9013 10994 9070 10994 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 32-112 32-112 Surface 2643 13-3/8" 32-2675 32-2675 5380 2670 Intermediate 8962 9-5/8" 29-8991 29-8483 6870 4760 Liner 701 7" 8756-9457 8263-8916 8160 7020 Liner 2886 3-1/2" x 3-3/16" x 2-7/6" 8740- 11626 8248-9013 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade : Tubing MD (ft): 9950-11550 9020-9014 4-1/2" 12.6# L-80 27-8808 Packers and SSSV Type: 41/2" TIW Packer Packers and SSSV MD (ft) and TVD (ft): 8687 / 8199 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: April 1, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended 0 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Aivano, Mike (Udelhoven) be deviated from without prior written approval. Contact Email: mike.aivano0tip.com Authorized Name: Worthigton, Area Contact Phone: +1 9075645475 Authorized Title: Intervent' 8 Integrity Engineer ) Authorized Signature. Date: COMMISSION USE ONLY Conditions of approval Notify Commission so that a representative may witness Sundry Number. Plug Integrity Grl� BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: A ®GCC `/`p 'Tbc- Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 11110"' Subsequent Form Required: fid. 104 { APPROVED BYTHE 3f Zo'� Approved by. COMMISSIONER COMMISSION J Date: 'IBDMSMAR 2 0A210�1A9�1Q ORIGINAL Mot—ARAW Submit Fonn and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate .� � w/ + �'r_'t.$•3 by D -27a P&A Intervention Engineer Mike Aivano (907) 564-5475 Reviewed by Aras Worthington (907) 564-4102 Production Engineer Chris Stone (907) 564-5518 Expected Start Date: April 1, 2019 History D -27A has multiple tubing leaks at 5063'& 5086' and PC leaks between 4945'- 4955'. A releasable spear was stung into the liner top packer at 8739' in an attempt to prep the well for a coil tubing side-track in 2014. The spear has not been able to be recovered by either slickline or coil efforts. The well was classified as Not Operable in May 2010 and has been recommended for P&A due to lack of value in its current state. Objective The objective of this procedure is to attempt to place a cement plug below a cement retainer into the production liner and lay -in a balanced cement plug above the production packer for abandonment of the wellbore. DPZ's present in the well: DPZ 1 from 2002 ft - 6148 ft and DPZ 3 from 9018 ft - 11626 ft. Procedural Steps Special Projects 1. Injectivity test into Control and Balance lines. 2. Cement Control and Balance lines with squeezecrete. Slickline 1. Drift and Tag top of fish at 8739 ft with 3.75" drift for cement retainer. Eline 1. Tbg punch just above the top of fish from -8725 ft - 8730 ft. 2. Tbg punch just above the seal assembly from 8660 ft - 8665 ft. 3. Set Cement Retainer at -8715 ft. D -27a P&A Sundry Q Coil Tubing 1. RIH with cement retainer stinger to —8690 ft. 2. Circulate the following up the CT x Tbg annulus at max rate allowed by tool rep: ➢ 5 bbls MEOH ➢ 10 bbls hot (160 deg) freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal UO67 ➢ 108 bbls 9.8 ppg brine f 3. Circulate the following up the Tbg x 9-5/8" annulus at max rate allowed by tool rep: ➢ 5 bbls MEOH ➢ 50 bbls hot (160 deg) freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal UO67 ➢ 465 bbls 9.8 ppg brine 4. Attempt to establish injection below the cement retainer with 20 bbls of 9.8 ppg brine (due to PC leak and Tbg leak unsure if spear is holding pressure or not). 5. If able to inject below the cement retainer at'/ bpm below 4000 psi then: ➢ Mix and Pump 75 bbls of Class G cement per design ➢ Squeeze approximately 24 bbls of cement below the cement retainer.' 6. If unable to inject below the cement retainer then unsting then lay -in 75 bbls of cement above the retainer in the 4-1/2" Tbg and 9-5/8" x 4-1/2" annulus 7. Once a volume of 24 bbls of cement has been pumped below the cement retainer or injection pressure is less than 1/4 bpm at 4000 psi un -sting from cement retainer. 8. Lay -in remaining volume of cement above the cement retainer in the 4-1/2" Tbg and 9-5/8" x 4-1/2" annulus Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab pp +/- 0.1 ppg Slurry Temperature: between 800 and 110°F Fluid Loss: 40-100cc (20-50cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: I Minimum 8 hours Slickline 1. Tag TOC AOGCC Witnessed Sundry to abandon upper section of the wellbore to follow. D -27a P&A Sundry Q Volume Calculations: If able to squeeze cement below the cement retainer and spear bbl/ft Rtm i 2-7/8" 0.0058 10994 10110 884 5.1 3-3/16" 0.0076 10110 8797 1313 10.0 3-1/2" 0.0087 8797 8740 57 0.5 4-1/2" 0.0152 8740 8715 25 0.4 Liner Volume Below Cement Retainer 16.0 9-5/8" x 4- 0.0152 8715 8687 28 0.4 1/2" 0.0535 8756 8725 150 8.0 x 4-1/1" Volume Below Cement Retainer 8.0 4-1/2" 0.0152 8715 8687 28 0.4 4-1/2" 0.0152 8687 7957 730 11.1 9-5/8" x 4- 1/2" 0.0535 8687 7957 730 39.1 Volume Above Cement Retainer 50.6 If unable to squeeze cement below the cement retainer bbl/ft Rtm r c ., i.. 4-1/2" 0.0152 8715 8687 ---�- 28 - 0.4 4-1/2"0.0152 8687 7600 1087 16.5 9-5/8" x 4- 0.0535 8687 7600 1087 58.2 Volume Above Cement Retainer 75.1 D -27a P&A Sundry v2 3 E- 4' U-ZIA AND SEAL ASSY 9 SO"' a ee7ARIOn`E" MKB. a -"IW I Crude behind _ DPZ 1 2002-6148 It 9.5/8"@SurfacetD 2077' 4.1?OI6178ES86Y Ip,o•9e1r 2151 h Est. Cmt behind 9-5/8" @ 2151- 2958 It Casing Leak @ 4945 -4955h Tubin Leak 5063-5086h Mlnirnum ID - 2.36"8744' � 1 BOT SEAL ASSY 6 LOCATOR I Est TOC behind 9-5/8" @ 7680 It 1" Liner fully cemented IF ITOPOF r LNTH 87j 1 r LW 260, L40 WSJ 03836q, D -827e' 7ELEV 71.$ 428' Mt•A 9500' olac U-ZIA AND SEAL ASSY 9 SO"' a ee7ARIOn`E" MKB. a -"IW I Crude behind _ DPZ 1 2002-6148 It 9.5/8"@SurfacetD 2077' 4.1?OI6178ES86Y Ip,o•9e1r 2151 h Est. Cmt behind 9-5/8" @ 2151- 2958 It Casing Leak @ 4945 -4955h Tubin Leak 5063-5086h Mlnirnum ID - 2.36"8744' � 1 BOT SEAL ASSY 6 LOCATOR I Est TOC behind 9-5/8" @ 7680 It 1" Liner fully cemented IF ITOPOF r LNTH 87j 1 r LW 260, L40 WSJ 03836q, D -827e' 8768' %O TO r Uel 29,, LAD BITS WW. SiI, 679' 13Z OOe70pC ID 2902' 2990 4-i? TBG, 1209. LAO, 0152,p1, D-3.e6T BBOT 95WCK479,1A05M.ID=6.691' q,t• Est TOC behind 3.3/16" @ 9274 It T0P07 OBIBIT Ry4 r 8190 N4TO/21205) 1 ■IRA TAOg9PSN1'OL 6490 rtMk2w,L40eTRS.037IbW ID.6.1M- f FUVD ATICNSL4ARI RS LOG SNS AXMONO1AA06 ANGLEATTOPREW erOISW NM9: Rtiv No ftc& 4 O br ftbrxal ri Mt9 SIMISITI WnWAL 10VA191 SHM I SO2 7 8 9950-'0150 O 01ABO8 7 8 IOB30. 10850 0 01ABOe 7 6 11390-11550 C DIMM GA.CI Mr1YY 4 ST ,D TVDIDEVi TYRE . VLV LATCHIFOODATE6 3002 2990 OT6t1�� DN IeJ5 506! 4854 OTBL D L7YY Ry4 6490 9090 b I0T6lBD ChN T893735022 i0I618D L,M M2 e 223 7607 24 'OML16D CW RA r el SEMNO Lagan N,OOW (p 21A) a5r-web D-147• RiOOE BAY LUT NOL a27A pew M IlM1930 AAW 504092154301 23. TIM RIX 1906 M e 169: BP WbrrrbA (Ab9E9) D -27a P&A Sundry Q 4 DPZ 1 2002-6148 ft DPZ3 9018-11626ft Crude in 13-3/8" x 9-5/8" Annulus from 2151 ft to Surface 13-3/8" Csg Shoe @ 2675 ft 13-3/8" x 9-5/8" Cm 2 151 -2958 it Leak in Production Casing 4945 -4955 ft Leak in Tubing 5063 -5086 ft 13-3/8" x 9-5/8" Est. TOC 7680 ft Tbg Punch 8725-8730ft 2.81" CT Spear stuck in Liner Top -- 8739 ft 7" Liner fully cemented 9-5/8" Shoe @ 8991 ft 7" x 3-3/16" Lnr Est. TOC 9274 ft 7" Shoe @ 9784 ft D-27 Proposed Injection below cement retainer w:: Calc/Estimated Cement behind pipe T_ Cement added for P&A f --- 4-1/2"SSSVNip@2073ft - Cement plug (-730ft) TOC @-7957 ft Tbg Punch 8660-8665 ft 9-5/8" x4-1 2"Pkr @ 8687 ft ti 4-1/2" Cmt Retainer @'8715 ft �} -- 4-112"KBLTP@8740ft 7 Liner Top @ 8756ft 2-7/8" CIBP @ 10994ft 3-3/16" x 2-7/8" Lnr PBTD @ 11589 ft Shoe @ 11626ft D -27a P&A Sundry Q 5 DPZ 1 2002-6148 ft DPZ 3 9018-11626 ft Crude in 13-3/8" x 9-5/8" Annulus from 2151 ft to Surface D-27 Proposed No Iniection below ce 13-3/8" Csg Shoe @ 2675 ft 13-3/8" x 9-5/8" Cmt 2151-2958 ft Leak in Production Casing 4945-4955 ft Leak in Tubing 5063 -5086 ft - 13-3/8" x 9-5/8" Est. TOC 7680 ft Tbg Punch 8725-8730 ft 2.81" CT Spear stuck in Liner Top 8739 ft 7" Liner fully cemented v, v 9-5/8" Shoe @ 8991 h 7" x 3-3/16" Lnr Est. TOC 9274 ft 7" Shoe @ 9784 ft retainer Calc/ Estimated Cement behind pipe Cement added for P&A 4-1/2" SSSV Nip @2073ft :-v Cement plug (`1087ft) TOC @ -7600 h Tbg Punch 8660-8665 ft w r� 9-5/8" x 4-1/2" Pkr @ 8687 ft iv 4-1/2" Cmt Retainer @ -8715 ft 4-1/2" KB UP @ 8740 ft 7 Liner Top @ 8756 ft CIBP @ 10994 ft 3-3/16" x 2-7/8" Lnr PBTD @ 11589 ft Shoe @ 11626 ft D -27a P&A Sundry Q 6 PTD Loepp, Victoria T (DOA) From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Tuesday,June 09, 2015 9:32 AM To: Loepp, Victoria T (DOA) Subject: D-27A (PTD#205-193) Expired Sundry(s) Follow Up Flag: Follow up Flag Status: Flagged Victoria, We have 2 approved sundries for this well that have or will expire. 314-355 (Repair Well, Pull Tubing, Alter Casing and Scab Liner) has expired,and we will let 314-385 (Plug for Redrill) also expire. Please let me know if you have any questions. Thank you, Joe Lastufka SCANNED JUL 0 1 2015 Information and Data Controller Cell: (907) 227-8496( Office: (907) 564-4091 ir BP Exploration AlaskaI900 E.Benson B1vd.1Room: 788DiAnchorage,AK 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 March 06, 2011 p -, 2,' �' MA Q j ;. �:.. a05- 1613 Mr. Tom Maunder C ' CEIV Alaska Oil and Gas Conservation Commission M•" 333 West 7 Avenue %Mk : Anchorage, Alaska 99501 ASaske Oil & Gas Cons. Cciaznission Subject: Corrosion Inhibitor Treatments of GPB D Pad IncnorEtue Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from D Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Date: 03/04/11 Corrosion • Initial top Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # of cement pumped cement date inhibitor sealant date ft bbls - ft na gal D -01A 1970780 50029200540100 NA N/A NA N/A 1/31/2011 D -03A 2001340 50029200570100 NA 14 NA 100.30 1/19/2011 D -04B 2031100 50029200560200 NA 4 NA 56.10 2/19/2011 D -05 1700060 50029200580000 NA 0 NA trace 1/19/2011 D -06A 1970430 50029201480100 NA 0.5 NA 3.40 1/7/2011 D -07B 2051810 50029201620200 NA 0.5 NA 3.40 1/7/2011 D -08A 2021230 50029203720100 NA 0.5 NA 3.40 2/9/2011 D -09A 1990850 50029203810100 NA 0.7 NA 3.40 1/19/2011 D -10 1790530 50029203890000 NA 2.3 NA 8.50 3/2/2011 D -11B 2100770 50029204350100 NA 3.5 NA 23.80 1/6/2011 D -12 1800150 50029204430000 NA 1.3 . NA 5.10 1/15/2011 D -13A 2000810 50029204490100 NA 0.5 NA 2.55 3/31/2010 1 D -14A 1961530 50029204500100 NA 0.2 NA 0.85 1/15/2011 D -15A 1972120 50029204610100 NA 0.2 NA 0.85 1/15/2011 • D -16A 2090250 50029206830100 NA 0.1 NA 0.85 2/20/2011 D -178 2021110 50029206920200 _ NA 1 NA 3.40 2/19/2011 D -18A 2011030 50029206940100 NA 5.4 NA 34.00 2/20/2011 D -19B 2011120 50029207070200 NA 0.8 NA 3.40 2/19/2011 D -20 1820440 50029207800000 NA 0.5 NA 1.70 2/19/2011 D -21 1820520 50029207880000 NA 0.2 NA 3.40 2/10/2011 D -22C 2081210 50029207370300 NA 0.2 NA 0.85 2/10/2011 D -23A 1961880 50029207380100 NA 13.5 NA 93.50 3/1/2011 D -24 1852990 50029215060000 NA 0.9 NA 6.80 1/8/2011 D -25A 2000240 50029215220100 NA 6 NA 32.30 1/15/2011 D -26B 2060980 50029215300200 NA 0.8 NA 3.40 2/19/2011 0-27A 2051930 50029215430100 NA 0.3 NA 1.70 2/10/2011 D -28B 2090890 50029215560200 NA 0.3 NA 1.70 2/10/2011 0-29 1852530 50029214700000 NA 13.3 NA 27.20 1/16/2011 D -30B 2061840 50029226460200 NA 2.2 NA 13.60 12/25/2010 D -31A 1960950 50029226720100 NA 3.3 NA 27.20 1/19/2011 D -33 1960360 50029226520000 NA 2.2 NA 18.70 1/8/2011 Schlumberger ~~~Y ~ `~ () ~ (. Alaska Data & Consulting Services ~ '-' ~' ~ ~ ~°q ~~'~~'~ 2525 Gamhell Street, Suite 400 ~+~ _ Anchorage, AK 99603-2838 f7°tl9 ~~ ATTN: Beth Well Job # Log Description NO. 5520 Company: State of Alaska Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD H-25 B-13A D-27A H 17A BCRD-00017 BBSK-00018 BCRD-00021 PRODUCTION PROFILE GRAVEL PACK/TBG PUNCWMP T LDL - 05/09/10 5/06/10 05/12/10 1 1 1 1 1 1 - BAUJ-00020 MEM PRODUCTION PRO ILE _. /04/10 1 1 F-12 07-328 Z-03A AVVO-00068 BBUO-00016 BD88-00006 PRODUCTION PROFILE - SCMT CN EDIT PD R EM O RELATI N 05/03/10 05/04/10 03/25!10 1 1 1 1 1 F-23A BBSK-00007 RST 02/17/10 1 1 C-13A AVYO-00060 RST - 02/16/10 1 1 E-33B AWJI-00078 MCNL _ 03/25/10 1 1 PLEASE ACKNOWt Ef)f;P REC EIPT wv ctrlJrfJ r wun oc~ruouwn_ nue n..o.. ~.n...•..- BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data 8 Consulting Services 2525 Gambell Street, Sude 400 Anchorage, AK 99503-2838 05/24!10 • r, ~,k; l~ ~Q-- DATA SUBMITTAL COMPLIANCE REPORT 2/26/2008 Permit to Drill 2051930 Well Name/No. PRUDHOE BAY UNIT D-27A Operator BP EXPLORATION (ALASKA) INC MD 11626 TVD 9013 Completion Date 1/6/2006 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: MWD GR / EWR, MGR /CCL /CNL Well Log Information: Log/ Electr Data Digital Dataset Ty Med/Frmt Number Name API No. 50-029-21543-01-00 UIC N Samples No Directional Surve Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments D D Asc Directional Survey D C Lis 13484 Neutron Neutron D D Lis 13796 Induction/Resistivity ~,~ 13796 LIS Verification / C I~s~„!S 14440 Induction/Resistivity 0 11626 Open 1 8515 11567 Case Mem CNL CCL GR 25 Blu 1 8515 11567 Case Mem CNL CCL GR 9098 11566 Open 3/9/2006 GR EWR4 ROP 9098 11566 Open 3/9/2006 GR EWR4 ROP 9098 11612 Open 1/29/2007 LIS Veri, GR, ROP w/Graphics Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Gored? Y /~j Daily History Received? Chips Received? ~l'~N--- Formation Tops ~/ N Analysis Lv~ Received? Comments: Compliance Reviewed By: _____~_ __ Date: ` _ ~ ~ ~ _. _~~~~ STATE OF ALASKA '~~'~~ ALA OIL AND GAS CONSERVATION COM ION fr REPORT OF SUNDRY WELL OPERATIONS ~~ ~~ ~~ Y n 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate Q %% ~ ~ ~' Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~ -r~S ~~ Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well ~ ,~~%rcy.. ~S' ~f?JtJ/~• 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to DriII Number: ` Name: Development ~ Exploratory 205-1930 3. Address: P.O. Box 196612 Stratigraphic j SerVlce ~' 6. API Number: Anchorage, AK 99519-6612 50-029-21543-01-00 r 7. KB Elevation (ft): 9. Well Name and Number: 71.9 KB ~ PBU D-27A 8. Property Designation: 10. Field/Pool(s): ADLO-028285 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11626 ~ feet Plugs (measured) None true vertical 9013.49 ~ feet Junk (measured) None Effective Depth measured 11589 ~ feet true vertical 9014 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" Surface - 110' Surface - 110' Surface 2675' 13-3/8" 72# L-80 Surface - 2675' Surface - 2675' 5380 2670 Production 8991' 9-5/8" 47# L-80 Surface - 8991' Surface - 8483' 6870 4760 Liner 1028' 7" 29# L-80 8756' - 9784' 8263' - 9042, 8160 7020 Liner 2886' 3-1/2x3-3/16x2-7/8" L8c 8740' - 11626' 8248' - 9013' Perforation depth: Measured depth: 9950 - 10150 10630 - 10850 11390 - 11550 True Vertical depth: 9019.94 - 9018.76 9014.49 - 9018.69 9024.73 - 9014.47 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 Surface - 8808' Packers and SSSV (type and measured depth) 9-5/8"X4-1/2" TIW PKR 8687' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: 566 19550 0 0 1176 Subsequent to operation: 566 18577 0 0 1202 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~+ Service ~' Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG GINJ ~' WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: ~ BFI JUL 1 7 20D7 N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 7/10/2007 S%~p Form 10-404 Revised 04/2006 ®~ ~ (~ ~ ~ f ~ ~ ~.~t!> /s%~~/~, ,Sru~mit Original Only D-27A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 7/3/2007'CTU #8, Acid Stim; Interact publishing during job. MIRU unit. MU and RIH with 2.0" BDN. Tag btm at 11555' ctmd. ... Cont' on WSR 07/04/07 ... 7/4/2007CTU #8, Acid Stim; ... Cont' from WSR 07/03/07 ... Interact publishing during ';',,job. Fluid pack IA with 270 bbls of diesel. Jet perfs with 65 bbls of 50/50 ddiesel/xylene and let treatment soak. Kill well with 115 bbls of 1%KCL followed by -.110 bbls of diesel. pump additional 112 bbls 1%KCL down the coil into the 'formation to ensure well bore is sufficiently cool. Pump 76 bbls 7.5%HCL / 7.5% 'L66 Acid - 24 bbls Wax beads - 190 bbls 2% KCL - No change in WHP when ';jetting across perfs - saw a slight increase(--245 psi) in WHP when 1st batch of ?beads on perfs -slight decrease in WHP(-250) when 2nd batch of acid on perfs - =no change in WHP with the remaining stages -over flush with 100 bbls behind ;pipe. POH -keeping hole full with Diesel -Secure well - RDMO. Turn well over to 'ASRC for acid flowback. **' Job Complete ""` 7.5% HcL -Titration is 7.4% HcL -Iron is < 20 FLUIDS PUMPED BBLS 831 1 %KCL - 80 DEGREES 316 DIESEL 65 50/50 DIESEVXYLENE 15 50/50 METH 76 7.5% HCL W ITH 7.5% L66 1327 TOTAL . - WELL LOG TRANSMITTAL To: State of Alaska November 13, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: C-23B, C-41A_PB1, D-27A, G-30B, J-27A, K-04B. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 C-23B: X63 '~O '~ I `-~~ ~' I l Digital Log Images: 1 CD Rom 50-029-20775-02 Digital Log Images: 1 CD Rom 50-029-22385-01, 70 D-27A: c~C~J ~q3 ~ 1`~~-1~/(~ Digital Log Images: 1 CD Rom 50-029-21543-00 G-30B: ~C~S -2U~ ~ l ~1~139 Digital Log Images: 1 CD Rom 50-029-21613-02 J-27A: ~aba -aoo ~ 1'-!'!3~ Digital Log Images: 1 CD Rom 50-029-21733-01 Digital Log Images: 1 CD Rom 50-029-21023-02 STATE OF ALASKA ALASK . LAND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~'`~~ ~: ~ r~ ~. d ~ n nfi 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ib. Well Class: ~ ~1 Ig ap Ic~B e~rvlic°11S3iG 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 1/6/2006 12. Permit to Dr 205-193 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 12/28/2005 13. API Number 50-029-21543-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 1/2/2006 14. Well Name and Number: PBU D-27A 1606 FNL, 1692 FEL, SEC. 23, T11 N, R13E, UM Top of Productive Horizon: 220' FSL, 3554' FEL, SEC. 14, T11 N, R13E, UM g, KB Elevation (ft): 71.9 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 1341' FSL, 4970' FEL, SEC. 14, T11 N, R13E, UM 9. Plug Back Depth (MD+TVD) 11589 + 9014 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 653461 y- 5959382 Zone- ASP4 10. Total Depth (MD+TVD) 11626 + 9013 Ft 16. Property Designation: ADL 028285 _ __ TPI: x-_651560 y- 5961170 Zone- ASP4 Total Depth: x- 650120 Y- 5962262 Zone- ASP4 11 • Depth where SSSV set None MD 17. Land Use Permit: ------------------- - ~- -~---------------- ------~---------- i k f P f t i8. Directional Surrey. ®Yes ^ No 19. Water depth, if offshore N/A MSL erma ros 20. Th c ness o 1900 (Approx.) 21. Logs Run: MWD GR / EWR, MGR / CCL / CNL 2. ASING, LINER AND EMENTING ECORD CASING ETTING DEPTH MD ETTINQ EPTH TVD I"'1(>LE OUNT'; SIZE WT. PER FT. GRADE OP TTOM OP TTOM $IZE CEMENTING RECORD PULLED 20" Conductor Surface 110' Surface 110' 36" 8 cu ds Concrete 13-3/8" 72# L-80 Surface 2675' Surface 2675' 17-1/2" 3255 cu ft Permafrost'E', 465 cu ft 9-5/8" 47# L-80 Surface 8991' Surface 8483' i2-1/4" 75 cu ft Class'G' 7" 29# L-80 8756' 9462' 8263' 8921' 8-1/2" 340 cu ft Class'G' s-1/2° x 3-3/16• x 2-7/8" e.a1 a / szu / s.1 sn L-80 8740' 11626' 8248' 9013' s-a/a• x a-,/a• 90 cu ft Class 'G' 23. Perforations open to Produc tion {MD + TV D of Top and " " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 8808' 8687' MD TVD MD TVD 9950' - 10150' 9020' - 9019' 10630' - 10850' 9014' - 9019' 25. >ACID, FRACTURE,': CEMENT SQUEEZE, ETC. 11390' - 11550' 9025' - 9014' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 2100' Freeze Protect with McOH 26• PRODUCTION TEST Date First Production: January 14, 2006 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 2/12/2006 Hours Tested 4 PRODUCTION FOR TEST PERIOD OIL-BBL 109 GAS-MCF 1,688 WATER-BBL 61 CHOKE SIZE 91.55° GAS-OIL RATIO 15,442 Flow Tubing Press. 20 Casing Pressure 960 CALCULATED 24-HOUR RATE OIL-BBL 656 GAS-MCF 10,128 WATER-BBL 366 OIL GRAVITY-API (CORK) 25.6 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 . None ~ ~ ~~ ~~~~: 1`~~ `f n' 2~~~ ~ ~ ~ ~ )~~ /(~ ~ J"~rice~t~ ~ 9~ I 3 ~`F"~~~rIT` 9 ~ ~ // V ~`./ - i. .. ~ 't Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS 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". Zone 2B / 23S6 9472' 8930' None 22TS 9539' 8983' Zone 2A / 21 TS 9638' 9032' 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. ~~ ^ ~O o~o<. Signed Terrie Hubble Title Technical Assistant Date PBU D-27A 205-193 Prepared By Name/Number. Terrie Hubble, 584-4628 Well Number Permit No. / A royal No. Drilling Engineer: Barbara Las/ey, 564-5128 INSTRUCTIONS GeNeaa~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 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. IreM 4b: TPI (Top of Producing Interval). IreM 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 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 BP EXPLORATION Operations Summary Report Legal Well Name: D-27A Common Well Name: D-27A Event Name: REENTER+COMPLETE Start: 12/26/2005 Contractor Name: NORDIC CALISTA Rig Release: 1/6/2006 Rig Name: NORDIC 1 Rig Number: Date 'From - To I Hours Task Code' NPT I Phase 12/25/2005 16:00 - 18:00 2.00 MOB - P ~_ PRE 18:00 - 20:30 2.50 MOB P PRE 20:30 - 00:00 3.50 MOB P PRE 12/26/2005 00:00 - 01:00 1.00 MOB P PRE 01:00 - 02:00 1.00 MOB P PRE 02:00 - 04:30 2.50 MOB P PRE 04:30 - 05:00 0.50 MOB P PRE 05:00 - 08:30 3.50 MOB P PRE 08:30 - 10:40 2.17 MOB P PRE 10:40 - 12:00 1.33 MOB P PRE 12:00 - 12:15 0.25 MOB P PRE 12:15 - 15:30 3.25 MOB P PRE 15:30 - 16:00 0.50 MOB P PRE 16:00 - 18:00 I 2.001 MOB I P I I PRE Page 1 of 11 Spud Date: 12/27/2005 End: Description of Operations Pull 2" CT reel out of reel house Swapped out reel plates to 2-3/8" plates Changed out BOP's to 2-3/8" elements. Changed out upper combi to 2-3/8" X 3-1/2" VBR and lower pipe slips to 2-3/8" Changed out annular element Prep rig for move to D-27a ND BOP stack PJSM, jack up rig, move off well. PT tree cap to 5000 psi. Move rig to edge of pad. N2ES is moving down the Spine Road to Oxbow Road. Held PJSM with Crew and BP Security on Rig move hazards Mobilze rig via Spine Road from DS 13 to DS 14 Stopped at entrance to DS 14. Wating on Nabors 2ES pits to travel from Y-Pad to DSion the Spine Mobilize rig Crew change at CPS-1 Mobilize rig Rig arrived on D Pad at 1530 hrs Rig on D-pad at 1530 hrs. Spotted rig near D-27. Held PJSM and discussed hazards on backing over well Spotted rig over well and set down. Rig accepted at 1800 hrs 12-26-2005 18:00 - 18:30 0.50 BOPSU P PRE Held PJSM on RU and associated hazard. 18:30 - 20:30 2.00 BOPSU P PRE NU BOP Stack 20:30 - 00:00 3.50 BOPSU P PRE Testing BOPE. Witnessing of BOP test waived by John Crisp AOGCC. 12/27/2005 100:00 - 02:15 ~ 2.251 BOPSUR P 02:15 - 03:30 1.25. RIGU P 03:30 - 06:00 2.50 RIGU P 06:00 - 06:45 0.75 RIGU P 06:45 - 08:30 I 1.751 RIGU I P 08:30 - 09:00 0.50 RIGU P 09:00 - 10:00 1.00 STWHIP P 10:00 - 12:00 I 2.001 STWHIPI P 12:00 - 15:00 I 3.001 STWHIPI P 15:00 - 17:30 I 2.501 STWHIPI P 17:30 - 19:08 1.63 STWHIP P 19:08 - 21:35 2.45 DRILL P RU Berm, spot tiger tank, RU hardlines, test PRE Finished testing BOP's, John Crisp w/ AOGCC waived witnessing BOP test PRE Finish replacing pins in chain on injector PRE RU cable to CT, stab pipe, set packoff, MU CTC PRE RU to cut 200 ft CT off to move fatique point out of window and build section Cutting off CT PRE Install CTC, pull tested to 40k. set CTC. Loaded CT with 5 bbl MEOH and 55 bbl biozan Vct = 59 bbl with dart. PT inner reel valve PRE Spud meeting with crew WEXIT PU window exit BHA. Mills 3.8" No/Go on mill and 2.79" No/Go on string mill WEXIT RIH Tagged GLV # 1 8550 ft, went through, RIH, tagged up at 9475', Up Wt 42 K, 2.5 bpm at 1600 psi WEXIT Time mill cement f/ 9475 - 9480.8' at pinch point, motor stalled, made -16.5' correction, top of window at 9464.3' WEXIT Milling window f/ 9464.3' to 9470', 400 psi mtr differential, 5 k on bit, drilled formation to 9482', returns showed metal shavings, cement and formation. Worked thru window several times with /without pumps, POH, EOP Flag at 9350' WEXIT POH to BHA PROD1 OOH, check flow, unstab injector head BHA = 66.70 ft with 3 deg bend X-treme motor. Installed DS CTC and pull tested to 37k. PT CTC to 3500 psi Printed: 1/9/2006 9:43:17 AM BP EXPLORATION Operations Summary Report Page 2 of 11 Legal Well Name: D-27A Common Well Name: D-27A Spud Date: 12/27/2005 Event Name: REENTER+COMPLETE Start: 12/26/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 1/6/2006 Rig Name: NORDIC 1 Rig Number: Date From - To Hours j Task Code ~ NPT ~'~ Phase ' Description of Operations 12/27/2005 21:35 - 23:30 1.92 DRILL P PROD1 RIH with 3 dge motor watching GLM. Shallow hole test at 550 ft Orienter test at 3,700 ft 23:30 - 00:00 0.50 DRILL P PROD1 Stopped at 9,141 ft to tie-in. Logging the lower Tsad. 12/28/2005 00:00 - 01:25 1.42 DRILL P PROD1 Finished tie-in and completed mud swap Corrected -13.5 ft 01:25 - 01:33 0.13 DRILL P PROD1 RIH to TOW at 9460 ft. Ran past WS with 19R TF Ttagged bottom at 9,488 ft 01:33 - 02:10 0.62 DRILL P PROD1 Drilling build section in Zone 2B at 20L TF Op = 2.7 bpm at 3058 psi WOB = 1.5k to 3.Ok ROP = 10 to 20 fph 02:10 - 02:30 0.33 DRILL P PROD1 Orient TF around 02:30 - 03:30 1.00 DRILL P PROD1 Drilling build section in Zone 2B Op = 2.7 bpm at 3,100 psi CTP ROP 10 to 40 FPH Had several stalls at 9,502 ft to 9,503 ft 03:30 - 03:45 0.25 DRILL P PROD1 Orient TF around from 41 R 03:45 - 04:48 1.05 DRILL P PROD1 Drilling build section in Zone 2B. TF 66L Qp = 2.7 bpm at 3,100 psi CTP ROP 10 to 40 FPH Vp = 305 bbls Still having several stalls. Will drill past the 25N and then re-log the RA marker 04:48 - 05:22 0.57 DRILL P PROD1 Orient TF around 05:22 - 06:10 0.80 DRILL P PROD1 Drilling build section in Zone 2B. TF 71 L. Oriented TF 2 clicks Qp = 2.7 bpm at 3,100 psi CTP ROP 10 to 40 FPH Vp = 303 bbls TOWS 9459 ft TOW 9462 ft RA Marker 9469 ft BOW 9468 ft 06:10 - 06:45 0.58 DRILL P PROD1 Orient TF around f/ 40R to 43L 06:45 - 08:35 1.83 DRILL P PROD1 Drilling build section in Zone 2B. TF 43L w/ 2.5 bpm at 3050 psi. 08:35 - 09:10 0.58 DRILL P PROD1 Orient TF around f/ 21 L to 80L 09:10 - 10:55 1.75 DRILL P PROD1 Drilling build section in Zone 2B. TF 88L and 20 L w/ 2.5 bpm at 3100 psi. 10:55 - 12:45 1.83 DRILL P PROD1 POH to BHA, std back inj. 12:45 - 15:15 2.50 DRILL P PROD1 POH w/ BHA, download MWD tools, adjust mtr to 1.2 degree bend, PU Res tool, orient MWD to mtr, upload MWD, MHA, CTC, stab Inj 15:15 - 17:30 2.25 DRILL P PROD1 RIH w/ BHA to bottom 17:30 - 19:55 2.42 DRILL P PROD1 Madd Pass f/ 9733' - 9500 ft Correct -12.5 ft 19:55 - 20:00 0.08 DRILL P PROD1 RIH to drill lateral. Tagged at 9,718.2 ft 20:00 - 20:25 0.42 DRILL P PROD1 Orient TF to HS or LHS 20:25 - 20:40 0.25 DRILL P PROD1 Drilling Lateral section in Zone 2A. Building TVD to 8,945 ft (27.ft) Op = 2.60 / 2.70 bpm Vp = 292 bbl WOB = 1-2k ROP = 120 to 140 fph. GR at 60API Found HOT at 9590 ft MD 8941 ft TVD To be corrected by Geo later 20:40 - 21:05 0.42 DRILL P PROD1 Orieting TF around. Having to PUH to base of WS to get clicks Printed: 1/9/2006 9:43:17 AM BP EXPLORATION Operations Summary Report Page 3 of 11 Legal Well Name: D-27A Common Well Name: D-27A Spud Date: 12/27/2005 Event Name: REENTER+COMPLETE Start: 12/26/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 1/6/2006 Rig Name: NORDIC 1 Rig Number: Date i From - To ' Hours i Task I Code', NPT Phase j Description of Operations 12/28/2005 121:05 - 21:20 ~ 0.251 DRILL ~ P PROD1 Drilling Lateral section building TVD to 8,945 ft (27.ft) 21:20 - 21:35 0.25 DRILL P 21:35 - 21:46 0.18 DRILL P 21:46 - 21:52 0.10 DRILL P 21:52 - 20:14 22.37 DRILL P 20:14 - 11:28 15.23 DRILL P 11:28 - 11:32 0.07 DRILL P 11:32 - 00:00 I 12.471 DRILL I P 12/29/2005 100:00 - 00:30 I 0.501 DRILL I P 00:30 - 00:52 0.37 DRILL P 00:52 - 01:10 0.30 DRILL P 01:10 - 01:20 0.17 DRILL P 01:20 - 01:28 0.13 DRILL P 01:28 - 02:05 0.62 DRILL P 02:05 - 02:20 0.25 DRILL P 02:20 - 02:30 0.17 DRILL P Op = 2.60 / 2.70 bpm Vp = 292 bbl WOB = 1-2k ROP = 120 to 140 fph. HOT at 8950 ft TVDss and 9610ft MD IA/OA = 450/19 psi PROD1 Sperry tool failed to send sigaa Cycle pump to restart MWD MW D in 40deg DL PROD1 Drilling Lateral section building TF @ HS Op = 2.68 / 2.70 bpm Vp = 290 bbl WOB = 1-2k ROP = 10-25 fph. Drilling through high DLS then will restart MWD PROD1 PUH 9748 ft to try and restart MWD Started up again at 9763 ft PROD1 Drilling Lateral section building TF @ HS Op = 2.68 / 2.70 bpm Vp = 290 bbl WOB = 1-2k ROP = 10-25-150 fph. Some stacking due to high DLS MW D started again at 9,763 ft MD IA/OA = 438 /20 psi Last survey at 9,743 = 8,974 ft TVD. Need to climb 29 ft in TVD At 9,788 ft MD drilling at 150 fph and MWD working PROD1 Orient TF 9L to 90 L. Pulled to base of WS to get oriented. MWD Tool quite working PROD1 Drilling Lateral section in Zone 2A TF at 100 L Op = 2.68 / 2.70 bpm Vp = 287 bbl WOB = 1-2k ROP = 150 fph. IA/OA = 438 /20 psi Drill 10 ft to see if we can get the MW D tool to sink to surface. PROD1 Trying to restart Sperry's MWD. Weak signal Drilling Lateral section Zone 2A; TF at 80L Op = 2.68 / 2.70 bpm Vp = 287 bbl WOB = 1-2.7k ROP = 100-150 fph. IA/OA = 505 /22 psi. Bleed IA down to 130 psi PROD1 Drilling Lateral section Zone 2A; TF at 60L Op = 2.60 / 2.71 bpm CTP = 3500 psi; Vp = 286 bbl WOB = 1 k ROP =150 fph. IA/OA = 190 /22 psi. PROD1 Orient TF to 160 L PROD1 Drilling Lateral section Zone 2A; TF at 147E Op = 2.60 / 2.71 bpm CTP = 3520 psi Vp = 286 bbl WOB = 1 k ROP =150 fph. IA/OA = 200 /23 psi. PROD1 Orient TF 176E to PROD1 Drilling Lateral section Zone 2A; TF at 106E Op = 2.60 / 2.71 bpm CTP = 3520 psi Vp = 284 bbl WOB = -1.51 k ROP =130-150 fph. IA/OA = 229 /26 psi. PROD1 Wiper trip to base of whipstock (Clean) Orient TF while RIH at 9850 ft PROD1 Trying to start Sperry's pulsar after wiper trip Finally started working, finish orient TF PROD1 Drilling Lateral section Zone 2A; TF at 79-93R Op = 2.5 / 2.6 bpm CTP = 3520 psi Vp = 280 bbl WOB = -1.51 k ROP =130-150 fph. Printed: 1/9/2006 9:43:77 AM BP EXPLORATION Operations Summary Report Legal Well Name: D-27A Common Well Name: D-27A Event Name: REENTER+COMPLETE Start: 12/26/2005 Contractor Name: NORDIC CALISTA Rig Release: 1/6/2006 Rig Name: NORDIC 1 Rig Number: Date .From - To ,Hours Task Code I NPT I Phase I~ _-_ -- -- 12/29/2005 102:20 - 02:30 0.171 DRILL ~ P I PROD1 02:30 - 04:18 1.80 DRILL N DFAL PROD1 04:18 - 07:45 3.45 DRILL N DFAL PROD1 07:45 - 08:40 0.92 i DRILL N DFAL PROD1 08:40 - 09:10 0.50 DRILL N DFAL PROD1 09:10 - 09:30 0.33 DRILL N DFAL PROD1 09:30 - 09:55 0.42 DRILL N DFAL PROD1 09:55 - 11:30 1.58 DRILL P PROD1 11:30 - 12:00 0.50 DRILL P PROD1 12:00 - 15:00 3.00 DRILL P PROD1 15:00 - 16:00 1.00 DRILL P PROD1 16:00 - 18:10 2.17 DRILL P PROD1 18:10 - 20:10 I 2.001 DRILL I P I I PROD1 20:10 - 21:45 I 1.581 DRILL I P I (PROD1 21:45 - 23:25 I 1.671 DRILL I P I I PROD1 23:25 - 00:00 I 0.581 DRILL I P I I PROD1 12/30/2005 00:00 - 01:11 1.18 DRILL P PROD1 01:11 - 01:52 0.68 DRILL P PROD1 01:52 - 02:02 0.17 DRILL P I PROD1 02:02 - 04:28 2.43 DRILL P ~ PROD1 Page 4 of 11 Spud Date: 12/27/2005 End: Description of Operations IA/OA = 250 /26 psi. Lossing signal while drilling, slow in updating from tool. Having to PUH, restart tool and when we tag bottom it quits. Not consistency with TF's and survey's POOH to change out failed MW D pulsar OOH, unstab injector head, Checked bit and external offset, (OK). Downloaded Resistivity Tool. Changed out MWD pulsar, upload Res tool, MU BHA, stab inj. RIH w/ BHA to 9520' Tie-In Pass f/ 9520' - 9475', -15' correction RIH w/ BHA to bottom Orient TF to 90 R Drilling Lateral section Lower Zone 2B, TF at 93 - 45 R w/ 2.6 bpm at 3800 psi, WOB 5 - 8 K, ROP 115 - 150 fph, IA/OA - 222/21 psi Wiper trip to 9485', no problems, hole looks good Drilling Lateral section Lower Zone 2B, TF at 29 R - 126 L w/ 2.5 bpm at 3900 psi, WOB 8 K, ROP 90 - 110 fph, IA/OA - 250 - 325 / 21- 26 psi Wiper trip to 9485', no problems, hole looks good Drilling Lateral section Lower Zone 2B w/ TF at 73 - 40 L w/ 2.65 bpm at 4000 psi, WOB 8 K, ROP 90 - 120 fph, IA/OA - 375 - 460 / 29 - 37 psi Wiper trip Reduced Op at 9,700 ft. Made MAD Pass from 10,007 ft to 9,940 ft Slowed pumps down at 9,730 ft while PUH through high DLS area to 9,600 ft Tie-in to RA Marker from 9,530 ft up. Corrected +5 ft Painted flag at 9,300 ft EOP POOH to LD Resivisty tool, causing tool to loss communication on wiper trips through high DL area. OOH, unstab, download Rest tool and LD PU new proble and RB bit # 4 Ext offset at 49.5 deg Geo sample at 40 to 45% cherty material ih the last 2 samples RIH, shallow hole pulse test at 500 ft and orienter test at 3500 ft RIH. Corrected to 9300 ft EOP flag (-16 ft) Orient TF to HS before going in open hole RIH with 57L TF past W S RIH and started mud swap. Orient TF to 120 L for drilling Drilling Lateral section Zone 2A; TF at 110E to 70R (180 reactive) Op = 2.6 / 2.6 bpm CTP = 3060/ 3300psi WOB = 1-12 k ROP =15-60 fph. Some stalling IA/OA = 151 /21 psi. Getting surveys on the fly. Started drilling and acts like we're drilling in the programmed fault at 10,475 ft MD or a massive chert stringer Slow drilling with high Gtotals /vibrations from MWD totals. Drills better with the TF at 70R instead of 100E and no vibrations. PUH and TF rolls back to 100E 180 deg reactive torque. Sample at Printed: 1/9/2006 9:43:17 AM BP EXPLORATION Operations Summary Report Page 5 of 11 Legal Welt Name: D-27A Common W ell Name: D-27A Spud Date: 12/27/2005 Event Nam e: REENTE R+COM PLET E Start : 12/26/2005 End: Contractor Name: NORDIC CALIST A Rig Release: 1/6/2006 Rig Name: NORDIC 1 Rig Number: Date ' From - To Hours Task ' Code NPT Phase Description of Operations 12/30/2005 02:02 - 04:28 2.43 DRILL P PROD1 10,430 ft was 65% chert. 04:28 - 04:55 0.45 DRILL P PROD1 PUH and TF rolls back from 90R to 98L. Drilling Lateral section Zone 2A; TF at 110E-130L Op = 2.6 / 2.6 bpm CTP = 3060/ 3300psi WOB = 1-12 k ROP =25 fph. IA/OA = 98 /18 psi. At 10468 TF rolled to 66R, PUH and restart 04:55 - 05:07 0.20 DRILL P PROD1 Orient TF to HS 05:07 - 05:24 0.28 DRILL P PROD1 Drilling Lateral section Zone 2A; TF at HS rolls to 173R Op = 2.6 / 2.6 bpm CTP = 3060/ 3100psi WOB = 2-12 k ROP =25-70 fph. IA/OA = 98 /18 psi. 05:24 - 05:30 0.10 DRILL P PROD1 Orient TF up to 100 L 05:30 - 06:10 0.67 DRILL P PROD1 Drilling Lateral section Zone 2A; TF at 103E Op = 2.6 / 2.6 bpm CTP = 3060/ 3100psi WOB = 2-3 k ROP =50-100 fph. IA/OA = 74 /16 psi. Finally got through it at 10480 ft 06:10 - 06:20 0.17 DRILL P PROD1 Orient TF to 80 R 06:20 - 11:25 5.08 DRILL P PROD1 Drilling Lateral section Z-2, TF at 60 R, 2.45 bpm, 3400 psi, WOB 20-25 k, ROP 0-5 fph, IA/OA 125 - 390/ 17 - 32 psi, Lithology - 11:25 - 13:30 2.08 DRILL P PROD1 POH to BHA, std back inj 13:30 - 15:15 1.75 DRILL P PROD1 POH w/ BHA, LD bit (rung out), Inspect Mtr, PU new bit, Res tool, orient, upload tool, RIH w/ BHA, Stab inj. 15:15 - 17:10 1.92 DRILL P PROD1 RIH w/ BHA, shallow test MWD, OK 17:10 - 18:15 1.08 DRILL P PROD1 Tie-in pass f/ 9530' to 9485', missed signal, repeat tie-in pass f/ 9545' to 9523 ft Corrected (-13 ft) 18:15 - 18:45 0.50 DRILL P PROD1 RIH tagged bottom at 10,580 ft 18:45 - 20:30 1.75 DRILL P PROD1 Coinduct MAD Pass up at 100 fph 10,586 ft to 11,380 ft 20:30 - 20:38 0.13 DRILL P PROD1 RIH to drill Tagged bottom at 10,581 ft MWD tool SD while RIH 20:38 - 22:00 1.37 DRILL P PROD1 Drilling Lateral section Zone 2A blind ; TF at 80R Orient 1 click Op = 2.6 / 2.6 bpm CTP = 3130/ 3400psi WOB = 1-5 k ROP =50-70 fph. Ratty drilling IA/OA = 371 / 34 psi. Unable to get surveys while drilling. Once the bit tags bottom there is no undating of TF or surveys due to nose. Set on bottom and try to get survey. Unable to get survey while PUH slowly. No directional data 22:00 - 23:50 1.83 DRILL N DFAL PROD1 POOH Conference Cali with Ted Stagg and Doug Stoner, Asset Geologist, expained the situtation with the present resistivity tool BHA. He was concerned with directional control rather than getting the information from the restisivity tool. Will drill through the chert conglomerate interval and then PU Restiviry Tool. 23:50 - 00:00 0.17 DRILL N DFAL PROD1 OOH, stand back injector, down load Res Tool, Change out motor and bit 12/31/2005 00:00 - 01:45 1.75 DRILL N DFAL PROD1 Change out BHA, bit and motor Unable to download data from Res Tool Bit at 1-1-RO N External offset at 132 deg 01:45 - 04:00 2.25 DRILL N DFAL ~ PROD1 ~ Set counters and RIH Tagged bottom at 10,602 ft Printed: 1/9/2006 9:43:17 AM BP EXPLORATION Operations Summary Report Legal Well Name: D-27A Common Well Name: D-27A Event Name: REENTER+COMPLETE Start: 12/26/2005 Contractor Name: NORDIC CALISTA Rig Release: 1/6/2006 Rig Name: NORDIC 1 Rig Number: Date From - To `Hours Task LCode'' NPT Phase 12/31/2005 104:00 - 04:08 0.131 DRILL ~ P ~ PROD1 I~ 04:08 - 04:20 0.201 DRILL ~ P ~ PROD1 04:20 - 04:35 0.25 DRILL P PROD1 04:35 - 05:15 0.67 DRILL P PROD1 05:15 - 05:30 0.25 DRILL P PROD1 05:30 - 06:10 0.67 DRILL P PROD1 06:10 - 07:10 ~ 1.001 DRILL P ~ PROD1 07:10 - 08:10 I 1.001 DRILL I P I I PROD1 08:10 - 09:30 1.33 DRILL P ~ PROD1 09:30 - 12:20 2.83 DRILL P { PROD1 12:20 - 13:55 1.58 DRILL P PROD1 13:55 - 14:15 0.33 DRILL P PROD1 14:15 - 16:45 2.50 DRILL P PROD1 16:45 - 17:00 0.25 DRILL P PROD1 17:00 - 18:45 1.75 DRILL P PROD1 18:45 - 19:04 0.32 DRILL P PROD1 19:04 - 20:30 1.43 DRILL N DPRB PROD1 20:30 - 21:00 0.50 DRILL N DPRB PROD1 21:00 - 22:45 1.75 DRILL N DPRB PROD1 22:45 - 22:54 0.15 DRILL N DPRB PROD1 22:54 - 23:00 0.10 DRILL C PROD1 23:00 - 23:38 0.63 DRILL C PROD1 23:38 - 23:48 0.17 DRILL C PROD1 23:48 - 00:00 0.20 DRILL C PROD1 1/1/2006 ~ 00:00 - 00:45 ~ 0.75 ~ DRILL P ~ PROD1 00:45 - 01:00 0.25 DRILL P PROD1 01:00 - 02:21 1.35 DRILL P PROD1 Page 6 of 11 Spud Date: 12/27/2005 End: Description of Operations Pump up survey. Getting good detection from tool. Log GR from 10,585 ft to 10,602 ft Drilling Lateral section Zone 2A ; TF at 134E Op = 2.6 / 2.6 bpm CTP = 2950/ 3400 psi WOB = 1-5 k ROP =50-150 fph. Ratty drilling, lots vibrations tool working getting surveys. Working to get reactive torque lined out Orient TF around to 150R Drilling Lateral section Zone 2A ; TF at 114E-125R Op = 2.6 / 2.6 bpm CTP = 2950/ 3400 psi WOB = 1-3 k ROP =50-100 fph. Ratty drilling. MWD working getting surveys while drilling. Orient TF around to 90R from 63R Drilling Lateral section Zone 2A ; TF at 90R Op = 2.6 / 2.6 bpm CTP = 2950/ 3450 psi WOB = 1-3 k ROP =50-130 fph. Attempt to orient TF around to 70 R 2 times, TF would roll pass each time, on 3rd attempt, oriented to HS Orient TF to 40 R, Drilling,Lateral section Zone 2, 2.5 bpm w/ 3450 psi, WOB 3 K, ROP 90 - 120 fph Wiper trip to 9485', no hole problems Orient TF to 69 - 108 R, Drilling Lateral section Zone 2, 2.5 bpm w/ 3750 psi, WOB 8 - 16 K, ROP 60 - 120 fph Wiper trip to 9480', no hole problems Orient TF to 153 R, Drilling Lateral section Zone 2, 2.5 bpm w/ 3450 psi, WOB 8 - 12 K, ROP fell off f/ 110 - 60 fph, Unable to set WOB, mtr stalling out, Lithology went f/ 50% chert, 50% sand to 80% chert, 20% sand POH to BHA, std back inj. Inspect BHA, C/O bit, 4-2-RO-A-N-1-BT-PR, Stab Inj RIH w/ BHA. Orient TF after tagging window at 9462 ft Working to get past the TOWS at 9459 ft. Oriented TF from 44L to 24 R and try to work past. Unable to get past W S POOH to PU BC bit Changed out bit to HTC RWD BC and try to get past window RIH With TF at 16L RIH to WS area. Tagged TOWS at 9459 ft at 16L TF. Orient TF 16L to 7R. RIH to 9510ft Log tie-in at RA Marker (-16 ft) RIH Orient TF to 125R off bottom Drilling Lateral section Zone 2A ; TF at 134E Op = 2.6 / 2.6 bpm CTP = 2944/ 3400 psi WOB = 1-5 k ROP =50-150 fph. Ratty drilling Llithology at 80% chert congratulate with trace of pyrite Drilling Lateral section Zone 2A ; TF at 153R Op = 2.6 / 2.6 bpm CTP = 2944/ 3400 psi WOB = 1-5 k ROP =50-120 fph. Ratty drilling Working at dropping TVD Orient TF around Drilling Lateral section Zone 2A ; TF at 106E Op = 2.7 / 2.8 bpm CTP = 2944/ 350 psi Printed: 1/9/2006 9:43:17 AM BP EXPLORATION Operations Summary Report Legal Well Name: D-27A Common Well Name: D-27A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 DateFrom - To Hours Task .Code NPT 1/1/2006 101:00 - 02:21 1.351 DRILL ~ P 02:21 - 04:45 2.40 DRILL P 04:45 - 06:00 1.25 DRILL P 06:00 - 08:30 I 2.501 DRILL I P 08:30 - 08:55 0.42 DRILL P 08:55 - 13:00 4.08 DRILL P 13:00 - 15:30 2.50 DRILL P 15:30 - 15:45 0.25 DRILL P 15:45 - 16:30 0.75 DRILL P 16:30 - 16:45 0.25 DRILL P 16:45 - 18:30 1.75 DRILL P 18:30 - 18:49 i 0.32 DRILL P Start: 12/26/2005 Rig Release: 1/6/2006 Rig Number: Page 7 of 1 1 Spud Date: 12/27/2005 End: Phase Description of Operations - - - PROD1 ~ WOB = 1-5 k ROP =5-140 fph. PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 18:49 - 19:08 0.32 DRILL P PROD1 19:08 - 20:00 0.87 DRILL P PROD1 20:00 - 20:10 0.17 DRILL P PROD1 20:10 - 20:35 0.42 DRILL P PROD1 20:35 - 20:48 0.22 DRILL P PROD1 20:48 - 21:28 0.67 DRILL P PROD1 21:28 - 21:48 I 0.331 DRILL I P I I PROD1 21:48 - 22:00 0.20 DRILL P PROD1 22:00 - 22:17 0.28 DRILL P PROD1 22:17 - 00:00 I 1.721 DRILL I P I I PROD1 Have trouble drilling at 11,025 ft to 11,040 ft ratty drilling with stacking and several stalls.Unable to get bit to drill after 79 ft drilled. Llithology at 80% chert congratulate with trace of pyrite. POOH for bit change. Changed out bit and MW D probe for downloading data Bit was 4-7-RO-Cored RIH with BHA # 10, no problems going thru window, tagged btm, -6.40' correction Orient TF around to 90 L Drilling Lateral section Zone 2, TF at 108 L, 2.5 bpm at 3800 psi, WOB 2 - 4 K, ROP 60 - 75 fph, PR dropped off f/ 60 - 0 fph within the last hour of drilling, Llithology at 75% chert conglomerate POH to BHA, std back inj. POH w/ BHA, C/O bit, inspect BHA, OK, Bit Grade - 7-2-RO-N-X-1-CT-PR Cut 20' of CT, Behead CTC, Pull test 35 K and PT 3500 psi CTC, OK MU MHA, Stab inj RIH with BHA # 11 Orient TF above TOWS to HS TF at 30 R, SD pump and RIH past WS to 9,520 ft Tie-in at 9,520 ft up Corrected (-16 ft) RIH to bottom at 11160 ft after correction at RA Marker Orient TF 180 deg Drilling Lateral section Zone 2A ; TF at 41 L rolled to 180 dge Op = 2.6 / 2.6 bpm CTP = 3500/ 3900 psi WOB = 2-5 k ROP =50-160 fph. Ratty drilling Orient TF to HS. Ordered mud swap Drilling Lateral section Zone 2A ; TF at 3R-35L (180 deg reactive torque) Op = 2.6 / 2.6 bpm CTP = 3500/ 4100 psi WOB = -15k to Ok Trying to drill with negative WOB ROP =unknown fph. Ratty drilling. Weight on bit transfer problems At 11,198 ft, hole angle at 80 deg the TVD at approximate) 8,960 ft. At 11,213 ft the ROP was somewhat consistent with -11 k Finally got through that area between 11,193 ft to 11,215 ft Drilling Lateral section Zone 2A & HOT ; TF at 3R-35L (180 deg reactive torque) Climbing out of HOT with HS TF Op = 2.6 / 2.6 bpm CTP = 3500/ 4100 psi WOB = -5k to 10k ROP at 70-150 fph PUH, pump up survey and orient TF Drilling Lateral section Zone 2A-TF at 60R-86R Op = 2.6 / 2.6 bpm; CTP = 3500/ 4100 psi WOB = -5k to 10k; ROP at 70-180 fph Pump up survey on bottom Wiper trip to base of WS Clean Lossing mud to formation at 0.9 -1.3 bpm (53%) at start of wiper trip at 11,300 ft. Printed: 1/9/2006 9:43:17 AM BP EXPLORATION Operations Summary Report Page 8 of 11 Legal Well Name: D-27A Common Well Name: D-27A Spud Date: 12/27/2005 Event Name: REENTER+COMPLETE Start: 12/26/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 1/6/2006 Rig Name: NORDIC 1 Rig Number: Date 'From - To !Hours Task Code' NPT Phase Description of Operations 1/1/2006 22:17 - 00:00 1.72 DRILL P PROD1 RIH tossing 1.3 bpm (50%) Return O increased 1.3 to 2.0 bpm while RIH At 11,300 ftOp=2.5/2.5 bpm 1/2/2006 00:00 - 00:15 0.25 DRILL P PROD1 Tagged bottom at 11300 ft. Op = 2.47 /2.46 bpm. Regained full cicrulation back on bottom. 00:15 - 00:34 0.32 DRILL P PROD1 PUH and Orient TF to 25R from 130E 00:34 - 01:04 0.50 DRILL P PROD1 Drilling Lateral section Zone 2A-TF at 40R Op = 2.66 / 2.65 bpm; Losing 0.1 bpm. CTP = 3025/ 3500 psi WOB = 5-8k; ROP-140 fph Good wt to bit transfer with new mud 01:04 - 01:30 0.43 DRILL P PROD1 TF rolled to 140R, PUH and orient TF around. Orienter failure. 18 cycles and no response. Orienter not holding TF Pulled tight at 11,300 ft while orientating 01:30 - 02:10 0.67 DRILL P PROD1 POOH tossing 0.2 - 0.75 bpm while POOH Tried orienter at base of WS and got 1:1 clicks. RIH to try it again on bottom 02:10 - 03:18 1.13 DRILL P PROD1 RIH and try the orienter at different depths Lossing 1.2 bpm 03:18 - 03:30 0.20 DRILL P PROD1 Tagged bottom Lossing 1.0 bpm .PUH and orient from TF 167R PUH to 11,187 ft to orient TF 03:30 - 05:08 1.63 DRILL P PROD1 Drilling Lateral section Zone 2A-TF at 3R-65R Qp = 2.66 / 1.8 bpm; Losing 0.80 bpm. Cir improving as we drill ahead to a 1:1 CTP = 3025/ 3500 psi WOB = -10-8k; ROP-40-120 fph At 11,380 ft, drilling with negative wt (-12k) At 11,398 ft, the WOB improved and ROP increased to controlled 170 fph At 11,405 ft, the ROP slowed down drilling with negative wt. Stacking 05:08 - 06:55 1.78 DRILL P PROD1 Wiper trip to WS w/ 2.6 bpm 3575 psi Losing 0.5 to 0.75 bpm on TOH Losing .3 bpm on T{H 06:55 - 09:00 2.08 DRILL P PROD1 Orient TF to 110 R, Drlg lateral section zone 2, TF 103 R, 2.6 bpm w/ 3450 psi, ROP 80 fph, unable to establish mtr work, PR dropped to nothing, loses at .3 - .4 bpm 09:00 - 11:40 2.67 DRILL P PROD1 POH to BHA, Std back Inj. 11:40 - 13:45 2.08 DRILL P PROD1 POH w/ BHA, C/O bit, inspect BHA, C/O MWD, PU Res tool, orient, upload, MU MHA, Stab Inj, Bit Grade - 1-3-CT-T-X-1-RO-PR 13:45 - 15:15 1.50 DRILL P PROD1 RIH w/ BHA to 9535', no problems slacking off through window 15:15 - 15:30 0.25 DRILL P PROD1 Tie-in pass, -18' correction 15:30 - 16:30 1.00 DRILL P PROD1 RIH to bottom, PVT- 204 bbls 16:30 - 18:00 1.50 DRILL P PROD1 Orient TF to 60 R, Drlg lateral section zone 2, TF 70 103 R, 2.7 bpm w/ 3950 psi, ROP 130 -200 fph, loses at .3 - .4 bpm 18:00 - 21:00 3.00 DRILL P PROD1 MAD pass open hole at 900 fph and tied-in at RA Markerl Logged up to 9480 ft Corrected +0.5 ft 21:00 - 22:08 1.13 DRILL P PROD1 RIH to confirm TD Tagged TD at 11,626 ft 22:08 - 22:20 0.20 DRILL P PROD1 Pumping pill to bit 22:20 - 00:00 1.67 DRILL ~ P i PROD1 POOH laying in Liner pill 150,000 LSRV and 3% LT with 0 ppg Printed: 1/9/2006 9:43:77 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: .............Date ~ From - To 1/2/2006 122:20 -00:00 D-27A D-27A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Hours Task 'I Code', NPT '. - __ 1.671 DRILL I P 1/3/2006 00:00 - 00:30 0.50 DRILL P 00:30 - 04:00 3.50 DRILL P 04:00 - 04:15 0.25 ~ DRILL P 04:15 - 09:30 5.25 CASE P 09:30 - 11:15 1.75 CASE P 11:15 - 12:00 0.75 CASE P 12:00 - 15:00 3.00 CASE P 15:00 - 16:15 1.25 CEMT P 16:15 - 18:45 2.50 CEMT P 18:45 - 19:00 0.25 CEMT P 19:00 - 20:00 1.00 CEMT P 20:00 - 21:00 1.00 EVAL P 21:00 - 21:15 0.25 EVAL P 21:15 - 00:00 I 2.751 EVAL I P 1/4/2006 100:00 - 01:30 I 1.501 EVAL I P 01:30 - 03:30 I 2.001 EVAL I P 03:30 - 04:30 I 1.001 EVAL I P 04:30 - 06:00 1.50 EVAL P 06:00 - 08:00 2.00 EVAL P 08:00 - 11:00 I 3.001 EVAL I N I DFAL 11:00 - 12:45 1.751 EVAL 1 P 12:45 - 14:15 I 1.501 EVAL I N I WAIT Page 9 of 11 Spud Date: 12/27/2005 Start: 12/26/2005 End: Rig Release: 1/6/2006 Rig Number: Phase Description of Operations PROD1 KlaGard Painted Flag at 8,700 ft EOP and 6,400 ft EOP PROD1 POOH losing 0.3 to 0.5 bpm PROD1 Set back injector, download Res. tool LD and load out drilling BHA. Install BOT CTD, Pull test 40k and PT to 4000 psi Stab dart and displace to CTC. Volume = 58.3 bbl RU to run liner. PROD1 PJSM on PU and handling 2-7/8" liner RUNPRD Run liner as per program RUNPRD RIH w/ Liner Assy, tagged bottom, no hole problems RUNPRD Drop 5/8" Aluminum ball, circ down at 1.75 - .50 bpm w/ 2475 - 1675 psi, loses at .5 - .1 bpm, calculated vol - 59.7 bbls, actual vol - 52.9 bbls, sheared at 4160 psi, PU, released f/ deployment sleeve RUNPRD Displace well to 2 °!° KCL water RUNPRD RU cementers. PT to 4000# Mix and pump 32.8 bbp of 15.8 cement. Drop dart and displace with 30bb1 bio. and KCL. With 46.1 bbl away zero out MM. Shear liner wiper dart @ 57.6 bbl displaced. Bumped plug at 76.D bbl calculated 76.75. Floats held. Pick up free from liner. Lost 5.2 cement bbl to formation. RUNPRD POH replacing voidage. RUNPRD Lay out BHA. RUNPRD Jet stack with side jetting nozzle. Function test BOPE. Well is full and holding a steady fluid level. LOWERI Prep SWS MCNL/GR logging tools and bring to rig floor. LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for M/U CNL/GR and motor/mill BHA. LOWERI M/U 2.30" mill, 2-1/8" motor, XO, 2 jts CSH, XO and SWS carrier with MCNL/GR. RIH with 47 stds of CSH workstring. Check torque on connections. M/U SWS MHA. OAL = 3012'. LOWERI RIH with 2.30" mill, motor and SWS Memory CNL/GR logging tools on CSH workstring. OAL = 3012'. Pump min rate while RIH. Full returns. LOW ER1 Log down from 8550' at 30 fpm, pump 1.5 bpm, 2600 psi UCA cement at 1000 psi. Tag PBTD at 11602' CTD, not tied-in. No motor work to bottom. Clean liner. LOWERI Log up at 60 fph, while laying in new FloPro Perf pill, 30 bbls, pump 0.7 bpm, 650 psi. Log up to 8550'. LOWERI POH with logging / cleanout BHA. LOWERI Drop ball and pump to open circ sub. Stand back CSH workstring. LOWERI LD logging tools and process data. No usable data. Notify acnhorage. Will relog . LOWERI Pressure annulus to 1000 psi. Test Liner lap to 2000 psi for 30 min. Current UCA value 3500 psi. Lost 500 psi on 30 minutes. Failed Test. LOWERI Wait on arrival of battery for memory logging tool. On 1-5-2006 Sperry identified the battery failure as cause of the problem. Printed: 1/9/2006 9:43:17 AM BP EXPLORATION Page 10 of 11 Operations Summary Report Legal Well Name: D-27A Common W ell Name: D-27A Spud Date: 12/27!2005 Event Nam e: REENTE R+COM PLET E Start : 12/26/2005 End: Contractor Name: NORDIC CALIST A Rig Release: 1/6/2006 Rig Name: NORDIC 1 Rig Number: Date ! From - To I Hours Task Code NPT Phase Description of Operations 1!4/2006 12:45 - 14:15 1.50 EVAL N WAIT LOW ER1 this was a new battery. 14:15 - 16:20 2.08 EVAL N DFAL LOWER! PU memory tool and 48 stands of 1-1/4" CSH. 16:20 - 17:20 1.00 EVAL N DFAL LOWER! RIH with logging BHA to 8550' 17:20 - 19:00 1.67 EVAL N DFAL LOWER! Log form 8550 to PBTD @ 30 ft/min. Tag bottom at 11601', ' not corrected. 19:00 - 20:00 1.00 EVAL N DFAL LOWER! Log up to 8550' while laying in new FloPro pert pill, 30 bbls. 20:00 - 21:30 1.50 EVAL N DFAL LOWER! POH with MCNUGR logging BHA. 21:30 - 23:00 1.50 EVAL N DFAL LOW ER1 Stand back CSH workstring. 23:00 - 23:15 0.25 EVAL N DFAL LOWER! SAFETY MEETING. Review procedure, hazards and mitigation for recovering SWS MCNUGR logging tools. 23:15 - 00:00 0.75 EVAL N DFAL LOWER! Recover logging tools and load out logging equipment off rig floor. SWS to download data and present log. Good data. No gas in lateral section. 1/5/2006 00:00 - 00:30 0.50 PERFO P LOW ER1 Prepare rig floor for running perf guns. 00:30 - 00:45 0.25 PERFO P LOWER! SAFETY MEETING. Review procedure, hazards and mitigation for running perf guns. 00:45 - 03:15 2.50 PERFO P LOWER! Run SWS, 2", 6SPF, 2006PJ pert guns and blanks as per program. 580' loaded at 6SPF, 3 intervals. 03:15 - 04:15 1.00 PERFO P LOWER! Run 22 stands CSH workstring and MHA. OAL = 2994.7'. 04:15 - 06:00 1.75 PERFO P LOWER! RIH with SWS perforating BHA. Circ at 0.3 bpm, 150 psi. RIH clean to PBTD. Tag bottom at 11,589' up depth and correct to 11,582' up depth. Pump 10 bbls new FloPro pert pill ahead of 5/8" ball. 06:00 - 07:15 1.25 PERFO P LOWER! Insert 5/8" AL ball. Pump 10 bbls FloPro and displace with KCL water. Pump 2 bpm at 1900 psi, to get ball around coil at surface. Pumped 20 bbl over displacement. No Ball on seat. 07:15 - 08:10 0.92 PERFO P LOWER! Launch Steel Ball displaced 10 bbl over displacement. No ball on seat. 08:10 - 08:40 0.50 PERFO P LOW ER1 PU 550' to get firing head at 24 degrees. Wait 15 min to allow ball to drop. 08:40 - 08:55 0.25 PERFO P LOWER! RIH to firing depth. 08:55 - 09:00 0.08 PERFO P LOWER! Cir 8 bbl no ball on seat. Decided to POH. Pumping down backside. 09:00 - 11:00 2.00 PERFO N DFAL LOWER! POH pumping down backside. 11:00 - 11:55 0.92 PERFO N DFAL LOWER! Found balls in failed check valve. Change out check valves and disconnect. 11:55 - 13:30 1.58 PERFO N DFAL LOWER! RIH to PBTD. Correct -18.5'. PU to ball drop position. 13:30 - 14:30 1.00 PERFO N DFAL LOWER! Wait on arrival of perf pill. Mud plant had to clean pits. 14:30 - 15:00 0.50 PERFO N DFAL LOW ER1 Circulate ball to firing head. 2.1 bpm @ 1900 psi. At 45 bbl into displacement slow to .97 bpm @ 590 psi. On seat with 53 bbls Shear at 2480 psi. In rate 1.29 Out rate 15:00 - 17:00 2.00 PERFO P LOWER! POH loosing .1 bpm 17:00 - 18:30 1.50 PERFO P LOWER! Stand back 22 stands of CSH. 18:30 - 18:45 0.25 PERFO P LOWER! SAFETY MEETING. Review procedure, hazards and mitigation for laying out fired pert guns. 18:45 - 00:00 5.25 PERFO P LOWER! Lay out fired pert guns and blanks, 76 guns total. All shots fired. PERFORATED INTERVALS: 9,950 - 10,150' Printed: 1/9/2006 9:43:17 AM BP EXPLORATION Page 11 of 11 Operations Summary Report Legal Well Name: D-27A Common Well Name: D-27A Spud Date: 12/27/2005 Event Name: REENTER+COMPLETE Start: 12/26/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 1/6/2006 Rig Name: NORDIC 1 Rig Number: Date ,From - To Hours Task , Code NPT Phase Description of Operations ~ _ _ J-- + __I~_ _ ~ _ _ -_ 1/5/2006 8:45 - 00:00 5.25 PERFOf~ P LOWERI 10,630 - 10,850' 11,390 - 11,550' 580' TOTAL 1/6/2006 ~ 00:00 - 00:45 0.75 ~ CASE ~ P 00:45 - 02:30 i 1.75 i CASE ~ P 02:30 - 03:40 I 1.171 CASE I P 03:40 - 04:45 I 1.081 CASE I P 04:45 - 05:10 I 0.421 CASE I P 05:10 - 05:45 0.58 CASE P 05:45 - 06:30 0.75 RIGD P 06:30 - 11:00 4.50 RIGD P 11:00 - 13:00 2.00 RIGD P 13:00 - 15:00 I 2.001 RIGD I P 15:00 - 17:30 I 2.501 RIGD I P AT 6 SPF RUNPRD M/U BOT 4-1/2" KB Liner top packer and seal assembly with running tools. OAL = 85.29'. RUNPRD RIH with Liner top packer. Circ at min. rate. Up Wt at 8700' = 34K, Down Wt = 23K. Set Down 9K at 8768.5' CTD. Not corrected. RUNPRD Pick up to 8730' and launch 5/8" steel ball. Pump 2.2 bpm for 40 bbls, slow to 0.5 bpm, ball on seat at 47 bbls. RIH and set down 3K at 8766.3 ft. Pick up free at 8763.5'. Pick up to 8762.6'. Press up to 2000 psi to set slips. Set down 10K on slips at 8766.2'. Bleed down press to zero and stack 10K at 8767.5'. Packer set with seal assembly 1 ft off landing point. Pressure test Packer seal to 2000 psi. Chart and hold for 20 min. 2010 psi at start,1920 psi at end, good test. Bleed off ann. pressure. Pressure up to 3500 psi and shear release running tool. RUNPRD Pull free from BOT KB Liner top packer. OK. Top of packer set at 8740'. POH with running tools. RUNPRD Freeze protect 4-1 /2" tubing with MEOH from 2100 - 0 ft while POH. RUNPRD Lay out BOT running tools. POST Jet stack before changing rams for 2" coil. POST Pickle coil and blow down with N2. POST Stand back injector. Cut off coil connector, change out packoff's. Clean pits. POST Pull back coil to reel and secure. Change BOP rams. General RD operations. Load out trailers etc. POST ND BOPE. RELEASED RIG AT 17:30 HRS, 01/06/06. TOTAL TIME FROM RIG ACCEPT TO RELEASE WAS 10 DAYS. 23 1/2 HOURS. Moved rig to G-30 B. Rig move started at 1900 hrs. On location at 2400 hrs. Printed: 1/9/2006 9:43:77 AM Halliburton Global Company: BP Amoco Date: 1/17/2006 '['imc: 14:20:28 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: D-27, True No rth Site: PB D Pad Vertical (TVD) Kefer ence: 43 :27 2/13/1986 00:00 71.9 ~ Well: D-27 V1'ellpath: D-27A Section (VS) Reference: Well (O.OON,O.OOE,315.OOAzi) Surcev Calculation Method: Minimum Curvature Db: Oracle ~ Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Cla rke 1866) Coordinate Syste m: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: D-27 Slot Name: D-27 Well Position: +N/-S 3764.94 ft Northing: 5959382.00 ft Latitude: 70 17 45.519 N +E/-W 1372.50 ft Easting : 653461.00 ft Longitude: 148 45 26.312 W Position Uncertainty: 0.00 ft Wellpath: D-27A Drilled From: D-27 5002921511301 Tie-on Depth: 9454.04 ft Current Datum: 43: 27 2/13/1986 00:00 Height 71.90 ft Above System Datum: Mean Sea Level Magnetic Data: 12/27/2005 Declination: 24.63 deg Field Strength: 57601 nT Mag Dip Angle: 80.87 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 3 1.40 0.00 0.00 315.00 Survey Program for Definitive Wellpath Date: 11/9/2005 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft 41.80 9454.04 1 : Schlumberger GCT multi shot (41.80-9791~Y~(~D.$ Schlumbe rger GCT multish ot 9459.00 11626.00 MWD (9459.00-11626.00) MWD MWD -Standard Survey MD Incl Azim TVD S~~s'fVD N/S E/W MapN b1apE "Fool ft deg deg ft ft ft ft ft ft 31.40 0.00 0.00 31.40 -40.50 0.00 0.00 5959382.00 653461.00 TIE LINE 41.80 0.25 208.73 41.80 -30.10 -0.02 -0.01 5959381.98 653460.99 GCT-MS 54.90 0.25 206.20 54.90 -17.00 -0.07 -0.04 5959381.93 653460.96 GCT-MS 68.00 0.25 204.49 68.00 -3.90 -0.12 -0.06 5959381.88 653460.94 GCT-MS 81.10 0.25 205.89 81.10 9.20 -0.17 -0.09 5959381.82 653460.92 GCT-MS 94.20 0.27 206.23 94.20 22.30 -0.23 -0.11 5959381.77 653460.89 GCT-MS 107.30 0.27 204.55 107.30 35.40 -0.28 -0.14 5959381.71 653460.87 GCT-MS 121.40 0.25 205.21 121.40 49.50 -0.34 -0.17 5959381.66 653460.84 GCT-MS 135.50 0.23 207.89 135.50 63.60 -0.39 -0.19 5959381.60 653460.82 GCT-MS 149.60 0.22 210.19 149.60 77.70 -0.44 -0.22 5959381.55 653460.79 GCT-MS 163.75 0.20 211.12 163.75 91.85 -0.49 -0.25 5959381.51 653460.76 GCT-MS 178.00 0.22 210.43 178.00 106.10 -0.53 -0.27 5959381.46 653460.74 GCT-MS 192.20 0.22 210.58 192.20 120.30 -0.58 -0.30 5959381.42 653460.71 GCT-MS 206.50 0.20 211.42 206.50 134.60 -0.62 -0.33 5959381.37 653460.69 GCT-MS 220.80 0.20 213.93 220.80 148.90 -0.67 -0.35 5959381.33 653460.66 GCT-MS 235.10 0.20 214.38 235.10 163.20 -0.71 -0.38 5959381.29 653460.63 GCT-MS 249.50 0.20 213.22 249.50 177.60 -0.75 -0.41 5959381.24 653460.61 GCT-MS 263.80 0.20 214.97 263.80 191.90 -0.79 -0.44 5959381.20 653460.58 GCT-MS 277.90 0.20 214.10 277.90 206.00 -0.83 -0.47 5959381.16 653460.55 GCT-MS 292.00 0.20 212.59 292.00 220.10 -0.87 -0.49 5959381.12 653460.53 GCT-MS 306.20 0.20 210.87 306.20 234.30 -0.91 -0.52 5959381.08 653460.50 GCT-MS 320.30 0.22 206.48 320.30 248.40 -0.96 -0.54 5959381.03 653460.48 GCT-MS 334.40 0.23 203.63 334.40 262.50 -1.01 -0.57 5959380.98 653460.45 GCT-MS 348.60 0.25 203.61 348.60 276.70 -1.06 -0:59 5959380.92 653460.43 GCT-MS 362.70 025 204.95 362.70 290.80 -1.12 -0.62 5959380.87 653460.41 GCT-MS 376.90 0.27 207.17 376.90 305.00 -1.18 -0.64 5959380.81 653460.38 GCT-MS 391.00 0.27 210.30 391.00 319.10 -1.24 -0.68 5959380.75 653460.35 GCT-MS 405.10 0.27 213.64 405.10 333.20 -1.29 -0.71 5959380.69 653460.32 GCT-MS 419.20 0.27 214.42 419.20 347.30 -1.35 -0.75 5959380.64 653460.28 GCT-MS Halliburton Global Company: BP Amoco Date: 1/17/2006 Time: 14:2028 Page: 2 ~'~, Field: Pru dhoe Bay Co-urd inate(NE) Reference: Weil: D-27, True No rth Site: PB D Pad Vertical (I'VD) Reference: 43 :27 2/13/1986 00.00 71.9 Well: D-27 Section (VS) Referen ce: Weld (O.OON,O.OOE,315.OOAzi) ~!'elipathr D-27A Survey Calculation Method: Mi nimum Curvature Db: Oracle Survey - - - _ _ -_ _ h1D Incl , ~~im T~ D , Sys fVU 'V/S N./W ~ Ma Y 1~1a F P Toul i ft deg deg ft ft ft ft ft ft 433.30 0.27 214.99 433.30 361.40 -1.40 -0.79 5959380.58 653460.24 GCT-MS 448.70 0.25 213.35 448.70 376.80 -1.46 -0.83 5959380.52 653460.20 GCT-MS 464.40 0.25 209.82 464.40 392.50 -1.52 -0.86 5959380.46 653460.17 GCT-MS 480.00 0.25 208.54 480.00 408.10 -1.58 -0.89 5959380.40 653460.14 GCT-MS 493.80 0.27 209.00 493.80 421.90 -1.63 -0.92 5959380.35 653460.11 GCT-MS 509.70 0.25 206.52 509.70 437.80 -1.70 -0.96 5959380.28 653460.08 GCT-MS 525.60 0.25 200.66 525.60 453.70 -1.76 -0.99 5959380.22 653460.05 GCT-MS 541.50 0.23 196.60 541.50 469.60 -1.82 -1.01 5959380.16 653460.03 GCT-MS 557.40 0.25 194.34 557.40 485.50 -1.89 -1.03 5959380.09 653460.01 GCT-MS 573.35 0.25 191.31 573.35 501.45 -1.96 -1.04 5959380.02 653460.00 GCT-MS 589.25 0.25 187.57 589.25 517.35 -2.02 -1.05 5959379.96 653459.99 GCT-MS 605.20 0.25 183.72 605.20 533.30 -2.09 -1.06 5959379.89 653459.98 GCT-MS 621.15 0.25 182.39 621.14 549.24 -2.16 -1.06 5959379.82 653459.98 GCT-MS 637.10 0.25 182.45 637.09 565.19 -2.23 -1.07 5959379.75 653459.98 GCT-MS 653.05 0.27 180.95 653.04 581.14 -2.30 -1.07 5959379.67 653459.98 GCT-MS 669.05 0.25 180.56 669.04 597.14 -2.38 -1.07 5959379.60 653459.98 GCT-MS 684.95 0.23 179.31 684.94 613.04 -2.44 -1.07 5959379.54 653459.98 GCT-MS 700.85 0.23 178.13 700.84 628.94 -2.51 -1.07 5959379.47 653459.98 GCT-MS 716.85 0.22 175.35 716.84 644.94 -2.57 -1.06 5959379.41 653459.99 GCT-MS 732.75 0.22 170.92 732.74 660.84 -2.63 -1.06 5959379.35 653460.00 GCT-MS 748.75 0.22 166.89 748.74. 676.84 -2.69 -1.04 5959379.29 653460.01 GCT-MS 764.65 0.22 163.57 764.64 692.74 -2.75 -1.03 5959379.23 653460.03 GCT-MS 780.65 0.23 164.64 780.64 708.74 -2.81 -1.01 5959379.17 653460.05 GCT-MS 796.65 0.27 168.07 796.64 724.74 -2.88 -1.00 5959379.10 653460.06 GCT-MS 812.55 0.25 166.85 812.54 740.64 -2.95 -0.98 5959379.03 653460.08 GCT-MS 828.55 0.20 157.83 828.54 756.64 -3.01 -0.96 5959378.97 653460.10 GCT-MS 844.55 0.18 149.82 844.54 772.64 -3.06 -0.94 5959378.93 653460.12 GCT-MS 860.50 0.17 145.47 860.49 788.59 -3.10 -0.91 5959378.89 653460.15 GCT-MS 876.55 0.17 135.36 876.54 804.64 -3.13 -0.88 5959378.85 653460.18 GCT-MS 892.45 0.20 116.29 892.44 820.54 -3.16 -0.84 5959378.82 653460.22 GCT-MS 908.45 0.27 100.60 908.44 836.54 -3.18 -0.78 5959378.80 653460.29 GCT-MS 924.45 0.30 93.45 924.44 852.54 -3.19 -0.70 5959378.80 653460.37 GCT-MS 940.45 0.32 92.95 940.44 868.54 -3.20 -0.61 5959378.79 653460.45 GCT-MS 956.45 0.33 96.62 956.44 884.54 -3.20 -0.52 5959378.79 653460.54 GCT-MS 972.45 0.38 94.31 972.44 900.54 -3.21 -0.42 5959378.78 653460.64 GCT-MS 988.45 0.45 90.75 988.44 916.54 -3.22 -0.31 5959378.78 653460.76 GCT-MS 1004.45 0.47 90.21 1004.44 932.54 -3.22 -0.18 5959378.78 653460.89 GCT-MS 1020.40 0.48 87.30 1020.39 948.49 -3.22 -0.05 5959378.78 653461.02 GCT-MS 1036.40 0.52 86.37 1036.39 964.49 -3.21 0.09 5959378.79 653461.16 GCT-MS 1052.20 0.57 88.10 1052.19 980.29 -3.20 0.24 5959378.80 653461.31 GCT-MS 1067.95 0.60 91.11 1067.94 996.04 -3.20 0.40 5959378.81 653461.47 GCT-MS 1083.65 0.62 92.88 1083.64 1011.74 -3.21 0.57 5959378.81 653461.64 GCT-MS 1099.40 0.65 92.74 1099.39 1027.49 -3.21 0.74 5959378.80 653461.81 GCT-MS 1115.10 0.65 93.07 1115.09 1043.19 -3.22 0.92 5959378.80 653461.99 GCT-MS 1130.70 0.63 94.65 1130.68 1058.78 -3.24 1.10 5959378.79 653462.16 GCT-MS 1146.30 0.62 98.75 1146.28 1074.38 -3.26 1.26 5959378.77 653462.33 GCT-MS 1161.90 0.63 100.19 1161.88 1089.98 -3.28 1.43 5959378.75 653462.50 GCT-MS 1177.70 0.63 98.97 1177.68 1105.78 -3.31 1.60 5959378.72 653462.67 GCT-MS 1193.40 0.63 97.39 1193.38 1121.48 -3.34 1.77 5959378.70 653462.84 GCT-MS 1209.20 0.63 98.71 1209.18 1137.28 -3.36 1.95 5959378.68 653463.01 GCT-MS 1224.95 0.63 101.52 1224.93 1153.03 -3.39 2.12 5959378.65 653463.19 GCT-MS 1240.70 0.65 102.00 1240.68 1168.78 -3.43 2.29 5959378.62 653463.36 GCT-MS Halliburton i Global Company: BP Amoco Date: 1/17/2006 Time: 14:20:28 Nape: 3 j Field: Pru dhoe Bay Co-or dinate(NE) Re ference. Weil: D-27, True North Cite: PB D Pad Vertic al (TVD) Refe rence: 43 :27 2/13/1986 0 0:00 71.9 Well: D-27 Sectio n (VS) Rcfcrence: Well (O.OON,O.OUE,315.OOAzi) Wellpath: D-27A Survey Caleulafion Method: Min imum Curvature llb: Oracle Sw~ve~ -- MD Intl Azim T'Vll Sys TVD N/S E/V1' 11lapN MapE Tool ~I fi deg deg ft ft ft ft ft ft 1256.40 0.67 102.90 1256.38 1184.48 -3.47 2.47 5959378.59 653463.54 GCT-MS 1272.15 0.68 105.75 1272.13 1200.23 -3.51 2.65 5959378.54 653463.72 GCT-MS 1287.85 0.63 111.25 1287.82 1215.92 -3.57 2.82 5959378.49 653463.89 GCT-MS 1303.55 0.57 117.16 1303.52 1231.62 -3.64 2.97 5959378.43 653464.04 GCT-MS 1319.35 0.55 121.15 1319.32 1247.42 -3.71 3.10 5959378.35 653464.18 GCT-MS 1335.00 0.57 121.75 1334.97 1263.07 -3.79 3.23 5959378.28 653464.31 GCT-MS 1350.75 0.57 121.83 1350.72 1278.82 -3.87 3.36 5959378.20 653464.44 GCT-MS 1366.45 0.52 125.41 1366.42 1294.52 -3.96 3.49 5959378.12 653464.57 GCT-MS 1382.15 0.47 129.17 1382.12 1310.22 -4.04 3.60 5959378.04 653464.68 GCT-MS 1397.85 0.45 131.99 1397.82 1325.92 -4.12 3.69 5959377.96 653464.78 GCT-MS 1413.55 0.47 129.92 1413.52 1341.62 -4.20 3.79 5959377.88 653464.87 GCT-MS 1429.25 0.48 125.11 1429.22 1357.32 -4.28 3.89 5959377.80 653464.98 GCT-MS 1444.95 0.47 124.18 1444.92 1373.02 -4.36 4.00 5959377.73 653465.09 GCT-MS 1460.65 0.45 125.06 1460.62 1388.72 -4.43 4.10 5959377.66 653465.19 GCT-MS 1476.35 0.47 126.19 1476.32 1404.42 -4.50 4.20 5959377.59 653465.29 GCT-MS 1492.05 0.50 129.37 1492.02 1420.12 -4.58 4.31 5959377.51 653465.40 GCT-MS 1507.75 0.50 133.96 1507.72 1435.82 -4.67 4.41 5959377.42 653465.51 GCT-MS 1523.40 0.48 134.62 1523.37 1451.47 -4.77 4.51 5959377.33 653465.60 GCT-MS 1539.10 0.50 132.31 1539.06 1467.16 -4.86 4.60 5959377.24 653465.70 GCT-MS 1554.85 0.48 134.72 1554.81 1482.91 -4.95 4.70 5959377.15 653465.80 GCT-MS 1570.55 0.45 137.30 1570.51 1498.61 -5.04 4.79 5959377.06 653465.89 GCT-MS 1586.25 0.45 132.18 1586.21 1514.31 -5.13 4.88 5959376.97 653465.98 GCT-MS 1601.90 0.45 128.82 1601.86 1529.96 -5.21 4.97 5959376.89 653466.08 GCT-MS 1617.70 0.43 130.75 1617.66 1545.76 -5.29 5.06 5959376.82 653466.17 GCT-MS 1633.35 0.42 131.37 1633.31 1561.41 -5.36 5.15 5959376.74 653466.26 GCT-MS 1649.10 0.40 130.40 1649.06 1577.16 -5.44 5.24 5959376.67 653466.35 GCT-MS 1664.80 0.38 131.09 1664.76 1592.86 -5.51 5.32 5959376.60 653466.43 GCT-MS 1680.50 0.37 134.45 1680.46 1608.56 -5.58 5.39 5959376.54 653466.51 GCT-MS 1696.20 0.32 136.77 1696.16 1624.26 -5.64 5.46 5959376.47 653466.57 GCT-MS 1711.90 0.32 137.61 1711.86 1639.96 -5.71 5.52 5959376.41 653466.63 GCT-MS 1727.65 0.32 138.18 1727.61 1655.71 -5.77 5.58 5959376.34 653466.70 GCT-MS 1743.40 0.32 140.48 1743.36 1671.46 -5.84 5.64 5959376.28 653466.75 GCT-MS 1759.10 0.30 147.19 1759.06 1687.16 -5.91 5.69 5959376.21 653466.81 GCT-MS 1774.70 0.27 155.39 1774.66 1702.76 -5.98 5.72 5959376.14 653466.84 GCT-MS 1790.35 0.23 160.15 1790.31 1718.41 -6.04 5.75 5959376.08 653466.87 GCT-MS 1805.95 0.23 160.92 1805.91 1734.01 -6.10 5.77 5959376.02 653466.89 GCT-MS 1821.45 0.20 159.40 1821.41 1749.51 -6.15 5.79 5959375.97 653466.91 GCT-MS 1836.95 0.20 159.90 1836.91 1765.01 -6.20 5.81 5959375.92 653466.93 GCT-MS 1852.45 0.22 156.61 1852.41 1780.51 -6.26 5.83 5959375.86 653466.96 GCT-MS 1867.95 0.22 151.57 1867.91 1796.01 -6.31 5.86 5959375.81 653466.98 GCT-MS 1883.45 0.22 152.93 1883.41 1811.51 -6.36 5.88 5959375.76 653467.01 GCT-MS 1898.95 0.25 155.77 1898.91 1827.01 -6.42 5.91 5959375.70 653467.04 GCT-MS 1914.35 0.23 154.67 1914.31 1842.41 -6.48 5.94 5959375.64 653467.07 GCT-MS 1929.85 0.22 151.90 1929.81 1857.91 -6.53 5.97 5959375.59 653467.10 GCT-MS 1945.35 0.22 152.07 1945.31 1873.41 -6.59 5.99 5959375.54 653467.13 GCT-MS 1960.75 0.23 152.87 1960.71 1888.81 -6.64 6.02 5959375.49 653467.16 GCT-MS 1976.25 0.27 159.98 1976.21 1904.31 -6.70 6.05 5959375.42 653467.18 GCT-MS i 1991.75 0.28 163.59 1991.71 1919.81 -6.77 6.07 5959375.35 653467.21 GCT-MS 2007.25 0.30 160.28 2007.21 1935.31 -6.85 6.10 5959375.28 653467.23 GCT-MS 2022.75 0.33 159.40 2022.71 1950.81 -6.93 6.13 5959375.20 653467.26 GCT-MS 2038.25 0.33 158.75 2038.21 1966.31 -7.01 6.16 5959375.12 653467.30 GCT-MS 2053.75 0.37 164.21 2053.71 1981.81 -7.10 6.19 5959375.03 653467.33 GCT-MS 2069.30 0.45 166.49 2069.26 1997.36 -7.21 6.21 5959374.92 653467.36 GCT-MS Halliburton Global Company: BP Amoco llate: 1/17/2006 'Circe: 14.20:28 __ Page: 4 { Field: P rudhoe Bay Co-ordinate(NE) Re ference: Well: D-27, True North ~ Site: PB D Pad Vertica l (TVD) Refe rence: 43 :27 2/13/1986 0 0:00 71.9 Well: D -27 Section (VS) Reference. Well (O.OON,O.OOE,315.OOAzi) Weilpath: D -27A Sun°ey Calculation Method: Min imum Curvature Db: Oracle Sur~'c~° - r MD Intl - Azim - TVD Sys TVD _. N/S .___ E/W - __._ MapN _. . _. _ f11apE -_. - -- -- -_. --° Tooi ft deg deg ft ft ft ft ft ft J 2084.75 0.50 162.17 2084.71 2012.81 -7.33 6.25 5959374.80 653467.40 GCT-MS 2100.30 0.52 160.65 2100.25 2028.35 -7.46 6.29 5959374.67 653467.44 GCT-MS 2115.80 0.52 161.04 2115.75 2043.85 -7.59 6.34 5959374.54 653467.49 GCT-MS 2131.35 0.52 161.27 2131.30 2059.40 -7.73 6.39 5959374.40 653467.54 GCT-MS 2146.80 0.52 160.31 2146.75 2074.85 -7.86 6.43 5959374.27 653467.59 GCT-MS 2162.35 0.55 162.87 2162.30 2090.40 -8.00 6.48 5959374.14 653467.64 GCT-MS 2177.85 0.60 162.35 2177.80 2105.90 -8.15 6.52 5959373.99 653467.69 GCT-MS 2193.40 0.63 158.04 2193.35 2121.45 -8.30 6.58 5959373.83 653467.75 GCT-MS 2208.90 0.65 156.09 2208.85 2136.95 -8.46 6.65 5959373.68 653467.82 GCT-MS 2224.40 0.67 151.77 2224.35 2152.45 -8.62 6.73 5959373.52 653467.90 GCT-MS 2239.90 0.67 147.96 2239.85 2167.95 -8.78 6.82 5959373.36 653467.99 GCT-MS 2255.40 0.67 149.25 2255.35 2183.45 -8.93 6.91 5959373.21 653468.09 GCT-MS 2270.80 0.67 152.86 2270.75 2198.85 -9.09 7.00 5959373.05 653468.18 GCT-MS 2286.20 0.63 154.43 2286.14 2214.24 -9.25 7.08 5959372.90 653468.26 GCT-MS 2301.80 0.65 152.98 2301.74 2229.84 -9.40 7.15 5959372.74 653468.34 GCT-MS 2317.40 0.68 151.79 2317.34 2245.44 -9.56 7.24 5959372.59 653468.43 GCT-MS 2332.90 0.68 150.76 2332.84 2260.94 -9.73 7.33 5959372.43 653468.52 GCT-MS 2348.45 0.67 147.09 2348.39 2276.49 -9.88 7.42 5959372.27 653468.62 GCT-MS 2364.00 0.67 146.04 2363.94 2292.04 -10.03 7.52 5959372.12 653468.72 GCT-MS 2379.55 0.70 148.00 2379.49 2307.59 -10.19 7.62 5959371.97 653468.83 GCT-MS 2395.05 0.70 150.42 2394.99 2323.09 -10.35 7.72 5959371.81 653468.93 GCT-MS 2410.65 0.67 153.77 2410.59 2338.69 -10.52 7.81 5959371.64 653469.02 GCT-MS 2426.20 0.67 152.96 2426.13 2354.23 -10.68 7.89 5959371.48 653469.10 GCT-MS 2441.75 0.68 148.74 2441.68. 2369.78 -10.84 7.98 5959371.33 653469.20 GCT-MS 2457.30 0.68 148.26 2457.23 2385.33 -11.00 8.07 5959371.17 653469.30 GCT-MS 2472.85 0.68 150.29 2472.78 2400.88 -11.16 8.17 5959371.01 653469.39 GCT-MS 2488.40 0.63 152.15 2488.33 2416.43 -11.31 8.25 5959370.86 653469.48 GCT-MS 2503.95 0.53 151.91 2503.88 2431.98 -11.45 8.33 5959370.72 653469.56 GCT-MS 2519.55 0.47 151.02 2519.48 2447.58 -11.57 8.39 5959370.60 653469.63 GCT-MS 2535.05 0.45 151.85 2534.98 2463.08 -11.68 8.45 5959370.50 653469.69 GCT-MS 2550.60 0.43 147.66 2550.53 2478.63 -11.78 8.51 5959370.39 653469.75 GCT-MS 2565.85 0.45 144.09 2565.78 2493.88 -11.88 8.58 5959370.30 653469.82 GCT-MS 2581.15 0.45 144.84 2581.08 2509.18 -11.98 8.65 5959370.20 653469.89 GCT-MS 2596.45 0.45 144.42 2596.38 2524.48 -12.08 8.72 5959370.11 653469.96 GCT-MS 2611.75 0.45 146.32 2611.68 2539.78 -12.17 8.79 5959370.01 653470.03 GCT-MS 2627.00 0.43 149.85 2626.93 2555.03 -12.27 8.85 5959369.91 653470.10 GCT-MS 2642.30 0.37 151.44 2642.23 2570.33 -12.37 8.90 5959369.82 653470.15 GCT-MS 2657.55 0.30 155.83 2657.48 2585.58 -12.45 8.94 5959369.74 653470.19 GCT-MS 2672.80 0.27 160.68 2672.72 2600.82 -12.52 8.97 5959369.67 653470.22 GCT-MS 2688.05 0.22 165.79 2687.97 2616.07 -12.58 8.99 5959369.61 653470.24 GCT-MS 2703.30 0.15 168.95 2703.22 2631.32 -12.63 9.00 5959369.56 653470.25 GCT-MS 2718.40 0.10 191.94 2718.32 2646.42 -12.66 9.00 5959369.53 653470.25 GCT-MS 2733.70 0.20 256.72 2733.62 2661.72 -12.68 8.97 5959369.51 653470.23 GCT-MS 2749.00 0.65 302.23 2748.92 2677.02 -12.64 8.87 5959369.55 653470.13 GCT-MS 2764.25 1.32 307.61 2764.17 2692.27 -12.49 8.66 5959369.70 653469.91 GCT-MS 2779.55 1.73 308.20 2779.47 2707.57 -12.23 8.34 5959369.94 653469.58 GCT-MS 2794.80 2.12 308.68 2794.71 2722.81 -11.92 7.94 5959370.25 653469.18 GCT-MS 2810.10 2.65 308.60 2809.99 2738.09 -11.52 7.44 5959370.64 653468.67 GCT-MS 2825.35 3.00 308.12 2825.23 2753.33 -11.05 6.85 5959371.09 653468.07 GCT-MS 2840.60 3.17 307.93 2840.45 2768.55 -10.55 6.20 5959371.58 653467.42 GCT-MS 2855.85 3.27 307.13 2855.68 2783.78 -10.03 5.52 5959372.09 653466.73 GCT-MS 2871.15 3.32 306.00 2870.95 2799.05 -9.50 4.82 5959372.60 653466.01 GCT-MS Halliburton Global Company: BP Amoco llate: 111 712 0 0 6 'Circe: 14:20:28 Page: 5 F~cld: Pru dhoe Bay Co-ord inate(VE) Re ference: Well: D-27, True North Site: PB D Pad Vertical (TVD) Reference: 43 :27 2/13/1986 0 0:00 71.9 Well: D-27 Section (VS) Reference: Well (O.OON,O.ODE,315.OOAzi) ~ Wellpath: D-27A Survey Calculation Method: Minimum Curvature - _ - Db: Oracle Survev Mll Incl Azim TVll Sys TVD N/S E/V1' MapN MapF, Cool ft deg deg ft ft ft ft ft ft 2886.40 3.37 304.99 2886.18 2814.28 -8.98 4.09 5959373.10 653465.27 GCT-MS 2901.65 3.45 303.97 2901.40 2829.50 -8.47 3.34 5959373.60 653464.52 GCT-MS 2916.95 3.53 302.78 2916.67 2844.77 -7.96 2.57 5959374.10 653463.73 GCT-MS 2932.15 3.63 301.45 2931.84 2859.94 -7.45 1.76 5959374.58 653462.91 GCT-MS 2947.45 3.77 300.36 2947.11 2875.21 -6.95 0.92 5959375.07 653462.06 GCT-MS 2962.65 3.97 299.49 2962.28 2890.38 -6.44 0.03 5959375.57 653461.16 GCT-MS 2977.95 4.12 298.91 2977.54 2905.64 -5.91 -0.92 5959376.07 653460.21 GCT-MS 2993.15 4.22 298.34 2992.70 2920.80 -5.38 -1.89 5959376.58 653459.22 GCT-MS 3010.35 4.42 297.00 3009.85 2937.95 -4.78 -3.03 5959377.16 653458.07 GCT-MS 3027.55 4.65 295.55 3027.00 2955.10 -4.18 -4.25 5959377.74 653456.83 GCT-MS 3044.85 4.77 294.95 3044.24 2972.34 -3.57 -5.54 5959378.32 653455.54 GCT-MS 3062.05 4.80 295.02 3061.38 2989.48 -2.97 -6.84 5959378.90 653454.22 GCT-MS 3079.35 4.82 295.04 3078.62 3006.72 -2.35 -8.15 5959379.48 653452.90 GCT-MS 3096.65 4.92 295.22 3095.85 3023.95 -1.73 -9.48 5959380.08 653451.56 GCT-MS 3114.00 5.12 295.83 3113.14 3041.24 -1.07 -10.85 5959380.71 653450.17 GCT-MS 3131.30 5.28 296.40 3130.37 3058.47 -0.38 -12.26 5959381.37 653448.75 GCT-MS 3148.60 5.42 296.90 3147.59 3075.69 0.34 -13.70 5959382.06 653447.30 GCT-MS 3165.90 5.53 297.31 3164.81 3092.91 1.09 -15.17 5959382.78 653445.81 GCT-MS 3183.30 5.73 297.89 3182.13 3110.23 1.88 -16.68 5959383.54 653444.28 GCT-MS 3200.70 6.03 298.78 3199.44 3127.54 2.73 -18.25 5959384.36 653442.70 GCT-MS 3218.20 6.30 299.46 3216.84 3144.94 3.64 -19.89 5959385.24 653441.04 GCT-MS 3235.70 6.43 299.95 3234.23 3162.33 4.61 -21.58 5959386.16 653439.33 GCT-MS 3253.15 6.58 300.26 3251.56 3179.66 5.60 -23.29 5959387.12 653437.60 GCT-MS 3270.60 6.77 300.64 3268.90 3197.00 6.63 -25.04 5959388.11 653435.83 GCT-MS 3288.00 6.97 301.16 3286.17 3214.27 7.69 -26.82 5959389.14 653434.03 GCT-MS 3305.20 7.25 301.74 3303.24 3231.34 8.81 -28.64 5959390.22 653432.19 GCT-MS 3323.90 7.52 302.32 3321.78 3249.88 10.08 -30.68 5959391.45 653430.13 GCT-MS 3344.95 7.73 302.80 3342.65 3270.75 11.58 -33.03 5959392.91 653427.74 GCT-MS 3366.65 8.00 303.40 3364.14 3292.24 13.21 -35.52 5959394.48 653425.22 GCT-MS 3388.35 8.30 304.02 3385.62 3313.72 14.91 -38.08 5959396.13 653422.63 GCT-MS 3410.05 8.63 304.55 3407.09 3335.19 16.71 -40.72 5959397.88 653419.95 GCT-MS 3431.75 8.92 305.01 3428.53 3356.63 18.60 -43.44 5959399.71 653417.20 GCT-MS 3452.85 9.27 305.47 3449.37 3377.47 20.53 -46.16 5959401.58 653414.43 GCT-MS 3473.65 9.60 305.88 3469.89 3397.99 22.51 -48.93 5959403.51 653411.63 GCT-MS 3494.45 9.88 306.14 3490.39 3418.49 24.58 -51.78 5959405.52 653408.74 GCT-MS 3515.40 10.18 306.31 3511.02 3439.12 26.74 -54.72 5959407.62 653405.75 GCT-MS 3536.25 10.63 306.65 3531.52 3459.62 28.98 -57.75 5959409.79 653402.68 GCT-MS 3557.20 11.15 307.02 3552.10 3480.20 31.35 -60.91 5959412.10 653399.46 GCT-MS 3578.10 11.63 307.28 3572.59 3500.69 33.84 -64.20 5959414.52 653396.12 GCT-MS 3600.15 12.12 307.39 3594.16 3522.26 36.60 -67.81 5959417.20 653392.46 GCT-MS 3622.80 12.52 307.39 3616.29 3544.39 39.53 -71.65 5959420.06 653388.56 GCT-MS 3645.50 12.97 307.44 3638.43 3566.53 42.57 -75.63 5959423.02 653384.52 GCT-MS 3668.60 13.45 307.57 3660.92 3589.02 45.79 -79.82 5959426.15 653380.27 GCT-MS 3692.20 14.00 307.75 3683.85 3611.95 49.21 -84.25 5959429.48 653375.77 GCT-MS 3716.60 14.60 307.89 3707.49 3635.59 52.90 -89.01 5959433.07 653370.94 GCT-MS 3742.00 15.10 308.06 3732.04 3660.14 56.91 -94.14 5959436.97 653365.72 GCT-MS 3768.40 .15.78 308.35 3757.49 3685.59 61.26 -99.66 5959441.21 653360.11 GCT-MS 3794.90 16.48 308.65 3782.95 3711.05 65.84 -105.42 5959445.67 653354.26 GCT-MS 3821.40 17.05 308.92 3808.32 3736.42 70.63 -111.38 5959450.34 653348.21 GCT-MS 3848.45 17.73 309.20 3834.13 3762.23 75.72 -117.66 5959455.30 653341.83 GCT-MS 3875.25 18.52 309.44 3859.60 3787.70 81.01 -124.11 5959460.45 653335.27 GCT-MS 3904.05 19.25 309.64 3886.85 3814.95 86.94 -131.30 5959466.24 653327.96 GCT-MS 3931.95 19.83 309.81 3913.15 3841.25 92.91 -138.48 5959472.05 653320.67 GCT-MS Halliburton Global Company: BP Amoco Date: 1/17!2006 1'ime• 1420:28 Pale: 6 Field: Pru dhoe Bay Co-ordinate(NE) Re ference: Well: D-27, True North Site: PB D Pad Verfical (TVD) Refe rence: 43 :27 2/13/1986 0 0:00 71.9 Well: D-27 Section (VS) Reference: Well (O.OON,O.OOE,315.OOAzi) Weltpath: D-27A Survey Calculation Method: Minimum Curvature Db: Orade Survc~~ I MD Inc] Azim TVD Sys TVD N/S E/W ___ MapN MapE Tool ft deg deg ft ft ft ft ft ft 3959.35 20.50 310.07 3938.87 3866.97 98.97 -145.72 5959477.97 653313.30 GCT-MS 3986.75 21.20 310.30 3964.47 3892.57 105.26 -153.17 5959484.11 653305.73 GCT-MS 4014.05 21.87 310.52 3989.87 3917.97 111.76 -160.80 5959490.44 653297.97 GCT-MS 4040.95 22.65 310.81 4014.76 3942.86 118.40 -168.53 5959496.92 653290.10 GCT-MS 4067.90 23.50 311.15 4039.55 3967.65 125.33 -176.50 5959503.69 653281.99 GCT-MS 4094.80 24.28 311.49 4064.15 3992.25 132.52 -184.68 5959510.71 653273.67 GCT-MS 4121.80 25.05 311.83 4088.69 4016.79 140.01 -193.10 5959518.03 653265.10 GCT-MS 4148.70 25.62 312.10 4113.00 4041.10 147.71 -201.66 5959525.55 653256.38 GCT-MS 4175.60 25.88 312.24 4137.23 4065.33 155.55 -210.32 5959533.21 653247.56 GCT-MS 4202.50 26.05 312.27 4161.41 4089.51 163.47 -219.04 5959540.95 653238.69 GCT-MS 4229.40 26.20 312.26 4185.56 4113.66 171.44 -227.80 5959548.74 653229.76 GCT-MS 4256.30 26.33 312.28 4209.69 4137.79 179.44 -236.61 5959556.56 653220.79 GCT-MS 4283.15 26.45 312.28 4233.74 4161.84 187.47 -245.44 5959564.41 653211.80 GCT-MS 4310.05 26.52 312.28 4257.82 4185.92 195.54 -254.32 5959572.30 653202.76 GCT-MS 4336.95 26.58 312.31 4281.88 4209.98 203.64 -263.21 5959580.20 653193.71 GCT-MS 4363.85 26.67 312.39 4305.93 4234.03 211.76 -272.12 5959588.14 653184.63 GCT-MS 4390.80 26.77 312.46 4330.00 4258.10 219.93 -281.06 5959596.13 653175.53 GCT-MS 4417.65 26.88 312.49 4353.96 4282.06 228.11 -290.00 5959604.13 653166.42 GCT-MS 4444.50 27.00 312.53 4377.90 4306.00 236.33 -298.97 5959612.16 653157.29 GCT-MS 4471.15 27.08 312.65 4401.63 4329.73 244.53 -307.89 5959620.18 653148.21 GCT-MS 4497.90 27.13 312.80 4425.44 4353.54 252.80 -316.84 5959628.26 653139.09 GCT-MS 4524.85 27.17 312.91 4449.43 4377.53 261.17 -325.86 5959636.44 653129.90 GCT-MS 4551.75 27.22 313.01 4473.35 4401.45 269.54 -334.85 5959644.63 653120.74 GCT-MS 4578.60 27.28 313.07 4497.22 4425.32 277.93 -343.84 5959652.84 653111.58 GCT-MS 4605.50 27.33 313.11 4521.12 4449.22 286.36 -352.85 5959661.08 653102.40 GCT-MS 4632.40 27.35 313.22 4545.02 4473.12 294.82 -361.86 5959669.35 653093.22 GCT-MS 4659.40 27.38 313.45 4569.00 4497.10 303.33 -370.89 5959677.68 653084.02 GCT-MS 4686.40 27.47 313.68 4592.96 4521.06 311.90 -379.90 5959686.06 653074.84 GCT-MS 4713.35 27.52 313.97 4616.87 4544.97 320.52 -388.88 5959694.49 653065.69 GCT-MS 4740.10 27.52 314.32 4640.59 4568.69 329.13 -397.74 5959702.91 653056.65 GCT-MS 4766.65 27.53 314.67 4664.14 4592.24 337.73 -406.50 5959711.33 653047.72 GCT-MS 4793.15 27.60 314.89 4687.63 4615.73 346.37 -415.20 5959719.79 653038.84 GCT-MS 4819.65 27.68 314.95 4711.11 4639.21 355.05 -423.91 5959728.29 653029.96 GCT-MS 4846.15 27.78 314.99 4734.56 4662.66 363.76 -432.63 5959736.82 653021.07 GCT-MS 4872.65 27.78 315.15 4758.01 4686.11 372.50 -441.35 5959745.39 653012.17 GCT-MS 4899.20 27.65 315.41 4781.51 4709.61 381.28 -450.04 5959753.98 653003.30 GCT-MS 4925.65 27.58 315.55 4804.95 4733.05 390.02 -458.64 5959762.55 652994.53 GCT-MS 4952.20 27.68 315.61 4828.47 4756.57 398.81 -467.26 5959771.16 652985.73 GCT-MS 4978.70 27.78 315.74 4851.93 4780.03 407.64 -475.87 5959779.80 652976.94 GCT-MS 5005.20 27.85 315.88 4875.37 4803.47 416.50 -484.49 5959788.49 652968.14 GCT-MS 5031.70 27.93 316.04 4898.79 4826.89 425.41 -493.11 5959797.22 652959.35 GCT-MS 5058.20 28.02 316.13 4922.19 4850.29 434.37 -501.73 5959806.00 652950.54 GCT-MS 5084.70 28.00 316.11 4945.59 4873.69 443.34 -510.36 5959814.79 652941.74 GCT-MS 5111.20 28.03 316.09 4968.98 4897.08 452.31 -518.99 5959823.58 652932.93 GCT-MS 5137.65 28.15 316.02 4992.32 4920.42 461.27 -527.63 5959832.37 652924.10 GCT-MS 5164.10 28.15 316.00 5015.64 4943.74 470.25 -536.30 5959841.17 652915.25 GCT-MS 5190.50 28.08 316.11 5038.92 4967.02 479.21 -544.93 5959849.95 652906.44 GCT-MS 5216.80 27.95 316.32 5062.14 4990.24 488.13 -553.48 5959858.69 652897.71 GCT-MS 5243.20 27.83 316.50 5085.47 5013.57 497.07 -561.99 5959867.46 652889.02 GCT-MS 5269.75 27.88 316.61 5108.95 5037.05 506.08 -570.52 5959876.29 652880.31 GCT-MS 5296.35 27.97 316.73 5132.45 5060.55 515.14 -579.07 5959885.17 652871.57 GCT-MS 5322.85 28.02 316.85 5155.85 5083.95 524.21 -587.59 5959894.06 652862.88 GCT-MS Halliburton Global __ Company: BP Amoco .bate: 1/17/2006 Time: 14:20:28 Page: 7 Field: Prudhoe Bay Co-ord inate(NE) Re ference: Well: D-27, True North Site: PB D Pad Vertica l (TVll) Refe rence: 43 :27 2/1311986 0 0:00 71.9 Well: D-27 Section (VS) Reference: Well (O.OON,O.OOE,315.OOAzi) Wellpath: D-27A Survey Calculation Method: Min imum Curvature llb: Oracle Sure ev MD Incl -- Azim - - TVD Sys"TVD - N/S - -- E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 5349.45 28.03 316.90 5179.33 5107.43 533.33 -596.13 5959903.01 __ 652854.15 _ _ - _ - GCT-MS 5376.00 28.05 316.92 5202.76 5130.86 542.44 -604.66 5959911.94 652845.44 GCT-MS 5402.55 28.07 316.97 5226.19 5154.29 551.57 -613.18 5959920.89 652836.73 GCT-MS 5429.15 28.10 316.98 5249.66 5177.76 560.72 -621.73 5959929.87 652828.00 GCT-MS 5455.25 28.17 316.98 5272.65 5200.78 569.72 -630.12 5959938.70 652819.42 GCT-MS 5481.30 28.20 316.98 5295.64 5223.74 578.72 -638.52 5959947.52 652810.85 GCT-MS 5507.40 28.20 317.04 5318.64 5246.74 587.74 -646.93 5959956.36 652802.25 GCT-MS 5533.50 28.17 317.08 5341.65 5269.75 596.76 -655.33 5959965.21 652793.67 GCT-MS 5559.55 28.07 317.02 5364.62 5292.72 605.75 -663.69 5959974.03 652785.13 GCT-MS 5585.60 28.03 316.98 5387.61 5315.71 614.71 -672.05 5959982.81 652776.59 GCT-MS 5611.70 28.07 317.01 5410.65 5338.75 623.68 -680.42 5959991.62 652768.04 GCT-MS 5637.75 28.03 317.01 5433.64 5361.74 632.64 -688.77 5960000.40 652759.51 GCT-MS 5663.75 27.98 316.92 5456.59 5384.69 641.57 -697.10 5960009.15 652751.00 GCT-MS 5689.85 27.92 316.89 5479.65 5407.75 650.50 -705.46 5960017.91 652742.46 GCT-MS 5715.85 27.83 316.94 5502.63 5430.73 659.38 -713.76 5960026.62 652733.97 GCT-MS 5741.95 27.77 316.91 5525.72 5453.82 668.27 -722.08 5960035.34 652725.48 GCT-MS 5768.00 27.68 316.92 5548.78 5476.88 677.12 -730.36 5960044.02 652717.03 GCT-MS 5794.00 27.53 317.06 5571.82 5499.92 685.93 -738.57 5960052.66 652708.63 GCT-MS 5820.00 27.38 317.22 5594.89 5522.99 694.72 -746.73 5960061.28 652700.30 GCT-MS 5846.10 27.28 317.37 5618.08 5546.18 703.52 -754.85 5960069.91 652691.99 GCT-MS 5872.10 27.22 317.54 5641.19 5569.29 712.29 -762.90 5960078.52 652683.77 GCT-MS 5898.10 27.22 317.66 5664.31 5592.41 721.08 -770.92 5960087.13 652675.57 GCT-MS 5923.90 27.28 317.76 5687.25 5615.35 729.82 -778.87 5960095.71 652667.45 GCT-MS 5949.75 27.28 317.90 5710.22 5638.32 738.60 -786.83 5960104.32 652659.32 GCT-MS 5975.80 27.23 317.93 5733.38 5661.48 747.45 -794.82 5960113.01 652651.14 GCT-MS 6001.85 27.15 317.96 5756.55 5684.65 756.29 -802.80 5960121.69 652642.99 GCT-MS 6027.85 27.08 318.09 5779.69 5707.79 765.10 -810.72 5960130.33 652634.89 GCT-MS 6053.95 27.13 318.12 5802.93 5731.03 773.95 -818.66 5960139.02 652626.77 GCT-MS 6079.95 27.15 318.14 5826.06 5754.16 782.78 -826.58 5960147.69 652618.67 GCT-MS 6106.05 27.07 318.22 5849.30 5777.40 791.65 -834.51 5960156.38 652610.56 GCT-MS 6131.85 26.95 318.34 5872.28 5800.38 800.39 -842.31 5960164.97 652602.59 GCT-MS 6157.45 26.90 318.39 5895.11 5823.21 809.06 -850.01 5960173.47 652594.71 GCT-MS 6183.00 26:92 318.27 5917.89 5845.99 817.69 -857.70 5960181.95 652586.85 GCT-MS 6208.60 26.92 318.05 5940.72 5868.82 826.33 -865.43 5960190.43 652578.95 GCT-MS 6234.20 27.00 317.71 5963.54 5891.64 834.94 -873.21 5960198.87 652570.99 GCT-MS 6259.80 27.20 316.92 5986.32 5914.42 843.51 -881.12 5960207.28 652562.91 GCT-MS 6285.30 27.58 315.60 6008.97 5937.07 851.98 -889.23 5960215.59 652554.63 GCT-MS 6311.00 28.07 313.91 6031.70 5959.80 860.43 -897.75 5960223.86 652545.94 GCT-MS 6338.90 28.60 311.70 6056.25 5984.35 869.42 -907.46 5960232.65 652536.04 GCT-MS 6366.95 29.02 310.01 6080.83 6008.93 878.26 -917.69 5960241.28 652525.64 GCT-MS 6395.05 29.30 309.33 6105.37 6033.47 887.00 -928.23 5960249.80 652514.93 GCT-MS 6423.15 29.48 309.11 6129.85 6057.95 895.72 -938.91 5960258.30 652504.07 GCT-MS 6451.25 29.53 309.09 6154.31 6082.41 904.45 -949.65 5960266.81 652493.15 GCT-MS 6479.50 29.28 308.95 6178.92 6107.02 913.18 -960.43 5960275.32 652482.20 GCT-MS 6507.75 29.08 308.77 6203.58 6131.68 921.83 -971.15 5960283.74 652471.30 GCT-MS 6536.00 29.03 308.80 6228.28 6156.38 930.42 -981.85 5960292.11 652460.44 GCT-MS 6564.25 28.88 308.85 6253.00 6181.10 938.99 -992.50 5960300.47 652449.61 GCT-MS 6592.60 28.72 308.83 6277.84 6205.94 947.56 -1003.14 5960308.81 652438.80 GCT-MS 6620.90 28.52 308.92 6302.68 6230.78 956.07 -1013.69 5960317.10 652428.07 GCT-MS 6649.20 28.25 309.00 6327.58 6255.68 964.53 -1024.15 5960325.34 652417.44 GCT-M5 6677.60 27.98 309.01 6352.63 6280.73 972.95 -1034.55 5960333.55 652406.87 GCT-MS 6706.10 27.78 309.11 6377.82 6305.92 981.35 -1044.90 5960341.74 652396.36 GCT-MS 6734.55 27.52 309.16 6403.02 6331.12 989.68 -1055.14 5960349.86 652385.95 GCT-MS Halliburton Global Company: BP Amoco llate: 1/17/2006 Time: 14:20:28 Page: 8 Field: P rudhoe Bay Co-ord inate(NE) Reference: Well: D-27, True No rth Site: P B D Pad Vertica l (TVD) Refe rence: 43 :27 2/13/1986 00:00 71.9 Well: D -27 Section (VS) Re-ference: Weil (O.OON,O.OOE,315.OOAzi) Wcllpath: D -27A Survey Calculation Method: Minimum Curvature Db: Oracle Sun'cy MD Incl Azim TVD Sys TVD N/S E/W MapN MapF. Tool ~ ft deg deg ft ft ft ft ft ft 6763.15 27.17 309.17 6428.43 6356.53 997.98 -1065.33 5960357.95 652375.60 GCT-MS 6791.65 26.87 309.10 6453.82 6381.92 1006.15 -1075.37 5960365.91 652365.39 GCT-MS 6819.75 26.65 309.04 6478.91 6407.01 1014.12 -1085.19 5960373.68 652355.41 GCT-MS 6847.85 26.42 309.02 6504.05 6432.15 1022.03 -1094.95 5960381.39 652345.50 GCT-MS 6875.85 26.17 309.04 6529.15 6457.25 1029.84 -1104.58 5960389.00 652335.70 GCT-MS 6903.85 25.97 308.97 6554.30 6482.40 1037.58 -1114.14 5960396.54 652325.99 GCT-MS 6931.95 25.77 308.88 6579.58 6507.68 1045.29 -1123.68 5960404.05 652316.29 GCT-MS 6959.95 25.53 308.89 6604.83 6532.93 1052.90 -1133.12 5960411.47 652306.71 GCT-MS 6987.95 25.30 308.80 6630.12 6558.22 1060.43 -1142.48 5960418.81 652297.20 GCT-MS 7015.95 25.07 308.71 6655.45 6583.55 1067.89 -1151.77 5960426.08 652287.75 GCT-MS 7043.90 24.80 308.72 6680.80 6608.90 1075.26 -1160.96 5960433.26 652278.41 GCT-MS 7071.90 24.55 308.72 6706.24 6634.34 1082.57 -1170.08 5960440.38 652269.15 GCT-MS 7100.00 24.30 308.76 6731.83 6659.93 1089.85 -1179.14 5960447.46 652259.94 GCT-MS 7128.00 24.07 308.77 6757.37 6685.47 1097.03 -1188.09 5960454.46 652250.85 GCT-MS 7156.10 23.78 308.73 6783.05 6711.15 1104.16 -1196.98 5960461.41 652241.82 GCT-MS 7184.15 23.57 308.81 6808.74 6736.84 1111.21 -1205.76 5960468.28 652232.89 GCT-MS 7212.15 23.45 308.81 6834.42 6762.52 1118.21 -1214.46 5960475.10 652224.05 GCT-MS 7240.20 23.32 308.85 6860.17 6788.27 1125.20 -1223.13 5960481.91 652215.24 GCT-MS 7268.25 23.10 308.85 6885.95 6814.05 1132.13 -1231.74 5960488.66 652206.49 GCT-MS 7296.35 22.87 308.85 6911.81 6839.91 1139.01 -1240.29 5960495.37 652197.81 GCT-MS 7324.35 22.62 308.90 6937.64 6865.74 1145.81 -1248.72 5960501.99 652189.24 GCT-MS 7352.25 22.33 308.88 6963.42 6891.52 1152.50 -1257.02 5960508.51 652180.81 GCT-MS 7380.25 22.00 308.92 6989.35 6917.45 1159.14 -1265.24 5960514.98 652172.45 GCT-MS 7408.15 21.77 308.82 7015.24 6943.34 1165.66 -1273.34 5960521.34 652164.22 GCT-MS 7436.20 21.67 308.75 7041.30 6969.40 1172.17 -1281.43 5960527.67 652156.00 GCT-MS 7464.25 21.50 308.72 7067.38 6995.48 1178.62 -1289.48 5960533.96 652147.82 GCT-MS 7491.85 21.40 308.71 7093.07 7021.17 1184.93 -1297.35 5960540.11 652139.82 GCT-MS 7519.45 21.37 308.91 7118.77 7046.87 1191.24 -1305.19 5960546.26 652131.85 GCT-MS 7546.95 21.32 309.05 7144.38 7072.48 1197.54 -1312.98 5960552.39 652123.94 GCT-MS 7574.55 21.28 309.15 7170.10 7098.20 1203.86 -1320.76 5960558.56 652116.04 GCT-MS 7602.05 21.27 309.36 7195.72 7123.82 1210.18 -1328.48 5960564.71 652108.18 GCT-MS 7629.65 21.35 309.48 7221.43 7149.53 1216.54 -1336.23 5960570.92 652100.31 GCT-MS 7657.25 21.35 309.59 7247.14 7175.24 1222.94 -1343.98 5960577.16 652092.43 GCT-MS 7684.80 21.25 309.82 7272.81 7200.91 1229.33 -1351.68 5960583.39 652084.60 GCT-MS 7712.35 21.08 309.99 7298.50 7226.60 1235.72 -1359.31 5960589.61 652076.84 GCT-MS 7739.95 20.95 310.22 7324.26 7252.36 1242.09 -1366.88 5960595.83 652069.14 GCT-MS 7767.45 20.98 310.51 7349.94 7278.04 1248.46 -1374.38 5960602.05 652061.52 GCT-MS 7795.05 21.10 310.75 7375.70 7303.80 1254.92 -1381.90 5960608.35 652053.87 GCT-MS 7822.65 21.23 311.15 7401.44 7329.54 1261.45 -1389.42 5960614.72 652046.21 GCT-MS 7850.20 21.37 311.84 7427.11 7355.21 1268.08 -1396.92 5960621.20 652038.58 GCT-MS 7877.70 21.60 312.56 7452.70 7380.80 1274.84 -1404.38 5960627.81 652030.99 GCT-MS 7905.30 21.83 313.23 7478.34 7406.44 1281.79 -1411.86 5960634.61 652023.37 GCT-MS 7932.90 22.08 314.04 7503.94 7432.04 1288.92 -1419.33 5960641.57 652015.75 GCT-MS 7960.50 22.37 314.82 7529.49 7457.59 1296.22 -1426.78 5960648.73 652008.15 GCT-MS 7988.10 22.67 315.46 7554.98 7483.08 1303.72 -1434.24 5960656.07 652000.55 GCT-MS 8015.70 22.98 316.12 7580.42 7508.52 1311.39 -1441.71 5960663.59 651992.93 GCT-MS 8043.30 23.30 316.68 7605.80 7533.90 1319.25 -1449.18 5960671.29 651985.29 GCT-MS 8070.90 23.58 317.08 7631.13 7559.23 1327.26 -1456.69 5960679.14 651977.62 GCT-MS 8098.50 23.87 317.46 7656.39 7584.49 1335.42 -1464.22 5960687.15 651969.92 GCT-MS 8125.80 24.05 317.89 7681.34 7609.44 1343.61 -1471.69 5960695.19 651962.29 GCT-MS 8152.80 24.13 3.18.26 7705.99 7634.09 1351.81 -1479.05 5960703.23 651954.76 GGT-MS 8179.95 24.13 318.47 7730.77 7658.87 1360.11 -1486.43 5960711.38 651947.22 GCT-MS Halliburtion Global Company: BP Amoco Date: 1/17/2006 7imc: 14:20:28 Pare: 9 Field: P rudhoe Bay Co-ord inate(NE) Re ference: Well: D-27, True North Site: PB D Pad Vertica l (~'VD) Refe rence: 43 :27 2/13!1986 00:00 71.9 Well: D -27 Section (VS) Reference: Well (O.OON,O.OOE,315.OOAzi) Wefipath: D -27A Sur~ev Calculation Method: Minimum Curvature Db: Oracle --- -- Sur~ev ~~~ MD Intl Azim TVD Sys TVD N/S E/W MapV MapE Tool ft deg deg ft ft ft ft ft ft 8207.10 24.03 318.69 7755.55 7683.65 1368.42 -1493.75 5960719.53 651939.73 GCT-MS 8234.20 23.92 318.87 7780.32 7708.42 1376.70 -1501.01 5960727.66 651932.30 GCT-MS 8261.30 23.80 318.87 7805.10 7733.20 1384.96 -1508.22 5960735.77 651924.93 GCT-MS 8288.45 23.67 319.08 7829.95 7758.05 1393.20 -1515.39 5960743:87 651917.59 GCT-MS 8315.50 23.47 319.31 7854.75 7782.85 1401.39 -1522.46 5960751.91 651910.35 GCT-MS 8342.60 23.23 319.30 7879.63 7807.73 1409.53 -1529.47 5960759.91 651903.19 GCT-MS 8369.70 23.02 319.46 7904.55 7832.65 1417.61 -1536.40 5960767.84 651896.09 GCT-MS 8396.79 22.82 319.62 7929.50 7857.60 1425.64 -1543.24 5960775.73 651889.09 GCT-MS 8423.90 22.60 319.69 7954.51 7882.61 1433.61 -1550.02 5960783.56 651882.15 GCT-MS 8451.00 22.42 319.89 7979.54 7907.64 1441.54 -1556.72 5960791.35 651875.29 GCT-MS 8478.10 22.30 320.03 8004.61 7932.71 1449.43 -1563.35 5960799:10 651868.50 GCT-MS 8506.30 22.20 320.19 8030.71 7958.81 1457.62 -1570.20 5960807.15 651861.49 GCT-MS 8546.29 22.05 320.66 8067.75 7995.85 1469.23 -1579.79 5960818.56 651851.66 GCT-MS 8568.00 21.88 321.01 8087.89 8015.99 1475.53 -1584.92 5960824.75 651846.40 GCT-MS 8576.90 21.80 321.18 8096.15 8024.25 1478.10 -1587.00 5960827.29 651844,27 GCT-MS 8586.30 21.77 321.34 8104.88 8032.98 1480.82 -1589.18 5960829.96 651842.03 GCT-MS 8595.60 21.78 321.46 8113.51 8041.61 1483.52 -1591.33 5960832.61 651839.82 GCT-MS 8605.00 21.80 321.53 8122.24 8050.34 1486.25 -1593.51 5960835.30 651837.60 GCT-MS 8614.40 21.77 321.57 8130.97 8059.07 1488.98 -1595.68 5960837.99 651835.37 GCT-MS 8623.75 21.65 321.62 8139.66 8067.76 1491.69 -1597.83 5960840.65 651833.17 GCT-MS 8633.10 21.52 321.74 8148.35 8076.45 1494.39 -1599.96 5960843.31. 651830.98 GCT-MS 8642.50 21.45 321.87 8157.10 8085.20 1497.10 -1602.09 5960845.97 651828.80 GCT-MS 8651.90 21.52 321.92 8165.84 8093.94 1499.81 -1604.21 5960848.63 651826.62 GCT-MS 8661.25 21.58 321.94 8174.54 8102.64 1502.51 -1606.33 5960851.29 651824.45 GCT-MS 8670.60 21.60 322.01 8183.23 8111.33 1505.22 -1608.45 5960853.96 651822.27 GCT-MS 8680.00 21.47 322.05 8191.98 8120.08 1507.94 -1610.57 5960856.63 651820.09 GCT-MS 8689.45 21.17 322.18 8200.78 8128.88. 1510.65 -1612.68 5960859.30 651817.93 GCT-MS 8698.85 21.02 322.43 8209.55 8137.65 1513.33 -1614.75 5960861.94 651815.81 GCT-MS 8708:30 20.97 322.59 8218.37 8146.47 1516.02 -1616.81 5960864.58 651813.69 GCT-MS 8717.79 20.78 322.56 8227.24 8155.34 1518.70 -1618.87 5960867.22 651811.58 GCT-MS 8727.25 20.68 322.55 8236.09 8164.19 1521.36 -1620.90 5960869.84 651809.49 GCT-MS 8736.75 20.80 322.76 8244.97 8173.07 1524.04 -1622.94 5960872.47 651807.40 GCT-MS 8746.20 20.98 323.09 8253.80 8181.90 1526.72 -1624.97 5960875.12 651805.31 GCT-MS 8755.65 21.08 323.34 8262.62 8190.72 1529.44 -1627.00 5960877.79 651803.23 GCT-MS 8764.95 21.00 323.55 8271.30 8199.40 1532.12 -1628.99 5960880.43 651801.18 GCT-MS 8774.25 20.88 323.80 8279.99 8208.09 1534.80 -1630.96 5960883.07 651799.16 GCT-MS 8783.55 20.82 324.02 8288.68 8216.78 1537.47 -1632.91 5960885.70 651797.16 GCT-MS 8792.90 20.72 324.08 8297.42 8225.52 1540.16 -1634.86 5960888.35 651795.16 GCT-MS 8802.20 20.67 324.06 8306.12 8234.22 1542.82 -1636.79 5960890.97 651793.17 GCT-MS 8811.55 20.77 324.05 8314.87 8242.97 1545.50 -1638.73 5960893.60 651791.18 GCT-MS 8820.85 20.75 323.99 8323.56 8251.66 1548.17 -1640.67 5960896.23 651789.19 GCT-MS 8830.15 20.52 324.05 8332.27 8260.37 1550.82 -1642.59 5960898.84 651787.21 GCT-MS 8839.45 20.38 324.27 8340.98 8269.08 1553.45 -1644.49 5960901.44 651785.25 GCT-MS 8848.75 20.38 324.30 8349.70 8277.80 1556.08 -1646.38 5960904.03 651783.31 GCT-MS 8858.05 20.32 324.26 8358.42 8286.52 1558.71 -1648.27 5960906.62 651781.37 GCT-MS 8867.29 20.28 324.32 8367.08 8295.18 1561.31 -1650.14 5960909.18 651779.44 GCT-MS 8876.60 20.35 324.30 8375.81 8303.91 1563.93 -1652.03 5960911.77 651777.51 GCT-MS 8885.85 20.42 324.27 8384.49 8312.59 1566.55 -1653.91 5960914.34 651775.57 GCT-MS 8895.15 20.37 324.35 8393.20 8321.30 1569.18 -1655.80 5960916.93 651773.63 GCT-MS 8904.45 20.30 324.45 8401.92 8330.02 1571.81 -1657.68 5960919.52 651771.69 GCT-MS 8913.75 20.43 324.41 8410.64 8338.74 1574.44 -1659.56 5960922.12 651769.76 GCT-MS 8925.30 20.47 324.44 8421.46 8349.56 1577.73 -1661.91 5960925.35 651767.34 GCT-MS 8965.80 19.77 325.08 8459.49 8387.59 1589.10 -1669.95 5960936.56 651759.07 GCT-MS • ~ Halliburton Global Company: BP Amoco Date: 1/17/2006 Time: 14:2028 Page: l0 Field: Pru dhoe Bay Co-ordinate(NE) Re ference: Well: D-27, True North Site: PB D Pad Vertica l (T~%U) Refe rence: 43 :27 2/1 311986 00:00 71.9 Well: D-27 Section (VS) Reference: Well (O.OON,O.OOE,315.OOAzi) I Welipath: D-27A Survey Calculation Method: Min __ imum Curvature llb: Oracle - --- _ Survey - NI D - _ lncl d _ Acim ~ 1'VD _- _ Svs T~ D _ N/S FlW Nla v P _ P- - Ma E - - - Tool ft eg deg ft ft ft ft ft ft 8983.29 19.65 325.53 8475.96 8404.06 1593.95 -1673.31 5960941.34 651755.62 GCT-MS 9008.39 19.67 326.83 8499.59 8427.69 1600.97 -1678.01 5960948.26 651750.78 GCT-MS 9038.10 19.82 328.45 8527.56 8455.66 1609.45 -1683.38 5960956.62 651745.23 GCT-MS 9065.79 19.97 329.33 8553.59 8481.69 1617.51 -1688.25 5960964.59 651740.20 GCT-MS 9093.54 20.08 329.67 8579.67 8507.77 1625.70 -1693.07 5960972.68 651735.21 GCT-MS 9121.25 20.12 329.58 8605.69 8533.79 1633.92 -1697.89 5960980.79 651730.23 GCT-MS 9148.95 20.13 329.21 8631.70 8559.80 1642.12 -1702.74 5960988.89 651725.21 GCT-MS 9176.70 20.32 328.74 8657.74 8585.84 1650.34 -1707.68 5960997.01 651720.10 GCT-MS 9204.45 20.72 328.30 8683.73 8611.83 1658.64 -1712.76 5961005.20 651714.86 GCT-MS 9232.35 21.18 327.98 8709.78 8637.88 1667.11 -1718.03 5961013.56 651709.42 GCT-MS 926020 21.65 327.77 8735.71 8663.81 1675.72 -1723.44 5961022.06 651703.84 GCT-MS 9288.04 22.15 327.48 8761.54 8689.64 1684.49 -1729.00 5961030.71 651698.10 GCT-MS 9315.95 22.62 327.33 8787.35 8715.45 1693.44 -1734.72 5961039.55 651692.19 GCT-MS 9343.85 23.03 327.32 8813.06 8741.16 1702.55 -1740.57 5961048.54 651686.16 GCT-MS 9371.85 23.52 327.07 8838.78 8766.88 1711.85 -1746.56 5961057.71 651679.98 GCT-MS 9399.45 23.98 326.62 8864.05 8792.15 1721.16 -1752.64 5961066.89 651673.71 GCT-MS 9426.75 24.38 326.32 8888.95 8817.05 1730.48 -1758.82 5961076.08 651667.35 GCT-MS 9454.04 24.77 326.11 8913.77 8841.87 1739.91 -1765.13 5961085.39 651660.85 GCT-MS 9459.00 24.84 326.06 8918.27 8846.37 1741.64 -1766.29 5961087.09 651659.65 MWD 9491.65 31.82 320.08 8947.00 8875.10 1753.95 -1775.66 5961099.20 651650.03 MWD 9522.30 41.66 316.59 8971.53 8899.63 1767.58 -1787.87 5961112.58 651637.54 MWD 9561.43 53.74 313.52 8997.82 8925.92 1787.97 -1808.33 5961132.55 651616.68 MWD 9591.71 61.17 307.12 9014.11 8942.21 1804.42 -1827.80 5961148.59 651596.88 MWD 9621.79 69.70 298.86 9026.62 8954.72 1819.23 -1850.73 5961162.93 651573.65 MWD 9657.06 78.22 292.71 9036.37 8964.47 1833.91 -1881.23 5961176.99 651542.86 MWD 9697.07 81.03 282.51 9043.59 8971.69 1845.79 -1918.69 5961188.09 651505.17 MWD 9743.53 93.10 292.04 9045.97 8974.07 1859.54 -1962.85 5961200.95 651460.73 MWD 9794.61 100.79 289.66 9039.80 8967.90 1877.58 -2010.20 5961218.01 651413.04 MWD 9824.69 98.68 285.08 9034.71 8962.81 1886.43 -2038.48 5961226.28 651384.58 MWD 9857.83 98.24 281.91 9029.83 8957.93 1894.08 -2070.35 5961233.27 651352.56 MWD 9882.83 .98.59 280.50 9026.18 8954.28 1898.88 -2094.61 5961237.58 651328.21 MWD 9916.66 95.59 276.80 9022.00 8950.10 1903.93 -2127.79 5961241.95 651294.94 MWD 9942.32 92.29 275.85 9020.24 8948.34 1906.75 -2153.23 5961244.25 651269.45 MWD 9973.64 91.19 276.45 9019.28 8947.38 1910.10 -2184.36 5961246.96 651238.26 MWD 10006.97 88.55 279.97 9019.36 8947.46 1914.86 -2217.34 5961251.05 651205.19 MWD 10037.77 88.55 281.73 9020.14 8948.24 1920.65 -2247.57 5961256.22 651174.84 MWD 10071.13 89.69 286.67 9020.65 8948.75 1928.83 -2279.90 5961263.74 651142.36 MWD 10098.52 91.63 291.25 9020.34 8948.44 1937.73 -2305.80 5961272.11 651116.29 MWD 10136.85 91.54 293.01 9019.28 8947.38 1952.16 -2341.29 5961285.81 651080.52 MWD 10166.11 94.63 294.42 9017.70 8945.80 1963.91 -2368.03 5961297.01 651053.54 MWD 10199.98 94.89 299.18 9014.89 8942.99 1979.13 -2398.15 5961311.60 651023.12 MWD 10230.61 91.37 300.94 9013.22 8941.32 1994.44 -2424.62 5961326.38 650996.35 MWD 10260.42 87.84 299.36 9013.42 8941.52 2009.41 -2450.39 5961340.82 650970.28 MWD 10314.96 84.93 292.66 9016.87 8944.97 2033.27 -2499.27 5961363.67 650920.92 MWD 10362.74 86.78 287.73 9020.32 8948.42 2049.71 -2543.98 5961379.20 650875.89 MWD 10390.60 90.22 287.37 9021.05 8949.15 2058.11 -2570.53 5961387.05 650849.17 MWD 10416.76 91.93 287.26 9020.56 8948.66 2065.89 -2595.50 5961394.32 650824.05 MWD 10452.88 92.90 287.96 9019.04 8947.14 2076.81 -2629.90 5961404.53 650789.44 MWD 10485.72 89.74 286.03 9018.28 8946.38 2086.41 -2661.29 5961413.48 650757.86 MWD 10513.25 89.56 282.69 9018.45 8946.55 2093.23 -2687.96 5961419.76 650731.06 MWD 10541.87 90.00 283.57 9018.56 8946.66 2099.73 -2715.83 5961425.69 650703.07 MWD 10593.67 94.75 288.14 9016.41 8944.51 2113.86 -2765.59 5961438.80 650653.03 MWD Halliburton Global ~ Company: BP Amoco Date: 1/17/2006 'l'ime: 14:2028 Page: ]1 Field: Pru dhoe Bay Co-ordin ate(NE) R eference: Well: D-27, Tr ue North Site: PB Q Pad Vertical (TVD) Reference: 43 :27 2/13/1986 00.00 71.9 Well: D-2 7 Section ( VS) Reference: Well (O.OON,O. OOE,315.OOAzi) Wellpath: D-2 7A Su rvey Calcula tion Method: Mi nimum Curv atu re Db: Oracle Surccy MD lncl Azim TVA Sys TV D N/S E/~V MapN MapN' 'Pool ft de g deg ft ft ft ft ft ft 10625 .02 91 .76 292 .36 9014. 63 8942 .73 2124 .69 -2794 .94 5961449 .03 650623. 47 MWD 10656 .02 89 .30 294 .64 9014. 34 8942 .44 2137 .05 -2823. 36 5961460 .81 650594. 80 MWD 10695 .02 87 .33 300 .17 9015. 49 8943 .59 2154 .99 -2857. 96 5961478 .03 650559. 85 MWD 10738 .78 88 .42 303 .43 9017. 12 8945 .22 2178 .03 -2895 .12 5961500 .30 650522. 23 MWD 10774 .92 88 .86 310 .29 9017. 97 8946 .07 2199 .69 -2924. 01 5961521 .37 650492. 90 MWD 10808 .74 88 .64 314 .13 9018. 71 8946 .81 2222 .40 -2949. 05 5961543 .56 650467. 41 MWD 10836 .02 90 .53 317 .85 9018. 91 8947 .01 2242. 02 -2968. 00 5961562 .79 650448. 06 MWD 10885 .68 92 .99 326 .28 9017. 38 8945 .48 2281. 12 -2998. 48 5961601 .26 650416. 79 MWD 10926 .44 95 .14 330 .47 9014. 49 8942 .59 2315 .73 -3019. 80 5961635 .43 650394. 77 MWD 10956 .23 95 .62 334 .37 9011. 70 8939 .80 2342 .02 -3033. 53 5961661 .42 650380. 51 MWD 10985 .53 91 .58 336 .48 9009. 86 8937 .96 2368. 60 -3045. 68 5961687 .75 650367. 81 MWD 11015 .63 87 .20 334 .85 9010. 18 8938 .28 2396. 02 -3058. 08 5961714 .91 650354. 86 MWD 11065 .14 88 .90 334 .25 9011. 86 8939 .96 2440. 70 -3079. 35 5961759 .14 650332. 69 MWD 11100 .92 87 .81 329 .35 9012. 89 8940 .99 2472. 21 -3096. 24 5961790 .30 650315. 16 MWD 11140 .38 84 .32 328 .96 9015. 60 8943 .70 2506. 00 -3116. 42 5961823 .67 650294. 29 MWD 11164 .88 83 .17 324 .73 9018. 27 8946 .37 .2526. 39 -3129. 74 5961843 .77 650280. 56 MWD 11192 .23 81 .15 323 .32 9022. 00 8950 .10 2548. 31 -3145. 65 5961865 .37 650264. 21 MWD 11227 .12 86 .34 322 .09 9025. 80 8953 .90 2575. 89 -3166. 66 5961892 .51 650242. 64 MWD 11255 .73 90 .04 326 .49 9026. 70 8954 .80 2599. 10 -3183. 34 5961915 .38 650225. 49 MWD 11301 .11 89 .69 328 .08 9026. 81 8954 .91 2637. 28 -3207. 87 5961953 .04 650200. 19 MWD 11335 .50 91 .54 334 .07 9026. 44 8954 .54 2667. 36 -3224. 49 5961982 .78 650182. 96 MWD 11367 .14 91 .45 333 .89 9025. 62 8953 .72 2695. 79 -3238. 37 5962010 .91 650168. 51 MWD 11403 .09 93 .83 338 .65 9023. 96 8952 .06 2728. 65 -3252. 82 5962043 .47 650153. 39 MWD 11433 .71 96 .74 344 .11 9021. 14 8949 .24 2757. 53 -3262. 55 5962072 .14 650143. 07 MWD 11476 .44 93 .30 346 .58 9017. 40 8945 .50 2798. 70 -3273. 31 5962113 .08 650131. 47 MWD 11510 .47 92 .16 352 .75 9015. 77 8943 .87 2832. 13 -3279. 41 5962146 .37 650124. 69 MWD 11542 .25 91 .72 357 .68 9014. 70 8942 .80 2863. 77 -3282. 06 5962177 .95 650121. 40 MWD 11565 .10 91 .28 358 .56 9014. 10 8942 .20 2886. 60 -3282. 81 5962200 .76 650120. 18 MWD 11598 .29 90 .31 0 .32 9013. 64 8941 .74 2919. 78 -3283. 13 5962233 .93 650119. 18 MWD 11626 .00 90 .31 0 .32 9013. 49 8941 .59 2947. 49 -3282. 97 5962261 .63 650118. 77 MWD TREE = 4" CNV l~~ELLHEAD = FMC ACTUATOR = AXELSON KB ELEV = 71.9' BF. ELEV = 42.8' KO_P = _ 3500' Max Angle = 100.8 @ 9795' Datum MD = 940 8' Datum TV D = _ _ ~ 8800' 13-3/8" CSG, 72#, L80, ID = 12.347" Minimum ID = 2.360" @ 8744' BOT KB PKR SEAL ASSEMBLY TOP OF 3-3/16" LNf~ 8745' TOP OF 7" LNR $756' 3.5" X Nip 2.813" ID 8764' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 8808' 9-5/8" CSG, 47#, L-80, ID = 8.681" 8991' PERFORATION SUMMARY REF LOG: SWS-MCNUGR, 01/04/2006 ANGLE AT TOP PERF: 92 DEG Q 9950" Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9950 - 10150' OPEN 01 /06/06 2" 6 10630 - 10850' OPEN 01 /06/06 2" 6 11390 - 11550' OPEN 01 /06/06 PBTD 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" D ~~ ~ ~ AND SEAL ASSY@ 8690' 8 86~MK6.5/8" PKR 2073' 4-1/2" OTIS SSSV NIP, ID = 3.813" O GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3002 2930 4 OTIS-LBD RA 5 5063 4854 28 OTIS-LBD RA 4 6460 6090 30 OTIS-LBD RA 3 7350 6889 22 OTIS-LBD RA 2 8123 7607 24 OTIS-LBD RA 1 8545 7994 22 OTIS-LBD RA 8614' ~-~4-1/2" OTIS XA SLIDWG SLV, ID= 3.813" 8672' ~ TBG SEAL ASSY 8687' 9-5/8" X 4-1/2" TNV PKR ID = 4.75" 8736' 3,740' 4-1 /2" OTIS X NIP, ID = 3.813" BOT4-1/2" KB LT PACKER ${ 775' I-14-1/2" OTIS XN NIP, ID = 3.725" (CTD milled out to 3.8") $$0$' 4-1/2" TBG TAIL ID = 3.958" 8804' ELMD TT -LOGGED 03/23/86 9434' -1 MARKER JOINT 10,110' 3-3/16 x 2-7/8 XO, LSL SUB 9459' ~-iMechanical Whipstock 3-3/16" X 2-7/8" crr~'ed and perfedl-i 11626' DATE REV BY COMMENTS DATE REV BY COMMENTS 03/01/86 ORIGINAL COMPLETION 02/07/01 SIS-SLT CONVERTED TO CANVAS 03/08/01 SIS-LG FINAL 05/19/01 RWTP CORRECTIONS 07/09/03 CMO/TLP MAX ANGLE CORRECTION 01/06/06 RRW CTD HORIZONTAL SIDETRACK PRUDI-IOE BAY UNIT WELL: D-27 A PERMff No: 205-193 API No: 50-029-21543-01 SEC 23, T11 N, R13E, BP bcploration (Alaska) WELL LOG TRANSMITTAL To: State of Alaska. February 14, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7`" Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: D-27A, AK-MW-4113773 1 LDWG formatted Disc with verification listing. ~~ API#: 50-029-21543-O1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 r Date: ~ C Signed: lti 5 -' ~ ~ 3 F,~~ r • 30-Jan-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE ~~~''~3 Re: Distribution of Survey Data for Well D-27A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 9,454.04' MD Window /Kickoff Survey: 11,598.29' MD (if applicable) Projected Survey: 11,626.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 cam- l'7~~k Signed ~i - Date , Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) Re: PBU D-27A BP Exploration (Alaska), Inc. Permit No: 205-193 Surface Location: 1606' FNL, 1692' FEL, SEC. 23, T11N, R13E, UM Bottomhole Location: 1247' FSL, 4998' FEL, SEC. 14, T 11 N, R 13E, UM Dear Ms. Lasley: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits -and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Co rat (907) 659- 3607 (pager). DATED this~day of November, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA AND GAS CONSERVATION CO ISSION PERMIT TO DRILL 20 AAC 25.005 ,~~~~i~ NQV ~ ~ 2r7~5 Alaska Oil $ Ges Cons. COCf1ffiNS$IOfl ~t Nl~{9ereww 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ®Development Oil ^ Multip a one ^ Stratigraphic Test ^ Service ^Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU D-27A ~<<~ z3 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11575 TVD 8960ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1606' FNL 1692' FEL T11 N R13E SEC 23 UM 7. Property Designation:. ADL 028285 Pool , , . , , , Top of Productive Horizon: 33' FSL, 3391' FEL, SEC. 14, T11 N, R13E, UM 8. Land Use Permit: 13. Approximate Spu ate: Janua 2 06 Total Depth: 1247' FSL, 4998' FEL, SEC. 14, T11 N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 25,500' 4b. Location of Well (State Base Plane Coordinates): Surface: x- X653461 - 5959382 Zone- ASP4 10. KB Elevation (Height above GL): 71.9 feet 15. Distance to Nearest well Within Pool 1000' to H-36A 16. Deviated Wells: Kickoff Depth: 9460 feet Maximum Hole Angle: 95 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3160 Surface: 2280 ~ 18. asing rogram: ize Specifications Setting Depth T Bottom uant~y o ement c.f. ar sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data s-a/a• x a-vs• ~-a/ts" x 2-7/8" 6.2# / 6.16# L-80 STL 2825' 8750' 8255' 11575' 8960' 163 cu ft Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): 9784 Total Depth TVD (ft): 9210 Plugs (measured): None Effective Depth MD (ft): 9741 Effective Depth TVD (ft): 9172 Junk (measured): None Casin Len h Size Cement Volume , MD TVD r n r 110' 20" cu ds Concrete 110' 110' 2675' 13-3/8" 3255 cu ft Permafrost 'E', 465 cu ft PF 2675' 2675' 8991' 9-5/8" 575 cu ft Class 'G' 8991' 8483' r in 1028' 7" 0 cu ft Class 'G' 8756' - 9784' 8263' - 9210' Pertoration Depth MD (ft): 9555' - 9597' Pertoration Depth TVD (ft): 9005' - 9043' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Barbara Lasley, ssa-5126 Printed Name Barbara Lasley Title CT Drilling Engineer Prepared By Name/NUmber: Si natur /~ c?C © Phone 564-5126 Date Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: - / API Number: 50- 029-21543-01-00 Permit Approval Date: See cover letter for other requirements Conditions of Approval: Sam Required (^ Yes ~No Mud Log Required ^ Yes ,~No H rog Sulfide Measures Yes ^ No Directional Survey Required Yes ^ No Other: ~ ~,e, D ~ SO v ro La' , APPROVED BY ,~~ A rove THE COMMISSION Date Form 10-401~evised 06/2004 ~ Submit In Duplicate a i ~. ~~~~ ~ ~~ 41 ~.. I ~" by To: Winton Aubert, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Barbara M. Lasley, CTD Engineer Date: November 18, 2005 Re: D-27A CTD Sidetrack Permit to Drill • The sidetrack, D-27A, is scheduled to be drilled by Nordic 1 during the first week of January. The plan calls for running a CIBP above the existing perforations prior to setting a whipstock for an exit into Zone 2B. D- ~" 27A will target Zone 2A production. CTD Sidetrack Summary Rig Work: 1. MIRU Nordic 1 and test BOPE to 250 psi low and 50 / psi high. ~ 2. Mi113.725' XN nipple at 8775' MD to 3.8". ~ 3. Mi113.80" window at 9,455' MD (8914' ss) in Zone 2B. 4. Drill approximately 2125' of horizontal sidetrack into Zone 2A target with Resistivity logging to 11,575' MD~ Bit selection size from 4.25" to 3.75". 5. Run 3-3/16" x 2-7/ s `lid liner, TOL at 8,750' MD (8255'ss). ~ 6. Cement liner with 29 bls 15.8 ppg cement to place top of cement at 9,300' MD. 7. Cleanout liner an f to 2000 psi. 8. Log memory CNL/GR/CCL from the tubing tail to PBTD. 9. Perforate liner as per Asset instructions, approximately 800' of perforations expected. 10. Freeze protect well and RDMO. Mud Program: • Well kill: 8.5 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. / Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Casing Program: • 3 3/16" x 2 7/8" fully cemented liner • A minimum of 29 bbls 15.8 ppg cement will be used for liner cementing. Casin finer Inform~n OD Grade Wei ht Burst Colla se 9-5/8" L-80 47# 6870 si 4760 si 7" L-80 29# 8160 si 7020 si 4-1/2" L-80 12.6# 8440 si 7500 si 3-3/16" L-80 6.2# 8520 si 7660 si 2-7/8" L-80 6.17# 10,570 si 11,160 si 4-1/4" - 3-3/4' O en hole Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. ~ • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 95 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 25,500 ft (North). • Distance to nearest well within pool - 1,000 ft (H-36A. Logging • MWD directional and Gamma Ray/Resistivity will be run over all of the open hole section. • Log memory CNLJGR/CCL from the tubing tail to PBTD. Hazards • The maximum recorded H2S level on D pad is S~pm (D-15 on 1/2/2005). Most wells are below 10 ppm. • Lost circulation risk is average. Reservoir Pressure • Res. press. is estimated to be 3160 psi at 8800'ss (6.9 ppg EMW). /< • Maximum surface pressure with gas (0.10 psi/ft) to surface is 2280 psi. Barbara M. Lasley j i~ CTD Drilling Engineer 564-5126 CC: Well File Sondra Stewman/Terrie Hubble ram= a• rnni WELLHEAD= FMC ACTUATOR= AXELSON KB. R_EV = 71.9' BF. ELEV = 42.8' KOP = 3500' Max An le = 30 ~ 6451' Datum MD = 9408' Datum ND= 8800' 13-3/8" CSG, 72#, L80, ID = 12.347' H 2675' Minimum ID = 3.725" ~ 8775' 4-1~2" OTIS XN NIPPLE D~27 AN~FAL ASSY ~ 86 0~& 86 O~MIB. 5/8" PKR 2073' 4-112' OTIS SSSV NIP, ID = 3.813' [;AS 1 IFT MANDR1=t S ST MD ND DEV NPE VLV LATCH PORT DATE 6 3002 2930 4 OTIS-LBD RA 5 5063 4854 28 OTIS-LBD RA 4 6460 6090 30 OTIS-LBD RA 3 7350 6889 22 OTIS-LBD RA 2 8123 7607 24 OTIS-LBD RA 1 8545 7994 22 OTIS-LBD RA 4-1/2° OTIS XA SLIDNG SLV, ID = 3.813" 8872' HTBG SEAL ASSY ~ 8687' 9-5/8° X 4-1 /2° TNV PKR, ID = 4.75' 8736' 4-1/2" OTIS X NIP, ID = 3.813' 7• LNR H 8756' 4112" TBG, 12.6#, L-80, .0152 bpf , m = 3.958° 9-5/8" CSG, 47#, L-80, m = 8.681 " 8775' 4-f/2" OTIS XN NIP, ID = 3.725" ~8' $$0$' 4-1/2" TBG TAIL ®= 3.958" R991' 8804' ELF TT -LOGGED 03/23/86 PERFORATgN SUMMARY REF LOG: SWS-BRCS ON 02/24/86 A NGLE A T TOP PERF: 26 ~ 9508 ' Note: Refer to Production DB for hstorical perf data SQE SPF iJTERVAL Opn/Sqz DATE 3-3/8" 4 9508 - 9539 S 05/30/95 3-3/8' 12 9539 - 9560 S 05/30/95 3-3/8' 4 9555 - 9574 O 05/28/95 3-3/8" 6 9582 - 9597 O 05/28/95 ~ PBTD 9741' 7' LNR, 29#, L-80, .0371 bpf, ®= 6.184" 97$4' 9434' H MA RKER JOM DATE REV BY COMMENTS DATE REV BY COMMENTS 03/01/86 ORIGINAL COMPLETION 02/07/01 SIS-SLT CONVEIiTEDTOCANVAS 03/08/01 SIS-LG FINAL 05/19/01 RWTP CORRECTIONS 07/09/03 CMO/TLP MAX ANGLE CORRECTION PRUDHOE BAY UNfT WELL: D-27 PEFtl1AfT No: 1860330 API No: 50-029-21543-00 SEC 23, T11 N, R13E, BP Exploration (Alaska) TREE= 4" ~ WELLHEAD = D-27A ; ACTUATOR= AXELSON SAFETYN OT'ES: WARNINCz LEAKING9-5/8" PKR KB. ELEV = 71,g, Proposed CTD Sidetrack AND SEAL ASSY ~ 8690' & 8670' MKB. BF. ELEV = 42.8' KOP = 3500' Max Angle = 30 ~ 6451' Datum MD 2073' 4-1/2' OTIS SSSV NIP ID= 3 813" = 9408' Q , . Datum ND = 8800' 13-3/8" CSG, 72#, L80, ID= 12.347' 2675' ST GAS LIFT MANDRELS MD ND DEV TYPE VLV LATCH PORT 6 3002 2930 DATE 4 OTIS-LBD Rq 5 5063 4854 28 OTIS-LBD Rq 4 6460 6090 30 OTIS-LBD RA 3 7350 6889 22 OTIS-LBD Rq Minimum ID .3.725" ~ 8775' 2 , 8123 7607 8sas 7ssa 24 OTIS-LBD Rq 22 OTIS-LBD 4-1/2" OTIS XN NIPPLE R,q (CTD to mill to 3.8") 8814' 4-1/2° OTIS XA SLgWG SLV, m= 3.813' 8672' TBG SEAL ASSY 8687' 9-5/8' X 4-1/2' TNV PKR, q = 4.75" 8736' 4-1/2" OTIS X NIP, q = 3.813' TOP OF 7' LNR 87~~ TOP OF 3-3/16° LN 8750' 3.5' X tJip 2.813^ q 8755' l 8775' 4-1/2' OTIS XN NIP, ID = 3.725° 4-1/2` TBG, 12.6#, L-80, .0152 bpf, q=3.958' 8808 t0 mi to 8808' 4-1/2" TBG TA L q = 3.958` 9-5/8' CSG, 47#, L-80, ID = 8.681 " $991' 8804' ELMD TT - LOGGm 03/23/86 Top of Cement 9300' PEAFORATgNSUMMARY 9434' MARKERJOWT REF LOG: SWS-BRCS ON 02/24/86 ANGLE AT TOP PERF: 26 ~ 9508' 10 00' 3-3/16 x 2-7/8 X-over Note: Refer to Production DB for historical p ert data SQE SPF INTERVAL Opn/Sqz DATE 3-3/8' 4 9508 - 9539 isolated proposed 3-3/8' 12 9539 - 9560 isolated proposed 3-3/8` 4 9555 - 9574 isolated 3-3/8' 6 9582 - 9597 proposed 9455' Mechanical Whipstock isolated proposed 3-3/16' X PBTD 7" LNR, 29#, L-80, .0371 bpf, q = 6.184" and PRUDHOEBAY UNff WELL: D-27 PERMIT No: 1860330 API No: 50-029-21543-00 SEC 23, T11 N, R13E, BP Exploration (Alaska) • • ~, Baker Hughes INTEQ Baker Hughes INTEQ Planning Report 11th s tN`I`Et,~ __.._..___ Company: BP Amoco pate: 11/17/2005 Time:. 10:28:01 Page: 1 Field:' Prudhoe Bay '' Co-ordinste(NE) Reference: WeII: D-27; True North Site: PB D Pad Vertical (TVD) Reference: 43:27 2/13/1986 00:00 71.9 We1L• D-27 Section (VS) Reference: " Well (O.OON,O.OOE,315. OOAzi) Wellpath: Plan 5„ D-27A Survey Calculation Method: -Mi nimum Curvature Db: Oracfe Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB D Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5955590.34 ft Latitude: 70 17 8.492 N From: Map Easting: 652165.06 ft Longitude: 148 46 6.316 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.16 deg Well: D-27 Slot Name: 27 D-27 Well Position: +N/-S 3766.74 ft Northing: 5959383.80 ft Latitude: 70 17 45.537 N +E/-W 1372.47 ft Easting : 653460.93 ft Longitude: 148 45 26.312 W Position Uncertainty: 0.00 ft Wellpath: Plan 5, D-27A Drilled From: D-27 Tie-on Depth: 9454.04 ft Current Daturo: 43:27 2/13/1986 00 :00 Height 71 .90 ft Above System Datum: Mean Sea Level Magnetic Data: 11/9/2005 Declination: 24.68 deg Field Strength: 57600 nT Mag Dip Angle: 80.87 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 31.40 0.00 0.00 315.00 Plan: Plan #5 Date Composed: 11/9/2005 Plan 4 used metic dogleg, PIanS corrects this Version: 7 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <-- Latitude. --> <-- Longitude: ---> Name. Description TVD +N/-S +E/-W Northing: Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft D-27A Polygon 71.90 1675.20 -1887.27 5961020.00 651540.00 70 18 2.010 N 148 46 21.333 W -Polygon 1 71.90 1675.20 -1887.27 5961020.00 651540.00 70 18 2.010 N 148 46 21.333 W -Polygon 2 71.90 2020.48 -2875.49 5961345.00 650545.00 70 18 5.402 N 148 46 50.148 W -Polygon 3 71.90 2899.14 -3532.74 5962210.00 649870.00 70 18 14.041 N 148 47 9.322 W -Polygon 4 71.90 2972.60 -3211.15 5962290.00 650190.00 70 18 14.765 N 148 46 59.946 W -Polygon 5 71.90 2154.94 -2602.67 5961485.00 650815.00 70 18 6.726 N 148 46 42.195 W -Polygon 6 71.90 1984.65 -1855.94 5961330.00 651565.00 70 18 5.053 N 148 46 20.422 W D-27A Fault1 71.90 1691.64 -2692.16 5961020.00 650735.00 70 18 2.169 N 148 46 44.799 W -Polygon 1 71.90 1691.64 -2692.16 5961020.00 650735.00 70 18 2.169 N 148 46 44.799 W -Polygon 2 71.90 2036.29 -2670.11 5961365.00 650750.00 70 18 5.559 N 148 46 44.160 W D-27A Fault3 71.90 2132.71 -3473.37 5961445.00 649945.00 70 18 6.504 N 148 47 7.581 W -Polygon 1 71.90 2132.71 -3473.37 5961445.00 649945.00 70 18 6.504 N 148 47 7.581 W -Polygon 2 71.90 2225.76 -3131.38 5961545.00 650285.00 70 18 7.420 N 148 46 57.611 W D-27A Fault2 71.90 2242.38 -2475.85 5961575.00 650940.00 70 18 7.586 N 148 46 38.498 W -Polygon 1 71.90 2242.38 -2475.85 5961575.00 650940.00 70 18 7.586 N 148 46 38.498 W -Polygon 2 71.90 2168.60 -1802.17 5961515.00 651615.00 70 18 6.863 N 148 46 18.856 W D-27A Fault4 71.90 3116.15 -3138.20 5962435.00 650260.00 70 18 16.177 N 148 46 57.820 W -Polygon 1 71.90 3116.15 -3138.20 5962435.00 650260.00 70 18 16.177 N 148 46 57.820 W -Polygon 2 71.90 2468.37 -2521.25 5961800.00 650890.00 70 18 9.809 N 148 46 39.824 W D-27A Faults 71.90 3184.82 -3806.99 5962490.00 649590.00 70 18 16.850 N 148 47 17.323 W -Polygon 1 71.90 3184.82 -3806.99 5962490.00 649590.00 70 18 16.850 N 148 47 17.323 W -Polygon 2 71.90 3188.28 -2996.69 5962510.00 650400.00 70 18 16.887 N 148 46 53.695 W ~~ Baker Hughes INTEQ Baker Hughes INTEQ Planning Report y~r~t~________ Company:' BP Amoco Date: 11/17!2005 Time: 10:28;01 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: D-27;7rue North Site: PB D Pad Vertical (TVD) Reference: 4 3:27 2!13/1986 00:00 71.9 Well: D-27 Section (VS}Reference: WeU (O.OON,0.00E,315.OOAzi) Wellpat6: Plan 5,' D-27A Survey Calculation Method: Minimum. Curvature Db: Oracle Targets Map `Map <- Latitude -> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Eastlng Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft D-27A Target 1 9031.90 1898.1 4 -2125.78 5961238.00 651297.00 70 18 4.202 N 148 46 28.289 W D-27A Target 2 9031.90 2143.46 -2872.98 5961468.00 650545.00 70 18 6.612 N 148 46 50.076 W D-27A Target 3 9031.90 2842.98 -3329.83 5962158.00 650074.00 70 18 13.490 N 148 47 3.405 W Annotation MD TVD ft ft 9454.04 8913.77 TIP 9460.00 8919.18 KOP 9480.00 8937.20 End of 9°/100' DLS 9702.35 9040.66 End of 32°/100' DLS 9775.35 9034.22 5 9835.35 9031.56 6 9995.35 9031.59 7 10295.35 9031.64 8 10475.00 9031.66 Fault Intersect 10495.35 9031.67 9 10995.35 9031.72 10 11195.35 9031.73 f 1 11575.00 0.00 TD Plsn Section Information MD .Inc! Azim TVD +N/-S +E/-W .DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft degH00ft deg 9454.04 24.77 326.11 8913.77 1739.91 -1765.13 0.00 0.00 0.00 0.00 9460.00 24.86 326.05 8919.18 1741.99 -1766.52 1.57 1.51 -1.01 344.34 9480.00 26.50 324.35 8937.20 1749.10 -1771.47 9.00 8.21 -8.52 335.00 9702.35 95.00 298.80 9040.66 1857.00 -1916.59 32.00 30.81 -11.49 333.00 9775.35 95.09 290.00 9034.22 1887.01 -1982.75 12.00 0.13 -12.05 271.00 9835.35 89.99 284.92 9031.56 1904.97 -2039.89 12.00 -8.51 -8.47 225.00 9995.35 89.99 265.72 9031.59 1919.73 -2198.46 12.00 0.00 -12.00 270.00 10295.35 89.99 301.72 9031.64 1989.71 -2485.13 12.00 0.00 12.00 90.00 10495.35 89.99 277.72 9031.67 2056.70 -2672.03 12.00 0.00 -12.00 270.00 10995.35 90.00 337.72 9031.72 2348.80 -3049.72 12.00 0.00 12.00 90.00 11195.35 90.00 313.72 9031.73 2512.84 -3161.56 12.00 0.00 -12.00 270.00 11575.00 90.00 359.28 9031.75 2851.90 -3309.00 12.00 0.00 12.00 90.00 Survey MD Inc! Azim SS TVD N/S E/W Map1V MapE - DLS VS TFO Tool ft deg deg ft ft tt ft ft deg/100ft ft deg 9454.04 24.77 326.11 8841.87 1739.91 -1765.13 5961087.19 651660.78 0.00 2478.44 0.00 M W D 9460.00 24.86 326.05 8847.28 1741.99 -1766.52 5961089.23 651659.34 1.57 2480.89 344.34 MWD 9475.00 26.09 324.75 8860.82 1747.30 -1770.19 5961094.47 651655.57 9.00 2487.24 335.00 MWD 9480.00 26.50 324.35 8865.30 1749.10 -1771.47 5961096.24 651654.25 9.00 2489.42 336.17 MWD 9500.00 32.33 318.91 8882.72 1756.77 -1777.59 5961103.78 651647.97 32.00 2499.17 333.00 MWD 9525.00 39.83 314.19 8902.91 1767.40 -1787.74 5961114.21 651637.61 32.00 2513.87 337.74 MWD 9550.00 47.48 310.77 8920.99 1779.02 -1800.48 5961125.56 651624.64 32.00 2531.09 341.56 MWD 9575.00 55.20 308.10 8936.60 1791.39 -1815.56 5961137.62 651609.31 32.00 2550.50 344.05 MWD 9600.00 62.97 305.89 8949.43 1804.27 -1832.69 5961150.15 651591.92 32.00 2571.72 345.72 MWD 9625.00 70.78 303.97 8959.25 1817.42 -1851.53 5961162.90 651572.82 32.00 2594.34 346.86 MWD 9627.34 71.51 303.80 8960.00 1818.65 -1853.36 5961164.10 651570.96 32.00 2596.51 347.61 D-27A T 9650.00 78.60 302.22 8965.84 1830.57 -1871.72 5961175.64 651552.37 32.00 2617.91 347.67 MWD 9675.00 86.43 300.57 8969.10 1843.47 -1892.86 5961188.10 651530.97 32.00 2641.98 348.07 MWD 9700.00 94.26 298.95 8968.95 1855.87 -1914.54 5961200.05 651509.04 32.00 2666.08 348.29 MWD 9702.35 95.00 298.80 8968.76 1857.00 -1916.59 5961201.14 651506.97 32.00 2668.33 348.28 MWD C7 • ~ Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~.~ Company: BPAmow Field:. .Prudhoe Bay Date: 11/17/2005 Time: 10:28:01 Co-ordinate(NE) Reference: Well: D-27, True North Page: 3 ' Site: PB D Pad Vertical (TVD) Reference: 43:27 2113/1986 00:00 71.9 Well: 0=27 Section (VS) Reference: Well (O.OON ,O.OOE,315.OOAzi) Wellpath: Plan 5 D-27A Survey Calculation Method: Minimum Curvature Db: O raGe - Survey MD ` Incl Azim SS TVD N/S E/W MapN MapE bLS " VS TFO Tool ft deg deg ft ft „ ft ft ft ` deg/100ft ft deg 9725.00 95.04 296.07 8966.77 1867.39 -1936.62 5961211.13 651486.74 12.00 2689.84 271.00 MWD 9750.00 95.07 293.06 8964.57 1877.74 -1959.27 5961221.01 651463.88 12.00 2713.17 270.76 MWD 9775.00 95.09 290.04 8962.35 1886.89 -1982.42 5961229.68 651440.55 12.00 2736.02 270.50 MWD 9800.00 93.00 287.91 8960.58 1894.99 -2006.00 5961237.30 651416.81 11.95 2758.42 225.57 MWD 9825.00 90.87 285.79 8959.74 1902.23 -2029.91 5961244.05 651392.75 12.00 2780.45 224.85 MWD 9835.35 89.99 284.92 8959.66 1904.97 -2039.89 5961246.59 651382.72 12.00 2789.44 224.78 MWD 9850.00 89.99 283.16 8959.66 1908.53 -2054.11 5961249.85 651368.44 12.00 2802.00 270.00 MWD 9875.00 89.99 280.16 8959.67 1913.58 -2078.59 5961254.40 651343.86 12.00 2822.89 270.00 MWD 9900.00 89.99 277.16 8959.67 1917.34 -2103.30 5961257.66 651319.08 12.00 2843.02 270.00 MWD 9925.00 89.99 274.16 8959.68 1919.81 -2128.17 5961259.62 651294.16 12.00 2862.36 270.00 MWD 9950.00 89.99 271.16 8959.68 1920.97 -2153.14 5961260.27 651269.18 12.00 2880.83 270.00 MWD 9975.00 89.99 268.16 8959.69 1920.82 -2178.14 5961259.61 651244.19 12.00 2898.40 270.00 MWD 9995.35 89.99 265.72 8959.69 1919.73 -2198.46 5961258.11 651223.90 12.00 2912.00 270.00 MWD 10000.00 89.99 266.28 8959.69 1919.41 -2203.10 5961257.69 651219.27 12.00 2915.05 90.00 MWD 10025.00 89.99 269.28 8959.69 1918.44 -2228.08 5961256.21 651194.32 12.00 2932.03 90.00 MWD 10050.00 89.99 272.28 8959.70 1918.78 -2253.07 5961256.04 651169.32 12.00 2949.94 90.00 M W D 10075.00 89.99 275.28 8959.70 1920.42 -2278.02 5961257.17 651144.35 12.00 2968.74 90.00 MWD 10100.00 89.99 278.28 8959.71 1923.37 -2302.84 5961259.61 651119.48 12.00 2988.38 90.00 MWD 10125.00 89.99 281.28 8959.71 1927.62 -2327.47 5961263.35 651094.76 12.00 3008.80 90.00 MWD 10150.00 89.99 284.28 8959.72 1933.14 -2351.85 5961268.38 651070.28 12.00 3029.95 90.00 MWD. 10175.00 89.99 287.28 8959.72 1939.94 -2375.91 5961274.69 651046.09 12.00 3051.76 90.00 MWD 10200.00 89.99 290.28 8959.72 1947.99 -2399.57 5961282.25 651022.27 12.00 3074.19 90.00 MWD 10225.00 89.99 293.28 8959.73 1957.26 -2422.79 5961291.04 650998.87 12.00 3097.16 90.00 MWD 10250.00 89.99 296.28 8959.73 1967.73 -2445.48 5961301.05 650975.97 12.00 3120.62 90.00 MWD 10275.00 89.99 299.28 8959.74 1979.38 -2467.60 5961312.25 650953.62 12.00 3144.49 89.99 MWD 10295.35 89.99 301.72 8959.74 1989.71 -2485.13 5961322.21 650935.88 12.00 3164.19 89.99 MWD 10300.00 89.99 301.16 8959.74 1992.14 -2489.10 5961324.56 650931.86 12.00 3168.71 270.00 MWD 10325.00 89.99 298.16 8959.74 2004.51 -2510.82 5961336.48 650909.89 12.00 3192.82 270.00 M W D 10350.00 89.99 295.16 8959.75 2015.72 -2533.16 5961347.24 650887.33 12.00 3216.55 270.00 M W D 10375.00 89.99 292.16 8959.75 2025.75 -2556.06 5961356.80 650864.24 12.00 3239.83 270.00 MWD 10400.00 89.99 289.16 8959.75 2034.57 -2579.45 5961365.14 650840.67 12.00 3262.61 270.00 MWD 10425.00 89.99 286.16 8959.76 2042.16 -2603.27 5961372.23 650816.71 12.00 3284.81 270.00 MWD 10450.00 89.99 283.16 8959.76 2048.48 -2627.45 5961378.06 650792.40 12.00 3306.38 270.00 MWD 10475.00 89.99 280.16 8959.76 2053.53 -2651.93 5961382.61 650767.82 12.00 3327.27 270.00 MWD 10495.35 89.99 277.72 8959.77 2056.70 -2672.03 5961385.36 650747.66 12.00 3343.72 270.00 MWD 10500.00 89.99 278.28 8959.77 2057.34 -2676.64 5961385.92 650743.05 12.00 3347.43 90.00 MWD 10525.00 89.99 281.28 8959.77 2061.59 -2701.27 5961389.66 650718.33 12.00 3367.85 90.00 MWD 10550.00 89.99 284.28 8959.77 2067.11 -2725.65 5961394.68 650693.85 12.00 3389.00 90.00 M W D 10575.00 89.99 287.28 8959.78 2073.91 -2749.71 5961400.99 650669.66 12.00 3410.81 90.00 MWD 10600.00 89.99 290.28 8959.78 2081.96 -2773.37 5961408.55 650645.84 12.00 3433.24 90.00 MWD 10625.00 89.99 293.28 8959.78 2091.23 -2796.59 5961417.34 650622.44 12.00 3456.21 90.00 MWD 10650.00 89.99 296.28 8959.79 2101.71 -2819.28 5961427.35 650599.54 12.00 3479.66 90.00 MWD 10675.00 89.99 299.28 8959.79 2113.35 -2841.40 5961438.55 650577.19 12.00 3503.54 90.00 MWD 10700.00 89.99 30228 8959.79 2126.14 -2862.88 5961450.90 650555.46 12.00 3527.77 90.00 MWD 10725.00 89.99 305.28 8959.80 2140.04 -2883.65 5961464.36 650534.40 12.00 3552.29 90.00 MWD 10750.00 89.99 308.28 8959.80 2155.01 -2903.68 5961478.92 650514.08 12.00 3577.03 90.00 MWD 10775.00 89.99 311.28 8959.80 2171.00 -2922.89 5961494.51 650494.54 12.00 3601.92 90.00 MWD 10800.00 89.99 314.28 8959.80 2187.98 -2941.24 5961511.11 650475.85 12.00 3626.90 90.00 MWD 10825.00 89.99 317.28 8959.81 2205.89 -2958.67 5961528.66 650458.06 12.00 3651.90 90.00 MWD 10850.00 89.99 320.28 8959.81 2224.69 -2975.14 5961547.12 650441.21 12.00 3676.84 90.00 MWD 10875.00 89.99 323.28 8959.81 2244.33 -2990.61 5961566.44 650425.34 12.00 3701.66 89.99 MWD 10900.00 90.00 326.28 8959.81 2264.75 -3005.03 5961586.56 650410.51 12.00 3726.30 89.99 MWD ~J • Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~~ >i"N~~~~ _._.____ Company: BP Amoco Date: 11/17/2005 Timer --10:28:01 Page: 4 Field: Prudhoe Bay Co-ordinste(NE) Reference: WBIL D-27, True North Site: ' PB D Pad Vertical (TVD) Reference: 4 3:27 2/13/1986 00:00 71.9 Well: D-27 Section (V5) Reference: Well (O.OON ,O.OOE,315.OOAzi) Wetlpath: Plan 5, D-27A Survey CalculationMet6od: Minimum Curvature. Dh: Oracle Survey MD Incl Azim SS TVD N!S" E/W MapN MapE , DLS VS " ' TFO'' Tool I ft deg = deg ft ft ft ft ft deg/100ft ft deg ~~ 10925.00 90.00 329.28 8959.82 2285.90 -3018.36 5961607.43 650396.76 12.00 3750.67 89.99 MWD 10950.00 90.00 332.28 8959.82 2307.71 -3030.56 5961628.99 650384.11 12.00 3774.73 89.99 MWD 10975.00 90.00 335.28 8959.82 2330.14 -3041.61 5961651.18 650372.61 12.00 3798.40 89.99 MWD 10995.35 90.00 337.72 8959.82 2348.80 -3049.72 5961669.67 650364.11 12.00 3817.33 89.99 MWD 11000.00 90.00 337.16 8959.82 2353.09 -3051.51 5961673.93 650362.24 12.00 3821.63 270.00 MWD 11025.00 90.00 334.16 8959.82 2375.87 -3061.81 5961696.48 650351.48 12.00 3845.02 270.00 MWD 11050.00 90.00 331.16 8959.82 2398.07 -3073.29 5961718.45 650339.55 12.00 3868.84 270.00 M W D 11075.00 90.00 328.16 8959.83 2419.64 -3085.92 5961739.76 650326.48 12.00 3893.02 270.00 M W D 11100.00 90.00 325.16 8959.83 2440.53 -3099.66 5961760.35 650312.32 12.00 3917.50 270.00 MWD 11125.00 90.00 322.16 8959.83 2460.66 -3114.47 5961780.18 650297.10 12.00 3942.21 270.00 MWD 11150.00 90.00 319.16 8959.83 2479.99 -3130.32 5961799.19 650280.87 12.00 3967.09 270.00 MWD 11175.00 90.00 316.16 8959.83 2498.47 -3147.15 5961817.31 650263.66 12.00 3992.06 270.00 MWD 11195.35 90.00 313.72 8959.83 2512.84 -3161.56 5961831.39 650248.96 12.00 4012.41 270.00 MWD 11200.00 90.00 314.28 8959.83 2516.07 -3164.90 5961834.55 650245.55 12.00 4017.06 90.00 MWD 11225.00 90.00 317.28 8959.84 2533.99 -3182.34 5961852.10 650227.76 12.00 4042.05 90.00 MWD 11250.00 90.00 320.28 8959.84 2552.79 -3198.81 5961870.56 650210.91 12.00 4066.99 90.00 MWD 11275.00 90.00 323.28 8959.84 2572.43 -3214.28 5961889.88 650195.04 12.00 4091.82 90.00 MWD 11300.00 90.00 326.28 8959.84 2592.85 -3228.69 5961910.00 650180.21 12.00 4116.45 90.00 MWD 11325.00 90.00 329.28 8959.84 2613.99 -3242.02 5961930.87 .650166.46 12.00 4140.83 90.00 MWD 11350.00 90.00 332.28 8959.84 2635.81 -3254.23 5961952.43 650153.81 12.00 4164.88 90.00 MWD 11375.00 90.00 335.28 8959.84 2658.23 -3265.27 5961974.62 650142.31 12.00 4188.55 90.00 MWD 11400.00 90.00 338.28 8959.85 2681.21 -3275.13 5961997.38 650131.99 12.00 4211.77 90.00 MWD 11425.00 90.00 341.28 8959.85 2704.66 -3283.77 5962020.66 650122.87 12.00 4234.46 90.00 MWD 11450.00 90.00 344.28 8959.85 2728.54 -3291.17 5962044.37 650114.98 12.00 4256.58 90.00 M W D 11475.00 90.00 347.28 8959.85 2752.77 -3297.32 5962068.47 650108.34 12.00 4278.06 90.00 MWD 11500.00 90.00 350.28 8959.85 2777.29 -3302.18 5962092.89 650102.98 12.00 4298.83 90.00 MWD 11525.00 90.00 353.28 8959.85 2802.03 -3305.76 5962117.55 650098.90 12.00 4318.86 90.00 M W D 11550.00 /90.00 356.28 8959.85 2826.92 -3308.03 5962142.38 650096.12 12.00 4338.07 90.00 MWD 11575.00 90.00 359.28 8959.85 2851.90 -3309.00 5962167.34 650094.64 12.00 4356.42 90.00 MWD BP Amoco wn~rAnr onuu wn 0. o-x7A ~ nM+~"m, a'uaea Nari° 1 Nw. wN.. u r n an>r+sw earao 7+.oor+ v ~ ~ o i~o a+a.oo• oao em a+.ao REFERENCEINfORMATION Co-ord'nate WE) Reference: WM Centre: D-27, True NoM Vertical ( D) Reference: S stem: Mean Sea Level Sectlai (VS) Reference: Sbt - 27 (O.OON,O.OOE) Measured Depln Reference: 43:27 2/13!1986 00:00 71.90 Calculation McNod: Minimum Curvature ar-r na r-r.r 1 a MT aM a m axafs RS]! aaw leap aan ai N1m aiilnx +l lrsfada FM iR>s aaaaJa bid isa.W +l.aa MM tlMAx NO YD MMatlan xa~ •w • .w s r. vh-yn t I,yyn ow+.n oasa.a Tn -- ow7.aa oawm Nor `~'°ic owa.ao woad w r rner ato aaw.ie vioa.as w w aa•nor eu "~ aaw.w aoas.as • °n.'..'OMO., i saeo aaw.w oaos.as 7 o- .moo x«zw .mau row aaw.7a +ono.as o ooao.7a +w7e.ao ra.rn rne.r.we aow.n +wos.a osw.ax +oow.as +o ww.aa+roa.aa ++ a+.ao ++naw m 8550 8600 I 8650 8700 ~I !~`' n C 8750 I N 8800 ', ,--, nR ~ 6850 KOP Qr En< ~ 8900 ~o_ ~ 8950 t7 ~ 9000 ~ 9050 I F 9100 ~~! ~ I 9150 9200 ' - i 9250 ~ i 9300 j . West(-)/East(+) [100ft/in] LEGENO T AzimllthS t0 TfVe North po"~ ~" ~ (0.27/Ran 5, D27A) r~.r o-r a27 M Magnetic North: 24.68° croated ey air MiMaelson Dace: 1 vl7noos - aw ~. a~7A BAKER %an45 s _-. ___ __. _ HU6NEg by Magnetic Field (c,nlort in!ormaoon Strength: 57600nT - ~u Michaelson 'L(„t Dip Angle: 80.87° Dared (907) 267E624 Date. 11/9/2005 Ceu (907)301-73570 Model: bggm2005 E-mal~. bin.michaelson~intepcom AM • Vertical Section at 315.00° [50ft/in] • • TERRIE L RUBBLE s si,252 241 BP EXPLORATION AK INC ~~Mastercard Check' PO BOX 1..9.6.61.2 MB T-5 - ANCHORAGE, AK 99519-6612 I ~ _~a,O DATE PAY TO .THE ~ /}. .ORDER OF `~~ ~ RS First National Bank Alaska Anchorage„ AK 99501 MEMO ~ ~ ~~~ T ~:i25200060~:99L4~~~622?~~~i556~~' 024 • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/pARAGR.APHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~~lil ~~~7L ~ PTD# Z~S''/ " " CHECK WHAT i CLUE ADD-ONS I APPLIES (OPTIONS) ment of ~ e se llb ~ g or MULTI The permit is for a new we ~ ~ LATERAL existing well , Permit No, API No. ~ ~ i (If API number ~ Production should continue to be reported as , last two (2) digits ~ a function of .the original API number stated i are between 60-69) !above. j I ~ I PILOT HOLE In accordance with 20 AAC 25.005(f), all , ~ (per ;records, data and logs acquired for the pilot j hole must be clearly differentiated in both PH j i ) ;name (name on permit plus ~ I and API number (50 j , 70/80) from records, data and togs acquired ~ ~ , I for well (name on permit). i ~ t to full b d ~ , jec su SPACING ~ The permit is approve EXCEPTION compliance with 20 AAC 25.055. Approval to i ent contin t i /i f g s ec n perforate and produce ~ I upon issuance of a conservation order exception. in ' ~~ g ; approving a spac '~, (Company Name) assumes ~, i I the liability of any protest to the spacing exception that may occur. I 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 j j 10' sample intervals through target zones. , ; Rev: 04/01/OS C\jody\transm ittal_checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOEOlL-640150 _Well Name: PRUDHOE BAY UNIT D-27A __ Program DEV Well bore seg ^ PTD#:2051930 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV! 1-OIL GeoArea 890 Unit t 1650 On/off Shore On Annular Disposal ^ Administration 1 PeCmitfeeattached___ ____________________--_-_- __Yes- 2 Lease numberappropriate____________________ __________ ___,__,-_Yes_..- ____ 3 Uniquewell_nameandnumber- -- --- - - ----- ---- - -Yes --- - -- ------- ~- ----- -- 4 Well located in_a-defnedpool- - , _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - - 5 Well located proper distance_from drilling unit_boundary_ - - _ - . _ - - - Yes - - 6 Well located pr_operdisiancefromotherwells____________________ _-----_--Yes__- __.--,_ 7 Sufficient acreageavail_ablein_d_ril_lingunit-___________ _________ ________Yes-___ ________-__________.__--__--_- 8 If deviated,is,wellboreplat_inclu_ded__________________________ _____ ___Yes-___ ____ - - 9 Operator only affected party, _ _ _ _ _ _ _ .Yes _ _ _ _ _ . - - . _ 10 Operator has.appropriate_bondinforcfl- -------- -- .._ -- -- -- Yes.- -- -- --------- -- ------ ----- -- --------- - -------- - - 11 Permit_can. be issued without conservation order___________________ _________Yes____ __,-.-__________----_________,..----_--__----_ Appr Date 12 Permitcanbeissuedwithoutadministrative_approval________________ ________Yes--_ -..______-____-_______ RPC 11128/2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and-strata authorized by-Injection Order# (put1O# in_comments)_(For_ NA_ _ _ - - - . . - _ - , - - -- , 15 All wellswithin 1/4.mile area of review identified (For service well only)_ . _ _ - _ _ _ _ _ _ - _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 16 Pre-produced injector:. duration of pre Production Less than_ 3 months_(For service well only) NA_ - - _ _ ACMP_Finding of Consistency_has been issued_forthis protect_ _ NA_ ------------------------------------------------------- Engineering i 18 Conductor string_p_rovided----------------------- ------- --------- NA----- -- - ---- --,---.----------_------------------ - -- 19 Surfacecasing_protect&allknownUSDWS____________________- -_--____-NA__- _-.--.,_________.--_________--.-_-,_ - -- 20 CMT_vol.adeguate_to circulate-on conductor_& surf_csg NA_ _ - - --- - 21 CMT.voladeguate_totie-in long string to surfcsg___________------ -- ------ NA__--- _-__________________---_ 22 CMT-willcoverallknown_productiyehorizon_s_-__---____________ _________Yes____ ___Adeguateexcess,______-_-_______--_-_. 23 CasingdesynsadequateforC,.T,6&_permafrost____--__--__.__ .._.._--_Yes____ _______ ___________________-_-,_--- - -- 24 Adequatetankage_o_rreseryepit___ ________________________ _____-._Yes__ __CTDII..___ ------------------------------------------------------- 25 If a_re-drill, has-a-10-403 for abandonment been approved Yes _ _ , 1112312005. _ _ _ - . 26 Adequatewellboreseperation-proposed_______________________ _________Yes____ ___....-,_________,.____-____-_ X 27 If_diverter required, does it rneet. regulations_ -- NA- _ _ - - ------- _ Sidetrack. _ - _ _ . --------------------- Appr Date 1 28 DriUingfluid_programschematic_&equiplistadequate________________ _________Yes__._ ---------------------------------- ___fvlaxMW-8,6RP9~---------_-------__-_.________.....___-__-_-..-_--_ WGA 11128!2005 29 _B_OPEs,_dotheymeetregulation________________________-- --____---Yes___- ----____ 30 BOPS-press rating appropriate; test to_(pu_t psig i_n comments). - . - - - - Yes _ Test to 3500 psi. _MSP 2280 psi.- , 31 Choke_manifoldcompliesw/APIRP-53(May84)____________ ______ _-_.____Yes___, --_--____________--______-___---,.._ ----------------------------------- 32 Work willocc_urwithoutoperationshutdown_______________ ___ __ ____,_--Yes___ ______________-_.-_______.-_--__,__ 33 Is presence of H2S gasprobable.. - - - - Yes . - - 50 ppm-on_pad. - - - 34 Mechanicalcontl_itionofwellswithinAORyerified(Fo[se[vicewell only)_____ .--__-___N_A_____ ____________________________________ -------------------------------- -- Geology 35 Permit_canbeissuedwlohydrogen_sulfidemeasur-es_.__.____ ____ -_-_-_____N_o_,__ -- - ______________________________________ _ ____ -------------------------- 36 Data_presentedonpotentialoyerpressur_ezones_______ -______ __ _________ NA--___ _____________________--- -___ Appr Date 37 Seismic anah/sis_of shallow gas_zones_ _ _ _ - _ _ - - _ _ _ _ _ _ _ . _ _ . _ NA_ _ - - - _ - . - - RPC 11!28/2005 38 Seabed conditionsurvey_(ifoff_-shore)______________ .__ ___ NA_____ - - __---- - - 39 Contact namelphone for weekly-progress reports [exploratory only] - .. _ NA_ - - Geologic Engineering Commissioner: Date: Commissioner: Date i ner Date • • Well History File APPENDIX Information of detailed nature that is not particularly germane io the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify t'inding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made io chronologically organize this category of information. w Sperry-Sun Dri~ ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Feb 14 09:03:29 2006 Reel Header Service name .............LISTPE Date .....................06/02/14 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/02/14 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER OPERATOR WITNESS SURFACE LOCATION SECTION: TOWNSHIP: Scientific Technical Services Scientific Technical Services D-27A 50029215430100 BP Exploration (Alaska) Inc. Sperry Drilling Services 14-FEB-06 MWD RUN 1 MWD RUN 2 MWD RUN 3 MW0004113773 MW0004113773 MW0004113773 S. LATZ S. LATZ S. LATZ R. BORDES/D. R. BORDES/D. R. BORDES/D. MWD RUN 4 MWD RUN 5 MWD RUN 6 MW0004113773 MW0004113773 MW0004113773 S. LATZ S. LATZ S. LATZ R. BORDES/D. R. BORDES/D. R. BORDES/D. MWD RUN 8 MWD RUN 9 MWD RUN 10 MW0004113773 MW0004113773 MW0004113773 S, LATZ S. LATZ S. LATZ R. BORDES/D. R. BORDES/D. R, BORDES/D. MWD RUN 11 MAD RUN 11 MW0004113773 MW0004113773 S. LATZ S. LATZ R. BORDES/D. R. BORDES/D. 23 11N ~ 0~ -(4 3 y. 1 RANGE: 13E FNL: 1606 FSL: FEL: 1692 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 71.90 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 4.125 7.000 9459.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD) . 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS). 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 9459'MD IN THE ORIGINAL D-27 WELLBORE. 4. MWD RUNS 1,4,6,8 COMPRISED DIRECTIONAL AND NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. MWD RUNS 9 and 10 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUNS 2,3,5,11 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (GM) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) NO DATA WERE ACQUIRED ON MWD RUN 7. MAD PASS DATA WERE ACQUIRED OVER THE RUN 1 AND RUN 4 INTERVALS, WHILE RIH FOR RUNS 2 AND 5, RESPECTIVELY. THESE MAD DATA WERE MERGED WITH THE RUN 2 AND RUN 5 MWD DATA. ADDITIONALLY, MAD PASS DATA WERE ACQUIRED OVER THE ENTIRE OPENHOLE INTERVAL WHILE POOH AFTER REACHING FINAL TD. THESE MAD DATA ARE PRESENTED SEPARATELY. 5. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY RUN IN THE D-27A WELLBORE ON 4 JANUARY 2006. THESE LOG DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 1 FEBRUARY 2006. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES 6. MWD RUNS 1-6,8-11 REPRESENT WELL D-27A WITH API#: 50-029-21543-O1. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11626'MD/8942'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. BRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. SGRC = SMOOTHE AMMA RAY COMBINED. SGRD = SMOOTHED NATURAL GAMMA RAY. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9098.0 11566.5 RPM 9453.0 11580.0 FET 9453.0 11580.0 RPS 9453.0 11580.0 RPD 9453.0 11580.0 RPX 9453.0 11580.0 ROP 9488.5 11612.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 9098.0 9097.5 9100.5 9100.0 9103.5 9102.5 9106.0 9105.5 9108.5 9107.5 9112.0 9111.0 9116.0 9115.5 9120.0 9118.5 9130.0 9129.0 9131,0 9130.5 9136.0 9135.0 9139.0 9138.0 9142.5 9142.0 9150.0 9148.0 9153.5 9152.0 9161.5 9159.5 9163.0 9161.0 9466,0 9468.5 9468,5 9471.5 9491.0 9490.5 9501.0 9501.0 9504.0 9504.5 r 9514.0 9514.0 9518.0 9518.5 9520.5 9521.5 9550.0 9550.5 9557.5 9557.5 9559.0 9559.0 9561.5 9561.0 9592.0 9592.5 9598.0 9598.5 9660.0 9664.0 9688.0 9690.5 9703.5 9707.0 9745.5 9753.5 9760.0 9767.5 9761.0 9769.0 9777.0 9784.0 9836.0 9841.0 9860.5 9870.0 9945.0 9956.0 9965.5 9974.5 9987.5 9997.0 9998.5 10007.5 10013.5 10023.0 10025.0 10033.5 10083.5 10092.0 10241.0 10247.5 10267.5 10273.0 10271.5 10278.0 10604.5 10614.5 10783.0 10792.5 10854.5 10866.0 10865.0 10877.5 10875.0 10888.5 10924.5 10939.0 10999.5 11019.0 11107.5 11131.0 11193.5 11220.0 11199.5 11225.5 11247.0 11274.0 11264.5 11293.5 11271.5 11301.0 11288.0 11317.5 11310.5 11337.0 11319.0 11344.0 11356.0 11381.0 11371.5 11395.5 11400.5 11425.5 11408.5 11431.0 11412.0 11433.0 11451.0 11463.0 11496.0 11513.0 11500.0 11516.0 11506.0 11523.0 11534.0 11550.0 11535.5 11551.0 11536.5 11553.0 11539.5 11556.0 11562.0 11576.5 11612.0 11626.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MWD 1 9097.5 MWD 2 9455.5 MWD 3 9930.5 MWD 4 10381.0 MWD 5 10394.0 MERGE BASE 9718.0 9975.0 10425.0 10580.0 10602.0 r MWD 6 10571.5 10961.0 MWD 8 10931.0 11040.0 MWD 9 11009.0 11163.0 MWD 10 11135.5 11529.0 MWD 11 9434.5 11630.0 REMARKS: MERGED MAIN PASS. s Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9098 11612 10355 5029 9098 11612 RPD MWD OHMM 0.07 2000 21.4207 2411 9453 11580 RPM MWD OHMM 0.13 1914.18 16.4471 2411 9453 11580 RPS MWD OHMM 0.19 2000 15.008 2411 9453 11580 RPX MWD OHMM 0.13 1893.56 8.91437 2411 9453 11580 FET MWD HOUR 0.13 26.7 5.84794 2411 9453 11580 GR MWD API 12.63 365.62 31.7311 4359 9098 11566.5 ROP MWD FT/H 0.08 3927.1 110.268 4248 9488.5 11612 First Reading For Entire File..........9098 Last Reading For Entire File...........11612 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name.., Version Number...........1.0.0 Date of Generation.......06/02/14 c Maximum Physical Record.. 35 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 9432.5 FET 9446.5 RPX 9446.5 RPS 9446.5 RPM 9446.5 RPD 9446.5 RAT 9478.0 all MAD runs merged using earliest passes. STOP DEPTH 11571.5 11585.0 11585.0 11585.0 11585.0 11585.0 11616.0 MERGED DATA SOURCE PBU TOOL CODE MAD RUN N0. MAD PASS NO. MERGE TOP MERGE BASE MWD 11 1 9434.5 11630.0 REMARKS: MERGED MAD PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT~H 4 1 68 4 2 GR MAD API 4 1 68 8 3 FET MAD HOUR 4 1 68 12 4 RPX MAD OHMM 4 1 68 16 5 RPS MAD OHMM 4 1 68 20 6 RPM MAD OHMM 4 1 68 24 7 RPD MAD OHMM 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9432.5 11616 10524.3 4368 9432.5 11616 RAT MAD FT/H 19 1189 883.126 4277 9478 11616 GR MAD API 8.41 366.73 29.5052 4279 9432.5 11571.5 FET MAD HOUR 0.28 139.46 74.4823 4278 9446.5 11585 RPX MAD OHMM 0.12 1737.91 6.94881 4278 9446.5 11585 RPS MAD OHMM 0.11 2000 8.92685 4278 9446.5 11585 RPM MAD OHMM 0.1 1877.77 8.56048 4278 9446.5 11585 RPD MAD OHMM 0.07 2000 13.7154 4278 9446.5 11585 First Reading For Entire File..........9432.5 Last Reading For Entire File...........11616 ~ • File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9097.5 9687.0 ROP 9488.5 9718.0 LOG HEADER DATA DATE LOGGED: 28-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9718.0 TOP LOG INTERVAL (FT) 9488.0 BOTTOM LOG INTERVAL (FT) 9718.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 24.8 MAXIMUM ANGLE: 81.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray 015 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT) 8808.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G) 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 19000 FLUID LOSS (C3) 5.8 s RESISTIVITY (OHMM) AT PERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 146.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MWDO10 FT/H 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9097.5 9718 9407.75 1242 GR MWDO10 API 17.87 365.62 41.2437 592 ROP MWDO10 FT/H 0.17 149.7 69.0777 460 First Reading 9097.5 9097.5 9488.5 Last Reading 9718 9687 9718 First Reading For Entire File..........9097.5 Last Reading For Entire File...........9718 File Trailer Service name .............STSLIB.003 Service Sub Level Name.... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 • • Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 9455.5 9943.5 RPM 9455.5 9943.5 RPS 9455.5 9943.5 FET 9455.5 9943.5 RPX 9455.5 9943.5 GR 9687.5 9930.0 ROP 9718.5 9975.0 LOG HEADER DATA DATE LOGGED: 29-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9975.0 TOP LOG INTERVAL (FT) 9718.0 BOTTOM LOG INTERVAL (FT) 9975.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 91.2 MAXIMUM ANGLE: 100.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 82758 EWR4 ELECTROMAG. RESIS. 4 178425 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 4.125 DRILLER'S CASING DEPTH (FT) 8808.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G) 8.60 MUD VISCOSITY (S) 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3) 5.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .090 65.0 MUD AT MAX CIRCULATING TERMPERATURE: .040 149.0 MUD FILTRATE AT MT: x150 65.0 MUD CAKE AT MT: .080 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: S Data Format Specification Rec'~rd • Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9455.5 9975 9715.25 1040 9455.5 9975 RPD MWD020 OHMM 0.07 2000 42.9792 977 9455.5 9943.5 RPM MWD020 OHMM 0.13 1914.18 29.6362 977 9455.5 9943.5 RPS MWD020 OHMM 0.19 2000 26.8497 977 9455.5 9943.5 RPX MWD020 OHMM 0.13 1893.56 12.2511 977 9455.5 9943.5 FET MWD020 HOUR 0.23 18.36 6.96745 977 9455.5 9943.5 GR MWD020 API 17.15 39.54 25.1364 486 9687.5 9930 ROP MWD020 FT/H 30.15 289.06 126.118 514 9718.5 9975 First Reading For Entire File..........9455.5 Last Reading For Entire File...........9975 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9930.5 10380.5 RPM 9944.0 10393.5 FET 9944.0 10393.5 RPD 9944.0 10393.5 RPX 9944.0 10393.5 RPS 9944.0 10393.5 ROP 9975.5 10425.0 LOG HEADER DATA DATE LOGGED: 29-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10425.0 TOP LOG INTERVAL (FT) 9975.0 BOTTOM LOG INTERVAL (FT) 10425.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.9 MAXIMUM ANGLE: 94.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 82758 EWR4 ELECTROMAG. RESIS. 4 178425 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 4.125 DRILLER'S CASING DEPTH (FT) 8808.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LBfG) MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Flo Pro 8.70 65.0 9.0 26000 5.8 .200 70.0 .100 155.0 .170 70.0 .150 70.0 Max frames per record .............Undefined S Absent value ... ............... ....-999 Depth Units .... ................... Datum Specifica tion Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9930.5 10425 10177.8 990 9930.5 10425 RPD MWD030 OHMM 3.93 14.93 8.64189 900 9944 10393.5 RPM MWD030 OHMM 3.62 14.58 8.371 900 9944 10393.5 RPS MWD030 OHMM 3.52 13.17 7.8526 900 9944 10393.5 RPX MWD030 OHMM 3.4 12.76 7.38467 900 9944 10393.5 FET MWD030 HOUR 0.18 8.57 1.12883 900 9944 10393.5 GR MWD030 API 15.9 38.01 24.7355 901 9930.5 10380.5 ROP MWD030 FT/H 1.2 932.58 109.281 900 9975.5 10425 First Reading For Entire File..........9930.5 Last Reading For Entire File...........10425 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02j14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10381.0 ROP 10425.5 header data for each bit run in separate files. 4 .5000 STOP DEPTH 10549.0 10580.0 ` u ~ t • • 1'F LOG HEADER DATA DATE LOGGED: 30-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10580.0 TOP LOG INTERVAL (FT) 10425.0 BOTTOM LOG INTERVAL (FT) 10580.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.6 MAXIMUM ANGLE: 92.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray 015 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 4.125 DRILLER'S CASING DEPTH (FT) 8808.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G) 8.70 MUD VISCOSITY (S) 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3) 5.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 159.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD040 API 4 1 68 4 2 ROP MWD040 FTjH 4 1 68 8 3 First Last Name Service Unit DEPT FT GR MWD040 API ROP MWD040 FT/H Min • Max 10381 10580 18.31 31.48 0.08 2142.22 First Reading For Entire File..........10381 Last Reading For Entire File...........10580 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF File Header Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.006 Mean Nsam ding 10480.5 399 10381 24.0085 337 10381 82.5628 310 10425.5 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 10394.0 10569.5 FET 10394.0 10569.5 RPS 10394.0 10569.5 RPX 10394.0 10569.5 RPD 10394.0 10569.5 GR 10549.5 10571.0 ROP 10580.5 10602.0 LOG HEADER DATA DATE LOGGED: 30-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10602.0 TOP LOG INTERVAL (FT) 10580.0 BOTTOM LOG INTERVAL (FT) 10602.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 94.8 MAXIMUM ANGLE: 94.8 TOOL STRING (TOP TO BOTTOM} VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 82758 Reading 10580 10549 10580 ~ EWR4 ELEC MAG. RESIS. 4 178425 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 4.125 DRILLER'S CASING DEPTH (FT) 8808.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G) 8.60 MUD VISCOSITY (S) 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3) 6.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF ) MUD AT MEASURED TEMPERATURE (MT) .200 65.0 MUD AT MAX CIRCULATING TERMPERATURE: .090 155.0 MUD FILTRATE AT MT: .170 65.0 MUD CAKE AT MT: .150 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ................ ..0 Data Specification Block Type... ..0 Logging Direction ............... ..Down Optical log depth units......... ..Feet Data Reference Point ............ ..Undefined Frame Spacing ................... ..60 .lIN Max frames per record ........... ..Undefined Absent value .................... ..-999 Depth Units ..................... .. Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10394 10602 10498 417 10394 10602 RPD MWD050 OHMM 4.04 16.86 5.78429 352 10394 10569.5 RPM MWD050 OHMM 3.46 18.95 5.41531 352 10394 10569.5 RPS MWD050 OHMM 3.31 18.49 5.07966 352 10394 10569.5 RPX MWD050 OHMM 2.99 18 4.55482 352 10394 10569.5 FET MWD050 HOUR 12.1 26.7 16.3431 352 10394 10569.5 GR MWD050 API 25.89 33.87 30.1334 44 10549.5 10571 ROP MWD050 FT/H 0.16 61.33 33.8136 44 10580.5 10602 First Reading For Entire File..........10394 Last Reading For Entire File...........10602 File Trailer Service name .............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF File Header Service name .............STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10571.5 10930.5 ROP 10602.5 10961.0 LOG HEADER DATA DATE LOGGED: 31-DEC-05 SOFTWARE 5URFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10961.0 TOP LOG INTERVAL (FT) 10602.0 BOTTOM LOG INTERVAL (FT): 10961.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.3 MAXIMUM ANGLE: 95.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG015 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 4.125 DRILLER'S CASING DEPTH (FT) 8808.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G) 8.70 MUD VISCOSITY (S): 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 24000 • • FLUID LOSS (C3) 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 167.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD060 API 4 1 68 4 2 ROP MWD060 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10571.5 10961 10766.3 780 10571.5 10961 GR MWD060 API 19.46 69.97 31.9639 719 10571.5 10930.5 ROP MWD060 FT/H 1.6 612.43 100.49 718 10602.5 10961 First Reading For Entire File..........10571.5 Last Reading For Entire File...........10961 File Trailer Service name .............STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.009 Physical EOF File Header Service name .............STSLIB.009 Service Sub Level Name... Version Number.,.........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......~LIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10931.0 11008.5 ROP 10961.5 11040.0 LOG HEADER DATA DATE LOGGED: O1-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.75 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11040.0 TOP LOG INTERVAL (FT) 10961.0 BOTTOM LOG INTERVAL (FT) 11040.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.2 MAXIMUM ANGLE: 95.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG015 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 4.125 DRILLER'S CASING DEPTH (FT) 8808.0 BOREHOLE CONDITIONS MUD TYPE: Flow Pro MUD DENSITY (LB/G) 8.70 MUD VISCOSITY (S) 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3) 5.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 167.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): $# REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point.....~......Undefined • Frame Spacing .. ............... ....60 .lIN Max frames per record ......... ....Undefined Absent value ... ............... ....-999 Depth Units .... ............... .... Datum Specifica tion Block sub- type...0 Name Service Order Units Size Ns am Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD080 API 4 1 68 4 2 ROP MWD080 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10931 11040 10985.5 219 10931 11040 GR MWD080 API 24.2 39.49 31.1643 156 10931 11008.5 ROP MWD080 FT/H 0.65 143.03 86.0059 158 10961.5 11040 First Reading For Entire File..........10931 Last Reading For Entire File...........11040 File Trailer Service name .............STSLIB.009 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.010 Physical EOF File Header Service name .............STSLIB.010 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11009.0 11135.0 ROP 11040.5 11163.0 LOG HEADER DATA DATE LOGGED: O1-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11163.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LBjG): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS ( C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (TN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 11040.0 11163.0 84.3 88.9 TOOL NUMBER 72829 4.125 8808.0 Flo Pro 8.60 64000.0 9.0 24000 5.8 .000 .0 .000 169.0 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD090 API 4 1 68 4 2 ROP MWD090 FT/H 4 1 68 8 3 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 11009 11163 11086 309 11009 GR MWD090 API 26.04 44.31 36.2627 253 11009 ROP MWD090 FT/H 2.04 123.88 66.2937 246 11040.5 Last Reading 11163 11135 11163 First Reading For Entire File..........11009 Last Reading For Entire File...........11163 ! !' / • ~ File Trailer Service name .............STSLIB.010 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.011 Physical EOF File Header Service name .............STSLIB.011 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11135.5 11502.0 ROP 11163.5 11529.0 LOG HEADER DATA DATE LOGGED: 02-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11529.0 TOP LOG INTERVAL (FT) 11163.0 BOTTOM LOG INTERVAL (FT) 11529.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 81.2 MAXIMUM ANGLE: 96.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 72829 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 8808.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): 6.2 ' ' r RESISTIVITY (OHMM) AT ~PERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 170.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD100 API 4 1 68 4 2 ROP MWD100 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11135.5 11529 11332.3 788 11135.5 11529 GR MWD100 API 21.69 64.34 38.7844 734 11135.5 11502 ROP MWD100 FT/H 0.52 3 927.1 162.255 732 11163.5 11529 First Reading For Entire File..........11135.5 Last Reading For Entire File...........11529 File Trailer Service name .............STSLIB.011 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.012 Physical EOF File Header Service name .............STSLIB.012 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.011 ~ ~ • Comment Record FILE HEADER FILE NUMBER: 12 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 11498.0 11594.5 FET 11498.0 11594.5 RPD 11498.0 11594.5 RPX 11498.0 11594.5 RPM 11498.0 11594.5 GR 11502.5 11581.0 ROP 11529.5 11626.0 LOG HEADER DATA DATE LOGGED: 02-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE .(MEMORY OR REAL-TIME): Memory TD DRILLER (FT} 11626.0 TOP LOG INTERVAL (FT) 11529.0 BOTTOM LOG INTERVAL (FT) 11626.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 90.3 MAXIMUM ANGLE: 91.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 78005 EWR4 ELECTROMAG. RESIS. 4 178425 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN}: EWR FREQUENCY (HZ): REMARKS: 4.125 8808.0 Flo Pro 8.60 65.0 9.0 23000 6.2 .170 69.0 .070 165.0 .140 69.0 .200 69.0 f (` ~ • Data Format Specification Red Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD110 OHMM 4 1 68 4 2 RPM MWD110 OHMM 4 1 68 8 3 RPS MWD110 OHMM 4 1 68 12 4 RPX MWD110 OHMM 4 1 68 16 5 FET MWD110 HOUR 4 1 68 20 6 GR MWD110 API 4 1 68 24 7 ROP MWD110 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11498 11626 11562 257 11498 11626 RPD MWD110 OHMM 6.62 14.79 9.30134 194 11498 11594.5 RPM MWD110 OHMM 4.17 17.57 8.66186 194 11498 11594.5 RPS MWD110 OHMM 3.54 17.14 8.24845 194 11498 11594.5 RPX MWD110 OHMM 2.95 15.71 7.56572 194 11498 11594.5 FET MWD110 HOUR 0.13 8.32 3.0949 194 11498 11594.5 GR MWD110 API 12.63 57.24 32.3011 158 11502.5 11581 ROP MWD110 FT/H 42.78 424.99 166.171 194 11529.5 11626 First Reading For Entire File..........11498 Last Reading For Entire File...........11626 File Trailer Service name .............STSLIB.012 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.013 Physical EOF File Header Service name .............STSLIB.013 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.012 Comment Record FILE HEADER FILE NUMBER: 13 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 ~ C S • • MAD RUN NUMBER: 11 MAD PASS NUMBER: 1 FIL E SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9434.5 11586.0 RPD 9448.5 11599.5 FET 9448.5 11599.5 RPM 9448.5 11599.5 RPS 9448.5 11599.5 RPX 9448.5 11599.5 RAT 9479.5 11630.0 LOG HEADER DATA DATE LOGGED: 02-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11625.0 TOP LOG INTERVAL (FT) 9486.0 BOTTOM LOG INTERVAL (FT) 11625.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 90.3 MAXIMUM ANGLE: 91.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 78005 EWR4 ELECTROMAG. RESIS. 4 178425 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 4.125 DRILLER'S CASING DEPTH (FT) 8808.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G) 8.60 MUD VISCOSITY (S) 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3): 6.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .170 69.0 MUD AT MAX CIRCULATING TERMPERATURE: .070 165.0 MUD FILTRATE AT MT: .140 69.0 MUD CAKE AT MT: .200 69.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type....,0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined ,~ M Frame Spacing............•......60 .lIN • Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD111 FT/H 4 1 68 4 2 GR MAD111 API 4 1 68 8 3 FET MAD111 HOUR 4 1 68 12 4 RPX MAD111 OHMM 4 1 68 16 5 RPS MAD111 OHMM 4 1 68 20 6 RPM MAD111 OHMM 4 1 68 24 7 RPD MAD111 OHMM 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9434.5 11630 10532.3 4392 9434.5 11630 RAT MAD111 FT/H 19 1189 883.331 4302 9479.5 11630 GR MAD111 API 8.41 366.73 29.5505 4304 9434.5 11586 FET MAD111 HOUR 0.28 139.46 74.7275 4303 9448.5 11599.5 RPX MAD111 OHMM 0.12 1737.91 6.89765 4303 9448.5 11599.5 RPS MAD111 OHMM 0.11 2000 8.86464 4303 9448.5 11599,5 RPM MAD111 OHMM 0.1 1877.77 8.50026 4303 9448.5 11599.5 RPD MAD111 OHMM 0.07 2000 13.6566 4303 9448.5 11599.5 First Reading For Entire File..........9434.5 Last Reading For Entire File...........11630 File Trailer Service name .............STSLIB.013 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/02/14 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.014 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06f02/14 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................06/02/14 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Scientific Technical Services Scientific Technical Services Physical EOF ~, ~ ,+ M Physical EOF End Of LIS File