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206-089
Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:206-089 6.50-029-22208-02-00 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 13655 12200 8731 11030 none none 7760 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 30 - 110 30 - 110 1490 470 Surface 3860 10-3/4" 30 - 3890 30 - 3511 3580 2090 Intermediate 4091 7-5/8" 28 - 4119 28 - 3698 6890 4790 Liner 7699 5-1/2" 3957 - 11656 3566 - 8303 7740 6280 Perforation Depth: Measured depth: 11631 - 13615 feet True vertical depth:8281 - 8775 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# x 3-1/2" 9.3# 13C 26 - 3392 26 - 3108 11030 7760Packers and SSSV (type, measured and true vertical depth) 3-1/2" HES TNT Liner 2402 11253 - 13655 7956 - 8774 13450 13890 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 910-750188946 45021998 -750 28109 1583 813 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: David Bjork David.Bjork@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564 - 4672 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8774 Sundry Number or N/A if C.O. Exempt: 321-238 No SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 Tubing Swap 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 Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028321, ADL 0028326 PBU 05-28B 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 3-1/2" x 3-3/16" x 2-7/8" By Meredith Guhl at 2:10 pm, Jul 26, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.07.26 13:51:12 -08'00' Bo York DSR-7/26/21 RBDMS HEW 7/26/2021 SFD 7/28/2021MGR30JUL2021 ACTIVITYDATE SUMMARY 5/22/2021 ***WELL S/I ON ARRIVAL*** (pre rwo) PULLED 45kb UPPER & 35kb LOWER PATCH SECTIONS FROM 2,972' MD. EQUALIZED & PULLED 1.78" RX-PLUG FROM 11,137' MD. PULLED 2.813" x 1.78" NIP-REDUCER FROM 11,137' MD. BRUSHED 11,050' - 11,150' SLM. SET 2.813" PX-PLUG BODY IN X-NIP @ 11,137' MD. ***WSR CONTINUED ON 5/23/21*** 5/23/2021 T/I/O= 580/460/50 Temp= SI. LRS unit 72 CMIT-TxIA (RWO EXPENSE) CMIT-TxIA to 3000 psi *PASSED* at 3199 psi (3250 psi max applied pressure) TxIA lost 35 psi during the first 15 minutes. T/IA lost 18 psi during the second 15 minutes. Pumped 14.9 bbls of 48* F crude to achieve test pressure. Bled back 10.9 bbls to final T/I/O= 497/491/50. 5/23/2021 ***WSR CONTINUED FROM 5/22/21*** (pre rwo) SET PRONG IN 2.813" PX-PLUG BODY @ 11,137' MD. ***JOB COMPLETE, WELL LEFT S/I*** 5/24/2021 ***WELL SHUT IN ON ARRIVAL*** JOB SCOPE: TBG PUNCH, CIRC-OUT, CHEM CUT - PRE RWO TBG PUNCH TBG @ 11065' - 11068' ( Below the top of the 120th joint below Sta#1). GOOD TxIA PRESSURE RESPONSE. FULLBORE TESTED TxIA - GOOD TEST. FULLBORE PERFORMED TxIA CIRC- OUT. CHEM CUT TBG @ 11,102'. NO PRESSURE RESPONSE FROM TBG OR IA. GOOD WEIGHT INDICATION. ALL TOOLS RECOVERED. FULLBORE CMIT FAILED BUT WILL TRY AGAIN AFTER WELL SITS OVER NIGHT. CORRELATED TO TBG TALLY 8/27/2007. ***JOB COMPLETE*** 5/24/2021 T/I/O= 650/300/50 Assist E-line (Pre-RWO) Pumped 5.5 bbls diesel to pressure up tubing and IA. Combo pressure test TxIA to 1000 psi PASS (post tubing punch) Circ- out down tubing, up IA, taking returns to 05-01 flowline: Pumped 10 bbl 35* diesel to confirm TxIA communication. Pumped a 5 bbl 50/50 methanol spacer followed by 340 bbls 135* 2% SKL400 and 105 bbls 35* diesel. U-tube tubing and IA freeze protect for 1 hour. Pumped a total of 1.5 bbls diesel in attempt to Combo pressure test tubing IA to1000 psi (Post Chem cut) FAILED (See log). Will retest in the morning when well stabilizes. E-line in control of well upon departure. ***Job continues on 5/25/2021 WSR*** 5/25/2021 T/I/O= 0/0/0 Pressure Test TxIA (Pre-RWO) Pumped 0.8 BBL's of 35* DSL down the tubing and IA to achieve test pressure. CMIT-TxIA to 1010 psi ***PASSED***. T/IA lost 40/30 psi in 1st 15 minutes, and 10/10 psi in the 2nd 15 minutes. Total T/IA pressure loss in 30 minutes ~ 50/40 psi. Bleed T/IA. FWHP= 0/0/0 Tags hung on WV/IA, AFE sign on MV. SV/WV/SSV= C MV=O IA/OA= OTG Well shut in upon departure. Daily Report of Well Operations PBU 05-28B Daily Report of Well Operations PBU 05-28B 5/30/2021 T/I/O = SSV/0/50. Temp = SI. PPPOT-T (PASS) ( pre RWO continued). PPPOT-T: RU test equipment, sting into tubing hanger test void, 0+ psi in test void, bled void to 0 psi. Monitor for 10 minutes and then check for psi, 0 psi on void. Functioned tubing hanger LDS, all moved freely to an out measurement of 4-3/4". Re- torqued LDS and GNs to 550 ft/lbs. Pumped through void, good returns. RU test manifold on SBMS monitor port, sting into monitor port, 0 psi. Monitor during testing. Pressured void to 5000 psi for 30 min test, lost 150 psi in the first 15 minutes, lost 50 psi in the second 15 minutes for a total of 200 psi loss in 30 minutes (PASS). Bled void to 0 psi and drained hyd fluid. RDMO. 6/4/2021 placeholder for CalIV tubing crossovers Invoice #002303 cost place holder for Shear Valve ticket # HC06202113 6/13/2021 T/I/O=Vac/0/0. Pre Thunderbird #1. Set and Test 4" "H" BPV / CTS Passed. , ND Tree and THA and NU BOP. ***Job Complete*** 6/20/2021 TBird - 1: Continue to RU TB-1. Set for AOGCC witnessed BOP testing. Found leak in Pit 1. Transfer fluids to UR w/ Vac truck. Remove pit and send for repair. Pre-BOP test w/ both crews. Receive completion and tubulars. WS, TS and TB Floor hand, start strapping pipe. Review procedure for testing BOP's, WC Plan, and line up. Chk valves per Standing Orders. Set up PVT's, trip tank, and trip sheet. Test PVT alarms, calibration & set points. Test gas alarms. Perform BOPE test 250psi low/3000psi high- AOGCC witness waived by Bob Noble. ***In Progress*** 6/21/2021 TBird - 1: Continue to test BOPE. 2 Fail/Pass - Test #2 - Choke valve #10 failed. Grease & retested, tested good and charted. Test #3 - Test chart hose leaking on JIC fitting. Tightened & retested, tested good and charted. Remote panels used to close rams on test #2 (panel #1) & test #3 (panel #2). RU & pull test dart/BPV. Rock out diesel. Forward circulate 1% KCl w/ Baraclean (surf to surf). Flow check well. Pull hanger free @ 75K work up to 143k to pull tbg free. PU Wt 95K after free as expected. Flow check well while over pulling and after - no losses. Pull completion. No visible erosion at identified leak points except for significant erosion at 4-1/2 x 3- 1/2 crossover. 136jts of 3-1/2" laid down. ***In Progress*** 6/22/2021 TBird - 1: Continue to LD 3-1/2" tubing. Jt #256 had string shot holes, 6ft recovered on jt 257 - chem cut looks good & fits inside OS. Prep to run 3-1/2"x4-1/2" tubing. Run new 3-1/2" 13Cr JFE Bear 9.3# x 4-1/2" 13Cr VAM TOP 12.6# completion, torque turned to spec. Two positive shears & stack out. Land completion over tubing stub at 11078.5ft. 93k PUW, 64k SOW. ***In Progress*** 6/23/2021 TBird - 1: Space out & land tubing. RILDS. RD Weatherford torque turn services. Reverse in 285 bbls 1% Baracor 100 w/ .1% Oxygon in 125F 1% KCL. Drop ball and rod (1-3/8" Fish Neck OAL 6.9'). Set Packer 3200 psi. MIT-T 3215 psi (PASS) lost 15/5 psi in 15/30 mins. Final pressure 3195 psi. MIT-IA 3200 psi (PASS) 0/0 in 15/30 mins. Final pressure 3200 psi. Bleed off tubing and to open shear valve in GLM #4. Bleed T and IA to zero. Set 4" H plug. RD and Move to 18-27E. ***Job Complete*** Daily Report of Well Operations PBU 05-28B 6/23/2021 T/I/O=0/0/0. Pull 13-5/8" BOP's. Install 11" 5M x 4-1/16" 5M THA & 4-1/16" CIW FLS tree. Torque THA x TBG spool to 1641 ft/lbs & MV x THA flange to 553 ft/lbs. PT tree to 500 psi low & 5000 psi high, passed. Pull 4" CIW H TWC. Reconnect S-riser and production piping. Set well shelter, flooring, backing & wellhead scaffolding. Dirt work & VSM placement ongoing. 6/24/2021 ***WELL S/I ON ARRIVAL*** (post rig) PULL B&R FROM 11037' SLM. PULL STA #3 BTM INT DUMMY FROM 7320' SLM (7326' MD) PULL STA #4 BTM INT SHEAR VALVE. 3479' SLM (3497' MD) PULLED 3 1/2" RHC-M FROM X-NIP @ 11045' SLM (11048' MD) PULLED PX-PRONG FROM PLUG BODY @ 11109' SLM SET STA #4 BK-LGLV(16/64" 1500PSI TRO) 3479' SLM (3497' MD) SET STA #3 OGLV(20/64"). 7320' SLM (7326' MD) PULL 3 1/2 PX PLUG BODY FROM X-NIP @ 11115' (11137' MD) ***WELL LEFT S/I ON DEPARTURE*** 6/26/2021 T/I/O = 250/1950/0. Temp = SI. TBG & IA FL (Ops call in). Poor boy AL SI (1860 psi). TBG FL @ 55' (.8 bbls). IA FL @ 7320' (#3, S/O). SV = C. WV, SSV, MV = O. IA, OA = OTG. 09:10 6/26/2021 T/I/O=1574/1946/5 Hot oil treatment . Post workover , well would not flow. Attemted to pump down tbg. TBG pressured up to 2950 after .5 bbls meth. Pumped 282 bbls crude down IA Rigged to TBG and pressured up with 2.6 bbls methonal continued pumping crude down IA for another 181 bbls ( total of 463) *** job continued on 6-27- 21*** 6/27/2021 *** Job continued from 6-26-21*** T/I/O= 2940/720/10 Pumped 930 bbls crude (1393 bbls total) at 180* and 295 bbls 1%KCL wate at 180* r followed by 150 crude and 15 bbls methonal down IA for well thaw. Pumped 10 bbls meth and 86 bbls crude at 180* down TBG to clear TBG of ice. Final T/I/O= 526/260/99 Turned over to DSO. 6/30/2021 AES reinstalling chemical injection tubing on well head for batch treats. 7/1/2021 Misc State Test. Pass. Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:206-089 6.API Number:50-029-22208-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028321 Property Designation (Lease Number):10. 8. PBU 05-28B 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well 5 Operations shutdown Op Shutdown GAS GSTOR WAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5Stratigraphic Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 13655 Effective Depth MD: 13Cr-80 11. 7/11/2021 Commission Representative: 15. Suspended Contact Name: David Bjork Contact Email: David.Bjork@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8774 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 11158 , 7873 Date: Liner 2402 3-1/2" x 3-3/16" x 2-7/8" 11253 - 13655 7956 - 8774 13450 13890 Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 30 - 3890 30 - 3511 14. Estimated Date for Commencing Operations: BOP Sketch 30 - 110 Structural 6890 Proposal Summary 13. Well Class after proposed work: 3-1/2" Baker SABL-3 Packer 11631 - 13615 8281 - 8775 4-1/2" 12.6# x 3-1/2" 9.2#26 - 11257 Liner 11137 8774 none 30 - 110 470 10-3/4" 7-5/8" Contact Phone:(907)564-4672 Date: 5-12-21 4790 80 149020"Conductor 2090 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 3860 3580 Intermediate 4091 28 - 4119 28 - 3698 7699 5-1/2" 3957 - 11656 3566 - 8303 7740 6280 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2470 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. 11137, 12200, 12900 By Meredith Guhl at 11:07 am, May 13, 2021 321-238 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.05.13 10:38:36 -08'00' Bo York X 10-404 DSR-5/13/21 ; ADL0028326 DLB BOPE test to 3000 psi. Annular to 2500 psi. MGR17MAY21 DLB05/13/2021 0 dts 5/17/2021 JLC 5/17/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.05.17 13:25:56 -08'00' RBDMS HEW 5/19/2021 RWO Procedure WELL: 05-28B PTD: 2060890 Well Name:05-28B API Number:500292220802 Current Status:Shut-In Rig:Thunderbird #1 Estimated Start Date:07/11/2021 Permit to Drill Number:2060890 First Call Engineer:Dave Bjork 907-564-4672 (O) 907-440-0331 (M) Second Call Engineer:Ryan Thompson 907-564-5280 (O) 907-301-1240 (M) Current Bottom Hole Pressure:3,350 psi @ 8,800’ TVD 7.4 PPGE | SBHPS offset 18-14C 12/1/19 Max. Anticipated Surface Pressure:2,470 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:1,000 psi (Taken on 3/16/21) Min ID:1.83” ID KB packer @ 3,009’ MD Max Angle:94 Deg @ 12,657’ Brief Well Summary: 05-28 was drilled in September 1991 and coil sidetracked in 2001 and 2007. The most recent sidetrack was a Z1A horizontal. In 2019 a plug was set above the Ivishak perfs and the Sag was perforated. The well was online and competitive until a tubing leak was found. It was patched and 3 additional leakpoints were discovered. We will now pursue a RWO to replace the leaking tubing. Wellbore Notes: x The 7-5/8” and 5-1/2” production casings have passed multiple CMIT-TxIA to 2,600 psi on 1/10/21 and 3/17/21. x The IC packoffs have tested to 3,500 psi on 4/20/21 x The Sag and Ivishak perfs will remain hydraulically isolated throughout RWO by tested PX plug at 11,137’ MD. Objective: Pull the existing 4-½” x 3-1/2” 13Cr80 tubing out of the well and replace with new 13 chrome tubing. Achieve a passing MIT-IA & MIT-T. Variance Request:20AAC25.412(b) Packer will be set greater than 200ft measured depth from open perfs. Existing tubing packer is at 11,158’MD which is 473’ MD above the uppermost open perforations at 11,631’. The new Packer setting depth will be ~11,048’ around 583’ MD. Pre Sundry Work: Slickline 1. Pull 45KB upper patch, pull 35KB lower patch, pull 1.78” RR plug and nipple reducer. 2. Set 2.81” PX plug @ 11,137’ DHD 1. CMIT-TxIA to 3,000 psi 2. Cycle LDS’s 3. PPPOT-T 4. PPPOT-IC Sundry Procedure (Approval required to proceed): Eline 5. Tubing Punch ~ 11,050’ 6. Cut tubing @ ~ 11,102’ - Not applicable for a development well. 00 DLB RWO Procedure WELL: 05-28B PTD: 2060890 7. Circulate well to 8.4 ppg 1% KCL or equivalent w/ diesel FP on T & IA Valve Shop/Ops 8. Bleed WHP’s to 0 psi 9. Set and test TWC 10. Nipple Down Tree and tubing head adapter. Inspect lift threads. 11. NU BOPE configured top down, Annular, 2-7/8” x 5-1/2” VBRs, Blinds and integral flow cross and 13- 5/8” x 11” Adapter. RWO 12. MIRU Thunderbird #1 Rig. 13. Test BOPE to 250 psi Low/3,000 psi High, annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. A. Perform Test per Thunderbird #1 BOP test procedure. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 2-7/8” x 5-1/2” VBR’s with 4-½” and 3-1/2” test joints. Test the Annular preventer with a 3-1/2” test joint. E. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 14. Pull TWC. 15. MU landing joint or spear, BOLDS and pull hanger to the floor. PU weights are expected to be ~98K 16. Pull 4 1/2” tubing to floor, circulate a tubing volume. 17. Run 4-½” x 3-1/2” 13Cr tubing with stacker packer completion as detailed on proposed schematic. 18. Land Hanger and reverse in corrosion inhibited 8.4 ppg 1% KCL or equivalent 19. Drop ball and rod and set packer with 3,500 psi pump pressure. 20. Perform MIT-T to 3,000 psi and MIT-IA to 3,000 psi for 30 charted minutes. 21. Shear valve in upper GLM. 22. Set TWC 23. Rig down Thunderbird #1. Valve Shop/Ops 1. ND BOPE 2. NU tree and tubing head adapter. 3. Test both tree and tubing hanger void to 500 psi low/5,000 psi high. 4. Pull TWC and freeze protect to ~2,000ft with diesel. Slickline 1. Pull Ball and rod and RHC profile 2. Set GLV’s per GL Engineer 3. RDMO & pop well. Obtain AOGCC witnessed SVS test within 5 days of putting well online. Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing Assure - overshot of tubing stub provides communication to IA at tubing cut. Lay down the same. RWO Procedure WELL: 05-28B PTD: 2060890 Wellbore Schematic RWO Procedure WELL: 05-28B PTD: 2060890 Proposed Wellbore Schematic RWO Procedure WELL: 05-28B PTD: 2060890 RWO BOPs RWO Procedure WELL: 05-28B PTD: 2060890 Hilcorp Alaska, LLC Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:206-089 6.50-029-22208-02-00 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 13655 11137 7854 11158 none 7873 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 30 - 110 30 - 110 1490 470 Surface 3860 10-3/4" 30 - 3890 30 -3511 3580 2090 Intermediate 4091 7-5/8" 28 - 4119 28 - 3698 6890 4790 Liner 7699 5-1/2" 3957 - 11656 3566 - 8303 7740 6280 Perforation Depth: Measured depth: 11631 - 13615 feet True vertical depth:8281 - 8775 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr-80 x 3-1/2" 11158 7873Packers and SSSV (type, measured and true vertical depth) 3-1/2" Baker SABL-3 Packer Liner 2402 11253 - 13655 7956 - 8774 13450 13890 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 910-750188946 00 0 28109 0 0 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: David Bjork David.Bjork@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:907.564.4672 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8774 Sundry Number or N/A if C.O. Exempt: n/a no SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 Reset tbg patch - failed 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 028321, 028326 PBU 05-28B 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 11137, 12200, 12900 By Samantha Carlisle at 1:13 pm, Apr 05, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.04.05 12:35:04 -08'00' Bo York DSR-4/5/21 RBDMS HEW 4/5/2021 SFD 4/6/2021MGR06APR2021 ACTIVITYDATE SUMMARY 3/12/2021 T/I/O=1000/1980/0 Assist Slickline (Tbg Patch) Lube and bleed IA. Bleed IAP down flowline from 1980 psi to 1000 psi. Pump 30 bbls crude down IA. Pumped 180 bbls crude down TBG Load. Pumped 10 bbls crude followed by 3 bbls 60/40 MEOH and 42 bbls of crude down FL to freeze protect. Pressured FL to 1100 psi Per DSO.*** WSR continued on 03/13/21*** 3/12/2021 ***WELL FLOWING ON ARRIVAL*** (Patch tubing / liner) TAG 45KB x 17' UPPER PATCH W/ 3.80" G-RING AT 2,950' SLM / 2,981' MD. PULL COMPLETE BAKER 45KB UPPER PATCH FROM 2,950' SLM / 2,981' MD. LRS TO REMAIN ONSITE TO LOAD TUBING / LUBE & BLEED IA. ***LDFN, LRS IN CONTROL OF WELL, CONTINUED ON 3/13/21 WSR*** 3/13/2021 *** WSR continued from 03/12/21*** Pumped 52 bbls crude into IA to fluid pack. SL set test tool in patch anchor. CMIT TxIA PASSED to 2500 psi. Pumped 12.6 bbls crude down Tbg & IA to test. T/IA lost 91/78 psi 1st 15 min & 37/35 psi 2nd 15 min. Bled back to ~600 psi for SL to POOH with test tool. SL set patch. MIT IA INCONCLUSIVE to 2500 psi. Pumped 2.8 bbls down IA to test. Attempted 4 MIT IA's total volume pumped=3.6 bbls. $th attempt IAP lost 101 psi 1st 15 min, 91 psi 2nd 15 min, & 84 psi 3rd 15 min. Bled IA back to 1000 psi Attempt MIT T Pumped 1.7 bbls down tbg to 2791 psi. TP lost 220 psi in 7 mins Bumped up to 2762 with 0.1 bbls. TP lost 232 psi in 15 mins & 159 psi in 2nd 15 mins. Bled Tbg & IA back. FWHPs=120/530/71 3/13/2021 ***CONTINUED FROM 3/12/21 WSR*** (Patch tubing / liner) SET 4-1/2" x 3-1/2" LINER TOP TEST TOOL IN 35KB ANCHOR AT 2,967' SLM. LRS PERFORMED SUCCESSFUL CMIT-T x IA TO 2593 PSI (Tbg & IA bled to 500 psi). PULL 4-1/2" x 3-1/2" LINER TOP TEST TOOL FROM 2,967' SLM. SET 4-1/2" BKR 45KB PATCH ASSEMBLY W/ SNAP LATCH IN ANCHOR AT 2,967' SLM. TOP OF PATCH AT 2,972' MD, 2.313" X-NIPPLE W/ 2-7/8" XX PLUG INSTALLED AT 2,989' MD. LRS PERFORMED FOUR UNSUCCESSFUL MIT-IA'S TO 2500 PSI. LRS PERFORMED TWO UNSUCCESSFUL MIT-T'S TO 2500 PSI. ***LDFN, WELL S/I & SECURED, CONTINUED ON 3/14/21 WSR*** 3/14/2021 ***CONTINUED FROM 3/13/21 WSR*** (Patch tubing / liner) SET 2.813" CAT STANDING VALVE IN 45KB PACKER AT 2,947' SLM. PERFORMED TWO FAILING MIT-T'S TO 2500 PSI. PULL 2.813" CAT STANDING VALVE FROM 45KB PACKER AT 2,947' SLM PERFORMED SUCCESSFUL COMBO T x IA PRESSURE TEST TO 2640 PSI. TEST PROVES INTEGRITY OF ANCHOR, SNAP LATCH SEALS, & 2-7/8" XX PLUG. RAN 4-1/2" D&D HOLE FINDER FROM TOP OF 45KB PACKER AT 2,947' SLM (See log for details). UNABLE TO FIND SOURCE OF COMMUNICATION W/ HOLE FINDER (PPPOT-T requested). ***LDFN, WELL S/I & SECURED, CONTINUED ON 3/15/21 WSR*** Daily Report of Well Operations PBU 05-28B Daily Report of Well Operations PBU 05-28B 3/15/2021 T/I/O = 950/1600/50. Temp = SI. PPPOT-T (eval TxIA). No AL. Assist Pollard wire line. Stung into SBMS void = 380 psi, bled void to 0 psi & monitor. No change in void pressure while slick line increased TP with diesel. Stung into THA void = 2300 psi, bled void to 0 psi & monitor. No change in void pressure while slick line increased TP with diesel. Pollard wire line in control of well upon departure. 10:30 3/15/2021 ***CONTINUED FROM 3/14/21 WSR*** (Patch tubing / liner) WELLHEAD GUY STUNG INTO TEST PORT & THA VOID (Both bled to 0 psi). PRESSURED UP TUBING TO 2750 PSI WHILE BLEEDING IA (Remained at 0 psi - tree seals good). PERFORMED SUCCESSFUL CMIT-T x IA TO 2486 PSI (See log for details). VERIFY COMMUNICATION WHILE PUMPING DOWN IA & THEN DOWN TUBING (Both the same). WILL BE MAKING A PASS WHILE PUMPING DOWN TBG & THEN DOWN IA (Acoustic LDL). ***LDFN, WELL S/I & SECURED, CONTINUED ON 3/16/21 WSR*** 3/16/2021 T/I/O=1500/1200/50 (Assist Slickline Load and Test) ***CMIT-TxIA FAILED 2nd Attempt*** Pressured TxIA with 28 bbls of Crude. Max applied pressure =2750 psi Target pressure= 2500 psi. !st 15 min TBG/IA lost 50/50 psi, 2nd 15 Min TBG/IA lost 50/75 psi. TBG/IA lost 100/125 psi in a 30 min test. Bled back TBG to 1000 psi per SL. Bled back 1bbl. SL to bleed back IA. Final WHPS=1000/850/50 SL In control of well upon departure. 3/16/2021 ***CONTINUED FROM 3/15/21 WSR*** (Patch tubing / liner) EQUALIZE & PULL 2-7/8" XX PLUG BODY FROM 2,965' SLM / 2,991' MD. THUNDERBIRD LOADED TUBING W/ 182 BBLS OF CRUDE. SET 1.781" RR PLUG IN NIPPLE REDUCER AT 11,096' SLM / 11,137' MD. THUNDERBIRD PERFORMED TWO UNSUCCESSFUL CMIT-T x IA TO 2500 PSI. GAS SUSPECTED IN IA, BLEED BACK PRESSURES & LET IT SIT OVER NIGHT. ***LDFN, WELL S/I & SECURED, CONTINUED ON 3/17/21 WSR*** 3/17/2021 ***CONTINUED FROM 3/16/21 WSR*** (Patch tubing / liner) PERFORMED SUCCESSFUL CMIT-T x IA TO 2686 PSI (Bled tubing & IA to 500 psi). ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** 3/21/2021 ...Well shut in on arrival... (HES EL - hoist read ldl) WIRELINE TOO BIG FOR GREASE TUBES AT APPROXIMATELY 10,400' (target 11,137'). CHANGE TUBES IN GREASE HEAD AND RELOG TOMORROW. ...Continued on 22-Mar-2021... 3/21/2021 T/I/O= 400/400/80 Temp=S/I Assist E-line-(Patch Tubing/Liner) Job postponed. Did not pump any fluids. Daily Report of Well Operations PBU 05-28B 3/22/2021 TIO=791/582/67, Temp= Ambient, LRS Unit 72 ( LEAK DETECTION LOG ) Assit E- Line with Leak Detection Log Pumping down I.A. taking returns up the TBG down the F/L, Pumped 14 bbls DSL down I.A, LLR @ .6 gal/min, ***job continued to 03-23-21*** 3/22/2021 ...Well shut in on arrival... (HES EL - acoustic ldl) LOG BASELINE TEMPERATURE PASS FROM SURFACE TO TTP AT 11,137'. LRS ESTABLISHED LLR PUMPING DOWN IA TAKING RETURNS THROUGH LEAKS, UP TBG, TO FLOWLINE. LOG READ CASED HOLE TANDEM ACOUSTIC LDL FROM 11,137' TO SURFACE. LEAKS IDENTIFIED AT 3,069' (tbg collar) and 2,997' (middle of patch). POSSIBLE TBG COLLAR LEAKS AT 3,038', 1,879', AND 1,548'. PERFORMED STOP COUNTS FOR ADDITIONAL ANALYSIS. ***Job Complete. Well shut in on arrival.*** Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:206-089 6.50-029-22208-02-00 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 13655 11137 7854 11158 none 11137',12200,129 7873 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 30 - 110 30 - 110 1490 470 Surface 3860 10-3/4" 30 - 3890 30 - 3511 3580 2090 Intermediate 4091 7-5/8" 28 - 4119 28 - 3698 6890 4790 Liner 7699 5-1/2" 3957 - 11656 3566 - 8303 7740 6280 Perforation Depth: Measured depth: 11631 - 13615 feet True vertical depth:8281 - 8775 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr-80 x 3-1/2" 26 - 11257 26 - 7959 11158 7873Packers and SSSV (type, measured and true vertical depth) 3-1/2" Baker SABL-3 Packer Liner 2402 3-1/2" x 3-3/16" x 2 11253 - 13655 7956 - 8774 13450 13890 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 879-7501699 20223715 -750 28801 1554 873 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: Dave Bjork David.Bjork@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564-4672 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8774 Sundry Number or N/A if C.O. Exempt: n/a no SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 install tubing patch 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 Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028321 & 028326 PBU 05-28B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:52 pm, Jan 28, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.01.28 11:42:17 -09'00' Bo York MGR18FEB2021 SFD 1/29/2021DSR-1/28/21 RBDMS HEW 1/29/2021 ACTIVITYDATE SUMMARY 1/1/2021 ***WELL FLOWING ON ARRIVAL*** DRIFT 2.85" CENT, AND BRUSH X-NIP @ 11137' MD. SET 3 1/2" X / 2 3/8" R NIPPLE REDUCER IN X-NIP @ 11137' MD. CHECK SET NIPPLE REDUCER (good set) @11137' MD. SET 1.781" RR PLUG IN 3 1/2" NIPPLE REDUCER @ 11137' MD. ***JOB CONTINUED ON 1/2/2021*** 1/1/2021 T/I/O=2263/2066/109 Assist Slickline (PT Plug) Pump 24 bbls crude down tbg to pressure up. TP lost 111 psi in 5 mins while IAP gained 47 psi. Bled back ~20 bbls. Bleed IAP to bleed tank FWHPs=2100/2000/95 1/2/2021 ***JOB CONTINUED FROM 1/1/2021*** ATTEMPT TO PULL 2 3/8 RR PLUG FROM NIP REDUCER @ 11137' MD. LOST EQ PRONG IN THE HOLE RETRIEVED 2 3/8" RR PLUG AND EQ PRONG ***WELL S/I UPON DEPARTURE*** (informed dso ready to POP) 1/2/2021 T/I/O = 2250/2030/100. Temp = SI. T & IA FL (eline request). No AL. T FL @ 9980' (1157' above TTP @ 11137'). IA FL @ 1450' (38 bbls). SV, WV, SSV = C. MV = O. IA, OA = OTG. 02:30 1/4/2021 T/I/O=1058/1250/50 ( Assist E-Line as required ) Pumped 28 bbls crude dn the TBG to assist e-line sting patch into lower anchor. .FWHP -754/1250/50 1/4/2021 Assist E-Line (PATCH TUBING /LINER) Pumped 120 bbls 90* crude down Tbg at 5 bpm. Pumped 100 bbls 180* crude down Tbg to warm up well for patch. ELine in control of well per LRS departure. IA,OA=OTG 1/4/2021 ***WELL FLOWING ON ARRIVAL*** (HES E-Line Patch) LRS LOADED TBG W/ 120 BBL'S OF CRUDE AT 5 BPM, FOLLOWED BY 100 BBL'S AT 1 BPM & 180*F. SET 2 TRIP 3-1/2" x 4-1/2" BAKER 35-45 KB PATCH 2983' - 3009' ELEMENT TO ELEMENT OVER 3.5"x4.5" TUBING XO (see log for details). ***WELL S/I ON DEPARTURE*** 1/6/2021 T/I/O = 800/1125/100. Temp = SI. Bleed IAP (Pre FB). No AL. IA FL @ 2611' (68.4 bbls, 877' above ST#2 DMY ). Bled IAP to OT from 1125 psi to 10 psi in 2.5 hrs. TP decreased 50 psi to 750 psi, OAP remained unchanged. IA FL unchanged. Monitor for 30 min, IAP increased 10 psi to 20 psi, TP 7 OAP are unchanged. FWHP's = 750/20/100. SV, WV, SSV = C. MV = O. IA & OA = OTG. 11:00. 1/6/2021 Attempted MIT-IA (PATCH TUBING / LINER) Pumped 81.8 bbls crude dow IA in an attempt of multiple MIT-IA. Loaded IA w/ 65 bbls 10* crude. Lube and bled a few times to try and purge gas from IA. Pumped IA up to 2750 psi 11 times and each time the test failed with in 2 to 3 mins(SEE LOG). Pumped and got a LLR of ~.15 bpm going off tank volumes. DSO notified of well status per LRS departure. SV,WV,SSV=C MV=O IA,OA=OTG 1/8/2021 ***WELL S/I UPON ARRIVAL*** SET 45KB PKR TEST TOOL IN 45KB PKR @ 2962' SLM ***JOB CONTINUED ON 1/9/2021*** Daily Report of Well Operations PBU 05-28B Daily Report of Well Operations PBU 05-28B 1/9/2021 T/I/O=800/505/96 Temp=SI LRS unit 46 Load TBG/IA (PATCH TUBING/LINER) Pumped a total of 20 bbls bbls down TBG. was unable to pump down (SEE LOG FOR DETAILS) Bled gas off of IA and fluid packed with 13 bbls of crude. DSO notified of well status upon LRS departure. SV/WV/SSV=C MV=O IA/OA=OTG. FWHP's=1000/240/85 1/9/2021 ***JOB CONTINUED FROM 1/8/21*** PT to 2000PSI W/ TRIPLEX PULL 4 1/2 TEST PLUG FROM KB PACKER @ 2961' SLM PULL UPPER 4 1/2 KB PATCH FROM 2961' SLM(qc sheared) SET QCLL TEST TOOL @ 2980' SLM. ***JOB CONTINUED ON 1/10/21*** 1/10/2021 ***JOB CONTINUED FROM 1/9/21*** LRS TEST LOWER PACKER CMIT-IA (passed) PULLED 3 1/2 QCLL TEST TOOL FROM 2975' SLM LRS LOADED TUBING WITH 100BBLS OF CRUDE 140 DEG. SET UPPER PATCH 45KB 2983' - 3009' MD. TOP OF PATCH 2981' MD. LRS CMIT-IA PASSED **WELL S/I ON DEPARTURE*** 1/10/2021 T/I/O=600/400/100 Assist Slickline / CMIT TxIA to 2500 psi (PASS) / MIT IA to 2500 psi (Patch Tbg) Pump 16 bbls crude down Tbg & IA to test. T/IA l0st 64/68 psi in 1st 15 min & 32/31 psi in 2nd 15 min Pump 100 bbls 180* crude down tbg. MIT IA FAILED 2 attempts Pump a total of 6 bbls down IA--See Log. Bleed back IAP FWHPs=240/460/95 1/11/2021 T/I/O = 240/350/100. Temp = SI. MIT-IA to 2500 psi **FAIL 3 attempts** (post patch). No AL. T FL @ 120'. IA FL @ near surface. Bled IAP from 350 psi to 200 psi (energized FTS). Pumped 2 bbls of diesel to increase IAP from 200 psi to 2692 psi. IAP lost 116 psi in 1st 15 min, IAP lost 62 psi in 2nd 15 min for a 30 min total of 178 psi in 1st test. IAP lost 60 psi in 1st 15 min, IAP lost 49 psi in 2nd 15 min for a 30 min total of 109 psi in 2nd test, IAP lost 51 psi in 1st 15 min, IAP lost 46 psi in 2nd 15 min for a 30 min total of 97 psi. IA LLR = 0.3 GPM. Bleed IAP to starting pressure. Bled IAP to 380 psi, 2.57 bbls. Tag hung. Final WHPs = 240/380/90. SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:15 1/21/2021 T/I/O = 270/590/100. Temp = 70°. WHPs (Under Eval). No AL. SV = C. WV, SSV, MV = O. IA, OA = OTG. 02:45 1/25/2021 T/I/O = 270/715/100. Temp = 70*. WHP's (under eval). No AL. IA FL @ 1134' (29.7 bbl). TP & OAP remained unchanged, IAP increased 125 psi from 1-21-21. SV = C. WV, SSV, MV = O. IA & OA = OTG. 09:00 1/27/2021 T/I/O = 890/770/100. Temp = 70°. WHPs/IA FL (Under eval). No AL. IA FL @ 1400' (37 bbls). TP increased 620 psi, IAP increased 50 psi, and the IA FL dropped 270' since 1/25/21. Ops recently moved TP from LP to HP. SV = C. WV, SSV, MV = O. IA, OA = OTG. 10:30 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS II IAI 1 L , JWJI\ I T 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operatisa rC /� L,Suspend El Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Appro rogr, 1 ❑ Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. Set CIBP 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number: 206-089 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigrephic ❑ Service ❑ 1 6. API Number: 50-029-22208-02-00 7. Property Designation (Lease Number): ADL 028326 & 028321 8. Well Name and Number. PBU 05-28B 9. Logs (List logs and submit electronic and printed data Per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11, Present Well Condition Summary: Total Depth: measured 13655 feel Plugs measured 12200, 12900 feet true vertical 8774 feet Junk measured None Leet Effective Depth: measured 12200feet Packer measured 11158 feet true vertical 8731 feet Packer true vertical 7873 feet Casing: Length: Size: MD: TVD: Burst. Collapse: Stroctural Conductor 80 20" 30-110 30-110 1490 470 Surface 3860 10-3/4" 30-3890 30-3511 Intermediate 4091 7-5/8" 28-4119 28-3698 6890 4790 Liner 7699 5-1/2" 3957-11656 3566-8303 7740 6280 Liner 2402 3-1/2" x 3-3/16" x 2-7/8' 11253 - 13655 7956-8774 13450 13890 Perforation Depth: Measured depth: 11631 -13615 feet True vertical depth: 8281-8775 feet Tubing (size, grade, measured and true vertical depth) 4-112" 12.6# x 3-1/2" 9.2#, 13Cr80 26-11257 26-7959 Packers and SSSV (type, measured and 3-1/2" Baker SABL-3 Packer 11158 7873 true vertical depth) No SSSV Installed 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: Shut -In 110 0 Subsequent to operation: 803 30579 0 0 881 14.Attachments(r uie per20MC25.07035071,&25283) 15. Well Class after work. Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NIA Authorized Name: Oestgaard, Finn Contact Name: Oestgaard, Finn Authorized Title: Produ Engineer Challenger Contact Email: FInn.OestoaardAbp.com �7, Authorized Signature: / Date: G! Irl \-t Contact Phone: +1 907 564 5026 Form 10-404 Revised 04/2017 •._ `;-j j _" SBDMS1_*v JUN 18 2019 Submit Onginal Only /©may//� Daily Report of Well Operations PBU 05-28B ACTIVITYDATE SUMMARY 5/19/2019 ***WELL S/1 ON ARRIVAL*** (perforating) RIGUP RELAY UNIT 046 ***CONT. TO 5/20/19 WSR*** ***CONT. FROM 5/19/19 WSR*** (perforating) BAILED SCALE OFF XX PLUG @ 11,190' SLM EQ 8 PULL 3.5" XX PLUG @ 11216' MD 5/20/2019 ***CONT. TO 5/21/19 WSR*** ***CONT. FROM 5/20/19 WSR*** (perforating) DRIFT W/ 2.70" CENT BARBELL, TO 12,270' SLM DRIFT W/ 32'x 2.70" DUMMY GUN TO 11,700' SLM SET WEATHERFORD EXTRA RANGE CIBP @ 12,200' MD, CCL- ME=14' CCL STOP @ 12,186' PERFORATED FROM 11.631 - 11.663' MD WITH 2.5" MILLENNIUM II, CCL - TOP SHOT=15.4' CCL STOP DEPTH = 11,615.6' CORRELATED TO MCML DATED 17 -AUG -2007 5/21/2019 ***JOB COMPLETE / DSO NOTIFIED*** TREE= 4-1/16' CMV WB_LHEAD= 3, FMC ACTUATOR= BAKE2C OKE. aEV = 70.0' REF EEEV = 63.7' BF. ELEV = 35.51' KOP= 1300' Max Angle = 94' @ 12657' 'I'= NA OetumTVD= 8800'SS 12.6#, 13 D = 3.958' W, HAO, 19.124' ITOPOF5-I2-LNR I1 395T Minimum ID = 2.377" @ 12368' 3-3/16" X 2-7/8" XO PIN 1312- TBG STUB 7-5/8' CSG. 29.7#. L-80 BTC -M, t 05-28B 13-12' TBG, 9.2#, 13CR-80 VAM TOP, .0087 bpf, D = 2.992' 1- 1126T 3-12' LNR 92#, L -BO STL, .0087 bpf, D = 2.992' 11289' 5-12' LNR, 16.8#, L-80 HYDRL 521, .0232 bpf, D= 4.892" 11656' 33/16' WFTCBP(0521/19) 2200' -1' SAFETY NO TES: WELL ANGLE> 70' @ 12254' "•CHROME TBG••• GAS LFT MAM R R -S ISTI MD I TVDI DEVI PERFORATION SUMMARY LATCH PORI709/12kI07 REF= LOG ?? 2 3488 3188 1 7314 5499 36 57 ANGLE AT TOP PERF: 30" @ 11631' Note: refer to Production DB for historical pert data SIZE SPF INTERVAL OPNISOZ SHOT I SOZ 2-1 6 11631 - 11663 O 05/21/19 BP Exploration (Alaska) 2' 6 12355 - 12400 C 05/02/14 2" 6 12490 - 12870 C 0822107 2' 6 12940 - 13470 C 0822107 2' 6 13550 - 13615 C 0822/07 05-28B 13-12' TBG, 9.2#, 13CR-80 VAM TOP, .0087 bpf, D = 2.992' 1- 1126T 3-12' LNR 92#, L -BO STL, .0087 bpf, D = 2.992' 11289' 5-12' LNR, 16.8#, L-80 HYDRL 521, .0232 bpf, D= 4.892" 11656' 33/16' WFTCBP(0521/19) 2200' -1' SAFETY NO TES: WELL ANGLE> 70' @ 12254' "•CHROME TBG••• GAS LFT MAM R R -S ISTI MD I TVDI DEVI TYPEI VLV LATCH PORI709/12kI07 PRUDHOE BAY UNIT VYB-L: 05-28B IT3ik8T No: 2060890 AR No: 50-029-22208-02 SEK; 32, Tl 1N. R15F 2431' FNL & 1059' PINI - 2 3488 3188 1 7314 5499 36 57 KBG2 DOME KBG2 SO M M 16 20 13668' D = 3.875' LNR HGR D=4.540' I MLLOUTWINDOW(05-28B) 4119'-4132' 1113T 3-12'HES X NP. ID=2.813' PKR = 2.770' PKG BORF D=2.750' 14-45"7 .45' BOT DEPLOY SLV, D = 4.00' 312' MULEEFDE, D= 2.992' 3.70' D0'LOY SLV SEALBORE D - 3.00' 312' RIPJOM, ,=12" = 2.992' 13-3/16"X 2-7/8" XO. ID = 2.377' 1 I 129OW I-12-7/8"CBP(07103/13)1 PRUDHOE BAY UNIT VYB-L: 05-28B IT3ik8T No: 2060890 AR No: 50-029-22208-02 SEK; 32, Tl 1N. R15F 2431' FNL & 1059' PINI - DATE REV BY COMMENTS DATE REV BY COMMENTS 09109191 D9 ORIGINAL COMPLETION 05108/08 MCZ/PJC DRLG DRAFT CORRECTIONS 1028101 NORDIC CTOSIDETRACK'A' 07/05/13 JPTPJC SErCBP(07/03/13) 08109106 WES SDTRCK'B' SUSPENDED 05/08/14 LLVJMD ADPETFS(05/02114) 08129/07 NORDIC 2 CTD SIDEFRACK'B' 01/31/17 MGS<#AD SET XX RUG (0123/17) 09/12/07 KSB/TLH GLV C/O 0529/19 06/13/19 NXVWJMD RILL PLUG, SET RUG, ADPEiFS DLVJMD ADDED OKB, RE=, BF & CONDVVEIGHT BP Exploration (Alaska) 04/06/08 7/ PJC DRLG DRAFT CORREEi1DNS • STATE OF ALASKA :+ it `1.,. '`1 ' ;%,i4 AL A OIL AND GAS CONSERVATION COMM, .)N REPORT OF SUNDRY WELL OPERATIONS i'' 2 1 s'.'ai 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other Lf A l 0 Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development Exploratory ❑ V 206-089-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 ' 50-029-22208-02-00 7.Property Designation(Lease Number): 8.Well Name and Number: ♦ADL0028321 1 PBU 05-28B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): 1 PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured `8 13655 feet Plugs measured 12900 feet true vertical 8774.14 feet Junk measured None feet Effective Depth measured 12900 feet Packer measured See Attachment feet true vertical 8774.48 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 29-109 29-109 1490 470 Surface 3858 10-3/4"45.5#J-55 32-3890 32-3511.22 3580 2090 Intermediate 4091 7-5/8"29.7#L-80 28-4119 28-3698.2 6890 4790 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12355-12375 feet 12375-12400 feet 12490-12870 feet 12940-13470 feet 13550-13615 feet True Vertical depth 8775.39-8777.06 feet 8777.06-8777.84 feet 8778.45-8774.13 feet 8773.69-8770.04 feet 8772.33-8774.53 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED JUN �}n{ �j�t�/ T /� Treatment descriptions including volumes used and final pressure: SCANNED 1 1 2D!4 pl�A 2 1 201 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 478 31132 0 -750 1057 - Subsequent to operation: 432 22520 13 -750 1806 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑Q • Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil • Q Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC-J 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: N/A Contact Garry Catron Email GarrY.Catron BP.Com Printed Name Garry Catron Title PDC PE Signature ii CtofAAr_CA -------- Phone 564-4424 Date 5/21/2014 vz-F 5/2z ilk AA- /7b://7 Form 10-404 Revised 10/2012 Submit Original Only Packers and SSV's Attachment ADL0028321 SW Name Type MD TVD Depscription 05-28B PACKER 3968 3574.49 5-1/2" BAKER ZXP PACKER 05-28B PACKER 11158 7872.46 3-1/2" Baker SABL-3 Packer C, U) Q p li 0toN- 1.0 0 Nr U O o 0 LCCCC° COOCO r CO N 10 v Q • O N M N CO CO O N O CO CO - N CO O a CO CO (.fl V' N 6) O O CO I� N- "' O) Co CO O) N- N- LU r-- C° C° CO CO CO CO NCO CO (NJ CO CO N- H O) co Lo Lr5O 4 N co N N N (ED Lo 00 N. CO N O) LO 0) O N- N- ch N- N- Cb N C O O co co c, N- O Inco CO Lo CO N co CO O O N CO M N Q QN M co rn LOCO 67 CO LO N CO O) N N N CO NCO = Q 0 � J dig CO O JOO CO ', -I J � MU = d r-- � N N CO N N L!) a7 LO O N N _ _ _ CO _ O •- U - °Dco - CV (N � `? N � r) N M O O) O CO f� M LO N- LO C CO O CO CO O CO CO CA N C V' N- - M N CO J IX I w C I-a . U W W 7) co UQUC7 U CC cc ct cc c Z Z Z w w w w w m m 0I- ZZZZjDD U z J J J J Cn F-- Q_c a) -o 4) 0 -o a) Q) o) a) _o O L C ° c ° Q^ E O E w iZ a) in U a' coU L o St 0_ D = Q c Q — a 'c ru � o x ,_ a) c a) T in o ca o C co 4= 0 - -a -0 a) CD e § 2 a) m° _. - , a) o N Z '�- O J 0 "- 0)`� V) § O O L D O (.c) U 0 O .0 N Q U) O _ t t b c � 't 0) E � 't * � � Q a) — N — Q a) o � Q a) — a) Q Y Q , < 0)p -o -O 'O O Q L o O (B C (Q (6 N D .Q a) �_ O c) -0 U) 4 a) O O a) (� O O m p a) O 3 E < L oo (� 0 3 (n L D p) O a) Q or)n 2 Y Y u) LL Y a) m (u � 3 Y O o o _ _ 7 w ` Q) (0 0 m 'L a) a) U) O C • a) a) E O Q Q '' Q O �- a) Y J O Q- Y =� CO N a) a) E m CO a) — U U I m a) ° O in 0 w .0CV 0.�y: 'O Q O gym�// O .= 0_a CO 7 O O _J as cB O - c o (B 03 0 O W i0 N N U) 2 3 o Q o E coc' N a)b',_ co cp u) co coCC ri, CO wO co _ Q _m 00 p 00 a .� 2 m E " d CNI _ L C CO TB COCD U U W C N Oca 0 o co ,- ''(:) a f-rr.0 C a) a (O E a 'C O >'co N U N E E O D p E c) Z x m ca x E o) a) U) H 00 O L O O `l 0 C C fn C N x C 0 _ O C C O -0 ,- 0 O J C7) a)* c (B a)* — m — p) V (0;'O Q c * C LL fl * C 4' 0) O O U) O C .*k a) 81(° a) o < C = * +Jv cam 0__TD n3 * �I� N Oen co N d a) a) co C2 (6 CO L all �, Tr eL Q o . 3 E ami o)y M d O eL > L m U) (O a > O H U c CL Q- CO N o * �N �r0 U � � � U � Em c a) C.) ESO Z Qpm v/) U � E -0 `n *k i� C - 2 >, - C c - ,� 2 L N a) 0) C a) a) - ,. o a) (D i U)p f to L C O L 4- — 0 0 0 C 4- O C c fl- L � L 4- L0.-O N- 0 O -6 r0 - a) - DN- OD _NC@•- C3) �r- p � 5XEM o a) c6 (I) O a) � N L ai .@ a) n °O .. ai D m N- cn m ° O Q 0 ai D - _ a) > o> -- ,..7 0.� E (13cc c 3 c -a c) o a a Q § o c (n -) c o o � (n : o rn (n o `O ? TD corn () o 3 v (a c -c a L-I-0 0 (n oma � o N 2 _ � U 2 _0 U t — 0 0 ' o 4' — U -s 0 00 ° F- a 0 � Oo CI-t �o U 2I' U -3 * EL � +L-. * Ute * E � Y o _1 rn* Ute * QN do N- O O C) C) N N O O N N O) C) r- N N CO V TREE='• 4-1/16"CNV s1AELLFEAD= F1AC 05-28B SP( ....OMETBGWELL ANGLE>70"@12254' *** ACTUATOR= BAKER C OKB.ELEV= 70' I I BF ELEV= NA / KOP= 1300' 2184' )-4-1/2"I-ES X NP,D=3.813" Max Angle= 94"@ 12657' 20"CONDUCTOR H 110' © J Datum M3= NA 94#,H-40, 2998' —4-1/2^L3-1:F7 112"XO,D 2.992" Datum ND= 8800'SS D=19.124' / MANDRELS 4-1/2"TBG, 12.6#,13CR-80 VAM TOP, H 2998' —11 ST MD tV ) DEV TYPE VLV LATCH PORT DATE _0152 bpf,13=3.958" 2 3488 3186 36 KBG2 DOME M 16 09/12/07 1 7314 5499 57 KBG2 SO M 20 09/12/07 10-3/4"CSG,45.5#,J-55,D=9.950" —{ 3896' TOP OF 5-1/2"LNR H 3957' 3957' I—7-5/8"X 5-1/2"BKR ZXP LTP,D=3.875" 3974' —7-5/8"X 5-112"BKR FLEX-LOCK Minimum ID = 2.377" @ 12368' LNRHGR D=4.540" 3-3/16" X 2-7/8" XO PIN FALLOUT WINDOW(05-28B) 4119'-4132' 7-5/8"WHPSTOCK(07/29/06) —I 4119' 11137' —3-1/2"HES X NP,13=2.813" 7-518"I SV(07/29/06) —I 4152' 11158' }—5-1/2"X 3-1/2"BKR S-3 PKR, _. -- 13-1/2"TBG STUB(07708/06) — 4300• D=2.770" 23 IS '_ 7-5/8"CSG,29.7#,L-80 BTC-M,ID=6.875' — 10150' _ ����4•�4!•• •� 1 �"'� 11216' I—3-1/2"I-ES X NP ♦ •• Q ii,_,�� w I PKG BORE,D=2.750" PERFORATION SUIMAARY _ REF LOG 7? ANGLE AT TOP PAF 83"@ 12355' = ' MEM—4.45"BOT DEPLOY SLV, Note: refer to Ptoduction DB for historical pert data - �� D=4.00" SCE SPF INTERVAL OPNISOZ SHOT SOZ _ 2" 6 12355- 12400 0 05/02/14 11257' 1___3-112"MULESHOE ==. 2" 6 12490- 12870 0 08/22/07 f D=2.992" 2" 6 12940- 13470 C 08!22/07II 11260' 3.70'DEOY SLV 2" 6 13550- 13615 C 08/22/07 _= /♦ / SEALBOREPLD 3.00' 11265' f—3-1/2"PUP JOINT, D=2.992" 3-1/2"TBG,9.2#,13CR-80 VAM TOP,.0087 bpf,ID=2.992" H 11257' , 11278' 1—3-1/2"X NP,ID=2.750" 3-1/2"LNR 9.2#,L-80 STL,.0087 bpf,D=2.992" —I 11289' \ 11289' I—3-112"X 3-3/16"XO,D=2.786" 5-1/2"LNR 16.8#,L-80 HYDE 521,.0232 bpf,D=4.892" l— 11656' D=2.377" 3-3/16"LNR,6.2#,L-80 TOl.0076 bpf,D=2.80" —I. 12368' _ 12900' I—2-7/8"CUP(07/03/13) I PBTD — 13625' I 2-7/8"LNR,6.41#,L-80 STL.0058 bpf,ID=2.441"H 13658' �4 DATE ' REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/09/91 D9 ORIGINAL COMPLETION 05/08/08 MCZ/PJC DRLG DRAFT CORRECTIONS WELL: 05-28B 10/28/01 NORDIC 1 CTD SIDETRACK"A" 07/05/13 JFYPJC SET CBP(07/03/13) PERMfT No: 2060890 08/09/06 N2 ES SDTRCK"B"SUSPENDED 05/08/14 LLVJMD ADPERFS(05/02/14) API No. 50-029-22208-02 08/29/07 NORDIC 2 CTD SIDETRACK"B" SEC 32,T11 N,R15E,2431'FM_&1059'RM 09/12/07 KSB/TLH GLV GO 04/06/08 ?/PJC DRLG DRAFT CORRECTIONS BP Exploration(Alaska) STATE OF ALASKA RECEIVED A KA OIL AND GAS CONSERVATION COM ON JUL 2 3 2013 REPORT OF SUNDRY WELL OPERATIONS AO G 1.Operations Abandon U Repair Well i Plug Perforations (J Perforate U Other[JC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development 5 • Exploratory ❑ 206-089-0 ' 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-22208-02-00 - 7.Property Designation(Lease Number): 8.Well Name and Number: 1 ADL0028321 PBU 05-28B • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): To Be Submitted PRUDHOE BAY,PRUDHOE OIL' 11.Present Well Condition Summary: Total Depth measured 13655 feet Plugs measured 12900 feet true vertical 8774.14 feet • Junk measured None feet Effective Depth measured 12900 feet Packer measured See Attachment feet true vertical 8774.48 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 30-110 30-110 1490 470 Surface 3867 10-3/4"45.5#J-55 29-3896 29-3516.08 3580 2090 Intermediate None None None None None None Production 4091 7-5/8"29.7#L-80 28-4119 28-3698.2 6890 4790 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12490-12870 feet 12940-13470 feet 13550-13615 feet True Vertical depth 8778.45-8774.13 feet 8773.69-8770.04 feet 8772.33-8774.53 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED NOV 0 € 2013 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 420 32991 2 -750 1062 Subsequent to operation: 643 33100 0 -750 942 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratorl❑ Development El • Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil [.,j • Gas U WDSPL.[J GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCJ 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: N/A Contact Nita Summerhays Email Nita.Summerhays4BP.com Printed Name - - - Title Petrotechnical Data Technician l /1, Signafur- %/1/Ij71//�7- . ;. :_-// Phone 564-4035 Date 7/23/2013 VL'r" ? RBDMS JUL 2 4 20i i 7-/3, J) 3 Form 10-404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028321 • . 01 v= •. o• o•jective: In` "'• ontingent / RIH w/2.25" nz for drift tagged PBTD @ 11610' painted a blue flag @ 13570' POOH. 7/2/2013 «< Continue WSR on 7/3/13 »> CTU#9 1.75" Coil (CV=39.1) Job objective: Drift/ PPROF/Contingent CIBP «< Continue WSR from 7/2/13 »> RIH w/SLB GR/CCL/SPINNER/TEMP/PRESS PPROF logging tools. ( MAX OD 1.75" ) Performed PPROF w/GHOST. 40/60/80 up/down pass's from 13592' (Blue flag) to 12400' CTM. Performed stop counts at 13500', 12900', 12400' Flagged pipe (White w/ red ???) at 12900' E 12909' M. Pooh. Download Good Data. Upload to Interact for APE review. Reviewed and will be setting CIBP at 12900' 7/3/2013 <<Job in Progress» • . 01 v= •. o• o•jec ive: In` • on ingen <« Continue WSR from 7/3/13 »> CIBP is set @ 12900' POOH. At 7/4/2013 surface recover ball RDMO. FLUIDS PUMPED BBLS 22 50/50 METH 107.1% KCL 129 TOTAL N. Casing / Tubing Attachment ADL0028321 Casing Length Size MD ND Burst Collapse CONDUCTOR 80 20"91.5# H-40 30 - 110 30 - 110 1490 470 LINER 7700 5-1/2" 17# L-80 3957 - 11657 3565.56 - 8303.96 7740 6280 LINER 36 3-1/2" 9.2# L-80 11253 - 11289 7955.58 - 7986.82 10160 10530 LINER 1079 3-3/16" 6.2# L-80 11289 - 12368 7986.82 - 8776.63 PRODUCTION 4091 7-5/8"29.7# L-80 28 - 4119 28 - 3698.2 6890 4790 SURFACE 3867 10-3/4"45.5#J-55 29 - 3896 29 - 3516.08 3580 2090 TUBING 2971 4-1/2" 12.6# 13Cr80 27 - 2998 27 - 2792.88 8430 7500 • TUBING 8259 3-1/2" 9.2# 13Cr80 2998 - 11257 2792.88 - 7959.06 10160 10530 LINER 1290 2-7/8"6.41#L-80 12368 - 13658 8776.63 - 8774.11 , • 1 • tfiEE= 41/16•C2V11 • - S NOT WELL ANGLE>70°a 12254' AWILLFEORD= BAKE C 05-28B "'CHROME TBG*** KB.EtEV= 63.7 - BF.B.B/= NA 1 1 2184' H41/TI XNP,D=3.813' 1 KOP Mau Angle= 94° 12657' 20'CONDUCTOR 110' l Ang 94# H-40 Datum NO= NA ■ / ( 2998 N4-1t2"X 3-112•XO,D=2.992• Datum N 800'D= 8 SS D=19.124' GAS LFT MANDRELS 4-1/T TBG,12.60,13CR-80 YAM TOR H 2996' iST PA) ND DEV 'TYPE VLV LATCH PORT DATE .0152 bpf,13=3.958' 2 3488 3186 36 KBG2 DOW NT 16 09/12/07 1 7314 5499 57 KBG2 SO M 20 09/12/07 1 10-3/4'CSG,45.5#,J-55,D=9.950" H 3896' 3 ,TOP OF 5-1/2'LNR H 395T 3967' H7-518"X 5-1/T BKRZXP LTP,13=3.875" 3974' }-7-58•X 5-1/T BKR FLDC-LOCK Minimum ID =2.377"@ 12368' LNR HGR,D=4.540' 3-3116"X 2-7/8"XO PIN - I MLLOUT WINDOW(05-28B) 4119'-4132' 17-5/8"rMf'STOCK(07/29/06) H 411W a PBZFC1071 N BUiARY REF" 'r"ON t00230' ANCtEAT ltIPP 02'•100.50 11137 N3-1t2'hES X NP,D=2813• NNW IbMb Role,l a OB fat Yibife.lpet dais 9¢E SF KM/AL Op°Bgc aIE 1.59' 0 10050-10590 O 1012407 1r6r ° "64 .7,M6E2sv( io6) 4152' �/ 11158' I-5-12"X3-12"BKR S3 PKR, 13-12-TBG STUB(07/08/06) H 4300' _11∎••._ - • • ( 11216' 1--3-12"HES X NIP , ••�•�; w/PKG BORE,D=2.750" •' 7-5/8"CSG„29.7#,L-80 BTC-M,D=6.875" 10150' -_- P�CfRA T1OP1 11253' `--4.45'BOT DEPLOY SLY, REF LOG:?? =-- D=4.00' ANGLE ATTOP PERF:89°r 12490' _= : ( 1125T H 3-1/2"MULESHOE, Note:refer to Reduction CB for historical pert data ..- D=2.992' SEE SFF INTERVAL OPWSQZ SHOT SQZ ' 11260' 1--3.70"DEPLOY SLY 2" 6 12490-12870 0 0$122/07 SEALBORE,D=3.00" 2" 6 12940-13470 C 08/22/07 2' 6 13550-13615 C 08/22/07 --- 11265' }--3-12 RP JOINT, D=2.992• 13-1/T TBG,9.2#,13CR-80 YAM TOP,.0087 bpf,D=2.997 H 11257 11278' H3-12"X NP,D=2.750' , 13-1/2'LNR,9.2#,L-80 STL,.0087 bpf,D=2.992 H 11289' — . 11289' H3-12'X 3-3/16"XO,13=2.786" 1 5-1/T LNR,16.8#,L-80 HYDRL 521,.0232 bpf,D=4.892" j--[ 11656' 12368* }--`3-3/18•X 2-7/8'XO,D=2.317' 13-3/16'LNR,62#,L-80 X/.0076 bpf,0=2.80' H 12368' 12900' H2-78-CBP(07/03/13) PBTD 13625' 12-78"LW,6.41#,L-80 STL.0058 bpf.D=2.441"H 13668" DATE REV BY C)AW1TS DATE REV BY COMMENTS PRIME BAY UNIT 09109191 D9 ORIGINAL COMPLETION 05A8(08 MC7IPJC DRLG DRAFT CORRECTIONS WELL: 05.286 10/28/01 NORIIG 1 CID SIDETRACK'A" 07/05/13 JPTPJC SET CEP(07103/13) PERMIT No:'2060890 08/09106 WEB SDTRII±K"B"SUSPENDED API No: 50-029-22208-02 08/29/07 NORDIC 2 CTD SIDETRACK"B" SEC 32,T11 N,R15E,2431'FM-&1059'PAL 09/12/07 KSB/TLH GO/CIO gp Exploration(Alaska) 04/06/08 ?/PJC DWG DRAFT CORRIECT10P6 • • Packers and SSV's Attachment ADL0028321 SW Name Type MD TVD Depscription 05-28B PACKER 3957 3501.86 5-1/2" BAKER ZXP PACKER 05-28B PACKER 11158 7808.76 3-1/2" Baker S-3 Packer • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 11,2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission SLAKED AUG 2, 1 LQt 333 West 7 Avenue Anchorage, Alaska 99501 a06 Subject: Corrosion Inhibitor Treatments of GPB DS -05 n5. Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 05 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, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) DS -05 Date: 01/10/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal 05 -01C 1990280 50029201360000 Sealed conductor NA NA N/A N/A NA 05 -02A 2012410 50029201440100 Sealed conductor NA NA N/A N/A NA 05 -03C 2000940 50029201470300 Sealed conductor NA NA N/A N/A NA 05 -04A 1960890 50029201520100 Sealed conductor NA NA N/A N/A NA 05 -05B 1961800 50029201700200 Sealed conductor NA NA N/A N/A NA 05 -06A 1950840 50029201730100 0 NA 0 N/A N/A NA 05 -07 1770130 50029202430000 Sealed conductor NA NA N/A N/A NA 05 -08A 2100550 50029202480100 Sealed conductor NA NA N/A N/A NA 05 -09A 1990140 50029202540100 Sealed conductor NA NA N/A N/A NA 05 -10C 2070980 50029202630300 Sealed conductor NA NA N/A N/A NA 05 -11A 1960970 50029202520100 Sealed conductor NA NA N/A N/A NA 05 -12B 2011800 50029202440200 Sealed conductor NA NA N/A N/A NA 05 -138 2071460 50029202500200 Sealed conductor NA NA N/A N/A NA 05 -14A 1930820 50029202530100 Sealed conductor NA NA N/A N/A NA 05 -15B 1960230 50029202550200 Sealed conductor NA NA N/A N/A NA 05 -16B 1991000 50029202620200 Sealed conductor NA NA _ N/A N/A NA 05 -17B 1981040 50029202710200 Sealed conductor NA NA N/A N/A NA 05 -18A 1981740 50029219600100 Split conductor NA NA N/A N/A N/A 05 -19 1890780 50029219620000 1.4 NA 1.4 N/A 8.5 4/11/2011 05 -20B 2042340 50029221370200 1.2 NA 1.2 N/A _ 5.1 4/18/2011 05-21A 1981180 50029219690100 Dust Cover _ NA NA N/A N/A N/A 05 -22B 2071260 50029219760200 3.1 NA 3.1 N/A 18.7 4/17/2011 05 -23B 2080610 50029219630200 1.2 NA 1.2 N/A 5.1 4/11/2011 05 -24A 2042180 50029222040100 1.5 NA 1.5 N/A 10.2 4/11/2011 05 -25C 2091240 50029219880300 6.0 NA 6.0 N/A 44.2 4/18/2011 05 -26A 2012210 50029219840100 0.5 NA 0.5 N/A 3.4 4/12/2011 05 -27B 2081910 50029219790200 Sealed conductor NA NA N/A N/A N/A - 05 -288 2060890 50029222080200 0.6 NA 0.6 N/A 1.7 4/10/2011 05 -30 1911150 50029222130000 1.2 NA 1.2 N/A 10.2 4/11/2011 05-31B 2100850 50029221590200 1.3 NA _ 1.3 N/A 6.8 4/12/2011 05 -32A 2020010 50029221900100 20.0 6.0 0.5 7/13/2011 3.4 7/23/2011 05 -33B 2100810 50029221680200 4.8 NA 4.8 N/A 37.4 4/27/2011 05 -34A 2080370 50029222170100 3.9 NA 3.9 N/A 18.7 1/4/2012 05 -35A 2081340 50029221720100 2.7 NA 2.7 N/A 18.7 4/18/2011 05 -36A 2050700 50029221820100 2.3 NA 2.3 N/A 13.6 4/12/2011 05 -38 1961850 50029227220000 1.8 NA 1.8 N/A 15.3 4/10/2011 05 -39 1961730 50029227150000 1.3 NA 1.3 N/A 10.2 4/10/2011 05 -40 1961590 50029227070000 1.6 N/A 1.6 N/A 16.2 1/10/2012 05-41A 2031700 50029226960100 5.0 NA 5.0 N/A 58.7 1/8/2012 ~x _ ~~~ ~ ~~ 4? ~~~ LR '~: JOE .~.-~ ~~ , ~~ ~:~ t ~~ r 1 ~. MICROFILMED 6/30/2010 DO NOT PLACE ANY. NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microftlm_Marker.doc ScNNen~~r~er Alaska Data & Consulting Services 2525 Gambell Street, Su#e 400 Anchorage, AK 99603-2839 ATTN: Beth Well Job # NO. 5478 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD .i ice. 05.01C AYKP-00062 RST 01/17/10 1 1 05-38 AYKP-00063 RST 01/22/10 1 1 12-05A OS-286 11963097 BBSK-00002 MCNL RST 06/02/08 01/20/10 1 1 1 1 YLtA~t AI:KNUWLtUIit NtI:tIYI C7 JIVNINV ANU Ht I UfiNlNli Vrvt I:VYP CAI:H 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-i 900 E. Benson Blvd. Alaska Data & Consulting Services 0?l2n/10 ~~ i b O` ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 7/2012009 Permit to Drill 2060890 Well Name/No. PRUDHOE BAY UNIT 05-286 Operator BP EXPLORATION (ALASKI~ INC API No. 50-029-22208-02-00 MD 13625 ND 8774 Completion Date 8/29/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey ~ DATAINFORMATqN Types Electric or Other Logs Run: MWD DIR / GR, CNL / GR / CCL (data taken from Logs Portion of Master Weli Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Intervai OH / I ype Meqltrmi rvumoer Name acaie rvieaia rvo ~Lart aiop ~.n rcecervea ~.ommencs i D D Asc Directional Survey 0 11666 Open 8l30/2006 Partial Survey ~ D Asc Directional Survey 0 13655 Apen 9/25/2007 . r pt Directional Survey 0 13655 Open 9/25/2007 ~'`" S a~~ ~~ ik D D Asc Directional Survey 0 12451 Open 9/25/2007 PB 1 pt Directional Survey 0 12451 Open 9/25/2007 PB 1 p~b C Las 15764 Induction/Resistivity 4094 11666 Open 12l3/2007 RPM, GR, ROP, RPD, RPX w/EMF and PDF graphics D C Las 15765 Gamma Ray 11287 12451 Open 12/3/2007 P61 GR, ROP w/PDF graphics og Neutron 2 Blu 10920 13496 Case 6/6/2008 MCNL, GR, CCL, CNL 17- Aug-2007 ~ED C Lis 16392 Neutron 10923 13500 Case 6/6/2008 LIS Veri, GR, CNT pt LIS Verification 3792 11666 Open 6/19/2008 LIS Veri, GR, RPD, RPM RPS, RPX, FET, ROP R'ED C Lis 16481 Induction/Resistivity 3792 11666 Open 6/19/2008 LIS Veri, GR, RPD, RPM RPS, RPX, FET, ROP og Induction/Resistivity 25 Col 4119 11666 Open 6/19/2008 MD DGR, EWR, ROP o Induction/Resistivity 25 Col 3698 8311 Open 6/19/2008 ND DGR, EWR, ROP D C 16482 See Notes 0 0 Open 6/19/2008 MD and ND on logs in PDS, EMF and CGM f ~ DATA SUBMITTAL COMPLIANCE REPORT 7/2012009 Permit to Drill 2060890 Weil Name/No. PRUDHOE BAY UNIT OS-286 Operator BP EXPLORATION (ALASK/~ INC nnu lSbZb ivu uii4 ~.ompieuonuaze 8/Ly/LVU/ ~.ompieuona~aws i-v~~ ..u~~c~ua~awa ~-v~~ ~~~, ~. t LIS Verification 11287 13654 Open 12/11/2008 LIS Veri, GR, ROP D C Lis 17289 LIS Verification 11287 13654 Open 12/11/2008 LIS Veri, GR, ROP LIS Verification 11287 12452 Open 12/11/2008 PB1 LIS Veri, GR, ROP D C Lis 17290 LIS Verification 11287 12452 Open 12/11/2008 P61 LIS Veri, GR, ROP og Gamma Ray 25 Col 11572 13655 Open 12/15/2008 ND GR 15-Aug-2007 og Gamma Ray 25 Col 11572 13655 Open 12/15/2008 MD GR 15-Aug-2007 og See Notes 2 Col 11280 13655 Open 12/15/2008 Depth Shift Monitor Plot 28- Oct-2008 og Gamma Ray 25 Col 11572 12451 Open 12/15/2008 PB1 MD GR 6-Aug-2007 g See Notes 2 Col 11286 12452 Open 12/15/2008 P61 Depth Shift Monitor PIot18-Nov-2008 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? Y-f-~i- Analysis Y~ Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~" Formation Tops ~ N API No. 50-029-22208-02-00 Comments: Compliance Reviewed By: Date: ~ • ~ ~/!~ BAKER NVGMES Baker Atlas PRINT DISTRIBUTION LIST CUMYAN Y 13Y r;XYLUfL411ON (ALASKA) 1NC COUN'i'Y NUKTH SLUY~ 13UKUU(iH WELL NAME OS-28B STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 12/10/2008 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 1498749 Copies of Copies Digital Copies of Copies Digital ~ Each Log ~ of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE, AK 99508 ANCHORAGE AK 99~01 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address ~ata Disseminated B~BAKER ATLAS-PDC 17015 Aldine Westfield. Houston, Texas 77073 This DisYribution List Completed By: ~(~(~ -(~~S I ~~1 Page 1 of 1 ~ ~ C:UMYAN Y WELL NAME //-~ BAKER N~J6l~ES Baker Atlas PRINT DISTRIBUTION LIST t3P ~XYLUKAl'1UN (ALASKA) lNC CUUN'1 Y NUK'1'H SWYE t3UKUU(iH OS-28BPB1 STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 12/10/2008 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 1498749 Copies of Copies Digital Copies of Copies Digital Each Log oFFilm Data Each Log of Film Da[a 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DNISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-I Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE AK 99508 ANCHORAGE AK 99501 1 Company EXXON MO$IL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield. Houston. Texas 77073 This Distribution List Com~leted B~ ~- ~o~ ~~~ Page 1 of 1 ~ ~ INTEQ Log ~ Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: OS-28BPB1 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) LAC Job#: 1498749 ~~~ -~~ ~ •~~j~ Sent by: Catrina Guidry Date: 12/10/08 Received by: ~~~ Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 ~~~` B41~t 1N/Q~lES IN'['~,Q ~ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~ ~ INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: OS-28B ;~ Contains the following: ;~ ~ ~~ ~~ 1 LDWG Compact Disc ;~ (Includes Graphic Image files) s : 1 LDWG lister summary ~{~ ~ ~I ~ ,~ ;~ 1 color print - GR Directional Measured Depth Log (to follow) ~ ';~ 1 color print - GR Directional True Vertical Depth Log (to follow) ~ a ~ ;~ , ~ ;~ ~ ~ ~~ O~`~ ~ ~~-~~' ~ ° LAC Job#: 1498749 ~ ~~ ~ Sent by: Catrina Guidr~y ? Date: 12/10/08 ~ , ,., Received by: '~ ~J~ '' v Date: , - - ,~ ____ w _ _ _ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ ~,~ ~~ ` 7260 Homer Drive ~~~ Anchorage, Alaska 99518 ~_, Direct: (907) 267-6612 _... ~1'~"~'~:~ ~ FAX: (907) 267-6623 ~ . ~I.L LOG TItANSMIT'd'AAI, ~'o: State of Alaska June 2, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data.: OS-28B AK-MW-4505187 1 LDWG formatted CD rom with verification listing. API#: 50-029-22208-02 PLEASE ACKNOWLEDGE RECEII'T BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Ancho~ag~r Alaska 99518 Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ %~' ~1 Signed: ~r~ ' ~~..~. ~,~-~~~ ~ ~~ ~~5 i • ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: OS-28B June 5, 2008 AK-MW-4505187 OS-28B: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 50-029-22208-02 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 50-029-22208-02 Digital Log Images: 50-029-22208-02 1 Color Log 1 Color Log 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNTNG A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Bivd. Anchorage, Alaska 99518 Date: _ ., _ BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ (r~~ ~ ~ Signed: ~`.s• ° '~ f~-~- ~;~~--v~~ ~ !~,~f~~~`- 06/04/OS ~ ~ ~~i~~~~U~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wall .Inh 3t NO. 4736 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ ..... n.. L-220 11975963 CH EDIT PDC GR (USIT) / 04/22/08 liviVl liV 1 L-221 11962592 CH EDIT PDC GR (USIT) 04/07/08 1 V-223 40016679 OH MWD/LWD EDIT ~ 03/20/09 2 1 W30 12034892 RST ~-~ ~/ 04/11/08 1 1 G-11B 11963085 MCNL ~~- / 04/01/08 1 1 05-286 11649987 MCNI (o.- 08/17/07 1 1 P2-36A 11209594 MCNt - 03/26/06 1 1 07-O1B 12021155 MCNL `jD 04/28/08 1 1 05-34 11966251 CH EDIT PDC GR (USIT) OM13/08 1 17-12 12057613 PRODUCTION PROFILE - v 05/23/OS 1 1 W-31 11999015 LDL OS/25/O8 1 1 GNI-02A 1205761$ PRESS/TEMP SURVEY (o - 3~ 05/24/08 1 1 13-12 11982434 USIT _ L ~~ 05/29/OS 1 1 ai FeeG er~nin~nn cnr_r o~ r-~~er o.. ~~...~ ~.~.. „ . .__.._........~_.....~.,~..~~. ~ ..~ .,~.a~.~~..~..~..,n~~~n~vnv~7v~VCVVF'T aN~,n iv: BP Exploration (Alaska) Ina Petrotechnical Data Center LR2-1 "~ - 900 E. Benson Blvd. +~-- •- ~ ~ Anchorage, Alaska 99508 Date Delivered: ~ ~~ ' ~ d '-° ~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 00 Anchorage, AK 99503- 83 ~ ATTN: Seth Received by: ~ ~ Date ll-30-2007 Transmittal Number:92922 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) nave an Contents 05-286 ~aC,-o~~i ~ IS-}(o~{ 05-28BPB1 ~o(,-0~9 " 1 S~'!os 1-39A/N-16~~.~-i~~ !.~ ~ (oa 1-39A/PB1 ~vt~- ~ b~ I 5$~ 15-126 -no /a~=. C-32C~o~-r39 -~-~s-364 E-116-no ~P3 E-11 BL1 ~o~--oC~9 # ~~ ~.~~, E-1~BL1-o1 ao~--bLa'~~~ ~--~a E-11 BL1 P61 ~o-~-oc~ r~ ~5~.~~ E-11BL1PB2aU~}_p~! ¢~s~;~ E-19B ao~--o~~ # i S~~-1 G-25B ao~-b ~r~ *' ! S~~-~ NK-14A~ 20~-03 I ~- ~~-~-3 NK-14APB1 ~oc. -031 ~t t~~~ ~.~ NK-61 A ~6(~-035 ~ 15~~ S contact llou~las llortch at the YllC: at Sb4-4y /:~ ~ ~~~- ~,. - a ~- ~ ~.,.r' ~ ~ ~ . .~... ~' ~ r` ~ ~ _ , <~ ; J~i;' ~;~~:~.~ ~ {~ ;~ , > E ~ ;e~ s, ~,, __ '; i ~ t:~ - _~ Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 1966 [ 2 Anchorage, AK 99519-6612 STATE OF ALASKA /'~^o~~' -o~ ~a ~' ~'' ~ IOIE C~ ; ALASKA~IL AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG `~~ `-~ ~~~ 2007 ~. ~ ~=~ ~ons. Garnmissi0ri 1a. Well Status: ~ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zonnc2s.~oe zoAnc2a~~o ^ GINJ ^ WtNJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1b. Weil Ciass: ,~j,~,j ~ g ~ Development ~~xploratory ^ Service ^ Strati raphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban~„/. 8/29/2007 •~rl~ ~~ 12. Permit to Drill Number 206-089 - 307-143 3. Address: P.O. Box 196612, Anchora e, Alaska 99519-6612 6. Date Spudded 07/31/2006 - 13. API Number 50-029-22208-02-00 ~ 4a. Location of Well (Governmental Section): Surtace: ' ' 7. Date T.D. Reached 8/14/2007' 14. Well Name and Number: PBU 05-28B ~ 2431 FNL, 4220 FEL, SEC. 32, T11N, R95E, UM Top of Productive Horizon: 4606' FSL, 95' FEL, SEC. 30, T11 N, R15E, UM 8. KB (ft above MSL): 63.7'. Ground (ft MSL): 35.2' 15. Field / Pool(s): _ Prudhoe Bay Field / Prudhoe Bay Total Depth: 166' FSL, 1100' FEL, SEC. 19, T11N, R15E, UM 9. Plug Back Depth (MD+TVD) 13625 - 8774 ~ Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 698128 y- 5949039 Zone- ASP4 10. Totaf Depth (MD+iVD) 13655 -. 8774 . 16. Property Designation: ADL 028321 ~ TPI: x- 696765 y- 5956043 Zone- ASP4 Total Depth: x- 695736 y- 5956856 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ~ Yes ^ No Submit I ctroni and rinte inf r ati n er 2 AA 2. 50 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information p r 20 AAC 25.0 1): MWD DIR / GR, CNL / GR / CCL ~~NDOS.~~' .y~//9iNN/J ,~6q~"yY~i 22. CASING, LINER AND CEMENTING RECORD ~ ~ CrASING -' _... , SE'f`FINO E~EPTH MD SETTING CIEPTFi TVD ~ I"ISSCE' ~~OUNT' ; UUT. PER FT. GRADE TOR `BOTfOM ' TOP ``' BOTTQM " SIZE .' CEMENTING RECbRO . `!PULLED. '' " 1 H-4 11 ' 110' " 11 Y r s Ar ' 10-3/4" 45.5# J-5 Surface 389 ' urfa 516' 13-1/2" 1265 sx CS I11, 35o sx'G', T~: 90 sx CSIi 7- /8" 2.7# L-80 urta e 11 ' urF 69 ' -7/8" 15 sx CI s'G' -1 /" 17# L-80 7' 11 7' 4' -/4" 1 1 x i 1 x I ss '' 3-1/ " x 3- /16" 9.2# /.41# L-80 112 3' 13 58' 79 6' 8774' a-,ia"x3-3/4~~ 1 x I s'' x CI s'G' x 2-7/ " / 6.16# 23. Open to production or inject ion? ~ Yes ^ No ~ ~~~ ~ ~ ~~.~,... 24. ; ~~ TuaiN~ R~cor~m ~~ If Yes, IISt @8CI1 Itlt@N8I Op2~ (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 SurFace - 2998' MD ND MD ND 3-1/2", 9.2#, 13Cr80 2998' - 11257' 11158' 12490' - 12870' 8778' - 8774' 12940' - 13470' 8774' - 8770' ; 25. AC~ > ~ ;; ...n. , D; Ft~~raRE, Cfa~rir :S4ueEZE, EtG 13550' - 13615~ $~~2~ -$775~ ~EPTH ~NTERVAL MD AMOUNT Hc KIND OF MATERIAL USED 2200' Freeze Protect w/ Diesel ZG. PRODUCTION TEST Date First Production: September 22, 2007 Method of Operation (Flowing, Gas Lift, etc.): Flowin Date of Test: 10/11 /2007 Hours Tested: ~ ~ PROOUCT~or, FoR TEST PERIOD OIL-BBL: 773 GAS-MCf: 11,907 WATER-BBL: -0- CHOKE SIZE: 64 GAS-OIL RATIO: 15,413 Flow Tubing Press. 1,244 Casing Press: 1,350 CA~cuu~Teo 24-HOUR RATE• OIL-BBL: 1,686 GAS-MCF: 25,979 WATER-BBL: -0- OIL GRAVITY-API ~CORR~: 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ~ No Sidewal l Core s A uired? Yes ~ No If Yes to either question, list formations and intervals cored (MD+ND 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 250.071. ~ ~OTt4i'L£7I~f~~ None ~~~ ~~~. ~,1~~ ~ r~ 1~~7 ~ ~=~~~~ Form 10-407 Revised 02/2007 ~ R < I G 1 I~ ~I ~D ~N REVERSE .SIDE ~~ (~~ \ ~ ZH. GEOLOG'w^ MARKERS ~LIST ALL FORMATIONS AN RS ENCOUNTERED~: 29. FORMATION TESTS NAME ND Well Teste . Yes No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 11615' 8267' None Shublik A 11668' 8314' Sadlerochit 11725' 8364' Top CGL / Zone 3 11882' 8505' Base CGL / Zone 2C 11957' 8570' 23SB / Zone 2B 12020' 8620' 22TS 12046' 8639' 21TS / Zone 2A 12118' 8687' Zone 1 B 12200' 8731' 14N 12220' 8740' 13N/ Zone 1A 12270' 8757' Formation at Total Depth (Name): 13N / Zone 1A 12270' 8757' 30. List of Attachments: Summary of Daily Drilling Repo~ts, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. b Signed Tercie Hubble Title Technical Assistant Date , ~'~~~ z PBU 05-28B 206-089 307-143 Prepared ey Name~vumber. Te~rie Hubble, 564-4628 Well Number P rmi N./ A r val N. Drilling Engineer: Greg Sarber, 564-4330 INSTRUCTIONS GeNew-~: 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 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Ctassification of Service Welfs: Gas Injection, Water Injection, Water-Atternating-Gas Injection, Salt Waier Disposal, Water Supply for lnjection, 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 and Ground Level elevation in feet above mean sea level. 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). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. 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). Ireat 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: 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 Y9: 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. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATIQN Page 1 of 1. Leak-Off Test Summary Legal Name: 05-28 Common Name: 05-28 Test Date ' TesYType Test Depth (TMD) Test 4epth (TVD) -~ AMW --- SurfacePressure -- Leak Off Pressure (BHP) EMW 7/29/2006 I LOT 4,119.0 (ft) 3,699.0 (ft) i 8.85 (ppg) ~ ~ r 500 (psi) I ~ 2,201 (psi) ~ I ~ i 11.45 (ppg) ~ ~ Printed: 9/74/2007 10:09:44 AM ~ ~ ~ BP EXPLORATION' Page 1 c~f 27' Clpera#ions Sumrnary Report Legal Well Name: 05-28 Common Well Name: 05-28 Spud Date: 10/17/2001 Event Name: REENTER+COMPLETE Start: 7/26/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 8/29/2007 Rig Name: NORDIC 2 Rig Number: ' Qate From - To Hau'rs Task Gode NPT Phase Description of UperafiQns 7/26/2007 05:00 - 09:30 4.50 MOB P PRE Jack up rig and prep to move off 1 B-08. Crew change PJSM. i Remove ESD and guard off nearby well. Move rig off of mats ~ and onto Pad parallel to wellhouses. Set rig down on Pad. , Lower 7-1/16" BOP's onto moving skid. Remove rig mats from well area and pick up herculite. Post Pad inspection 09:30 - 13:00 ! 3.50 MOB P PRE Scope down upper section of derrick. Open pipeshed doors and LD derrick. Close doors. Secure derrick and pipeshed area for move 13:00 - 18:00 , 5.00 MOB P PRE PJSM. Move off of 16 Pad and head to GPB on Spine road. ~ ~ Using over 200 rig mats in soft road areas. Stop for 1/2 hr at I , 1C turnoff to leapfrog mats. Arrive MPU turnoff at 1800 hrs 18:00 - 00:00 I 6.00 MOB P PRE WO TS to leapfrog and set mats on road SW S convert stuffing box and injector for 2-3/8" CT Nordic inspect derrick 7/27/2007 00:00 - 03:45 ! 3.75; MOB P PRE Wait at MPU turnoff for rig mats to be staged ahead of rig for ' soft spots in the road before Z Pad turnoff 03:45 - 07:00 ! 3.25 MOB P PRE ~ Resume moving rig to Z pad turnoff 07:00 - 13:45 ', 6.75 MOB P PRE Wait at Z Pad turnoff for rig mats to be staged ahead of rig for soft spots in the road before Kuparuk River bridge. 13:45 - 21:00 I 7.25 MOB P PRE Resume moving on Spine Road towards GPB 21:00 - 00:00 ~, 3.00 MOB P PRE Turn off from Spine at Twin Towers and head toward West ~ Dock Rd. Go by TWA at midnite 7/28/2007 00:00 - 06:30 I 6.50 MOB P PRE Continue move from TWA to West Dock Rd. Stop at PAd 10 ~ for field and rig crew change. 06:30 - 18:15 ~, 11.75 MOB P PRE Move rig on to DS 5 accesss road. PJSM with CPS hands. Move onto DS 5. Raise and scope derrick. Move mats from access road to back side road. Prep area around wellhead. Spot herculite and rig mats. Move rig to BS of Pad and onto 18:15 - 19:30 ~ 1.25 MOB P PRE mats in front of well Rig crew change/safety mtgs/Prespud mtg while wo crane to ~ arrive. CPS is guiding crane under DS 5 access powerline. Safety mtg w/ VECO crane day crew. Spot crane. Safety mtg w/ VECO crane nite crew. 19:30 - 21:00 1.50 MOB P PRE Set 13-5/8" BOPE skid behind wellhead. Had to replace slings twice due to uneven lengths. RDMO VECO 140T crane I 21:00 - 22:00 1.00 MOB P PRE Safety mtg. Move rig over well, level up and set down ~ 22:00 - 00:00 2.00 RIGU P PRE Accept riq for operation at 2200 hrs 7/9R/~nm ~ RU to tree and IA to circulate. Spot cuttings box. Offload trailers Take on rig water and fuel 7/29/2007 00:00 - 02:30 2.50 RIGU P PRE Fin RU to circ. Fill lines w/ KCI water and PT @ 2500 MIRU satellite camp. Offload trailers. Offload 290 bbls 1% KCI in pits ~ SITP 0, IA 0, OA 185 02:30 - 04:45 2.25 RIGU P PRE Spot tiger tank. DSM RU hardline and PT. RU DSM lubricator and PT @ 500 psi. Pull CIW type H BPV w/ no press. RDMO DSM 04:45 - 06:00 1.25 BOPSU P ~ DECOMP MIRU LRS. PT Q 2500. Rev 40 bbls 110F diesel down the IA ~ taking crude returns from the tubing to the tiger tank at 1.37 bpm/400 psi. RDMO LRS 06:00 - 09:00 3.00 BOPSU P DECOMP Hold PJSM with crew to discuss pump job. Also check out manifold in cellar with crew to review how flow paths are j established. Rig displace diesel w/ 140 bbls 1% KCI at 502 psi Printed: 9/14/2007 10:09:50 AM ~ ~ ~ BP' EXPLORATION Page 2 of 27' Operatians Summa~y Report Legal Well Name: 05-28 Common Well Name: 05-28 Spud Date: 10/17/2001 Event Name: REENTER+COMPLETE Start: 7/26/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 8/29/2007 Rig Name: NORDIC 2 Rig Number: ' pate ' From - To Hours Task Code NPT Phase Description of Operations 7/29/2007 06:00 - 09:00 i 3.00; BOPSU ~ P DECOMP @ 4.9 bpm. Haul 150 bbls diesei and crude for recyle. 09:00 - 10:30 ''I 1.50 i BOPSU P DECOMP Circulate 250 bbls KCL water dn tbg taking rtns from IA. 10:30 - 11:30 1.00 BOPSU P PRE Set two way check valve in tbg hanger. Test from below to 1000 psi. 11:30 - 12:30 I 1.00 ~ BOPSU P PRE Hold PJSM after crew change. Discuss ND/NU and hazard I with live OA. 12:30 - 15:00 ; 2.50! BOPSU P PRE ND 4-1/2" tree and tubing head adapter. Remove from cellar. 15:00 - 00:00 ~I 9.00' BOPSU P PRE NU 13-5/8" BOPs. Install kill and choke lines, and all hydraulic lines. NU shooting flange on top of annular. SIMOP's 1900-2000 SWS load 2-3/8" E-CT from VECO lowboy into reel house I SWS mechanic investigate traction motor bearing noise w/ no ~ ~ ~~ ' ~ conclusions 7/30/2007 00:00 - 01:00 , 1.00 ~, BOPSU P PRE Finish NU 13-5/8" BOPE and shooting flange. Shell test to 3500 psi and found VBR ram door leaking 01:00 - 02:00 i 1.00 BOPSU P PRE Tighten all nuts on both rams doors and retest okay 02:00 - 06:45 4.75 BOPSU P PRE Test 13-5/8" BOPE 3500/250. The AOGCC waived the right to ~I witness the test 06:45 - 08:00 ' 1.25 ~ BOPSU P PRE PJSM to pull tools to floor and pull TWC. RU DSM lubricator. ~ ' Pressure test to 500 psi. Engage and pull two way check valve ' from tbg hanger. ND lubricator. Remove from rig floor. 08:00 - 13:00 5.00 I BOPSU P PRE Hold PJSM. ND SLB riser. ND shooting flange. NU riser and fiow line between annular and catch pan under rig floor. 13:00 - 15:00 2.00 PUL~ P DECOMP MU landing joint. Engage tbg hanger. Puil hanger to floor. i ~ Break out and LD same. 15:00 - 21:00 i 6.00! PULL P DECOMP Pull and lay down 4-1/2" tubing. Load out tubing, all in good ~ ~ '~ shape 21:00 - 00:00 3.00 '~~ BOPSU P WHDTRE Load one joint 5-1/2" tubing w/ mule shoe WLEG (41.2' OA) into pipeshed along w/ special 5-1/2" x 11" FMC tubing hanger w/ TC11 threads. Preload 5" Type H TWC. MU XO to hanger on 3-1/2 DP and land in tubing hanger. RfLDS. PT TWC to ~ 1000 psi from IA. Clear floor of tools 7/31/2007 00:00 - 00:20 0.33I BOPSU P WHDTRE Safery mtg re: ND riser, 13-5/8" BOPE and skid out 00:20 - 03:00 2.67 i BOPSU P WHDTRE ND and load out riser. ND 13-5/8" BOPE and skid out 03:00 - 03:15 0.25 ~~ i BOPSU P WHDTRE Safety mtg re: NU 7-1/16" BOPE assy 03:15 - 06:30 3.25 BOPSU P WHDTRE NU 11" x 7" DSA followed by two 7" Gray valves (master and swab) 06:30 - 09:30 3.00 BOPSU P WHDTRE Remove excess KCL from rig before moving. 09:30 - 10:30 ~ 1.00 BOPSU P WHDTRE Disconnect rig from misc equipment. Back off well. 10:30 - 11:00 0.50 j BOPSU P WHDTRE Spot 7-1/16" BOPs behind well head. 11:00 - 11:30 0.50 BOPSU P WHDTRE Move rig back over well. RU disconnected lines etc. Test same. 11:30 - 16:45 5.25 BOPSU P WHDTRE U the 7-1/16" BOPs. Connect hydaulic lines. MU kill and 16:45 - 21:00 ' 4.25 I BOPSU P WHDTRE Install rams for 2-3/8" operations 21:00 - 00:00 3.00 i BOPSU P WHDTRE PT MV, SV and BOPE 250/3500 against TWC. AOGCC did not return 3 calls over 24 hrs 8/1/2007 00:00 - 03:15 3.25 BOPSU P WHDTRE BOPE test per AOGCC regs. 03:15 - 03:30 0.25 W HSUR P WHDTRE PJSM prior to pulling TWC. 03:30 - 05:00 1.50 WHSUR P WHDTRE RU lubricator & pull 5" 'H' style BPV from profile in hanger. 05:00 - 05:15 0.25 'i RIGU P W EXIT PJSM prior to handling injector. 05:15 - 05:45 0.50 ~i RIGU P W EXIT PU stuffing box & stab onto well. PU & stab injector onto I , stuffing box. Printed: 9/14/2007 10:09:50 AM ~ • ~ BP EXPLORATION '' Page 3 of 27 Operations Summary Report Legal Well Name: 05-28 Common Well Name: 05-28 Spud Date: 10/17/2001 Event Name: REENTER+COMPLETE Start: 7/26/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 8/29/2007 Rig Name: NORDIC 2 Rig Number: ', Date ' l FrQm - To f Hours ~ Task Code 1 NPT ~ Phase ~'' Descri~tic~n of Ouerations 8/1/2007 05:45 - 06:00 ~ 0.25 RIGU ~ P 06:00 - 09:00 3.00 RIGU i P 09:00 - 10:45 1.75~ i RIGU P 10:45 - 13:45 3.00' RIGU P 13:45 - 14:00 0.25 RIGU P 14:00 - 15:20 1.33 DRILL P 15:20 - 17:50 2.50 DRILL P 17:50 - 19:30 1.67 DRILL P 19:30 - 19:45 0.25 DRILL P 19:45 - 21:00 1.25 ~ DRILL P 21:00 - 00:00 I 3.00; DRILL I P 8/2/2007 100:00 - 02:30 I 2.501 DRILL I P 02:30 - 02:35 0.08 DRILL P 02:35 - 03:40 1.08 DRILL P 03:40 - 04:20 I 0.671 DRILL I P 04:20 - 05:50 I 1.501 DRILL I P ~ _._ W EXIT Crew change/safety mtg WEXIT RU gooseneck and fin RU injector. Install internal grapple and PT. Pull CT to floor and stab W EXIT Fill CT w/ 1% KCI. Reverse slack back. PT packoff and inner reel valve C~3 3500 W EXIT Cut off 110' CT to find wire. Prep end of CT. Install Kendall CTC. PT 35k, 4000 psi WEXIT Safety mtg re: MU milling BHA W EXIT MU 4.75" D331 + motor + PH6 +jars + MW D WEXIT RIH w/ BHA #1 circ thru mill 0.2/100 w/ KCI taking wellbore returns to tiger tank W EXIT Log GR tie-in to PDC down from 11350' to tag W EXIT Lightly tag C~3 11,577ft. PU (42.5k up wt), make -5ft corr. Begin pumping Flo Pro @ 2.8bpm. WEXIT MiII LWP from 11,573 ft. <`Z~~ ,~~,~~. Q~~S~ TP = 2,750 psi off bottom Qp=2.76/2.78bpm Density = 8.65 / 8.61 ppg BHP = 4,315 psi at 8.89 ppg ECD WHP = 95 psi PVT = 218 bbl (Taking on fluid) WOB 0.1-0.3 klb ROP 3- 10 fph W EXIT Miiling on float collar. Let mill off & time drill. Mill float collar @ 11,616 ft, _ TP = 2,750 psi off bottom Qp=2.6/2.6bpm Density = 8.65 / 8.61 ppg BHP = 3,950 psi at 9.33 ppg ECD WHP = 59 psi PVT = 338 bbl WOB 1-1.8 klb Recovered rubber & fiber across shaker. W EXIT Continue milling on float collar. Let mill off & time drili. Mill float collar @ 11,617 ft. TP = 2,850 psi off bottom Qp=2.65/2.65bpm Density = 8.62 / 8.67 ppg BHP = 3,899 psi at 9.22 ppg ECD WHP = 59 psi PVT = 341 bbl WOB 1-2.8 klb WEXIT Larger chunks of rubber & fiber coming across the shaker. WEXIT Drilling now @ a faster pace, assume we have milled past the float collar now. Mill cement from 11,620 ft. _ TP = 2,850 psi off bottom Qp=2.57/2.55bpm Density = 8.62 / 8.65 ppg BHP = 3,892 psi at 9.20 ppg ECD WHP = 41 psi PVT = 339 bbl WOB 1.5-2.8 klb WEXIT Milling on shoe. Let mill off & time drill. Mill float shoe @ 11,663 ft. TP = 2,750 psi off bottom Qp=2.49/2.47bpm Density = 8.62 / 8.65 ppg BHP = 3,966 psi at 9.32 ppg ECD WHP = 59 psi PVT = 338 bbl WOB 2-4.0 klb W EXIT Drilling now @ a faster pace, assume we have milled past the Printed: 9l14/2007 10:09:50 AM ~ • ~ BP EXP'LORATION Operations Summary Repo Legal Well Name: 05-28 Common Well Name: 05-28 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 I ,; i I I I 8/2/2007 I 04:20 - 05:50 ~ 1.50 ~ DRILL ~ P Page 4 of Spud Date: 10/17/2001 Start: 7/26/2007 End: Rig Release: 8/29/2007 Rig Number: T Phase ~ D~~cription of Qperations ! W EXIT I shoe now 05:50 - 06:45 i 0.92 DRILL P ~ WEXIT 06:45 - 08:30 ~ 1,75 DRILL P ~ W EXIT 08:30 - 09:45 1.25 DRILL P W EXIT 09:45 - 11:00 1.25 DRILL P WEXIT 11:00 - 12:25 I 1.42 DRILL P PROD1 12:25 - 14:30 I 2.08 DRILL P I PROD1 14:30 - 15:00 0.50 DRILL P ~ PROD1 15:00 - 21:00 6.00 DRILL P ~ I PROD1 21:00 - 21:15 I 0.251 DRILL I P I I PROD1 21:15 - 21:40 ~ 0.42 ~ DRILL I P I ~ PROD1 21:40 - 00:00 ! 2.331 DRILL I N I DFAL I PROD1 8/3/2007 00:00 - 00:10 0.17 DRILL ' N DFAL PROD1 0~:10 - 01:45 1.58 DRILL N DFAL PROD1 01:45 - 02:30 0.75 DRILL N I DFAL I PROD1 02:30 - 04:30 2.00 ~ DRILL N DFAL PROD1 04:30 - 05:00 0.50 DRILL N DFAL PROD1 Mill outside 5-1/2" liner from 11,664 ft. ~ TP = 2,850 psi off bottom Qp=2.57/2.55bpm Density = 8.62 / 8.65 ppg BHP = 3,967 psi at 9.20 ppg ECD WHP = 41 psi PVT = 339 bbl WOB 0.5-2 klb Back ream/ream section from 11,680ft to 11,560ft. PVT 337 POOH 35k 2.8/3000 circ thru mili w/ full returns. Open EDC at 11000' to get more rate 3.24/3060 w/ 2.66 'ouY at 100'/min. OA reacts to ECD 188 psi static, 197 psi w/ 9.4 ECD POH from 3950' 3.28/2980 w/ 2.83 bpm 'ouY w/ minimal additional solids near surface LD miliing assy Change out DGS, add HOT. MU 4-1/4" bi-bit w/ 1.1 deg motor and MWD assy RIH w/ BHA #2 circ thru bit 0.2/680 Log MAD pass for GR down from 11630' to tag at 11690', corr -8' PVT 337 (start centrifuge) Drill from 11682' 2.7/3100/90L w/ 150 psi diff, 2k wob w/ 9.4 ECD. Had several initial stalls, then had occassional bit jet plugging. Drill ahead w/ avg 2.5/3250 FS. After 11695' had high vibrations so reduced rate to 2.44/2830 Took 3 hrs to driN to 11708' W iper to shoe - clean. W iper to bottom - clean. Getting magnetic interference i.e. no azimuth, perform fiow off check shot on bottom to verify tool is ok (high vibrations while pumping). Still getting magnetic interference with pumps off, however survey tool appears to be working fine. Drill ahead 20 ft to get father away from nearby casing & see if problem is related. Drillingfrom 11,800ft TP = 2,700 psi off bottom Qp=2.45/2.42bpm Density = 8.64 / 8.68 ppg BHP = 4,042 psi at 9.38 ppg ECD WHP = 48 psi PVT = 356 bbl WOB 1-2 kib ROP - 50-80 fUhr Centrifuges are running. Try multiple pump off check shots. Intermitant survey's, unable to get clean survey's. POH to change out tool. Open EDC inside 5-1/2" liner & pump 3.2bpm while POH. Getting spiraled shaped rubber chunks across shaker, possible stator rubber. Prep & new BHI tool on catwalk. MU new bi-center bit to new motor (1.1 AKO) on rig floor. PJSM regarding BHA handling while POH. Flow check well - no flow. Pop off well. Purge BHA w/ water & air. LD BHA on cat walk & break apart & replace survey tooi. MU & torque up BHI tool & test on catwalk. Single nozzle on bit was plugged with rubber. PU BHI tools & attach to motor. MU coil to BHI tools. MU injector to well. Set counters. Power up & test BHI tool. Open EDC & RIH pumping 2.71 bpm. Log for tie in Q 11620ft. (-14ft corr). Stop pumping & close Printed: 9/14/2007 10:09:50 AM ~ • ~ BP. EXF Qpera~ion~ ~ Legal Well Name: 05-28 Common Weil Name: 05-28 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 i i ~ i ~ a LORATION' Page 5 of 27 ummary Repart Spud Date: 10/17/2001 Start: 7/26/2007 End: Rig Release: 8/29/2007 Rig Number: ~se ~ Qescription o# C}peratiorrs ~ - D1 I EDC. D1 II Ream to bottom. TP = 2,660 psi off bottom IQp=2.49/2.51 bpm I Density = 5.65 / 8.67 ppg j BHP = 4,000 psi at 9.43 ppg ECD WHP = 51 psi ', PVT = 348 bbl WOB .1-.5 klb Centrifuges are running. High vibrations still causing tool to give bad surveys, otherwise tool works fine. Continue to ream to bottom before taking 'pump off' check shots. Take check shots and find that we are only getting 10 deg/100 in turn D1 I Drill from 11820' 2.78/3040/SOR w/ 100-200 psi diff, 1.0-1.5k ! wob w/ 9.42 ECD at 25 deg in Z4 at 30-70'/hr. Watch surveys ; closely and are still not getting planned turn (hardline boundary). Need to start build soon also. Drill to 11882' and li elect to trip for bigger bend motor D1 Wiper to shoe was clean D1 Park at 11640' to open EDC. Get it to 8% open, but can't close ~or fuily open it. WO lead MWD hand to arrive to get it fully ~open ~ D1 I POOH for bigger bend motor circ thru EDC 3.31/3000 w/ 2.72 i returns at 100'/min D1 I LD BHA. Changeout DGS and reconfigure above the DPS in II the MWD assy. Adjust motor to 1.4 deg. Bit was 1-1-I. Change to less aggressive HCC bi bit due to immediately entering Z3. MU BHA D1 RIH w/ BHA #4 circ thru bit 0.3/900 D1 Log tie-in down from 11640', corr -16' D1 Wiper to TD 2.75/2930 tagged at 11881' D1 Drill from 11881' 2.74/2880/20R w/ 100-200 psi diff, 0.5-1.5k ~ wob w/ 9.44 ECD at 25 deg and begin build D1 ROP has dropped. Go through motions to regain ROP. BHA wiper - clean. W iper to bottom - clean. D1 Drill from 11923' 2.44/2600/25R w/ 200-400 psi diff, 3-4.5k wob w/ 9.38 ECD. D1 Can't make any more hole. POH. Open EDC inside 5-1/2" liner. D1 PJSM regarding handling BHA while POH. D1 Tag up. Flow check well. D1 Pop off well. Place injector over bung hole. Kick drill. PU BHI tools. Change out bits. Recovered aluminum sheath from float shoe! MU injector to BHI tools. Stab onto well. Set counters. D1 Open EDC & RIH. D1 Log for tie in (-17ft corr). D1 Continue to RIH. D1 Drill from 11923' 2.44/2600/25R w/ 200-400 psi diff, 1-1.5k wob w/ 9.60 ECD. VP's=339. Centrifuge is running. Top of Z2 @ 11957', drill to 11989'. Have had hi vibration (5-6 on bottom, 2-3 off bottom) the whole run D1 PUH 35k, red rate to 2.2 bpm and no change to vibration. Drill from 11990' at 20'/hr, NBI is 36 deg. Penetration rate increased as more of Z2 was drilled. Drill to 12090'. Project to be 2 deg ahead on angle and will be well within the polygon on 8/3/2007 04:30 - 05:00 0.50 DRILL N DFAL PRO 05:00 - 06:00 1.00 DRILL P PRO 06:00 - 07:30 ~ 1.50 ~ DRILL ~ P ~ ~ PRO 07:30 - 07:45 ~ 0.25 DRILL N DPRB PRO 07:45 - 08:40 ( 0.92 DRILL N DFAL PRO 08:40 - 10:40 2.00 DRILL N DPRB PRO i0:40 - 13:25 2.75 DRILL N DPRB PRO I 1325 - 15:25 2.00 DRILL N DPRB PRO 15:25 - 15:45 0.33 DRILL N DPRB PRO 15:45 - 16:00 0.25 DRILL N DPRB PRO 16:00 - 21:45 5.75 DRILL P PRO 21:45 - 21:55 0.17 DRILL P PRO 21:55 - 22:10 0.25 DRILL P PRO ', 22:10 - 00:00 1.83 DRILL P PRO 8/4/2007 00:00 - 00:30 0.50 DRILL P PRO 00:30 - 00:40 0.17 DRILL P PRO 00:40 - 01:20 0.67 DRILL P PRO 01:20 - 03:30 ~ 2.17 DRILL P PRO 03:30 - 03:50 0.33 DRILL P PRO 03:50 - 04:00 0.17 DRILL P PRO 04:00 - 06:40 2.67 DRILL P PRO 06:40 - 09:40 I 3.001 DR~LL I P I I PRO Printed: 9/14/2007 10:09:50 AM . • . BP EXPLORATION Page 6 of 27 Qperatic~r~s Summary Report Legal Well Name: 05-28 Common Well Name: 05-28 Spud Date: 10/17/2001 Event Name: REENTER+COMPLETE Start: 7/26/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 8/29/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task C4de MPT Phase Descripfion of Operatic~ns 8/4/2007 06:40 - 09:40 'i 3.00 DRILL P PROD1 turn so this is the end of the correction run 09:40 - 10:00 0.33I DRILL P PROD1 Wiper to window 10:00 - 11:20 ! 1.33 ~ DRILL P PRODf POOH circ thru EDC 3.28/3160 11:20 - 12:20 ~I 1.001 DRILL P PROD1 Gen #1 had a hickup. SD pumps and power pack to start backup gen. Resume POOH 3.48/3000 w/ 2.8 bpm returns at ~ 80'/min. Hole cleaning appears to be good while drilling since few additionai solid are recoverd on trips 1220 - 13:00 13:00 - 16:30 I 8/5/2007 0.67 DRILL P PROD1 LD drilling BHA 3.50) DRILL N SFAL PROD1 Safety mtg re: SWS prep power pack, Nordic CDL , SWS drain hyd oil from power pack into tote. Nordic electrician remove electrical. SWS remove hyd hoses Nordic slip and cut 100' drilling line 0.50 DRILL N SFAL PROD1 MIRU Peak 90T crane. Remove roof from power pack housing. Remove power pack (14k) from house and set on ' Peak bed truck and take to SWS shop to swap out traction motor 17:00 - 22:00 I 5.00 i DRILL N SFAL PROD1 SWS clean up power pack housing 16:30 - 17:00 22:00 - 22:10 I i 0.17 DRILL N 22:10 - 00:00 ! 1.83 DRILL N 00:00 - 03:50 ~ 3.83 ~ DRILL N 03:50 - 04:55 I 1.08 I DRILL I N 04:55 - 05:00 05:00 - 06:00 0.08' DRILL N 1.00 DRILL P 06:00 - 07:00 07:00 - 09:05 09:05 - 09:25 09:25 - 09:50 09:50 - 10:00 10:00 - 10:35 10:35 - 10:50 10:50 - 12:40 12:40 - 14:50 1.00 DRILL P 2.08 DRILL P 0.33 DRILL P 0.42 DRILL P 0.17 ~ DRILL P 0.58 DRILL N 0.25 DRILL N 1.83 DRILL N 2.17 i DRILL N 2.33 DRILL N Nordic electrician check out gen #1 Nordic crew perform other maintenance tasks SFAL PROD1 Safety mtg re: Heavy lifting & installation of SLB power pack. Review ASH handbook per lifting ops. SFAL PROD1 Hoist power pack onto rig. Hoist roof covering power pack room back onto rig. Start hooking up components to power pack. SFAL PROD1 Continue working on traction motor. Replace electrical connectors going to traction motor. Hook up hoses & electrical connections. Fili up hydraulic tank. SFAL PROD1 Start up generators. Remove iock-out tag out on SCR's. Start up traction motor - no go. Trouble shoot motor, motor is wired backwards & produces a harley-davidson like sound! Perform lock out tag out. SFAL PROD1 Remove lock-out tag out and try traction motor again. Traction motor works! Trouble shoot remainder of minor problems. PROD1 PU injector with blocks. Close cattle chute. Fiil hole with c-pump (1 bbl to fill up). Remove tree cap, fluid @ surface. PROD1 MU driiling BNA w/ used bi bit and 1.1 deg motor PROD1 RIH w/ BHA #6 circ thru bit 0.3/940 PROD1 Log tie-in down from 11640' PROD1 Wiper to TD was clean PVT 315 PROD1 Resume drilling from 12090' 2.76/3100/5R w/ 100-250 psi diff, 0.5-2.Ok wob w/ 9.67 ECD continuing the build to land within 5' TVD above BSAD in 400'. Drill to 12092' and HOT is not working (no NBI) DFAL PROD1 Troubleshoot while PUH 5'/min 2.0/2320 and no solution DFAL PROD1 Wiper to window was ciean DFAL PROD1 POOH circ thru bit DFAL PROD1 LD drilling BHA. Change out HOT and test. Change bit due to vibration. Stab back on-toois did not test DFAL PROD1 LD drilling BHA again. Reconfigue and test okay. MU BHA. ~ Stab back on Found bad DPS tool which was also the assumed culprit on i BHA #6 17:10 - 19:15 2.08 ~ DRILL N DFAL PROD1 RIH w/ BHA #7 circ thru bit 0.36/970 19:15 - 19:30 ~ 0.25 DRILL N DFAL PROD1 Log tie-in down from 11640'. (-19ft corr). 14:50 - 17:10 Printed: 9/14/2007 10:09:50 AM • ~ , ' BP EXF Operations ~ Legal Well Name: 05-28 Common Well Name: 05-28 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 i ~ ~ ~ ~ 8/5/2007 19:30 - 19:50 ~ ~ 0.33I DRILL N 19:50 - 22:35 i 2.75 DRILL P 22:35 - 23:00 ~ 0.42 j ~ DRILL P 23:00 - 00:00 1.00 i i DRILL P 8/6/2007 00:00 - 01:00 1.00 ~ DRILL P I 01:00 - 01:45 i i 0.75 DRILL P i 01:45 - 02:10 i 0.42 DRILL P 02:10 - 02:20 0.17 i DRILL I P 02:20 - 02:35 i ~ 0.25 DRILL ~ P 02:35 - 02:45 '. 0.17I DRILL P 02:45 - 03:10 0.42 ~ DRILL P 03:10 - 04:30 1.33I i DRILL P 04:30 - 04:35 04:35 - 05:20 05:20 - 08:15 08:15 - 09:00 09:00 - 10:00 10:00 - 12:20 1220 - 13:50 13:50 - 15:55 15:55 - 16:15 16:15 - 16:35 16:35 - 16:50 16:50 - 18:55 18:55 - 19:20 19:20 - 19:25 0.08i DRILL P I OJ5I DRILL P 2.921 DRILL I P 0.75~ DRILL P 1.OOI DRILL P 2.33 STKOH P 1.50 STKOH P 2.08 STKOH P 0.33 STKOH P 0.33! STKOH P 025iSTKOH N 2.08I STKOH I N f 0.42 STKOH N 0.08 STKOH N Start: 7/26/2007 Rig Release: 8/29/2007 Rig Number: DFAI. PROD1 PROD1 PROD1 PROD1 iPROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 DFAL PRODi DFAL PROD1 DFAL PROD1 DFAL PROD1 Page 7 of Spud Date: 10/17/2001 End: Description of Opera#ions Wiper to TD. Tight spot from 12040ft to 12055ft (start of Zone 2). PVT 324. Drill from 12090' 2.56/3100/5R w/ 100-250 psi diff, 0.5-2.Ok wob w/ 9.62 ECD. Wiper to window. Pulled 12k over off bottom - otherwise clean to window. W iper to TD - ciean. Drill from 12234' 2.54/3000/30L w/ 100-250 psi diff, 0.5-2.Ok wob w/ 9.74 ECD. ROP slowed down from 90fUhr to 10fUhr @ 12,335ft. PU - 12k over pull. Resume drilling from 12335' 2.54/3000/5L w/ 100-250 psi diff, 0.5-2.Ok wob w/ 9.67 ECD. Having problems sliding, elect for wiper trip, Pull heavy off bottom -15k over. Wiper to window, little motor work @ 12,020ft, otherwise clean. Elect to log for tie due to numerous overpuils while drilling. Stop POH while @ shoe. Stop pumping & open EDC. Jet max rate while PUH to 11,OOOft to further remove cuttings/solids from well. RIH from 11,OOOft. Log tie-in down from 11,640ft (+2.5ft corr). Stop pumping & close EDC. W iper to TD - clean. Resume drilling from 12365' 2.54/3000/15L w/ 100-250 psi diff, 2.5-3.5k wob w/ 9.64 ECD. PVT = 312 Max downhole TEMP thus far is 120 degrees. Problems sliding/stacking weight & differential sticking off bottom (-15k over). Order mud from MI. Eiesume drilling from 12422' 2.63/3300/ w/ 200-350 psi diff, 2-3.Ok wob w/ 9.69 ECD. Upon further review of geological data on hand, we have drilled into the BSAD. Town/team asset has decided to sidetrack. Ensure hole is clean & POH. LD drilling BHA SWS change out electrical depth encoder and test WO BOT to do machine work on anchor for OH WS prior to installion by BTT Bring BTT WS assy to floor and prep. Add HOT to BHI MWD assy. MU MWD assy RIH w/ BHA #8 circ thru EDC 0.25/860 11600' 39.Ok Log tie-in down from 11645', corr -12'. Close EDC RIH thru open hole w/ WS, clean Park at 12161'. Pressure up on CT to 1850 psi and lost pressure quickly. Should have pressured up to 3600 psi before tool stroked. PUH 43k to verify released for 5'. RBIH to stack wt to 12166' and wouldn't take wt Attempt to pressure up again and had just circ press. PUH 42.7k w/o drag for 20'. Open EDC POOH thru open hole circ 0.45/1000 POOH thru 5-1/2" liner. Had no overpulls anywhere PJSM while POH with whipstock. Tag up, ciose EDC, power down tools. Printed: 9/14/2007 10:09:50 AM • ~ _ BP EXPLORATIf)N Page 8 of 27' Operations Summary R~pctrt Legal Well Name: 05-28 Common Well Name: 05-28 Spud Date: 10/17/2001 Event Name: REENTER+COMPLETE Start: 7/26/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 8/29/2007 Rig Name: NORDIC 2 Rig Number: i ' Date ' From - To Hours Task Code ~ NPT Phase I E}escription of Operations 8/6/2007 19:25 - 19:30 0.08 STKOH N DFAL PROD1 19:30 - 20:50 1.33, STKOH N DFAL PROD1 20:50 - 20:55 I 0.08) STKOH I N I DFAL I PROD1 20:55 - 23:00 I 2.081 STKOH I C 23:00 - 23:15 0.25 STKOH C 23:15 - 00:00 0.75 STKOH C 8/7/2007 00:00 - 00:35 0.58 ( STKOH C 00:35 - 02:40 2.08 ~ STKOH C 02:40 - 02:50 i 0.17 STKOH C 02:50 - 03:25 I 0.58 STKOH C 03:25 - 04:30 1.08 STKOH C 04:30 - 05:10 0.67 STKOH C 05:10 - 06:00 0.83 STKOH C 06:00 - 10:30 4.50 STKOH C 10:30 - 10:45 0.25 STKOH C 10:45 - 11:20 0.58 STKOH C 11:20 - 11:50 I 0.50 I STKOH I C 11:50 - 12:00 ~ 0.17 I STKOH ~ C 12;00 - 12:30 0.50 STKOH C 12:30 - 13:00 0.50 STKOH C PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 13:00 - 13:10 0.17 STKOH C , PROD1 13:10 - 15:30 2.33 STKOH C PROD1 15:30 - 15:45 0.25 STKOH C PROD1 Flow check well. Pop off well. Move injector over bung hole. Pull BHA out of hole - OH WS is not on tool setting tool, setting tool is fully stroked. Break off setting tool & place BHI tool sin weli. Purge BHI tools with air & water. Fluid @ bottom of BOP's, close swab.LD BHI tools on catwalk. PU BOT setting tool & service break it. send setting tool down beaver slide. Pressure test coil to 4000 psi - good test. BHI pressure tested tool string to 2100 psi - good test. Confirm with BOT that there was no problems with OH WS setting tool. Order 18jts of 2-3/8" PH6. Order cement from SLB - SLB blending & testing @ lab. Convert elevators to handle 2-3/8" PH6. Load 18jts of 2-3/8" PH6 into pipe shed & tally/drift it. Break UQC from end of coil connector. Prep end of e-line with protective boot. Set injector over bung hole. PJSM regarding handling PH6 tubing. MU cement dump nozzle & PU/RIH with 20 jts of PH6 tubing. Continue MU BHA. PU injector & MU to BHA. Stab injector onto well. Set depths. RIH & circ 0.94bpm @ 1348 psi. Make -15ft correction. Continue RIH. Appears that we are nushina the OH WS dnwn hole startina @ 11970ft. OH WS won't go down any further, try 3 times. Tr q Of OH WS is at 12408ft. PUH & wait for cementers. Up WT = 43k. Park coil at 11,600ft. Wait on cementers & Iab results. PJSM regarding cementing ops. Ru cementers hardline & RU rig water hose to cement pump truck. Back in rinsate vac truck. Cementers are taking on fluid & priming up. Wait on lab results. Update from SLB lab regarding cement, reconfigure & retest cement in lab. Results in - 3-4 hrs. Safety mtg re: cementing RIH from 11630' circ 1.0/1500 while cementers finish prep to pump cement. SWS cementers pump 5 bbis FW, PT @ 4000. Cement to wt at 1120 hrs Cementers load CT w/ 10 bbls 17.0 ppg G cement w/ 4:15 TT at 2.2/2130 and displace w/ 5 bbls FW. Rlg displace w/ mud 1.52/1500 while retag at 12407'. PUH 43k, 2-5'/min while incr rate 2.24/1730 and displace cement to nozzle Cement at nozzle at 12350'. After 2 bbls out nozzle, red rate to 1.0 bpm and lay in cement while PUH 60'/min. Had a few nice OP's, so incr rate to 1.5 bpm while PUH 75'/min. WCTOC calc @ 11740'. PUH to 11620'. CIP 1200 hrs .~-~--'+- PUH 6'/min circ 1.0/1400 while WOC RIH dilutinq/washinq out cement w/ mud 3.0/3200 at 30'/min to POH thru OH 3.0/3030 at 35'lmin POH chasing cement to surface 3.0/2960, Divert 30bbls of high PH returns to cuttings box. Tag up. Divert returns to TT to clean up choke manifoid (dead ~ legs), purge with air as required. Printed: 9l14/2007 10:09:50 AM , • . BP EXPLORATION Page 9 of 27 Qperations Summary Repc~rt Legal Well Name: 05-28 Common Well Name: 05-28 Spud Date: 10/17/2001 Event Name: REENTER+COMPLETE Start: 7/26/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 8/29/2007 Rig Name: NORDIC 2 Rig Number: Date ' From - To Hours Task Cade NPT Phase '~ Description of Operations ~ 8/7/2007 15:45 - 15:55 0.17 STKOH C ~ PROD1 i PJSM regarding laying down 20 jts of PH6. 15:55 - 17:45 1.83 STKOH C PROD1 , LD PH6 tubing horizontai. Prep end of e-line cabie to reverse ~i~ circulate. Stab back onto well with injector. I 17:45 - 18:15 0.50 STKOH C PROD1 I Pump slack back into reel. ~ 18:15 - 18:25 0.17 STKOH C PROD1 ~ I Bleed off. C/O with night crew. 18:25 - 18:35 0.17 STKOH C I I PROD1 PJSM regarding cutting coil & re-heading. 18:35 - 19:30 0.92 STKOH C , ; PROD1 ~ C/O injector packoffs & clean out injector sump. Pop injector ' ; off well. PU hydraulic tubing cutter. 19:30 - 20:00 0.50 STKOH C i PROD1 ~ Begin cutting coiL Cut 350 ft wire and 370 ft coiled tubing i i (3.37% slack) CT 14,822 ft 20:00 - 23:00 3.00 STKOH C PROD1 RD cutter, make hand and test wire 47 ohms Installed dimple ; CTC and pull test to 35k. Reheaded UQC and tested li connection. 14 mega ohms. PU RR HYC Bit with 1.37 deg , j bend w/ BHI's CoilTrac system. Stab on well 23:00 - 00:00 1.00 STKOH C ; PROD1 I RIH to 300 ft and open EDC. Inc Qp to 3.00 bpm. CTP-3439 8/8/2007 ~ 00:00 - 01:15 1.25 STKOH C ~~ ', PROD1 ' psi RIH 01:15 - 01:30 0.25 STKOH C I PROD1 Log tie in at 11,640 ft MD. Corrected -11 ft. Orient TF to HS and closed EDC 01:30 - 01:50 0.33 STKOH C PROD1 RIH looking for cement to sidetrack off of Seen tight spot at 12,040 ft. Clean below 12,060 ft Wt check at 12,100 ft MD = ~I 38k, RIH and tagged hard cement at 12,139 ft, stalL Cement ~ at 2000 psi compressive strength at 22:00 hrs 8/7/2007 01:50 - 02:15 0.42 STKOH C ~ PROD1 ; ~ Orient TF to 25 R and drill moderate to soft cement from i ~ 12, i 39 ft to 12,144 ft. W ork BC bit down to T~C at 12,139 ft ? ; Working way in the hole looking for constant hard cement. ~ Stall at 12,142 ft. RIH at lfpm with Iittle or no DHWOB. Need to be sidetrack at 12,164 ft. Qp=2.61/2.60bpm CTP = 3200 psi off bottom BHP 4750 psi 9.9 ppg ECD 02:15 - 02:40 I 0.42 STKOH C PROD1 PUH due to soft cement at 12,145 ft 02:40 - 05:30 2.83 STKOH C PROD1 ~ Circulate and WOC at 1.57 bpm through open EDC 05:30 - 05:45 0.25 STKOH C PROD1 SD pump and closed EDC, orient TF to HS, RIH to check j cement compressibiiiy I Tagged at 12,144 ft set down 8k. PUH and increased the Qp to ~ 2.5 bpm 05:45 - 06:00 0.25 STKOH C PROD1 Drilling cement 1 fph with 500 Ib DH WOB, ROP 1 fpm / 60 fph. Drilled from 12,144 ft to 12,148 ft. Cement still soft but, I better than uo hole. 06:00 - 09:00 3.00 STKOH C PROD1 PUH to WOC. 09:00 - 09:25 0.42 STKOH C PROD1 Close EDC & RIH. 09:25 - 10:05 0.67 STKOH C PROD1 i Orient TF to 30-40R and drill from 12,148ft to 12162ft ~ QP=2.62/2.65bpm CTP = 3200 psi off bottom BHP = 4432 psi 9.95 ppg ECD Ease down to bottom. Start drilling @- 30fUhr with 3001bs WOB with 150psi motor work. Stalled @ 12148.9ft. PU & ~ resume drilling with 800-10001bs WOB & 200 psi motor work Q ~ 30fUhr. 10:05 - 11:15 1.17 STKOH C PROD1 j Begin time drilling. Start driling with 30R TF Q 1 Whr from I12,162ft Printed: 9/14/2007 10:09:50 AM ~ s +~ ' BP'' EXPLORATION ` ' Page 10 of 27 ` Uperations Surnmary Report Legal Well Name: 05-28 Common Well Name: 05-28 Spud Date: 10/17/2001 Event Name: REENTER+COMPLETE Start: 7/26/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 8/29/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Coeie NPT Phase ~ Deseription af Qperations 8/8/2007 11:15 - 1225 ~ 1.17 STKOH C PROD1 Start driling with 30R TF @ 2ft/hr from 12,163ft. Stalled @ ~ 12,163.2ft. PU & RIH, set down & stop @ 12,162.2ft - have 700 ! Ibs WOB & 200 psi motor work. 12:25 - 12:50 0.42 STKOH C PROD1 I Should b. Kn'ci intn Sirlatrack nnW. Start driling @ 3ft/hr from i 12,164Jft. Now seeing -500 to 7001bs WOB & 100 psi motor work. 12:50 - 13:30 0.67 STKOH C PROD1 Start drilling with 30R TF @ 5-9fUhr from 12,166.5ft. Getting 100 psi motor work & 300-5001bs WOB. j 13:30 - 13:50 0.33 STKOH C PROD1 ~ Start drilling with 30R TF @ 20fUhr from 12,171ft. Getting 200 ' psi motor work & 400-600ibs WOB. Stacking WOB @ 12174ft, I appears that we are drilling on hard formation that correlates with previous drifling ROP spike at this depth. 13:50 - 14:15 0.42 STKOH C PROD1 Start drilling with 30R TF @ 40-50fUhr from 12,180ft. Getting 300 psi motor work & 700-10001bs WOB. ~ 14:15 - 14:50 0.58 STKOH C PROD1 ; Turn TF to straight up to build angle - follow directionai plan. I ~ Appears that we are kicked off & sidetracked, according to NBI ~, & now/versus previous drilled hole. QP=2.62/2.65bpm CTP = 3200 psi off bottom - 200-300psi diff li BHP = 4432 psi 9.88 ppg ECD ,600-10001bs WOB I 14:50 - 16:00 1.17 STKOH C PROD1 ~ Perform pump off survey check. Survey says; we are sidetracked. Call for new mud from MI. Continue to drill 10ft ahead. Bottom's up sample from 12,166ft is sand per Geo. BHI is re-configuring database on computer to adopt changes for sidetrack. 16:00 - 21:00 5.00 STKOH C PROD1 Drill build section from 12,222ft with TF 15R. ~QP=2.62/2.65bpm I CTP = 3200 psi off bottom - 200-300psi diff ~ BHP = 4446 psi 9.81 ppg ECD 1.5-2.5klbs WOB, 25-40ft/hr ROP 10-80 fph 21:00 - 22:05 1.08 STKOH C PROD1 Driiling Build Section Qp = 2.6 / 2.6 bpm CTP = 2966 psi (OB) 200-300 psi diff BHP = 4454 psi 9.88 ppg ECD WOB = 1.5 to 2.5 klbf; ROP 20-60 fph Having troubie sliding due to mud condition 22:05 - 23:20 1.25 STKOH C PROD1 Wiper trip to shoe while RU to conduct mud swap. Started mud swap 23:20 - 00:00 0.67 STKOH C PROD1 Drilling Build Section TF at H to 15L Qp = 2.58/ 2.59 bpm CTP = 3164 psi (OB) 200-300 psi diff BHP = 4454 psi 9.88 ppg ECD WOB = 1.5 to 2.5 klbf; ROP 20-60 fph 8/9/2007 00:00 - 01:15 1.25 STKOH C PROD1 Drilling Build Section TF at H to 20L Qp = 2.60/ 2.60 bpm CTP = 3164 psi (OB) 200-300 psi diff BHP = 4354 psi 9.71 ppg ECD WOB = 1.5 to 2.5 klbf; ROP 20-70 fph Having to PU to get survey. DH Vibration is causing the problem. New mud around. 01:15 - 01:30 0.25 STKOH C PROD1 Work CT to try and get a survey around 12,315 ft bit depth 01:30 - 03:45 2.25 STKOH C PROD1 Drilling Build Section TF at H to 20L. Zone IA Try and land at 8,717 ft Qp = 2.60/ 2.60 bpm CTP = 3100 psi (OB) 200-300 psi dift BHP = 4342 psi 9.61 ppg ECD Printed: 9/14/2007 10:09:50 AM y i ~ BP' EXPLt3RATION' Page 11 of ~7'' Operatrons Summary Repor# Legal Well Name: 05-28 Common Well Name: 05-28 Spud Date: 10/17/2001 Event Name: REENTER+COMPLETE Start: 7/26/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 8/29/2007 Rig Name: NORDIC 2 Rig Number: i ~ i i ~ i i 8/9/2007 01:30 - 03:45 2.251 STKOH C I 03:45 - 06:45 ~I 3.00 ~ STKOH N 06:45 - 06:55 0.17 STKOH N 06:55 - 07:00 0.08 STKOH N 07:00 - 07:25 ; 0.42 STKOH I N 07:25 - 08:00 ', 0.58 ~ STKOH ~ N 08:00 - 10:15 I 2.251 STKOH ~ N 10:15 - 10:35 0.331 STKOH N 10:35 - 11:05 0.50 ~ STKOH N 11:05 - 14:05 3.00 STKOH C PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 DFAL PROD1 PROD1 PROD1 PROD1 WOB = 1.5 to 2.5 klbf; ROP 20-90 fph. Pressure inc to 4400 psi acts like the motor is shedding the rotor Circulating pressure changes 1100 psi while working CT and then There is 30 stalis on motor at present. Unable to drill POOH to look at restriction causing the motor to pressure up. Projection at bit is 89 deg at 8,713 ft TVD Qp = 2.60 / 2.37 bpm at 22 fpm through open hole section Slowed down at 11,660 ft, orient TF to HS. Reduced Qp to 0.5 bpm and pull through liner shoe Increase Qp to 3.00 / 2.78 bpm at 90 fpm and POOH PJSM regarding handling BHA. Flow check well. Pop off weU. Break off BHA. Milk motor - feels fine. Break off bit, bit is plugged with rubber. MU used hughes bi-center bit to new 1.1 AKO motor. PU & MU to BHI BHA. PU injector & stab onto tools. Stab injector onto well. Power up & test tools. Set depths. Circ through bit for 2 bbls to ensure there is no blockage/test mud motor. Stop pumping & open EDC. RIH circulating @ 3bpm. Log down for tie-in from 11,640ft (-13ft corr). Wiper to bottom - clean. Drill from 12,405ft TF at 150L. Zone IA Try and land at 8,717 ft Qp = 2.58 / 2.58 bpm CTP = 2754 psi (OB) 200-300 psi diff BHP = 4343 psi 9.60 ppg ECD WOB = 1.5 to 3.5 klbf; ROP 10-15 fph. Problems sliding, make up lubricious pill. Drili from 12,442ft TF at 60L. Zone IA Try and land at 8,717 ft Qp = 2.75 / 2.69 bpm CTP = 3130 psi (OB) 200-300 psi diff BHP = 4379 psi 9.67 ppg ECD WOB = 1.5 to 4.5 klbf; ROP -10 fph. ifferential stickin - no signs of packing off. Shut pumps offs & let coil relax for 5 min. Try to move coil - no go. Try pumping & moving, again no signs of packing off. Shut pumps offs & let coil relax again tor 15-20 min. Popaed free - differential 14:05 - 14:25 'i 0.33 ~ STKOH I C 14:25 - 14:55 I 0.50 I STKOH I C 14:55 - 15:42 0.78 STKOH C 15:42 - 16:30 0.80 STKOH C 16:30 - 18:55 ~ 2.42 I STKOH ~ C 18:55 - 19:39 i 0.731 STKOH I P PROD1 Elect to let bottom section of hole relax. PUH & wiper to shoe circulating @ 2.67bpm. W iper to window was clean. PROD1 Wiper to bottom - clean. Bottom's up sample was a mixture of 90% sand & 10%siltstone, nothing definative. PROD1 Drill from 12,442ft TF at 60L. Qp = 2.64 / 2.63 bpm CTP = 3120 psi (OB) 300-500 psi diff BHP = 4379 psi 9.76 ppg ECD WOB = 1.5 to 4.5 klbf; ROP 10-20 fph. Stall - clean pick up. Resume drilling. PROD1 Problems sliding again (stacking weight on surface & no WOB). ROP is inconsistant, surveys say we are skipping across something & not able to drop angle. Continue to drill ahead..... Drill from 12,470ft TF at 115L. Qp = 2.64 / 2.63 bpm CTP = 3120 psi (OB) 300-500 psi diff BHP = 4379 psi 9.76 ppg ECD WOB = 1.5 to 4.5 klbf Printed: 9/14/2007 10:09:50 AM ~ ~ ~ BP`` EXPLORATI Operations Summai Legal Well Name: 05-28 Common Well Name: 05-28 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 ~ ,~ ,~ r ~ , 8/9/2007 19:39 - 21:00 1.35 i STKOH P ~ 21:00 - 21:30 I 0.501 STKOH I P 21:30 - 00:00 I 2.50 I STKOH I N 8/10/2007 I 00:00 - 00:30 I 0.50; STKOH I N 00:30 - 01:45 I 1.25 I STKOH i N 01:45 - 04:08 I 2.38I STKOH N 04:08 - 04:30 i 0.37' STKOH N 04:30 - 05:05 ~ 0.58 !, STKOH N 05:05 - 05:45 I 0.671 STKOH ; P 05:45 - 08:10 I 2.42 I STKOH I P 08:10 - 12:10 I 4.001 STKOH i P 12:10 - 13:00 I 0.83 ~ STKOH I P PROD1 PROD1 PROD1 W iper trip. Some motor work at 12,200 ft to 12,170 ft. Motor work at 12,120 ft in the shale section RIH This motor is starting to act like the other one Safety Stand down with Night Crew with Lowell Crane and pat Archey Drill from 12,484ft TF at 110L. Qp = 2.58 / 2.68 bpm CTP = 3120 psi (OB) 300-500 psi diff BHP = 4436 psi 9.79 ppg ECD WOB = 1.5 to 4.5 klbf; ROP 10-20 fph. Stall - clean pick up. After 20 stalis the motor started acting like the other motor pulled. POOH. Rig went black at 8,800 ft while POOH. POOH using Gen 2& 3 Qp=4.2/3.2bpm POOH, Held PJSM on BHA handling and identify the hazards and mitigated the same LD BHA and change O-ring. Inspect motor and bit. large chunck of stator rubber in bit. PU new motor set at 1.1 and RB HCC BC Bit. Changed o-rings on LQC RIH Tied in at 11,640 ft and corrected -13.5 ft RIH and tagged at 12,484 ft Qp = 2875 psi at 2.6 bpm at 12483 ft Drilling lateral looking for some sand. TF at 120L API values are approving Qp = 2.59 / 2.58 bpm CTP 2875 / 3252 psi DHWOB = 2.0 k to 3.Ok BHP = 4354 psi at 9.62 ppg ECD PVT = 337 bbl ROP at 25 fph The fire alarm went off at 07:30am in the rig camp. All camp attendants went to muster point & all were present. Upon exiting the camp, it was noticed that a computer bag was placed in front of a heater in the hall way leading to the escape route. No visible smoke was present however it could be smelt. The heater was turned off & the computer bag was removed from the area. A call was made to 659-5634 to report the alarm incident. Starting to lose fluid to formation -.1 bpm. Drill ahead from 12558ft TF - 90L. QP=2.65/2.53 CTP 2900 / 3000 psi DHWOB 0.5-lklbs BHP = 4371psi @ 9.66 ppg ECD PVT = 322 bbls ROP 10-20 fph Start and try to build angle, interpolation TVD is - 8718ft Drill ahead from 12574ft to 12660 ft. QP=2.65/2.53 CTP 2900 / 3000 psi DHWOB 0.5-lkibs BHP = 4371psi @ 9.66 ppg ECD PVT = 322 bbls ROP 10-20 fph W iper trip to shoe. Tight spot @ 12593ft (pulled heavy), Page 12 ~rt Spud Date: 10/17/2001 Start: 7/26/2007 End: Rig Release: 8/29/2007 Rig Number: PROD1 PROD1 DFAL PROD1 DFAL PR~D1 DFAL PROD1 DFAL . PROD1 PROD1 DFAL PROD1 PROD1 Printed: 9/14/2007 10:09:50 AM . ~ ~ BP EXPLORATION '': Page 13 of 27 Operations Surnmary R~part Legal Well Name: 05-28 Common Well Name: 05-28 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 --~ 8/10/2007 12:10 - 13:00 0.83 STKOH ( P I 13:00 - 13:45 0.75 STKOH P 13:45 - 16:00 2.25 STKOH P 16:00 - 17:40 I 1.671 STKOH I P 17:40 - 18:40 1.00 STKOH ; P 18:40 - 19:05 0.42 ~ STKOH ~ P 19:05 - 20:00 0.92' , STKOH P 20:00 - 22:25 2.42 STKOH P 22:25 - 23:20 ~ 0.92 ~ STKOH ~ P 23:20 - 00:00 0.67 STKOH P 8/11/2007 00:00 - 01:15 1.25 STKOH P 01:15 - 03:15 2.00 STKOH P 03:15 - 03:35 0.33 STKOH P 03:35 - 04:55 1.33 STKOH P Spud Date: 10/17/2001 Start: 7/26/2007 End: Rig Release: 8/29/2007 Rig Number: NPT Phase D~scription of Operations PROD1 12510ft (pulled heavy), 12440ft (motor work, no over pull)- all do not appear to be tool face related. PROD1 Wiper to bottom. Motor work @ 12,460ft. Set down @ 12487ft. Work through areas. j PROD1 Drill ahead from 12660ft to 12780 ft. '~ QP = 2.65 / 2.61 (1:1 returns now) CTP 2900 / 3200 psi DHWOB 0.5-lklbs BHP = 4435psi @ 9.79 ppg ECD PVT = 321 bbis I ROP 10-90 fph i PROD1 Stalled....BHA wiper trip.... CTP free spin is 200 psi higher.... Resume Drilling Drill ahead from 12780 ft to 12838 ft. QP=2.65/2.61 CTP 3300 / 3500 psi ; DHWOB 0.5-lklbs BHP = 4500psi @ 9.94 ppg ECD i ~ PVT = 329 bbls (pumped 12bb1 lubricious pill) ~ ROP 10-59 fph PROD1 Wiper to window. PROD1 Tie-in at 11,630 ft. Corrected +5 ft. SD pumps and closed EDC II PROD1 RIH Two spot 12,400 ft and 12,440 ft the CTP 300 psi higher. ~ Tagged at 12,842 ft i PROD1 Drill ahead at TF = 90R from 12,842 ft to 12920 ft ~ QP=2.65/2.65bpm CTP 3310 / 3486 psi DHWOB 0.5-1 kibs BHP = 4435psi @ 9.79 ppg ECD PVT = 317 bbls ROP 50-90 fph ~ Shut down cleaning of rig due to issues with the Nordic's i scaffording and Schlumberger rig personnel j PROD1 Seen some shale evidence, turned TF to 45 deg RHS Drill ahead at TF = 90R from 12,920 ft to QP=2.65/2.65bpm CTP 3310 / 3250 psi DHWOB 0.5-1 klbs BHP = 4487psi @ 9.92 ppg ECD PVT = 312 bbls ROP 20-90 fph Stacking PROD1 Wipertrip PROD1 Finished wiper trip PROD1 Drill lateral from 12942 ft to 13026TF = 75R ~ Qp = 2.61 / 2.60 bpm CTP 3200 / 3460 psi DHWOB 0.5-lklbs BHP = 4487psi Q 9.92 ppg ECD PVT = 307 bbls ROP 20-90 fph PROD1 100 ft wiper trip PROD1 Drill lateral from 13026 ft to TF = 120R Qp = 2.62 / 2.58 bpm, could be lossing a smail amount of fluid CTP 3200 / 3460 psi DHWOB 0.5-lklbs BHP = 4487psi @ 9.92 ppg ECD PVT = 304 bbis i ROP 20-90 fph Printed: 9/14/2007 10:09:SO AM . ! • BP` EXPLORATION Page 14 of 27' ; Qperations Summary Repart Legal Well Name: 05-28 Common Well Name: 05-28 Spud Date: 10/17/2001 Event Name: REENTER+COMPLETE Start: 7/26/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 8/29/2007 Rig Name: NORDIC 2 Rig Number: Date : From - To Haurs Task Code NPT Phase ~~! ~escription of Operations 8/11/2007 04:55 - 07:00 2.08 STKOH P PROD1 W iper trip to window, slight motor work & tight @ 12,380ft & ; 12,346ft. Wiper to bottom - slight motor work & tight @ 12,346ft & 12,380ft & 12,888ft & 12,905ft. 07:00 - 11:25 4.42 STKOH P ~ '~ PROD1 ~ Drill lateral from 13100 ft to TF = 90R i Qp = 2.61 / 2.58 bpm ~ CTP 3200 / 3460 psi ~ DHWOB 0.8-1.9klbs BHP = 4480psi Q 9.91 ppg ECD ~ PVT = 296 bbls ; ROP 20-90 fph 11:25 - 13:00 1.58 STKOH P ; PROD1 Wiper trip to shoe. Had motor work Q 12,468ft & 12,498ft. 13:00 - 13:10 0.17 STKOH P ~ PROD1 Log down for tie-in (+4ft). 13:10 - i3:45 0.58 STKOH P PROD1 I Wiper to bottom - clean. 13:45 - 17:40 3.92 STKOH P PROD1 ~ Drill lateral from 13253 ft to 13400 TF = 90L i Qp=2.66/2.58bpm CTP 3200 / 3460 psi DHWOB 0.8-1.9klbs BHP = 4535psi Q 10.03 ppg ECD PVT = 279 bbls i i ROP 20-90 fph 17:40 - 20:00 2.33 STKOH P ' ' ~, PROD1 Wiper trip to shoe. I, RIH and set down twice at 12444 ft with motor work Worked ~ through at 1.00 bpm i RIH at 2.00 bpm 20:00 - 20:15 0.25 STKOH P PROD1 ' I Drill lateral from 13253 ft to 13418 TF = 90L Qp = 2.52 / 2.45 bpm TF 110L ~ CTP 3200 / 3460 psi ' DHWOB 0.8-1.9klbs BHP = 4535psi @ 10.03 ppg ECD ~ PVT = 279 bbls Conducting mud swap after tagging bottom ~ i ROP 50-90 fph. I Pulled 72k at 13,409 ft to get free. TVDss at 8705 ft projected 20:f5 - 20:30 0.25 STKOH P PROD1 Wiper to clean up 20:30 - 22:25 1.92 STKOH P PROD1 Trying to drill lateral from 13,418 ft to 13,492 ft TF = 90L Lots of stacking with new mud around Qp = 2.52 / 2.45 bpm TF 110L CTP 3200 / 3,460 psi I DHWOB 0.8-1.9klbs CTW = Ok BHP = 4535psi @ 10.03 ppg ~ ECD PVT = 279 bbls Conducting mud swap after tagging bottom ROP is a function if i can get wt WOB, grabby formation ROP ~ at 110-120 fph ! Hold 89 deg hole angle until 8,907 ft TVD is reached. Not much luck drilling, stacking 22:25 - 00:00 1.58 STKOH P ~ PROD1 W iper to shoe 8/12/2007 00:00 - 01:15 1.25 STKOH P ~ PROD1 RIH and set down at 12,850 ft worked throug. RIH with small ~ set down. 01:15 - 02:00 0.75 STKOH P PROD1 Drili lateral from 13492 ft to 13,497 ft TF = 80L Qp=2.60/2.64bpm ~ CTP = 2690 / 2736 psi ~ DHW OB = 0.8-1.9klbs i BHP = 4363psi @ 9.65 ppg ECD ' PVT = 181 bbls Motor acts like its getting weak with all of the statl. CTP isn't increasing with 2k DHWOB Printed: 9/14/2007 10:09:50 AM ' ~ ~ BP'' EXPLORATION Opera#ions Summary Report Legal Well Name: 05-28 Common Well Name: 05-28 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 ~ i ~ ~ i ~ 8/12/2007 02:00 - 05:45 ~ 3.75 STKOH P 05:45 - 07:00 I 1.251 STKOH I P 07:00 - 07:50 0.83 STKOH P 07:50 - 08:15 0.42 STKOH P 08:15 - 09:45 09:45 - 09:55 09:55 - 11:00 11:00 - 11:55 1.50 STKOH P 0.17 STKOH P 1.08 STKOH P 0.92 STKOH P 11:55 - 12:15 I 0.331 STKOH I P 12:15 - 15:30 I 3251 STKOH I P 15:30 - 15:50 0.33 STKOH P 15:50 - 17:43 1.88 STKOH P 17:43 - 18:55 1.20 STKOH P 18:55 - 19:30 0.58 STKOH P Spud Date: 10/17/2001 Start: 7/26/2007 End: Rig Release: 8/29/2007 Rig Number: Phase ~ ; Description of Operatians PROD1 POOH to change bit and motor Pulied tight; 12,912 ft 12,457 ft, 12,440 ft, 12,350 ft; 12,217 ft SD pump at 11,680 and pull into liner. Open EDC and cir at 2.75 bpm while changing swabs in MP1 PROD1 ~ OOH, unstab injector head. LD Coiltrac and change out motor ~ and bit - bit was balled & numerous jets were plugged with ciay. Motor was hard/chunky to turn with wrenches. RU BHI mwd toois & new HYC bit. Stab coil onto tools & onto well. Power up & test tools. Set counters. PROD1 RIH. Open EDC @ 500ft & pump 2.8bpm while RIH. PROD1 WHP increased by -50psi. Stop RIH with coil & park coil Q 3909ft. Stop pumping & flow check well. Flow has stopped, watch for 5 min - a ok. Purge/blow down micro-motion - large debris coming across the shaker - aluminum, rubber & formation. Purge/blow down across kill/choke line to pits. Lines are clear. PROD1 , Continue RIH while pumping @ 2.87bpm. PROD1 ~ Log down for tie-in (-7ft corr). Close EDC. PROD1 ~ Wiper to bottom. Set down & work through 12948ft - 12970ft. PROD1 Drill lateral from 13497 ft to 13,497 ft TF = 85L Qp=2.67/2.64bpm CTP = 2900 / 2736 psi DHWOB = 0.8-1.9klbs BHP = 4389psi @ 9.69 ppg ECD ; PVT = 342 bbls PROD1 ' Picking up hole when all of a sudden..... the lights went out. Set reel brake. Get generators back on line. Slowly PU & start pumping @ 2.58bpm. PROD1 Drill lateral from 13497 ft to 13,529 ft TF = 85L Try to drop 2' TV D Qp = 2.58 / 2.51 bpm ~ CTP = 2730 / 2736 psi i DHWOB = 0.8-1.9kibs BHP = 4354psi @ 9.63 ppg ECD PVT = 339 bbls Pump 15 bbl lubricious pill PROD1 Wipertrip. PROD1 Drill lateral from 13529 ft to 13,559 ft TF = 130L Try to drop 2' ~ TV D Qp = 2.59 / 2.54 bpm CTP = 2730 / 3100 psi DHWOB = 0.8-2.5klbs BHP = 4383psi @ 9.69 ppg ECD i PVT = 331 bbls ~ Pump 20bb1 lubricious pill.- PROD1 W iper trip during crew change to 13,000 ft PROD1 Drill lateral from 13559 ft to 13576 ft TF = 130L Try to drop TVD down from 8,708 ft to 8,711 ft ND maintaining 88 deg hole angle. if sand is encountered, level out, if not, talk with town on plan forward. Several stalls while trying to get it to drill. ;Qp=2.59/2.54bpm ~i CTP = 2730 / 3100 psi I DHWOB = 0.8-2.3klbs Printed: 9/14/2007 10:09:50 AM ~ ~ ~ ,~ Legal Well Name: 05-28 Common Well Name: 05-28 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 _ I-' _ I I I_; 1: ;~, 8/12/2007 18:55 - 19:30 I 0.58 STKOH P PROD1 19:30 - 20:00 ', 0.50 STKOH P PRODi 20:00 - 20:45 I 0.75 I STKOH P PROD1 ~I I 20:45 - 00:00 I 3.25 STKOH N STUC PROD1 8/13/2007 I 00:00 - 00:40 ( 00:40 - 00:55 00:55 - 01:05 01:05 - 03:05 03:05 - 05:15 05:15 - 09:20 09:20 - 11:15 11:15 - 14:10 ' tXi-'LUFi/~ I lUN ` rage ~ tr wns Summary Report Spud Date: 10/17/2001 Start: 7/26/2007 End: Rig Release: 8/29/2007 Rig Number: Description o# Operations 0.67 STKOH N STUC PROD1 0.25 STKOH N STUC PROD1 0.171 STKOH I N I STUC I PROD1 2.001 STKOH I N I STUC I PROD1 2.171 STKOH I N I STUC I PROD1 4.081 STKOH I N I STUC I PROD1 1.921 STKOH I N I STUC I PROD1 2.921 STKOH I P I I PROD1 BHP = 4383psi @ 9.69 ppg ECD PVT = 326 bbis W iper Drill lateral from 13576 ft to 13,652 TF = 85L Drilled into sand at 13,548 ft leveled out at 90 deg and confirmed with town. Qp = 2.59 / 2.54 bpm CTP = 2730 / 3100 psi DHWOB = 0.8-2.3klbs BHP = 4383psi @ 9.69 ppg ECD PVT = 324 bbls ROP picked up to 120 fph PU and differentiai stuck at 13558 ft (on bottom} Work CT between 0 k and 74 k. Seeing no WOB, SD pump and allow formation to relax. After a couple times, seen O.8k WOB, orientor will turn, stuck somewhere above BHA on bottom at 13,651ft. Set wt down, WOB increased from 0.59k to 2.70 k. Seeing movement at DPS sub. SD pump several times to allow reseroior relax. Ordered 100 bbl dead crude. Mixed up and pumped 40 bbl 10% Lotorq pill and spotted around BHA. SD pump and aliowed to soak, moved orienter. Waiting on crude and working stuck pipe Held PJSM and HARC on pumping crude. Discussed hazards and their mitigation Review SOP on checking crude vapor pressure. Spot crude truck, finish paper work, check vapor pressure Vp = 1.45 psia Pump 20 bbl 7.32 ppg crude down CT. Followed by 8.7 ppg flo-pro. set WOC and spotted 5 bbl crude in annulus, SD pump and allow to soak. Worked between Ok and 73 k, pumped another 1 bbl / 6 bbl's out, work CT. Worked CT between Ok and 73k pumped another 1 bbl / 7 out, work CT finaliy getting pull at the bit. WOB between -6k and 1.0 k, pump another 1 bbl / 9 bbl outside. Allow to soak. Pulled between 74k and -1 k. Pumped 1 bbl / 10 outside Allow to soak for 40 minutes, pump 1 bbl 11 outside and ~ulled free at 75k, finally. Work CT and displace crude out of hole. PUH chasing crude to surface. Take crude to tiger tank Pulled a little tight at shoe (11,660 ft) worked area twice and pulled into liner. Pulled up to 11,500 ft and RIH to surge cutting out. SD and open EDC. Circulate at 3.75 bpm and PUH chasing crude to tiger tank. Circulated 133 bbl to tiger tank. Circulate welibore clean while PUH. Take on 150 bbis of new mud & segregate 40 bbls for liner pill with Alpine beads. Check chains on injector - start replacing pins & greasing pins on the injector, replace 7 pins. Elect to POH to PU agitator, look @ motor & bit, CO BHI tool string (approaching critical hrs on tools). MU new BHI mwd BHA & test on catwaik. Conduct PJSM while POH regarding BHA/tool handling. Stop pumping & close EDC. Tag up & fiow check well - no flow. Pop off well & place injector over bunghole. Remove BHI tools from well. Milk motor - good to go. Bit is in perfect condition. Test agitaor on rig floor - good vibrations! PU & scribe motor, agitator, xo's & dart check valves & place in well bore. PU BHI mwd BHA & MU to motor & agitator. PU injector & inspect coil Prinied: 9/14/2007 10:09:50 AM ' ! ~i BP' EXPLORATION Page ~ 7 af 27 ' Operation~ Summary Repc~rt Legal Well Name: 05-28 Common Well Name: 05-28 Spud Date: 10/17/2001 Event Name: REENTER+COMPLETE Start: 7/26/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 8/29/2007 Rig Name: NORDIC 2 Rig Number: ( f I _ ~ 1 _ - I I: . . _ _ 8/13/2007 11:15 - f4:10 I 2.92; STKOH~P PROD1 14:10 - 16:20 2.171 STKOH P PROD1 16:20 - 16:35 0.25I STKOH P PROD1 16:35 - 20:57 4.371 STKOH ~ N DPRB PROD1 20:57 - 21:30 I 0.551 STKOH I N I DPRB I PROD1 21:30 - 22:00 0.50 i STKOH N DPRB ' PROD1 22:00 - 22:26 0.43 i STKOH N DPRB PROD1 22:26 - 00:00 1.571 STKOH N DPRB PROD1 I 8/14/2007 I00:00 - 01:30 I 1.50 I STKOH ~ N ~ DPRB I PROD1 01:30 - 0220 0.83 j STKOH N DPRB PROD1 02:20 - 02:45 0.421 STKOH N DPRB PRODi 02:45 - 06:15 I 3.501 STKOH I N I DPRB I PROD1 06:15 - 06:30 0.25 ~ STKOH N DPRB PROD1 06:30 - 09:05 2.581 STKOH N DPRB PROD1 connector, torque up set screws. Break off LQC & remove cheack valves & install blanks. Stab onto well. Set counters. Power up & test tools. RIH. Open EDC Q 560ft, pump @ 2.7bpm while RIH. Log down for tie-in from 11,640ft (-13ft). Close EDC. W iper to TD. Pump 2.2bpm @ 2888psi. Set down @ 11,680ft. Work area until ciean. Work area @ 12,296ft. Work area @ 12,440ft-12,490ft. Stuck @ 12,442ft. Can move 10-15ft up & down but not down past 12,487ft or up past 12,440ft. PUH using auto driller to back ream out of trouble Seen some motor work wo pull at 12,435 ft Motor work at 12,428 ft wo/ any pull on CT or DHWOB Had to work free. PUH back reaming at 0.2 fpm and 2.00 bpm PU to 12425 ft RIH and PU again to 12,423.2 ft (63k) Work way back in hole PUH and pulling tight at 12,423.4 ft at 67k (-19kDHW06) Pulling something along with us Working out of hole Finally beat our way down, RIH to 12,500 ft. PUH started pulling tight at 12,450 ft Worked free. POOH. Open EDC at 11630 ft PUH while circulating at 3.3 bpm PUH circulating at 3.5 bpm Tie in at 11,640 ft Corrected +7.5 ft RIH to cleanout to bottom. Tagged 12,417 ft Cieaned out to 12,430 ft, PUH to 12,380 ft, clean; RIH to 12,438 ft Motor and CTW. Working to clean up area between 12,450 ft and 12,390 ft Cleaning up area between 12,380 ft to 12,450 ft. Area between t2,400 ft tpo 12450 ft is unstable is sluffing into welibore. One time it clean then the next time its ratty and pulling tight. Ordered out salt to bing density up to +/-9.00 ppg Density = 8.6 / 8.7 ppg RIH to 12,550 ft, PUH clean. Stiil ratty pulling up from 12,500 ft to 12,380 ft RIH to 12,935 ft tagged PU, tight Working at cleaning up 12,900 to 12,952 ft. Started mixing NaCI / KCL on rig to inc the density. The hole at 12,937 ft is hard. Starting to see problems with orienter and NBI. unable to cleanout without true orienter values. POOH to look at failed orienter and check 12,400 ft area. Not bad pullling through 12,400 ft area. orient started working again at 12,100 ft. POOH. SD pump at 11,680 ft and pull into 5-1/2" casing. Pulled tight, worked back down, clean. PUH to 11, 630 ft and open EDC. POOH mixing salt to 9.00 ppg. PJSM regarding handling BHA. Tag up & flow check well - no flow. Pop off well & place injector over bunghole. Purge tool string with water & air. Remove BHI tools from well & lay them down on the catwalk & reconfigure tool string. Milk motor - good to go, metai scaring on side of motor. Bit is in perfect condition. PU BHI mwd BHA & MU to motor. PU injector & inspect coil connector, torque up set screws. Break off LQC & remove blank check valves & install flapper check valves. Stab onto well. Set counters. Power up & test tools. Printed: 9/14/2Q07 10:09:50 AM , ~ ~ .~,~_~. 3P EXPLORATJ Legal Well Name: 05-28 Common Well Name: 05-28 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 ~ Date ' From - To Hours Task Code ~ NPT Start: 7/26/2007 Rig Release: 8/29/2007 Rig Number: ,; 8/14/2007 09:05 - 11:00 1.92 STKOH N DPRB I PROD1 11:00 - 11:10 0.17 STKOH N DPRB i i PROD1 11:10 - 11:20 0.17 i STKOH ~ N i DPRB ~ PROD1 11:20 - 11:35 0.25 STKOH ~ N DPRB j i PROD1 11:35 - 02:30 14.92I I STKOH N ~ I i i DPRB PROD1 2:30 - 16:00 3.50 i i ~ ~ STKOH ~ ~ ~ i ~, , I DPRB I I ROD1 16:00 - 18:00 2.00 STKOH I N DPRB PROD1 18:00 - 19:50 1.83 STKOH N DPRB I ~ PROD1 19:50 - 21:30 1.67 STKOH P i i ~ PROD1 21:30 - 21:55 0.42 STKOH P PROD1 21:55 - 23:00 1.08 STKOH P PROD1 23:00 - 00:00 1.00 STKOH P PROD1 8/15/2007 00:00 - 00:30 0.50 STKOH P PROD1 00:30 - 02:00 1.50 STKOH P PROD1 02:00 - 02:45 0.75 STKOH P PROD1 02:45 - 04:00 1.25 STKOH P PROD1 04:00 - 07:15 325 STKOH P PROD1 07:15 - 07:30 0.25 STKOH P j PRODi 07:30 - 13:00 5.50 CASE P ~ RUNPRD 13:00 - 13:45 0.75 CASE P RUNPRD 13:45 - 18:00 4.25 CASE P RUNPRD 18:00 - 18:30 0.50 CASE P RUNPRD 18:30 - 23:15 4.75 CASE P RUNPRD ~ Page 18 of 27 Spud Date: 10/17/2001 End: -tians RIH. Open EDC @ 700ft. RIH pumping 2.5 bpm. Lights are flickering...... lost #1 generator. Stop RIH & reduce i Pump. I Continue RIH. Log down for tie-in from 11,640ft (-14.5ft corr). Stop pumping & close EDC. Set down solid @ 11,722ft - something hard. Can't get through it. Try different speeds 5-30 ft/min. Different pump rates 1.7-2.5bpm. Try various tool faces. Try to yo-yo it in. Try to drill past it at 5fVmin - stalled right away. Try to drill past, sit down & get 50psi motor work & set brake - stalled. Third attempt to driil past sit down & get 50psi motor work & set brake - CTP came up to stall pressure then lost returns - 1 bbl. Work up & down area. RIH @ 20 ft/min. Set down @ 12,115ft, work past. RIH Q 20fUmin. Set down at 12,258ft - pickup, acting like dragging ! something up - pick up to 12,200ft. Micro stalls & micro tags @ ~ 12,444ft & 12,453ft & 12,465ft. Slight bobble @ 12,920ft. Set down @ 12,960ft (slight motor work), pick up & motor stalied - abie to pump @ 12,920ft. (this acts like a sticky shale/clay!) Ream & backream area from 12,940ft to 12,960ft taking 10ft bites & coming upto 12,900ft. RIH and set down at 12,492 ft work through. Density = 9.1 / 9.1 ppg. Several stalls at 13,492 ft, unable to pass. PUH to check hole inteqrity Puil tight at 12440 ft too 73k / to get free PUH to 12380 ft and RIH to 12450 ft, PUH Pumped 20 bbl 120k LSRV sweep and increase the density to 9.2 ppg. Still a little tight at 12,430 ft PUH and acts like I'm draging, Clean above 11,830 ft. Stopped at 11,680 ft RIH Few pressure spikes in CT from 12,380 ft to 12,480 ft.. Seen some wt and motor work at 12,938 ft worked through without picking up RIH past 13,492 ft. Tagged bottom at 13 650 ft MD. PUH wiper trip for liner and tie-in. Pulled little at 12,450 ft w/ motor work. Pull tigh coming into shoe from 11,660 ft to 11630 ft RIH and try to clean up to 11,683 ft PUH and tie-in Tie-in Corrected +7 ft RIH. Start liner pill down hole. Tag corrected TD at 13,655'. Circulate out of hole. Lay in high vis flo pro pill. Clean hole for liner. Continue to lay in liner pill. Condition hole for liner. Open EDC. Circulate at 3.55 bpm @ 3860 psi while POH. Log CCL from 4150' to 3800'. Continue to pull out of hole. At surface. Get off well. LD Inteq BHA. Prep e-line. PJSM on PU and running liner PU Liner as per Summary. Lay out and strap 1-1/4" CSH. RU BOT's false table Run 55 jts 1-1/4" CSH, drift and rattle Crew change and PJSM meeting to discuss running liner. Continue to make up liner. Fill liner siowly to avoid surge. Pressure test CSH x liner annulus. MU CTLRT. MU 20 jts 2-3/8" PAC to contain e-line. MU coil connector. Test same. i Test reel valve. Stab coil. Get on well. Printed: 9/14/2007 10:09:50 AM ~ ~ ~ BP' EXPLORATION Page 19 of 27 Qperations Summary Report Legal Well Name: 05-28 Common Well Name: 05-28 Spud Date: 10/17/2001 Event Name: REENTER+COMPLETE Start: 7/26/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 8/29/2007 Rig Name: NORDIC 2 Rig Number: Date ' From - To Hours Task Code NPT Phase ~ Description af C}p~ratiQns 8/15/2007 23:15 - 00:00 0.75 CASE P RUNPRD i' Run in hole. 8/16/2007 00:00 - 02:00 2.00 CASE P RUNPRD ' Continue to run liner assembly in hole. Circulate at min rate. ! 54k# up wt at 11,600'. ~ Circulate at 1.1 bpm @ 2300 psi. Run through shoe area ~ ! slowly to check for "ciay balls". '; Set dn at 13430'. Work past. Set down several times last 50'. ',Tag and call btm at 13,682'. o a rop depth. 62k# up wt. I 02:00 - 03:00 1.00 CASE P RUNPRD ~, Drop 5/8" balL Circ at 3340 psi @ 1.8 bpm. Reduce rate to 0.5 '~I bpm/1740 psi at 45 bbis pumped. Ball on seat at 56.5 bbls. Pressure up to 4200 psi and wait for shear. Pressure up to I~ 4800 psi and CTLRT sheared. PU and got an up wt of 45k#. ' Released from liner. 03:00 - 03:30 0.50 CASE P ~ RUNPRD ' Wait on KCL water from Veco. 03:30 - 08:00 4.50 CASE P j RUNPRD i Displace weil to KCL water. 3650 psi at 2.0 bpm. I ; Rig up SLB cementers. 08:00 - 10:15 2.25 CASE P j RUNPRD , Wait on KCL and mix up Biozan 10:15 - 10:30 0.25 CASE P ~ RUNPRD I~ Held PJSM / THA with crews and discussed operations and i HAZARDS. Migitated Hazards 10:30 - 11:18 0.80 CASE P RUNPRD I Batch mix 34 bbl cement. (28 bbl pumpable) 11:18 - 12:24 1.10 CEMT P RUNPRD I, Pumped 3 bbl water, PT to 4000 psi, open up and pumped ~I another 2 bbl water ~Pumped 28 bbl of 15.8 ppp Class G cement at 1.6 to 2.5 bpm Max pressure at 4000 psi I Pumped 3 bbl water followed by 48 bbl of Bio. Max flowrates I when needed. lossing 0.2 -0.3 bpm through out job. W ith 57.5 ' bbl pumped , slowed Qp down to 0.5 bpm and unstung from ; O-ring sub with cement at O-ring sub. Recored 23 bbl of ~ cement behind pipe ~ PUH contanimating cement with biozan at min flowrate. from i 13,621 ft to 11, 300 ft 12:24 - 15:00 2.60 CEMT P RUNPRD ~i PUH contaminating with biozan at min flowrate. from 13,621 ft to 11,300 ft Contaminated fluid at deployment sleeve a max rate from 11,300 ft to 11,100 ft. 15:00 - 15:10 I 0.17 CEMT P RUNPRD PJSM on handling BHA / tubulars 15:10 - 19:30 4.33 CEMT P RUNPRD Unstab injector, Recovered 322 ft wire. 175 slack left at 0.5%. Stand 2-3/8" and 1-1/4"in CSH derrick. 19:30 - 00:00 4.50 BOPSU P RUNPRD ~ Review test procedure with crews. Test BOP equipment. ! W itness waived by C. Scheve with A C. 8/17/2007 00:00 - 01:30 1.50 BOPSU P RUNPRD ~ Test injector packoff. Test inner reel valve. Mix biozan in pits. 01:30 - 03:30 2.00 CASE P I RUNPRD ~ MU 4J5" D-331 mill on straight motor w/ BTT tools and 20 jts 'I2-3/8" PH6 drili pipe. 03:30 - 06:00 2.50 CASE P RUNPRD I Run in hole. Pump at 2.49 bpm once insdie 5-1/2" liner. 'I Tag TOL at 11268'. No evidence of cement in 5-1/2" liner. Paint EOP flag at 10,500'. 06:00 - 08:05 2.08 CASE P RUNPRD Circulate out of hole. Some cement at surface, divert to ' cutting box. 08:05 - 08:30 0.42 CASE P RUNPRD PJSM and unstab injector 08:30 - 10:00 1.50 CASE P RUNPRD ~ Recovered 5 ft cabie. PUH standing back 10 stds 2-3/8" PH6 ; PU BOT polishing mill BHA and RIH with 10 std 2-3/8" PH6 10:00 - 12:57 2.95 CASE P il Tubing RUNPRD RIH and corrected to EOP flag at 10,500 ft to 11,161.52ft (+7.3 Printed: 9/14/2007 10:09:50 AM • ~ ~ ' BP EXPLORATION Page 20 0# 2~ Ope~ratians Sumrnary Report Legal Well Name: 05-28 Common Well Name: 05-28 Spud Date: 10/17/2001 Event Name: REENTER+COMPLETE Start: 7/26/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 8/29/2007 Rig Name: NORDIC 2 Rig Number: , Date From - To Hours Task Cade NPT PF~ase Description of Q~~ratic~ns ~- 8/17/2007 10:00 - 12:57 2.95 CASE P RUNPRD ft) Tagged No/Go at 11,273.5 ft 5.4 deeper than the tag with the 4-3/4" D331 Mil. Tagged twice to confirm 11,273.5 ft. 12:57 - 15:00 2.05 CASE P RUNPRD POOH 15:00 - 15:20 0.33 CASE P RUNPRD PJSM on BHA and tubing handling 15:20 - 16:10 0.83) CASE P RUNPRD POOH and stood PH5 in the derrick 16:10 - 16:45 ~ 0.58 ~ CASE P RUNPRD PU motor and mill and stabbed in the hole. Held PJSM on PU j and running MCNL and motor I 16:45 - 18:00 ; 1.25 EVAL P LOWERI I PU MCNL BHA ~ 18:00 - 18:30 j 0.50 EVAL P LOW ER1 i Crew change. Change out then hold PJSM to discuss BHA ' I I ~ make up. 18:30 - 22:30 4.00 EVAL P LOWERI ~ Run 78 jts CSH. BHA length: 3178.6'. 22:30 - 00:00 1.50 EVAL P LOWERI ; Run in hole. Verify SWS loggers depth tracking. RIH at 50 fpm ~ until ail CSH is inside 5-1/2" liner top at 3957'. 8l18/2007 00:00 - 00:30 0.50 EVAL P LOWERI I Continue to run in hole w/ MCNL on clean out assembly. 00:30 - 05:00 4.50 EVAL P LOWERI ~ Log down pass from 11,000' at 30 fpm. Tag hard cement at 13,488'. Begin milling ahead. 1380 psi fs at 1.15 bpm. Mill from 13,488' to 13,570'. 05:00 - 07:00 2.00 EVAL P LOW ER1 PU, check parameters, mix up pill in pit 4 CTP= 1,270 psi free spin WOB 1 k Delta P=200 psi. ROP 60 ~ fph 07:00 - 07:30 I 0.50 ~ EVAL P LOW ER1 W iper trip and chase sweep 07:30 - 07:45 I 0.25 i EVAL P LOW ER1 Drilling cement with sweep at motor, WOB 1 k and ROP = 40 fph Qp = i .13 bpm ~ 07:45 - 09:00 I, 1.25 EVAL P LOW ER1 PUH chasing sweeps out of hole. Pulled to 12,300 ft and then ~ ~ RIH ( 09:00 - 09:15 j 0.25 EVAL P LOW ER1 Drilled 13589 ft to 13,596 ft at 40 fph ~ 09:15 - 09:30 ~ 0.25 EVAL P LOWERI Wiper to 13500 ft, pumping 10 bbl sweeps ~ 09:30 - 10:15 0.75 EVAL P LOW ER1 Drilling 13596 ft to 13,613ft Pumping 10 bbl sweeps. ~ 10:45 - 11:35 0.83 EVAL P LOWERI ' PUH 70k to make wiper trip to 13,000 ft 11:35 - 13:15 1.67 EVAL P LOWERI Drilling 13,611 ft to 13,622 ft at 10 to 17 fph 13:15 - 14:41 1.43 EVAL P LOWERI ' Wiper trip at 13,622 ft to 13,000 ft having trouble geting down PUH again to 13,300 ft, RIH and stiil tagging at 13581 frt, Unable to cleanout below. Set down at 13581 ft 14:41 - 15:30 0.82 EVAL P LOWERI PUH logging at 60 fpm from 13,581 ft to 11,000 ft 15:30 - 16:10 0.67 EVAL P LOWERI RIH to finish cleanout and lay in perf pill. RIH and tagged at 13,621 ft, PUH and unable to get below 13,580 ft and it not solid. 16:10 - 18:30 2.33 EVAL P LOWERI POOH to change motor and mill if required 18:30 - 19:00 0.50 EVAL P LOWERI Drop ball and open cire sub. 19:00 - 22:30 3.50 EVAL P LOW ER1 Stand back PH6 and CSH in derrick. Pipe pulling wet. Slow operation. 22:30 - 22:45 i 0.25 EVAL P LOW ER1 Hold PJSM with crew to discuss handling MCNL source and rest of BHA. 22:45 - 00:00 1.25 EVAL P LOW ER1 Remove source. LD logging tool. Remove rest of BHA trom well. 8/19/2007 00:00 - 03:30 3.50 EVAL N DPRB LOW ER1 Make up 2nd liner clean out BHA. 03:30 - 05:00 1.50 EVAL N DPRB LOWERI Run in hole with 3 bladed mill and motor clean out assembly. Run at 50 fpm until CSH is inside the 5-1/2" liner. 05:00 - 06:55 1.92 EVAL N DPRB LOWERI Continue to run in hole. Pumped 10 bbl Bio Pill. Tagged at 13622 ft (hard cement) ~, 06:55 - 07:30 0.58 EVAL N DPRB LOWERI Miiling Cement from 13,622 ft to 13630.5 ft. Tagged twice ' confirmed. i PBTD at 13,625 ft, corrected to GR/CCU MCNL dated Printed: 9/14/2007 10:09:50 AM J ~ ~ ' 8P'` EXPLORATION Page 21 of 27' Operations Summary Report Legal Well Name: 05-28 Common Well Name: 05-28 Spud Date: 10/17/2001 Event Name: REENTER+COMPLETE Start: 7/26/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 8/29/2007 Rig Name: NORDIC 2 Rig Number: ' Date '' From - To Hours Task Cade ~IPT Phase Description af Operations 8/19/2007 06:55 - 07:30 i 0.58t EVAL N DPRB LOWERI 8/17/2007 i Qp = 1.34 bpm at 1685 psi ROP = 18-20 fph with 1.7k Ibf WOB TOL at 11,253 ft i 2.75" X Nipple = 11,279 ft I PBTD (O-Ring Sub) = 13,624.69 ft I ~ Shoe at 13,658 ft 07:30 - 08:15 ~ 0.75 j EVAL N DPRB LOWERI Cir 120k LSRV Perf Pill down hale 08:15 - 10:40 ; 2.42 ~ EVAL N DPRB LOWERI POOH laying in Perf Pill 10:40 - 11:15 ! 0.58 EVAL P LOWERI Stand Injector back and drop 1/2" ball and open cir sub at 2831 ' ft 11:15 - 14:10 I 2.92 EVAL P IOWERI POOH standing PH6 and CSH in the derrick. LD 30 jts 1-1/4" , CSH and milling BHA 14:10 - 17:00 ', 2.83 EVAL P LOWERI RD BOT and unload pipe shed of 1-1/4" CSH. Loading pipe I shed with guns I I PT Liner Lap to 2000 psi closed valves ! ~ P1 = 2076 psi @ 15:04 hrs ~ ' P2 = 1655 psi @ 15"09 hrs ; P3 = 1550 psi @ 1514 hrs Failed ~ Retest to 2000 psi then closed valves P1 = 2150 psi @ 15:33 hrs ~, P2 = 1796 psi @ 14:40 hrs 'I P3 = 1443 psi @ 14:46 hrs Failed i Retset to 2000 psi then closed vaives I P1 = 2153 psi @ 15:53 hrs ~I P2 = 1783 psi @ 15:57 hrs I P3 = 1501 psi @ 16:13 hrs Failed Called town and looked at plan forward 17:00 - 18:00 1.00 ~i REMCM N CEMT RUNPRD Brin in 30 ~ts of 1-1/4" CSH for down s ueezin liner la . i 18:00 - 18:30 ~ 0.50 ~ REMCM N CEMT RUNPRD Crew change. Hold PJSM to discuss re-testing liner lap. 18:30 - 19:30 ! 1.00; REMCM N CEMT RUNPRD Pressure test surface equ+pment as lined up to 2750 psi. Held ( I solid. Pressure test liner lap: ~'~ ~ 19:27 2000 psi 'I 19:31 1750 psi 19:35 1670 psi 19:38 1630 psi 19:42 1582 psi 19:45 1556 psi i 19:47 1534 psi 19:51 1512 psi ~ , 19:55 1490 psi i 19:57 1479 psi 19:30 - 23:00 3.50 REMCM N CEMT RUNPRD MU cementing BHA assembly with 2.25" nozzle, 80 jts 1-1/4" CSH and 20 jts 2-3/8" PAC pipe. 23:00 - 00:00 1.00 REMCM N CEMT RUNPRD Run in hole with nozzle BHA. Running speed is 50 fpm until CSH is inside 5-1/2" liner. 8/20/2007 00:00 - 02:30 2.50 REMCM N CEMT RUNPRD Continue to run in hole with cement nozzle assembly. Tag btm at 13630'. Correct to 13,625'. Mix NaBr brine pill. 02:30 - 03:30 ; 1.00 I REMCM N CEMT RUNPRD Lay in high vis NaBr brine pili from TD to liner top. 03:30 - 04:00 0.50 ' REMCM N CEMT RUNPRD Hoid PJSM with SLB and Nordic crews to review cement procedures. 04:00 - 06:15 2.25 REMCM N CEMT RUNPRD Pump 5 bbls water. Pressure test lines to 4000 psi. Batch mix Printed: 9/14/2007 10:09:50 AM • ~ ~ BP EXPLORATION 'Page 22 of 27' Operations Summary Repar~ Legal Well Name: 05-28 Common Well Name: 05-28 Spud Date: 10/17/2001 Event Name: REENTER+COMPLETE Start: 7/26/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 8/29/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Cade NPT Phase Description of Operations 8/20/2007 04:00 - 06:15 ~ 225 i REMCM N CEMT RUNPRD 13 bbls 15.8 Class G cement. Up to wt at 04:55. Displace 13 i ~ ~ bbls into reel. Pump 5 bbls water behind. Displace cement ' I ~ down hole at 2 bpm with 2500 initial circ press. ~ I Let 1 bbl out nozzle. Lay in 1:1. TOC at 11,080'. POOH to safety at 10,750'. CIP at 0605. 06:15 - 07:15 1.00 REMCM N CEMT RUNPRD Closed choke S m 1.5 bbl / 2.8bb1 = 390 psi 1.7 bbl / 2.6 bbl = 500 psi 2.0 bbl / 2.3 bbl = 700 psi 2.5 bbl / 1.8 bbl = 970 psi 2.75 bbl / 1.55 bbi= 1143 psi ~ ! 3.00 bbl / 1.3 bbl = 1280 psi SD, WHP straight lined ~ ~ 3.25 bbl / 1.05 bbl; 1350 psi ; ~ 3.50 bbl / 0.80 bbl = 1480 psi , SD 06:42 hrs 0.7 bbl (30 ft) ' above liner. ~ 06:48 hrs psi = 1263 psi; 07:04 = 1090 psi 07:12 = 1040 psi Pumped another 0.2 bbl and pressure increase 1050 to 1150 psi 07:15 - 08:35 1.33 REMCM N CEMT RUNPRD Bleed well off slowly Final welihead pressure = recovered 2 bbl. ' ( and 2.3 bbl behind liner ! ~ RIH circulating and contamining cement at 1:1 to 13,624ft. 08:35 - 11:25 ~ 2.83 ~ REMCM N CEMT RUNPRD POOH chasing cement and brine to surface. 11:25 - 12:00 0.581 REMCM N CEMT RUNPRD Circ and cleanout lines. 12:00 - 14:45 2.75 i REMCM N CEMT RUNPRD PUH standing CSH and PH6 in the derrick 14:45 - 16:30 1.75) REMCM N CEMT RUNPRD PU injector and swizzle out BOP stack 16:30 - 17:20 0.83' REMCM N CEMT RUNPRD PU 4-3/4" BHA with 5 stds of 2-3/8" PH6 tubing 17:20 - 19:30 2.17 REMCM N CEMT RUNPRD RIH with 4.75" mill. Tag liner top at 11,263'. Circulate hi vis sweep around. 1630 psi @ 2.6 bpm. 19:30 - 21:30 2.00 REMCM N CEMT RUNPRD Circulate out of hole. 21:30 - 23:00 1.50 REMCM N CEMT RUNPRD At surface. Get off well. Stand back PH6 in derrick. Remove DSM mill. MU BTT polishing tools. Run 5 stds PH6. Stab coil. Get on well. 23:00 - 00:00 1.00 REMCM N CEMT RUNPRD Run in hole. 8/21/2007 00:00 - 01:45 1.75 REMCM N CEMT RUNPRD Continue to run in hole with polishing mill assembiy. 01:45 - 02:00 0.25 REMCM N CEMT RUNPRD Tag liner sleeve btm at 11,274'. Dress sleeve with a few up and down ream passes. 02:00 - 04:00 2.00 REMCM N CEMT RUNPRD Circulate out ot hole. 04:00 - 05:00 1.00 REMCM N CEMT RUNPRD Stand back PH6. LD polishing mill assembly. 05:00 - 06:30 1.50 REMCM N CEMT RUNPRD Line up to pressure test liner lap. Close master valve. Verify good " body" test to 2500 psi. Open master. Pressure liner up to 2000 psi: ~ 05:27 2125 psi 05:31 1934 psi 05:35 1725 psi ~ 05:39 1622 psi 05:43 1615 psi. Pressure back up to 2050 psi: 05:46 1974 psi 05:50 1688 psi 05:54 1582 psi 05:58 1527 psi 06:15 1457 psi I ! I06:30 1390 psi Printed: 9/14/2007 10:09:50 AM , ~ ~ BP EXPLORATION '' Page 23 of 27 Operations Summary Repvrt Legal Well Name: 05-28 Common Well Name: 05-28 Spud Date: 10/17/2001 Event Name: REENTER+COMPLETE Start: 7/26/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 8/29/2007 Rig Name: NORDIC 2 Rig Number: Date '~ Fr~m - To Hours Task ~ Code NPT Phase ~ Description af Operations 8/21/2007 06:30 - 06:45 0.25 REMC 06:45 - 09:45 3.00 09:45 - 13:10 3.42 13:10 - 16:00 I 2.831 REM 16:00 - 18:00 2.00 18:00 - 18:30 0.50 18:30 - 19:15 0.75 19:15 - 20:15 1.00 20:15 - 21:00 0.75 21:00 - 23:00 2.00 23:00 - 23:50 0.83 23:50 - 00:00 0.17 R 8/22/2007 00:00 - 02:05 2.08 R 02:05 - 03:40 1.58 R 03:40 - 05:35 1.92 R 05:35 - 07:30 1.92 R CEMT RUNPRD ! PJSM on bleeding off wellhead pressure and PU and handling ~ liner cleanout BHA CEMT ~I RUNPRD i PU Liner cleanout BHA CEMT I RUNPRD RIH and tagged the top of the 5-1/2" liner at 3,957 ft and ' worked through. RIH and tagged PBTD at 13630 ft PUH and ' puilling heavy without pump. Circulate perf pilli down CT CEMT i RUNPRD POOH laying in Perf pill at 1:1 to 11,200 ft. Stopped at 11,00 i ft. Drop ball and open cire sub above motor. Continue to circulate out of hole. 3280 pis @ 2.59 bpm. CEMT I RUNPRD Stand back PH6 and CSH pipe in derrick. CEMT RUNPRD Crew change. Hold PJSM to discuss liner lap test procedure. CEMT RUNPRD Fin standback CSH. LD BHA CEMT RUNPRD Body test to 2500 psi. PT wellbore to 2000 psi. Bled to 1505 psi in 15 min CEMT RUNPRD I MU BTT seal assy + 5 stds CSH CEMT RUNPRD ( RIH w/ BHA #22 circ thru seal assy 0.3/210 CEMT RUNPRD ~ 11270' 46.6k See seal assy enter TOL at 11270' CTD, SD i pump. Stack 2k to 11275' ~ Start pump down CT @ 0.5 bpm and pressure welibore (CT + ~ liner) to 2500 psi and had partial bleed by (returns at 0.3 bpm). ~ PUH 20', clean. RIH and stack 8k to 11276.8'. Start pump I ~, 0.25 bpm and had bleed by again. PUH w/ 52.6k? for 15'. ~~ ~; RBIH and stack 8k to 11276J'. Start pump 0.4 bpm and incr ~ WHP to 750 psi and had 0.2 bpm returns. Swap to BS w/ CT i open. Pressure wellbore to 1500 psi and had 0.1 bpm returns i thru CT. Assume seals are torn or BHA is leaking. PUH w/ ~ another 4k overpull for 10' CEMT ~ RUNPRD POOH to check BHA circ 1.0 bpm CEMT RUNPRD Finish POOH w/ seal assy CEMT RUNPRD PT CTC thru CT @ 4000, okay. Standback PH6. Seals on~ seal assy okay. PT disconnect, okay. PT swivel and leaked. Rerun seal assy. MU one stand PH6 CEMT RUNPRD RIH w/ BHA #23 circ thru seal assy 0.46/300 , CEMT RUNPRD Sting into deployment sub at 11270' CTD. Stack 6k to 11276.6'. Start pump @ 0.3 bpm and pressure liner to 2000 psi w/ 0.5 bbls KCI. SD and monitor and had slow bleed off. Repressure to 2000 psi. Start 30 min PT Q 0545 hrs 0545 1978 psi 0548 1580 psi 0552 1475 psi 0600 1370 psi Appear to be leak off down liner. Through shoe ? Hoid 500 psi on coil/liner. Pressure up down coil annulus/liner I lap. i ; 0650 2050 psi i 0655 2040 i 0700 2030 I 0705 2025 0710 2020 0715 2014 0720 2010 Bleed off backside, then coil. Appears shoe leaks, lap is good Printed: 9l14/2007 10:09:50 AM , ~ ~" BP EXPLORATION Page 24 of 2' ~perations Summary Report Legal Well Name: 05-28 Common Well Name: 05-28 Spud Date: 10/17/2001 Event Name: REENTER+COMPLETE Start: 7/26/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 8/29/2007 Rig Name: NORDIC 2 Rig Number: ~ate Frorn - To Haurs Task Code NPT Phase ~ Description of Operatians 8/22/2007 07:30 - 10:00 2.50 REMCM N CEMT RUNPRD Pull out of hole with seal assembly. 10:00 - 11:00 1.00 REMCM N CEMT RUNPRD ~'I Stand back PH6. LD BTT seal assembly. 11:00 - 11:15 0.25 PERFO C LOWERI I Hold PJSM with crews to discuss picking up perf guns. 11:15 - 11:30 025 PERFO C LOWERI Rig up floor to run perf guns. 11:30 - 15:30 4.00 PERFO C LOW ER1 MU 55 SLB 2.0" 6SPF 2006PJ guns OAL: 1151.2' . MU 22 stands 1-1/4" CSH and 5 stds PH6. 15:30 - 18:40 3.17 PERFO C LOW ER1 I Run in hole with perf gun assembly. ~ 18:40 - 18:50 0.17 PERFO C LOW ER1 Tag at 13636' CTD. PUH 59.6k for 50'. RBIH and tag at i 136342'. Corr to 13625'. PUH/RBIH to perf depth @ 13615.7' 18:50 - 20:00 1.17 PERFO C ~ LOW ER1 Load CT w/ 25 bbls fresh FloPro mud 1.65/1470. Load 1/2" aluminum ball. Displace w/ 18 bbis fresh FloPro mud followed ' by 2% KCI 2.0/2366. Red rate to 1.0 bpm 15 bbls before ball ~ ~ on seat. Ball seated at 62.6 bbls. Begin drive by and guns ', ~ ; ~ shot at 3060 psi. Wellbore went on vac and had total losses i i ~ I while pulling 69.3k. Lost 3 bbls before regaining partial returns I I I while pumping 1.0 bpm ~~, i j Perforated ~, ' ! I i 12490-12870', 12940-13470', 13550-13615' w/ 2.0" 2006PJ I ~ i I ~ guns @ 6 sp ' ~, 20:00 - 23:15 ! 3.25 PERFO C ' LOW ER1 ! Continue POH at slow rate due to higher than normal up wt I +/-60k. Losses slowly healed. Fin POOH circ 1.0/650 23:15 - 00:00 ~ 0.75 PERFO C LOW ER1 ', Set injector on legs. LD 2-3/8" PH6 tubing 8/23/2007 00:00 - 02:00 2.00 PERFO C ~OWER1 I LD 1-1/4" CSH singles 02:00 - 02:15 025 PERFO C LOW ER1 ; Safety mtg re: LD perf guns j 02:15 - 05:45 3.50 PERFO C LOW ER1 ~ LD 55 2" perf guns w/ blanks-ASF 05:45 - 09:00 3.25 PERFO C LOW ER1 ~~ Bundle and unload pert guns from pipe shed. I Offload used KCL from pits. Load clean completion 1% KCL. 09:00 - 10:45 1.75 PERFO P LOWERI ! ~ RIH with CSH. 10:45 - 12:30 1 J5 PERFO P LOW ER1 ! POOH and LD CSH in singles. 12:30 - 14:00 1.50 RUNCO RUNCMP ~ MU nozzie BHA. 14:00 - 14:45 0.75 RUNCO P RUNCMP j Run in hole with nozzle assembly. 14:45 - 16:15 1.50 RUNCO SFA~ RUNCMP ; Injector is making noise. Trouble shoot same. Found some ~ cotter pins and clips missing from chain. Inspect both chains. 16:15 - 17:50 1.58 RUNCO P RUNCMP I Continue to run in hole with nozzle on PH6 to 11250'. 17:50 - 20:30 2.67 RUNCO RUNCMP ; POOH displacing wellbore from biozan/KCI to clean KCI taking ; returns to tiger tank 2.5/1700 in 5-1/2", 4.1/3930 above 4100' ~ and in 7-5/8". 'OuY MM plugged off when at 1500' 20:30 - 21:15 0J5 RUNCO P RUNCMP i Set injector on legs. LD nozzle assy and 10 jts 2-3/8" PH6 and ~ load out 21:15 - 22:15 1.OOI WHSUR P WHDTRE WO SWS slickline 22:15 - 22:35 0.33 WHSUR P WHDTRE i Safety mtg re: RU slickline/set WRP 22:35 - 00:00 1.42 WHSUR P WHDTRE Spot SWS slickline unit. RU lubricator, BOP's, etc 8/24/2007 00:00 - 00:55 0.92 WHSUR P WHDTRE Finish RU SWS siickline. PT lub @ 2500 psi 00:55 - 05:30 4.58 WHSUR N DPRB WHDTRE RIH w/ 4.6" GR w/ 4.5" TS to set down at 3975' WLM (assume i TOL). POOH RIH w/ 5-1/2" GS (4.5" OD) w/ 4.5" TS to set down 3985' WLM. POOH ~ RIH w/ 3.625" sample bailer on 3.625" TS to 4200'-a little mushy at 4000', but otherwise clean RIH w/ 4.5" centralizer to 4105' and was mushy at 4000'-had to work to get down W FT RPB does not have a rounded nose on the bottom of the ~ tool, only a square shoulder. There are no threads to attach a Printed: 9/14/2007 10:09:50 AM . • ~ BP! EXPLORATION Page 25 of 2~ . Qpera~tior~s Surnmary Report Legal Well Name: 05-28 Common Well Name: 05-28 Spud Date: 10/17/2001 Event Name: REENTER+COMPLETE Start: 7/26/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 8/29/2007 Rig Name: NORDIC 2 Rig Number: _ . I_ _ I.. I _ . I_ . I_.__I _. I _ ... .~ .. ---~ -- ~ ~ - - ----- 8/24/2007 00:55 - 05:30 4.58 WHSUR N DPRB WHDTRE guide. Also, the tool can be set by medium b{ows in a downward direction. Not looking good for getting the W RP I past the TOL to the planned set spot at 4050'. Start checking other other options 05:30 - 07:30 2.00 WHSUR N WHDTRE Place WL unit on standby while discuss options 07:30 - 09:00 1.50 WHSUR N WHDTRE Call BTT for IBP to set in 5-1/2" liner. Order KCL for setting IBP. ~ Hold PJSM. Rig down SLB slickline unit. 09:00 - 10:00 1.00 WHSUR N WHDTRE Wait on BTT IBP and toois. Load 10 jts 2-3/8" PH6 into pipe shed. 10:00 - 11:00 ~ 1.00 WHSUR N WHDTRE Hold PJSM to discuss handling the BHA. MU Baker 3-5/8" IBP ~ on 10 jts of PH6. Take on 150 bbis KCL. 11:00 - 12:45 ~ 1.75 WHSUR N WHDTRE Run in hole. 12:45 - 13:30 ; 0.75 WHSUR N WHDTRE IBP at 4050'. Circulate 1/2" ball on to seat. 13:30 - 16:30 ~ 3.00 WHSUR N WHDTRE Wait on wellbore fluid and IBP temp to stabilize. 16:30 - 17:00 ; 0.50 WHSUR N WHDTRE Circuiate at 0.2 bpm to inflate IBP. Pressure up to 790 psi and hold for 5 minutes. Pressure up to 1620 psi and hold for 5 '; minutes. Pressure up to 2040 psi and hold for 5 minutes. Pressure up to 2660 psi and hold for 2 min. Pressure to 2805 psi, setting tool sheared and released from IBP. 17:00 - 17:45 i 0.75 WHSUR N WHDTRE Circuiate out of hole. Hold PJSM to discuss testing IBP and ! LD BHA. 17:45 - 18:00 ; 0.25 WHSUR P WHDTRE At surface. Shut in well and pressure test IBP from above to ~ 1000 psi for 10 min. Heid solid. Bleed off WHP. 18:00 - 19:00 ~ 1.00 WHSUR P WHDTRE LD and load out 10 jts 2-3/8 PH6 tubing and IBP running tools 19:00 - 20:00 i 1.00 WHSUR P WHDTRE FMC dry rod TWC. PT @ 500 psi from below, then 600 psi from above MI RU SWS N2 20:00 - 20:15 I 0.25 RIGD P WHDTRE Safety mtg re: pickle CT and blow down w/ N2 20:15 - 21:15 ~ 1.00 RIGD P WHDTRE WO vac truck w/ bleach water 21:15 - 23:00 i 1.75 RIGD P W HDTRE Pump 16 bbls lithium hypochlorite water + 60 bbis FW + 15 bbls corrosion inhib + 5 bbls MeOH. PT DS N2 @ 4000. I Displace CT w/ N2 and blow down to tiger tank 23:00 - 23:15 I 0.25 RIGD P WHDTRE Safery mtg re: pull CT back to reel 23:15 - 00:00 I 0.75 RIGD P WHDTRE Cut off CTC. Install internal grapple and PT. Pulf CT back to reel and secure ~ Nordic begin ND 7-1/16" BOPE 8/25/2007 00:00 - 02:00 i 2.00 RIGD P WHDTRE SWS finish secure CT on reel. Load out reel on VECO lowboy. Set injector on floor off to the side ~ , Nordic continue ND 7-1/16" BOPE and tree valves 02:00 - 04:15 I 2.25 BOPSU P WHDTRE Finish ND BOPE and lift w/ blocks. Move outside equipment. Prep moving system Vac pits of excess tluid Pipeshed is loaded w/ 2 rows (since last week) which is the max allowed by Nordic for move off of weli 04:15 - 04:30 0.25 RNWOR WHDTRE Safety mtg re: move off well 04:30 - 04:45 0.25 RNWOR WHDTRE Move rig off well 04:45 - 06:00 1.25 BOPSU P WHDTRE Set down and move out of cellar the 11" spool, 7" valves and 7-1/16" BOPE. Set BOP on stump 06:00 - 06:30 0.50 BOPSU P WHDTRE Crew change. Hold PJSM to discuss rig prep for moving back ~ over well. 06:30 - 07:15 0.75 I RNW OR W HDTRE Prep rig to move back. Move rig back over well head. 07:15 - 08:30 1.25 I RNWOR WHDTRE Rig equipment back up. Printed: 9/14/2007 10:09:50 AM A ~ ~ BP EXPLORATION ` Page 26 af 27 Operations Summary Repart Legal Well Name: 05-28 Common Well Name: 05-28 Spud Date: 10/17/2001 Event Name: REENTER+COMPLETE Start: 7/26/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 8/29/2007 Rig Name: NORDIC 2 Rig Number: Date ' From - To Hours Task Code NPT Phase ' Description of Operations 8/25/2007 08:30 - 12:30 4.00 ~ BOPSU P W HDTRE Hold PJSM with crew. Skid BOPs into cellar. Lift with bridge I I crane. NU 13-5/8" BOP stack. 12:30 - 15:00 - 2.50 BOPSUH~ P W HDTRE Hold PJSM with crew. NU riser from annular to fioor. 15:00 - 18:00 3.00 BOPSUo N RREP WHDTRE Function test BOPs. Attempt to pressure test BOP body. ~ Replace graylock components on choke line. 18:00 - 22:00 , 4.00 ~ BOPSU P WHDTRE Body test against blinds and TWC at 250/3500 j I~ Be in BOPE test. The right to witness was waived by the ~ AOGCC. Use 3-1/2 DP on VBR test ~ Continue loading pipeshed when activation of hydraulics don't ~ ~ affect Nordic chart recording 22:00 - 23:45 1.75 i BOPSU P WHDTRE BOLDS from dummy hanger. Pull hanger w/ TWC installed to I floor. LD 3-1/2 DP. Wash and LD hanger and 41' jt of 5-1/2" tubing w/ WLEG RU 4-1/2" tubing jt on test plug and set in hanger profile 23:45 - 00:00 0.25'', BOPSU P WHDTRE PT VBR's against 4-1/2" tubing 250/3500 8/26/2007 00:00 - 00:30 0.50', BOPSU P WHDTRE Fin pressure test VBR's on 4-1/2" tubing. Pull test plug. Load ! ; out test joints 00:30 - 03:00 BOPSU~ 2.50'~, P WHDTRE ND riser, NU shooting flange to top of Hydril. Instail 7" riser to ~ I , floor. Install tree cap and PT against B/S at 2500 psi. Move ~ ' riser off of catwalk i I Fin load pipeshed w/ max tubulars which will still allow ~ I lubricator to be brought in 03:00 - 04:45 1.75 BOPSU N WAIT WHDTRE WO slickline unit ' 04:45 - 05:00 ~ 0.25 BOPSU P WHDTRE Safety mtg re: RU slickline lubricator and BOP s 05:00 - 06:00 I 1.00; BOPSU P WHDTRE Spot SWS slickline unit. Bring lubricator into pipeshed 06:00 - 07:00 1.00 ~~ BOPSU P WHDTRE Crew change for rig and slickline crews. Hold PJSM to discuss ~ picking up BOPs, rigging up, and job scope. 07:00 - 10:00 3.00! BOPSU P WHDTRE Bring slickline tools & BOPs to floor. Rig up same. Test ! lubricator to 500 psi. 10:00 - 12:15 2.25 i BOPSU P WHDTRE RIH with IBP releaselretrieval tool. Tag plug at 4050'. Sheared tool trying to engage IBP mandrel. POOH. j Redress tool. RIH. Engage IBP. Release internal pressure and allow plug to relax for 15 minutes. Pull out of hole with plug. No metal or rubber missing from IBP. 12:15 - 13:45 1.50 BOPSU P WHDTRE Hold M. Rig down SLB slickline unit and equipment. ', Remove lubricator from pipe shed. ' 13:45 - 14:45 ~ 1.00 BOPSU P WHDTRE Hold PJSM. ND shooting flange. , 14:45 - 15:45 I 1.00 I BOPSU P WHDTRE NU fiow riser on top of annular. 15:45 - 22:00 6.25 RUNCO RUNCMP Continue to load pipe shed with 3-1/2" tubing-335 jts total 22:00 - 22:20 0.33 RUNCO P RUNCMP Safety mtg re: RU prior to run tub+ng 22:20 - 23:45 1.42 RUNCO P RUNCMP Bring Doyon casing crew tools and torque turn equipment to ~ floor and RU ~ Prep jewelry 23:45 - 00:00 0.25' RUNCO P RUNCMP Safety mtg re: run tubing 8/27/2007 00:00 - 06:00 6.00 i RUNCO RUNCMP MU 3-1/2" muleshoe jt, 'X' nippie w/ 2.75" bare, BOT 3-1/2 x 5-1/2 SABL 3 9CR packer, etc. Bakerlocked all connections below packer i, MU 3-1/2" 9.2# 13Cr80 Vam Top R2 tubing ' 06:00 - 06:30 0.50 RUNCO P RUNCMP Crew change. Change out, make rounds, hold PJSM to ' discuss rng completion. 06:30 - 16:30 10.00 RUNCO P RUNCMP Continue to run 3-1/2" VAM Top tbg and jeweiry. 16:30 - 21:45 525 RUNCO P RUNCMP MU 3-/12" x 4-1/2" XO. Run 4/1/2" 12.6# 13Cr 80 Vam Top , tubing. MU 4-1/2" 'X' nipple as SSSV profile followed by 4-1/2" Printed: 9/14/2007 10:09:50 AM ~ ~ ~ . BP EXPLORATION Page 27 ofi 27 Operations Summary Repart Legal Well Name: 05-28 Common Well Name: 05-28 Spud Date: 10/17/2001 Event Name: REENTER+COMPLETE Start: 7/26/2007 End: Contractor Name: NORDIC CALISTA Rig Release: 8/29/2007 Rig Name: NORDIC 2 Rig Number: - Qate From - TQ Hours Task ~ Code NPT Phase L7escri~tion of Gperations 8/27/2007 16:30 - 21:45 5.25 RUNCO~ IP ~ RUNCMP tubing to surface. Tag at calc depth and set 10k twice to verify ~ set down 21:45 - 22:30 0.75 RUNCON IP RUNCMP LD two joints and figure space out. No spacer pups necessary 22:30 - 00:00 1.501 RUNCO P RUNCMP PU FMC hanger w/ pup and MU on 5-1/2 TC11 landing joint. ~ Land hanger 175k up, 153k dn. RILDS ( Ran 328 joints of 3-1/2 and 4-1/2 tubing. Bottom of muleshoe ~ guide is at 11257.33' which is 2.45' above bottom of deployment sleeve 8/28/2007 00:00 - 01:15 1.25 RUNCO P RUNCMP RU to rev circ 01:15 - 05:45 4.50 RUNCOIv IP RUNCMP Reverse circ down IA and up tubing w/ 315 bbls 2% KCI at BTT ~ I recommended 2 bpm max rate at 2.0/315 and take returns thru i I densiometer to tiger tank until returns were ciean. Had full returns thruout. Watch an amazing lunar eclipse! Swap to ~ ciean 1% KCI w/ corrosion inhibitor and reverse in 220 bbls 2.0/330 05:45 - 07:15 1.50 RUNCOI~ IP RUNCMP Drop ball on rod and wait to fall 07:15 - 08:15 1.00 RUNCO y "P RUNCMP Pressure tubin to 4500 si to set acker. Hold pressure for 30 I ' min. Minimal bleed off. Record on SLB chart. 08:15 - 09:15 1.00 RUNCO ~ P ; RUNCMP Bleed tbg to 1500 psi. Pressure test IA to 3500 psi for 30 min. , i Minimal bleed off. Record on Nordic chart. Bleed tbg off. ~ I DCK valve in GLM #2 sheared. 09:15 - 10:15 1.00 BOPSU P ~ WHDTRE Dry rod TWC throuqh BOPs. Test from below to 500 psi. 10:15 - 16:15 6.00 BOPSUF~ P i WHDTRE Hold PJSM. ND flow riser. ND 13-5/8" BOPs and skid out. 16:15 - 16:30 0.25 WHSUR j P I WHDTRE Safety mtg re: NU tree 16:30 - 18:00 1.50 WHSUR j P I WHDTRE NU adaptor flange. NU tree. 18:00 - 18:30 0.50 WHSUR ~ P WHDTRE C/O with day crew. PJSM regarding RU tree. 18:30 - 20:0~ 1.50 WHSUR I P WHDTRE Continue to NU tree. 20:00 - 20:30 0.50 WHSUR P WHDTRE FMC performed a PPOT-T to 5000 psi good test. PT tree to 5000 psi good test. 20:30 - 20:45 0.25 WHSUR P WHDTRE PJSM regarding pulling TWC with DSM. 20:45 - 22:00 1.25 ~ WHSUR P WHDTRE R/U DSM lubricator & PT to 500 psi. Pull 4" TWC. RD DSM lubricator. UD SLB 7" lubricator for yearly inspection. 22:00 - 23:00 1.00 WHSUR P WHDTRE R/U 2" hoses & tree cap & IA & well head. R/U LRS to IA. P.T. lines to 3500 psi. 23:00 - 23:15 0.25 WHSUR P WHDTRE PJSM regarding pumping diesel freeze protect with LRS & rig crew. 23:15 - 00:00 0.75 WHSUR ~ P WHDTRE Pump diesel down IA taking returns up tubing to the T.T. via sheared DCK valve in mandrel. 8/29/2007 00:00 - 00:45 0.75 WHSUR P WHDTRE Finish pumping diesel FP down IA. 00:45 - 01:30 0.75 WHSUR P WHDTRE Let tubing & IA u-tube via 2" hose. 01:30 - 01:45 0.25 WHSUR P WHDTRE PJSM regarding setting BPV. 01:45 - 02:30 0.75 WHSUR P WHDTRE RU lubricator & set 4" BPV. Test from below to 500 psi - good test. I 02:30 - 03:00 0.50 RIGD P ~ POST RD LRS. RD DSM. RU misc tree jewelry. Secure kill line in I ~ cellar. Blow down lines to T.T. RD 2" line in cellar. Secure I biocks. Rig released @ 03:00 hrs. Printed: 9/14/2007 10:09:SO AM Company: 6P Amoco - - Uate: 812012dQ7 Time 15:29:47 Page: '' 1~ Rield: Prudh4~ Bay Co-ordinate(NEj Refereuee: ~ Well: 05-28, True North ~~ Sife: Pg DS 0~ Verkical (TVDj Reference: ' 05-28B; 63.7 Well= 05-28 ~ ~ ~ ~ Sec4ion (VS} ~2eference: Vl~ell (Q.Q(}N,~_(70E,349.26Azi) VI'ellpath: ;45-2~6P,B'I 3urvey Caicula#ion M~thod: Minimum Curvafure `. Db: Oracle Annotation MI} ' TVD. ; ft r(t -: 11628.83 8279.49 Tie to Rotary Suroey 12451.00 8805.20 TD Survey: Start Date: Company: Engineer: Tool: Tied-to: Survey MD incl': A~im . 'PVD Sys TVD N!S EfW MapN ;"~a~E ! YS DLS Toot : ft deg: " '<te9 : if 8 ' ~t ' ft ft ', #t : ~ f~ deg/10Dft 28.50 0.00 0.00 28.50 -35.20 0.00 0.00 5949038.65 698127.91 0.00 0.00 TIE LWE 55.40 0.45 40.50 55.40 -8.30 0.08 0.07 5949038.73 698127.98 0.07 1.67 GCT-MS 70.10 0.52 32.45 70.10 6.40 0.18 0.14 5949038.83 698128.05 0.15 0.66 GCT-MS 84.60 0.50 24.91 84.60 20.90 0.29 0.20 5949038.95 698128.11 0.25 0.48 GCT-MS 99.20 0.33 17.30 99.20 35.50 0.39 0.24 5949039.05 698128.14 0.34 1.22 GCT-MS 113.70 0.10 359.94 113.70 50.00 0.44 0.26 5949039.10 698128.15 0.39 1.63 GCT-MS 128.20 0.00 257.07 128.20 64.50 0.46 0.26 5949039.11 698128.15 0.40 0.69 GCT-MS 142.80 0.02 145.47 142.80 79.10 0.45 0.26 5949039.11 698128.15 0.40 0.14 GCT-MS 157.30 0.08 115.03 157.30 93.60 0.45 0.27 5949039.10 698128.17 0.39 0.44 GCT-MS 171.90 0.13 102.47 171.90 108.20 0.44 0.29 5949039.10 698128.19 0.38 0.38 GCT-MS 186.40 0.15 94.87 186.40 122J0 0.43 0.33 5949039.09 698128.23 0.37 0.19 GCT-MS ~ 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 : bggm2007 Site: PB DS 05 TR-11-15 UNITED STATES : North Slope Site Position: Northing: 5947204.70 ft Latitude: 70 15 35.696 N From: Map Easting: 697428.91 ft Longitude: 148 24 14.424 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.50 deg Well: 05-28 Slot Name: 05-28 Well Position: +N/-S 1815.10 ft Northing: 5949038.65 ft Latitude: 70 15 53.547 N +E/-W 746.88 ft Easting : 698127.91 ft Longitude: 148 23 52.687 W Position Uncertainty: 0.00 ft Wellpath: OS-28BP61 Drilled From: 05-28 ~~ 500292220802 Tie-oo Depth: . 410670 ft Current Datum: 05-286: Height 63.70 ft Above System Datu m: Mean Sea Level Magnetic Data: 7/27/2006 Declination: 24.35 deg Field Strength: 57640 nT Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg ~ 28.50 0.00 0.00 349.26 i Survey Program for Definitive Wellpath Date: 8/17/2006 Validated: Yes Version: 6 Actual From To Survey Tooleode Tool Name ft ft 55.40 4106.70 1: Schlumberger GCT multishot GCT-MS Schlumberger GCT multishot 4119.00 11628.83 05-286PB1 IIFR Rotary Drillout MWD+IFR+MS MWD + IFR + Multi Station 11660.00 12451.00 05-28BPB1 MWD Coil Drillout (1 MWD MWD - Standard ~ ~ .~, ~~ BP Alaska Baker Hughes INTEQ Survey Report ~~ e~ ~ )_„~I°T1~:(,~ ~ Companu: BP Amoco Date: 8/20/2007 ' Time: 1~:2~;47 , Page: : 2~ Field: Prudhoe'Bay Co-ordinate(NE) Reference: Weii; R5 2$, True North ~ ~ Site: ~~~PB DS Q5 Vertical (TVq) Reference: ~~ 0~-288:: 83.7 ~ WeIL• 05 2$ Section (VS) Reference: Welf (Q.QON,4.Q43E,349.26Azi) Wellpath: '05-2$BP61 Su~vey Calcu lation Method: ' Minirrtum Curvature ' Db: QraCle Survey ~ MD Incl '; Azim TVD Sys TYD N/S E/W MapN MapE ', ~'S DLS Tool ft deg °. deg ' ft ft ft ft ft' : ft ft degf10t~ft 200.80 0.15 91.10 200.80 137.10 0.43 0.37 5949039.09 698128.26 0.36 0.07 GCT-MS 215.40 0.13 85.58 215.40 151.70 0.43 0.40 5949039.09 698128.30 0.35 0.17 GCT-MS 229.90 0.10 63.73 229.90 166.20 0.44 0.43 5949039.10 698128.33 0.35 0.36 GCT-MS 244.40 0.12 41.84 244.40 180.70 0.46 0.45 5949039.12 698128.35 0.37 0.32 GCT-MS 259.20 0.15 32.19 259.20 195.50 0.49 0.47 5949039.15 698128.37 0.39 0.25 GCT-MS 273.70 0.18 21.65 273.70 210.00 0.52 0.49 5949039.19 698128.39 0.42 0.29 GCT-MS ( 288.10 0.23 8.74 288.10 224.40 0.57 0.50 5949039.24 698128.40 0.47 0.47 GCT-MS ~ 302.70 0.25 353.24 302.70 239.00 0.63 0.50 5949039.30 698128.40 0.53 0.46 GCT-MS ~ 317.20 0.25 337.92 317.20 253.50 0.69 0.49 5949039.36 698128.38 0.59 0.46 GCT-MS ~ I ~ 331 JO 0.22 328.36 331 JO 268.00 0.75 0.46 5949039.41 698128.35 0.65 0.34 GCT-MS I i 346.30 0.13 318.33 346.30 282.60 0.78 0.44 5949039.44 698128.32 0.69 0.65 GCT-MS ~ ~I 360.80 0.05 311.69 360.80 297.10 0.80 0.42 5949039.46 698128.31 0.71 0.56 GCT-MS 375.30 . 0.03 358J3 375.30 311.60 0.81 0.41 5949039.47 698128.30 0.72 0.25 GCT-MS , 389.90 0.12 44.15 389.90 326.20 0.82 0.43 5949039.48 698128.31 0.73 0.69 GCT-MS 404.40 0.22 38.18 404.40 340.70 0.86 0.45 5949039.52 698128.34 0.76 0.70 GCT-MS 419.00 0.25 27.68 419.00 355.30 0.91 0.49 5949039.57 698128.37 0.80 0.36 GCT-MS 430.70 0.28 21.85 430.70 367.00 0.95 0.51 5949039.62 698128.39 0.84 0.34 GCT-MS 437.20 0.32 20.26 437.20 373.50 0.99 0.52 5949039.65 698128.40 0.87 0.63 GCT-MS 451.60 0.42 15.54 451.60 387.90 1.07 0.55 5949039.74 698128.43 0.95 0.73 GCT-MS 465.80 0.45 10.49 465.80 402.10 1.18 0.57 5949039.84 698128.45 1.05 0.34 GCT-MS 480.10 0.45 4.99 480.10 416.40 129 0.59 5949039.96 698128.46 1:16 0.30 GCT-MS ~ 494.60 0.45 274 494.60 430.90 1.40 0.59 5949040.07 698128.47 1.27 0.12 GCT-MS ~ 509.10 0.45 376 509.09 445.39 1.52 0.60 5949040.18 698128.47 1.38 0.06 GCT-MS 523.60 0.45 5.04 523.59 459.89 1.63 0.61 5949040.30 698128.48 1.49 0.07 GCT-MS ~ 538.10 0.43 5.09 538.09 474.39 174 0.62 5949040.41 698128.48 1.60 0.14 GCT-MS 552.70 0.43 6.15 552.69 488.99 1.85 0.63 5949040.52 698128.49 1.70 0.05 GCT-MS 567.20 0.48 9.24 567.19 503.49 1.97 0.65 5949040.63 698128.50 1.81 0.38 GCT-MS 581.70 0.52 9.25 581.69 517.99 2.09 0.67 5949040.76 698128.52 1.93 0.28 GCT-MS 596.20 0.52 9.15 596.19 532.49 2.22 0.69 5949040.89 698128.54 2.05 0.01 GCT-MS 610.70 0.55 11.19 610.69 546.99 2.35 0.71 5949041.02 698128.56 2.18 0.25 GCT-MS 625.20 0.63 11.89 625.19 561.49 2.50 0.74 5949041.17 698128.59 2.32 0.55 GCT-MS 639.80 0.68 10.49 639.79 576.09 2.66 0.77 5949041.33 698128.61 2.47 0.36 GCT-MS 654.30 0.70 9.47 654.29 590.59 2.84 0.80 5949041.51 698128.64 2.64 0.16 GCT-MS 668.80 0.70 10.60 668.79 605.09 3.01 0.83 5949041.68 698128.67 2.80 0.10 GCT-MS 683.30 0.72 11.61 683.29 619.59 3.19 0.87 5949041.86 698128.70 2.97 0.16 GCT-MS 697.80 0.73 11.44 697.79 634.09 3.37 0.91 5949042.04 698128.73 3.14 0.07 GCT-MS 712.30 0.77 10.48 712.28 648.58 3.55 0.94 5949042.23 698128.76 3.31 0.29 GCT-MS 726.70 0.78 9.76 726.68 662.98 3.74 0.98 5949042.42 698128.79 3.50 0.10 GCT-MS 741.10 0.80 9.82 741.08 677.38 3.94 1.01 5949042.62 698128.82 3.68 0.14 GCT-MS ( 755.60 0.80 10.61 755.58 691.88 4.14 1.05 5949042.82 698128.85 3.57 0.08 GCT-MS I 770.00 0.77 11.32 769.98 706.28 4.33 1.08 5949043.01 698128.88 4.06 0.22 GCT-MS 784.20 0.73 11.01 784.18 720.48 4.52 1.12 5949043.19 698128.91 4.23 0.28 GCT-MS 798.50 0.73 10.98 798.48 734.78 4.69 1.15 5949043.37 698128.94 4.40 0.00 GCT-MS 812.70 0.78 11.22 812.67 748.97 4.88 1.19 5949043.56 698128.97 4.57 0.35 GCT-MS 826.90 0.78 12.30 826.87 763.17 5.07 123 5949043.75 698129.01 4.75 0.10 GCT-MS 841.10 0.80 14.38 841.07 777.37 5.26 1.28 5949043.94 698129.05 4.93 0.25 GCT-MS 855.30 0.87 15.20 855.27 791.57 5.46 1.33 5949044.14 698129.09 5.11 0.50 GCT-MS 869.50 0.90 15.51 869.47 805.77 5.67 1.39 5949044.35 698129.15 5.31 0.21 GCT-MS 883.70 0.92 16.78 883.67 819.97 5.89 1.45 5949044.57 698129.20 5.51 0.20 GCT-MS 897.90 1.02 17.02 897.87 834.17 6.12 1.52 5949044.80 698129.27 5.73 0.70 GCT-MS 912.10 1.18 16.39 912.06 848.36 6.38 1.60 5949045.07 698129.34 5.97 1.13 GCT-MS i 926.30 1.37 16.16 92626 862.56 6.68 1.69 5949045.37 698129.42 6.25 1.34 GCT-MS i 940.50 1.63 16.00 940.45 87675 7.04 1.79 5949045.73 698129.51 6.58 1.83 GCT_MS ~ ~ ~ .~ ~~ BP Alaska Baker Hughes INTEQ Survey Report ~' ~~~~~ i=~~~ ~~c~---- Company: ;BP AmoCO Date: 8/20/20Q7 Time: 15:29:47 ~ Page: 3 ! Field: iPrudhoe Bay Site: PB DS 0~ Co-ordinate(1VE) Reference: Vertical (TVt3j Reference: Well: ~5 28, True NoRh 05-286; 63.7 '; ~ Well: sD5-2$ SecEion (VS) IZeference: Well (O:QON,O.OQE,349.26Azi) V1~e~ipath: ,"05- 28BPB1 Survey Calcu latian Mefhud: ' Minimum Curv a#ure Db: Oracle Survey . MD Inc} ` Azim TVD Sys'PVD N/S E!W iVlapN `, Map~ US DLS Tool fE deg deg ft ft ft ft ft' ft ft degf10~ft 954.50 1,95 16.29 954.45 890J5 7.46 1.91 5949046.15 698129.62 6.97 2.29 GCT-MS 968.50 2.25 16.74 968.44 904.74 7.95 2.06 5949046.65 698129.76 7.43 2.15 GCT-MS 982.50 2.58 16.68 982.43 918.73 8.51 2.23 5949047.22 698129.91 7.95 2.36 GCT-MS 996.80 3.05 16.60 996.71 933.01 9.19 2.43 5949047.90 698130.09 8.57 3.29 GCT-MS 1010.90 3.55 16.99 1010.78 947.08 9.96 2.66 5949048.68 698130.31 9.29 3.55 GCT-MS 1025.00 4.07 17.13 1024.85 961.15 10.86 2.94 5949049.58 698130.56 10.12 3.69 GCT-MS 1039.20 4.53 16.80 1039.01 975.31 11.88 3.25 5949050.61 698130.84 11.07 324 GCT-MS 1053.40 4.90 16.38 1053.17 989.47 13.00 3.58 5949051.74 698131.15 12.10 2.62 GCT-MS 1067.60 5.27 15.84 1067.31 1003.61 1421 3.93 5949052.95 698131.46 13.23 2.63 GCT-MS 1081.90 5.60 15.18 1081.55 1017.85 15.51 4.29 5949054.27 698131.79 14.44 2.35 GCT-MS 1096.20 5.93 14.11 1095.77 1032.07 16.90 4.65 5949055.67 698132.12 15.74 2.43 GCT-MS 1110.50 6.38 12.87 1109.99 1046.29 18.39 5.01 5949057.17 698132.43 17.14 328 GCT-MS 1124.80 6.75 11.88 112420 1060.50 19.99 5.36 5949058.77 698132.74 18.64 2.71 GCT-MS 1139.10 7.10 10.93 1138.39 1074.69 21.68 5.70 5949060.47 698133.04 20.24 2.58 GCT-MS 1153.40 7.52 9.51 1152.58 1088.88 23.47 6.02 5949062.27 698133.31 21.94 3.20 GCT-MS 1167.60 7.80 8.13 1166.65 1102.95 25.34 6.31 5949064.15 698133.55 23.72 2.36 GCT-MS 1181.90 8.02 7.32 1180.81 1117.11 27.29 6.58 5949066.10 698133.77 25.59 1.72 GCT-MS 1196.20 8.30 6.43 1194.97 1131.27 29.31 6.82 5949068.12 698133.96 27.52 2.15 GCT-MS 1210.50 8.53 5.82 1209.11 1145.41 31.39 7.04 5949070.21 698134.12 29.52 1.73 GCT-MS 1224.80 8.72 5.67 122325 1159.55 33.52 7.26 5949072.35 698134.28 31.58 1.34 GCT-MS 1239.10 8.95 5.16 1237.38 1173.68 35.71 7.47 5949074.54 698134.43 33.69 1.70 GCT-MS 1253.40 9.18 4.69 1251.50 1187.80 37.95 7.66 5949076J9 698134.57 35.86 1.69 GCT-MS 1267.70 9.40 4.54 1265.62 1201.92 40.25 7.84 5949079.09 698134.69 38.09 1.55 GCT-MS 1282.00 9.73 4.40 1279.72 1216.02 42.62 8.03 5949081.46 698134.81 40.38 2.31 GCT-MS 1296.30 10.08 4.12 1293.80 1230.10 45.07 821 5949083.92 698134.93 42.75 2.47 GCT-MS 1310.70 10.33 3.77 1307.98 1244.28 47.62 8.39 5949086.47 698135.04 45.22 1.79 GCT-MS 1325.00 10.52 3.76 1322.04 1258.34 50.20 8.56 5949089.06 698135.14 4773 1.33 GCT-MS 1339.30 10.65 4.01 1336.10 1272.40 52.82 8.74 5949091.68 698135.25 50.27 0.96 GCT-MS 1353.60 10.82 3.76 1350.15 1286.45 55.48 8.92 5949094.34 698135.36 52.85 123 GCT-MS 1367.90 11.08 3.09 1364.19 1300.49 58.19 9.08 5949097.06 698135.45 55.48 2.02 GCT-MS 1382.20 11.28 2.58 1378.22 1314.52 60.96 9.21 5949099.83 698135.52 58.18 1.56 GCT-MS 1396.60 11.42 2.28 1392.33 1328.63 63.79 9.33 5949102.66 698135.56 60.94 1.06 GCT-MS 1410.90 11.55 2.04 1406.35 1342.65 66.64 9.44 5949105.51 698135.59 63.71 0.97 GCT-MS 1425.20 11.72 1.62 1420.35 1356.65 69.52 9.53 5949108.39 698135.61 66.53 1.33 GCT-MS 1439.60 11.87 1.05 1434.45 1370.75 72.46 9.60 5949111.34 698135.60 69.40 1.32 GCT-MS 1453.80 11.98 0.55 1448.34 1384.64 75.40 9.64 5949114.27 698135.57 72.28 1.06 GCT-MS 1467.90 12.08 359.87 1462.13 1398.43 78.33 9.65 5949117.21 698135.50 75.16 1.23 GCT-MS 1482.00 12.22 359.31 1475.92 1412.22 81.30 9.63 5949120.17 698135.40 78.08 1.30 GCT-MS 1496.00 12.32 358.89 1489.60 1425.90 84.28 9.59 5949123.14 698135.27 81.02 0.96 GCT-MS 1510.10 12.42 358.16 1503.37 1439.67 87.30 9.51 5949126.16 698135.12 84.00 1.32 GCT-MS 1524.30 12.60 356.92 1517.23 1453.53 90.37 9.38 5949129.23 698134.90 87.04 2.28 GCT-MS 1538.40 12.77 355.58 1530.99 1467.29 93.46 9.17 5949132.31 698134.62 90.11 2.41 GCT-MS 1552.50 12.88 354.77 1544.74 1481.04 96.58 8.91 5949135.42 698134.28 93.23 1.49 GCT-MS 1566.60 12.97 354.33 1558.48 1494.78 99.72 8.61 5949138.55 698133.89 96.37 0.95 GCT-MS 1580.70 13.08 353.59 1572.22 1508.52 102.88 8.28 5949141.70 698133.48 99.53 1.42 GCT-MS 1594.70 13.22 352.58 1585.85 1522.15 106.04 7.89 5949144.85 698133.01 102.71 1.92 GCT-MS 1608.70 13.38 351.90 1599.48 1535.78 109.23 7.46 5949148.03 698132.49 105.93 1.60 GCT-MS 1622.70 13.57 351.55 1613.09 1549.39 112.46 6.99 5949151.25 698131.94 109.19 1.48 GCT-MS 1636.60 13.68 351.15 1626.60 1562.90 115.69 6.50 5949154.47 698131.36 112.46 1.04 GCT-MS 1650.70 13.78 350.79 1640.30 1576.60 119.00 5.97 5949157.76 698130.75 115.80 0.93 GCT-MS 1664.70 13.92 350.65 1653.89 1590.19 122.31 5.43 5949161.05 698130.12 119.15 1.03 GCT-MS 1678.80 14.10 350.46 1667.57 1603.87 125.67 4.87 5949164.40 698129.47 122.57 1.32 GCT-MS ~ ~ ~ ~~ ~.~~~ BP Alaska .~ ~~~~~ ` Baker Hughes INTEQ Survey Report ~r ~b~ R ~~~~~s ~.~vPr~.+~ ~ - Companyc BP Amoco -ate: 8/20/2007 Time: 15:29:47 Page: ' 4 Field: ~~~~ Pru dhoe'~ Bay ~~ ~~ Co-ordinate(iVE) Reference: ` WeIC 05 28, Tru~: ~lorth - ~ Sife: PB DS 05 Vertical (TVD) Reference: 0528B; 63.7 ' ~ Well: ~05 28 Section (VS) iteference: ~~ Welt (O.OOM11,0 .0(}E,349.26Azi) ~: Wellpath: 05 28BPB1 $urvey Calcu lation Method: Minimum Curvature ' Dh: C3racle Survey ` MD lnct' Azim TVD ' Sys TVD N/S E/W MapN NtapE ': YS llI.S ' Tpot ft deg deg ' ft fit ° i ft ' ft ft ' ft ft deg(1Q4ft ' 1692.90 14.37 350.10 1681.24 1617.54 129.09 4.28 5949167.80 698128.80 126.03 2A2 GCT-MS 1707.00 14.63 349.67 1694.89 1631.19 132.57 3.66 5949171.26 698128.08 129.56 2.00 GCT-MS 1721.00 14.87 34928 1708.43 1644.73 136.07 3.01 5949174.75 698127.34 133.13 1.86 GCT-MS 1735.06 15.12 349.04 1721.95 1658.25 139.63 2.33 5949178.28 698126.57 136.75 1.84 GCT-MS 1748.90 15.43 348.88 1735.36 1671.66 143.22 1.63 5949181.86 698125.77 140.41 2.25 GCT-MS 1762.90 15.77 348.71 1748.84 1685.14 146.92 0.90 5949185.53 698124.94 144.18 2.45 GCT-MS 1776.90 16.13 348.67 1762.30 1698.60 150.69 0.14 5949189.28 698124.09 148.02 2.57 GCT-MS 1790.80 16.58 348.76 1775.64 1711.94 154.53 -0.62 5949193.10 698123.22 151.94 3.24 GCT-MS 1804.80 17.00 348.73 1789.04 1725.34 158.49 -1.41 5949197.04 698122.33 155.98 3.00 GCT-MS 1818.70 17.28 348.78 1802.33 1738.63 162.51 -2.21 5949201.04 698121.42 160.08 2.02 GCT-MS 1832.70 17.60 349.08 1815.68 1751.98 166.63 -3.02 5949205.13 698120.51 164.27 2.37 GCT-MS 1846.70 18.05 349.57 1829.01 1765.31 170.84 -3.81 5949209.32 698119.61 168.56 3.39 GCT-MS 1860.70 18.45 350.13 1842.31 1778.61 175.16 -4.58 5949213.62 698118.72 172.94 3.12 GCT-MS 1874.70 18.73 350.47 1855.58 1791.88 179.56 -5.33 5949217.99 698117.85 177.41 2.14 GCT-MS 1888.60 19.02 350.67 1868.73 1805.03 183.99 -6.07 5949222.41 698117.00 181.90 2.14 GCT-MS 1902.60 19.38 351.09 1881.95 1818.25 188.54 -6.80 5949226.93 698116.15 186.50 2.75 GCT-MS 1916.60 19.82 351.47 1895.14 1831.44 193.18 -7.51 5949231.55 698115.32 19120 3.27 GCT-MS 1930.50 2028 351.35 1908.20 1844.50 197.89 -8.22 5949236.25 698114.48 195.96 3.32 GCT-MS 1944.40 20.75 350.91 1921.21 1857.51 202.70 -8.97 5949241,04 698113.60 200.83 3.56 GCT-MS 1958.20 21.22 350.52 1934.10 1870.40 207.58 -9.77 5949245.89 698112.68 205.77 3.55 GCT-MS 1972.00 21.73 350.28 1946.94 1883.24 212.56 -10.62 5949250.85 698111.71 210.82 3.75 GCT-MS 1985.90 22.33 349.93 1959.83 1896.13 217.70 -11.51 5949255.96 698110.67 216.03 4.42 GCT-MS 1999.90 22.93 349.41 1972.75 1909.05 223.00 -12.48 5949261.23 698109.57 221.42 4.52 GCT-MS 2014.00 23.52 348.72 1955.71 1922.01 228.46 -13.53 5949266.66 698108.37 226.98 4.61 GCT-MS 2028.10 24.02 347.98 1998.61 1934.91 234.02 -14.68 5949272.19 698107.08 232.66 4.13 GCT-MS 204220 24.33 347.53 2011.47 1947.77 239.67 -15.91 5949277.80 698105.70 238.43 2.56 GCT-MS 2056.30 24.52 347.39 2024.31 1960.61 245.36 -17.17 5949283.46 698104.29 244.26 1.41 GCT-MS 2070.4Q 24.75 347.29 2037.13 1973.43 251.09 -18.46 5949289.16 698102.85 250.14 1.66 GCT-MS 2084.50 25.07 347.23 2049.92 1986.22 256.89 -19.77 5949294.91 698101.39 256.07 2.28 GCT-MS 2098.60 25.42 347.24 2062.67 1998.97 262.75 -21.10 5949300.74 698099.91 262.08 2.48 GCT-MS 2112.80 25.83 347.26 2075.47 2011.77 268.74 -22.45 5949306.69 698098.39 268.22 2.89 GCT-MS 2126.90 26.45 347.28 2088.13 2024.43 274.80 -23.82 5949312.71 698096.87 274.43 4.40 GCT-MS 2141.00 27.12 347.30 2100.72 2037.02 281.00 -25.22 5949318.87 698095.31 280.78 4.75 GCT-MS 2155.20 27.77 347.54 2113.32 2049.62 287.39 -26.65 5949325.22 698093.71 287.32 4.64 GCT-MS 2169.30 28.67 348.26 2125.74 2062.04 293.90 -28.04 5949331.70 698092.14 293.98 6.82 GCT-MS 2187.40 29.90 349.48 2141.53 2077.83 302.59 -29.75 5949340.34 698090.21 302.84 7.55 GCT-MS 2209.40 31.05 350.92 2160.49 2096.79 313.59 -31.65 5949351.25 698088.02 313.99 6.19 GCT-MS 2231.30 31.77 352.09 2179.18 2115.48 324.87 -33.33 5949362.52 698086.04 325.40 4.31 GCT-MS 225320 32.30 352.88 2197.75 2134.05 336.39 -34.85 5949373.99 698084.22 336.99 3.09 GCT-MS 2275.10 32.90 353.29 2216.20 2152.50 348.10 -36.27 5949385.66 698082.49 348.77 2.92 GCT-MS 2290.00 33.62 353.43 2228.66 2'l64.96 356.22 -37.21 5949393.75 698081.34 356.92 4.86 GCT-MS 2307.40 34.75 353.57 2243.05 2179.35 365.93 -38.32 5949403.43 698079.97 366.67 6.51 GCT-MS 2332.80 36.43 353.22 2263.70 2200.00 380.62 -40.02 5949415.06 698077.89 381.41 6.66 GCT-MS 2358.30 37.93 352.19 2284.02 2220.32 395.90 -41.98 5949433.29 698075.53 396.79 6.37 GCT-MS 2383.70 38.72 351.06 2303.95 2240.25 411.48 -44.28 5949448.80 698072.82 412.53 4.16 GCT-MS 2409.20 38.95 350.50 2323.81 2260.11 427.27 -46.84 5949464.51 698069.85 428.51 1.65 GCT-MS 2434.60 39.03 350.36 2343.55 2279.85 443.03 -49.50 5949480.20 698066.78 444.49 0.47 GCT-MS 2460.00 39.10 350.29 2363.27 2299.57 458.81 -52.19 5949495.90 698063.67 460.50 0.33 GCT-MS 2485.50 38.97 350.30 2383.08 2319.38 474.64 -54.89 5949511.65 698060.55 476.55 0.51 GCT-MS 2510.90 38.32 350.11 2402.92 2339.22 490.27 -57.59 5949527.20 698057.44 492.41 2.60 GCT-MS 2536.30 37.37 349.45 2422.98 2359.28 505.60 -60.36 5949542.46 698054.27 508.00 4.07 GCT-MS 2561.80 36.87 348.90 2443.31 2379.61 520.72 -63.25 5949557.49 698050.99 523.38 2.35 GCT-MS 2587.30 36.82 348.89 2463.72 2400.02 535.72 -66.19 5949572.42 698047.65 538.67 0.20 GCT-MS ~ ~ ~~~~ ~ BP Alaska ~ : =~ ~~~~ Baker Hughes INTEQ Survey Report ~~ ~ ~~,~~~~ ~ti r t~,~? Company: ,BP Amoco Date: 8/20/2QQ7 ' I'ime: 15:29:47 ! Page: ' S ~ Field: '~~Prudhoe~~~ Bay ~ ~ Co-ordinate(~l E} Reference: ~ WeU: Q5-28, Tr~~ North i~~ Sife: PB C3S 05 Vertical (TVF3j l2eference: O~a-2$B;. 63.7 WeIL• ~~45-28 Sectioo (VS) iieference: '~~ 4Ne11 ~i}.QpN,0.Q0E,349.2fiAzi) Wellgath: '435-286PB't Survey Caicutation Method_ Minimum Curvature Db: Oracle Survey MD Incl '' Azam TuD Sys TVD N!S E/W MrtpN 1VIapE ' VS DLS Tool ft deg deg ft ft' ft ft ft ft ft deg/100ft 2612.80 36.80 349.08 2484.13 2420.43 55072 -69.11 5949587.33 698044.34 553.95 0.45 GCT-MS 2638.10 36.80 349.35 2504.39 2440.69 565.61 -71.95 5949602.14 698041.11 569.11 0.64 GCT-MS 2663.20 36.85 349.75 2524.48 2460.78 580.40 -74.67 5949616.85 698037.99 584.15 0.98 GCT-MS 2688.20 36.77 350.31 2544.50 2480.80 595.15 -77.27 5949631.53 698035.01 599.13 1.38 GCT-MS 2713.50 36.73 350.78 256477 250L07 610.09 -79.75 5949646.39 698032.13 614.26 1.12 GCT-MS i 2739.00 36.80 351.17 2585.20 2521.50 625.16 -82.15 5949661.40 698029.34 629.52 0.96 GCT-MS 2764.50 36.85 351.55 2605.61 2541.91 640.27 -84.44 5949676.44 698026.65 644.79 0.91 GCT-MS 2790.00 37.00 351.59 2626.00 2562.30 655.42 -86.69 5949691.53 698024.01 660.10 0.60 GCT-MS 2815.60 37.03 351.26 2646.44 2582.74 670.66 -88.99 5949706.70 698021.31 675.50 0.78 I GCT-MS 2841.20 36.95 350.96 2666.88 2603.18 685.88 -91.37 5949721.85 698018.53 690.90 0.77 GCT-MS 2866.60 36.78 350.89 2687.21 2623.51 700.93 -93.77 5949736.83 698015.73 706.13 0.69 GCT-MS 2891.70 36.67 350.97 2707.32 2643.62 715.75 -96.14 5949751.58 698012.98 721.13 0.48 GCT-MS 2916.80 36.60 351.26 2727.47 2663.77 730.55 -98.45 5949766.31 698010.27 736.10 0.74 GCT-MS 2942.00 36.40 351.68 2747.72 2684.02 745.37 -100.67 5949781 A7 698007.66 751.08 1.27 GCT-MS i 2967.10 36.22 352.08 2767.95 2704.25 760.09 -102.77 5949795.73 698005.18 765.93 1.19 GCT-MS 2992.20 36.18 352.35 2788.20 2724.50 774.77 -104.78 5949810.35 698002.78 780.73 0.65 I GCT-MS I 3017.20 36.20 352.78 2808.38 2744.68 789.41 -106.69 5949824.94 698000.49 795.47 1.02 GCT-MS 3042.30 36.23 353.31 2828.63 2764.93 804.13 -108.49 5949839.60 697998.30 810.26 1.25 GCT-MS 3067.40 36.28 353.79 2848.87 2785.17 818.88 -110.16 5949854.30 697996.25 825.07 1.15 GCT-MS 3092.50 36.33 354.33 2869.10 2805.40 833.66 -111.69 5949869.04 697994.32 839.88 1.29 GCT-MS 3117.60 36.53 354.50 288929 2825.59 848.50 -113.14 5949883.83 697992.48 854.72 0.89 GCT-MS 3142.70 36.98 354.09 2909.40 2845.70 863.44 -114.64 5949898.73 697990.60 869.68 2.04 GCT-MS 3167.60 37.58 353.26 292922 2865.52 878.43 -116.30 5949913.67 697988.54 884.72 3.14 GCT-MS 3192.60 38.07 352.71 2948.96 2885.26 893.65 -118.17 5949928.83 697986.27 900.02 2.38 GCT-MS 3217.60 38.32 352.72 2968.61 2904.91 908.98 -120.13 5949944.11 697983.91 915.45 1.00 GCT-MS 3242.60 38.38 352.81 2988.22 2924.52 924.37 -122.09 5949959.44 697981.55 930.93 0.33 GCT-MS 3267.30 38.28 352.80 3007.59 2943.89 939.57 -124.00 5949974.58 697979.23 946.22 0.41 GCT-MS 3292.00 37.68 352.36 3027.06 2963.36 954.64 -125.97 5949989.59 697976.87 961.40 2.67 GCT-MS 3316.60 36.78 351.32 3046.65 2982.95 969.37 -128.08 5950004.26 697974.37 976.26 4.46 GCT-MS 3341.30 36.12 350.37 3066.52 3002.82 983.86 -130.41 5950018.68 697971.66 990.93 3.52 GCT-MS 3366.20 35.80 350.11 3086.67 3022.97 998.27 -132.89 5950033.02 697968.80 1005.55 1.42 GCT-MS 3391.10 35.75 350.33 3106.87 3043.17 1012.62 -135.36 5950047.30 697965.95 1020.11 0.55 GCT-MS 3416.10 35.67 350.78 3127.17 3063.47 1027.01 -137.76 5950061.62 697963.18 1034.69 1.10 GCT-MS 3441.00 35.55 351.26 3147.42 3083.72 1041.33 -140.02 5950075.88 697960.54 1049.19 1.22 GCT-MS 3466.00 35.53 351.72 3167.76 3104.06 1055.70 -142.17 5950090.19 697958.01 1063.71 1.07 GCT-MS 3491.00 35.52 352.06 3188.11 3124.41 1070.08 -144.22 5950104.51 697955.59 1078.22 0.79 GCT-MS 3516.00 35.37 352.40 3208.47 3144.77 1084.45 -146.18 5950118.82 697953.25 1092.70 0.99 GCT-MS 3540.50 35.18 352.86 3228.48 3164.78 1098.48 -148.00 5950132.79 697951.07 1106.82 1.33 GCT-MS 3564.60 35.17 353.16 3248.17 3184.47 1112.26 -149.69 5950146.52 697949.02 1120.67 0.72 GCT-MS 3588.70 35.20 353.39 3267.87 3204.17 1126.05 -151.31 5950160.27 697947.03 1134.53 0.56 GCT-MS 3613.30 35.18 353.66 3287.98 3224.28 1140.14 -152.91 5950174.31 697945.06 1148.66 0.64 GCT-MS 3638.00 35.13 353.97 3308.17 3244.47 1154.28 -154.44 5950188.40 697943.15 1162.84 0.75 GCT-MS 3662.70 35.23 354.29 3328.36 3264.66 1168.43 -155.90 5950202.51 697941.33 1177.02 0.85 GCT-MS 3687.40 35.62 354.65 3348.49 3284.79 1182.68 -157.28 5950216.72 697939.57 1191.28 1.79 GCT-MS 3711.80 36.27 354.96 3368.24 3304.54 1196.95 -158.57 5950230.94 697937.90 1205.54 2.77 GCT-MS 3736.50 36.85 354.91 3388.08 3324.38 1211.60 -159.87 5950245.56 697936.22 1220.18 2.35 GCT-MS 3761.20 37.05 354.52 3407.82 3344.12 1226.39 -161.24 5950260.30 697934.46 1234.96 1.25 GCT-MS 3785.80 36.98 354.18 3427.46 3363.76 1241.13 -162.70 5950274.99 697932.62 1249.71 0.88 GCT-MS 3810.50 36.87 354.05 3447.21 3383.51 1255.89 -164.22 5950289.71 697930.71 1264.49 0.55 GCT-MS 3835.20 36.60 354.10 3467.00 3403.30 1270.58 -165.75 5950304.36 697928.80 1279.22 1.10 GCT-MS 3859.90 3622 354.21 3486.88 3423.18 1285.16 -167.24 5950318.90 697926.92 1293.82 1.56 GCT-MS 3884.50 35.90 354.31 3506.77 3443.07 1299.57 -168.69 5950333.26 697925.09 1308.25 1.32 GCT-MS ~ U ~ ~~ BP Alaska ~~ ~~' Baker Hughes INTEQ Survey Report .~'~ ~~~~~~ ,__~ ~ ~_.~ ~ Company; BP Amoco Date: 8/20/2007 Time: 15.29:47 Page: b ~ Field: Pru dho~, Bay C o-ordinate(AlE) Reference: ~ Well: 05-28, Tru~ NOdk~ ~ i Site: PB QS 05 V ertical (TVD) Reference: 05-2&B: 63,7 ` ~ Well A5 28 Section (VS) ReSerence: UUeil (Q {ttlN,{}.44~E,349.26Azi)" ~Wellpath: .05 286PB1 Survey Calculation Method: Minimum Cwrvature '. Db: I~Facle SurveV MD Incl Azim TVD ', SysT~ N/S E/W MapN MapC+ I YS DLS Tool ' ft deg deg ft ft: ft ft ft' ft it degflt~ft ; ~ 3909.20 35.77 354.38 3526.79 3463.09 1313.96 -170.11 5950347.61 697923.29 1322.65 0.55 GCT-MS I 3933.90 35.82 354.41 3546.83 3483.13 1328.34 -171.52 5950361.94 697921.50 1337.04 0.21 GCT-MS 3958.60 35.75 354.42 3566.86 3503.16 1342.72 -172.93 5950376.28 697919.72 1351.43 0.28 GCT-MS 3983.30 35.52 354.46 3586.94 3523.24 1357.04 -174.32 5950390.56 697917.95 1365.76 0.94 GCT-MS 4008.00 35.27 354.50 3607.07 3543.37 1371.28 -175.70 5950404.75 697916.20 1380.00 1.02 GCT-MS 4032.70 35.00 354.53 3627.27 3563.57 1385.43 -177.06 5950418.86 697914.47 1394.16 1.10 GCT-MS 4057.30 34.78 354.41 3647.45 3583.75 1399.43 -178.41 5950432.83 697912.74 1408.17 0.94 GCT-MS 4082.00 34.72 354.10 3667.75 3604.05 1413.44 -179.82 5950446.79 697910.96 1422.20 0.76 GCT-MS 4106.70 34.57 353.29 3688.07 3624.37 1427.40 -181.36 5950460.70 697909.06 1436.20 1.96 GCT-MS 4119.00 34.42 352.64 3698.20 • 3634.50 1434.31 -182.22 5950467.59 697908.02 1443.15 3.23 MWD+IFR+ 4159.04 34.09 352.82 3731.31 3667.61 1456.65 -185.07 5950489.84 697904.59 1465.62 1.05 MWD+IFR+ 4208.87 35.86 353.03 3772.16 3708.46 1484.96 -188.58 5950518.05 697900.33 9494.'!0 3.72 MWD+IFR+ 4251.44 38.71 353.19 3806.03 3742.33 1510.56 -191.67 5950543.56 697896.56 1519.83 6.70 MWD+IFR+ 4345.30 44.93 353.50 3875.94 3812.24 1572.70 -198.91 5950605.48 697887.69 1582.22 6.63 MWD+IFR+ 4437.70 48.50 353.77 3939.28 3875.58 1639.53 -206.36 5950672.09 697878.49 1649.28 3.87 MWD+IFR+ 453220 52.63 356.11 3999.30 3935.60 1712.21 -212.75 5950744.58 697870.18 1721.88 4.77 MWD+IFR+ 4626.71 56.41 358.43 4054.15 3990.45 1789.07 -216.38 5950821.30 697864.54 1798.06 4.47 MWD+IFR+ 4717.69 57.82 357.84 4103.55 4039.85 1865.43 -218.87 5950897.57 697860.04 1873.54 1.64 MWD+IFR+ 4813.50 57.60 359.64 4154.74 4091.04 1946.39 -220.65 5950978.46 697856.12 1953.43 1.60 MWD+IFR+ 4905.74 56.87 359.47 4204.66 4140.96 2023.96 -221.26 5951055.97 697853.48 2029.74 0.81 MWD+IFR+ 4997.93 56.74 358.64 4255.13 4191.43 2101.09 -222.53 5951133.Q4 697850.18 2105.76 0.77 MWD+IFR+ 5090.52 58.01 359.35 4305.05 4241.35 2179.06 -223.89 5951210.94 697846.77 2182.62 1.52 MWD+IFR+ 5182.92 57.74 358.36 4354.18 4290.48 225729 -225.45 5951289.10 697843.14 2259.78 0.95 MWD+IFR+ 5277.47 56.99 0.16 4405.18 4341.48 2336.90 -226.49 5951368.65 697840.02 2338.19 1.79 MWD+IFR+ 5370.87 55.99 359.77 4456.74 4393.04 2414.78 -226.53 5951446.50 697837.92 2414.71 1.13 MWD+IFR+ 5463.50 57.05 359.37 4507.84 4444.14 2492.03 -227.12 5951523.71 697835.31 2490.72 1.20 MWD+IFR+ 5556.97 57.69 359.47 4558.24 4494.54 2570.75 -227.91 5951602.37 697832.44 2568.20 0.69 MWD+IFR+ 5649.72 57.69 358.68 4607.81 4544.11 2649.13 -229.18 5951680.68 697829.11 2645.44 0.72 MWD+IFR+ i 5742.53 57.41 359.11 4657.61 4593.91 2727.43 -230.69 5951758.91 697825.54 2722.66 0.49 MWD+IFR+ 5834.95 58.21 358.40 4706.85 4643.15 2805.62 -232.39 5951837.03 697821.78 2799.80 1.08 MWD+IFR+ 5927.95 58.11 0.30 4755.91 4692.21 2884.62 -233.29 5951915.97 697818.81 2877.58 1.74 MWD+IFR+ 6021.48 58.00 0.58 4805.40 4741.70 2963.98 -232.68 5951995.32 697817.33 2955.44 0.28 MWD+IFR+ 6115.10 57.43 1.25 4855.41 4791.71 3043.12 -231.42 5952074.45 697816.51 3032.96 0.86 MWD+IFR+ 6209.28 57.77 0.55 4905.87 4842.17 3122.62 -230.17 5952153.96 697815.66 3110.84 0.72 MWD+IFR+ 6302.21 58.02 1.06 4955.26 4891.56 3201.34 -229.06 5952232.67 697814.70 3187.97 0.54 MWD+IFR+ 6395.88 58.29 357.82 5004.69 4940.99 3280.89 -229.84 5952312.17 697811.82 3266.27 2.95 MWD+IFR+ 6489.29 56.73 359.00 5054.87 4991.17 3359.64 -232.03 5952390.83 697807.56 3344.05 1.98 MWD+IFR+ 6582.72 56.16 357.51 5106.51 5042.81 3437.46 -234.40 5952468.56 697803.14 3420.95 1.46 MWD+IFR+ 6675.63 55.57 357.53 5158.65 5094.95 3514.29 -237.73 5952545.27 697797.80 3497.06 0.64 MWD+IFR+ 6769.47 56.92 0.94 5210.80 5147.10 3592.28 -238.75 5952623.21 697794.72 3573.88 3.35 MWD+IFR+ 6863.18 56.92 0.58 5261.95 5198.25 3670.80 -237.71 5952701.72 697793.70 3650.82 0.32 MWD+IFR+ 6957.66 57.04 1.20 5313.43 5249.73 3750.01 -236.48 5952780.93 697792.84 3728.42 0.56 MWD+IFR+ 7051.40 59.12 358.02 5363.00 5299.30 3829.55 -237.05 5952860.42 697790.18 3806.67 3.63 MWD+IFR+ 7144.96 59.79 358.43 5410.55 5346.85 3910.09 -239.54 5952940.86 697785.57 3886.26 0.81 MWD+IFR+ 7238.86 58.54 357.17 5458.68 5394.98 3990.65 -242.63 5953021.31 697780.36 3965.99 1.76 MWD+IFR+ 7332.23 56.98 357.77 5508.49 5444.79 4069.55 -246.12 5953100.08 697774.80 4044.16 1.76 MWD+IFR+ 7425.11 56.81 0.57 5559.22 5495.52 4147.33 -247.25 5953177.81 697771.62 4120.79 2.53 MWD+IFR+ 7520.21 56.99 2.06 5611.16 5547.46 4226.97 -245.42 5953257.46 697771.36 4198.69 1.33 MWD+IFR+ 7611.68 57.61 1.58 5660.58 5596.88 4303.90 -242.98 5953334.43 697771.77 4273.83 0.81 MWD+IFR+ 7705.64 58.23 1.54 5710.48 5646.78 4383.49 -240.81 5953414.04 697771.85 4351.61 0.66 MWD+IFR+ 7798.19 58.08 0.55 5759.31 5695.61 4462.09 -239.38 5953492.65 697771.21 4428.57 0.92 MWD+IFR+ 7890.79 57.50 359.59 5808.67 5744.97 4540.44 -239.28 5953570.97 697769.25 4505.53 1.08 MWD+IFR+ 7984.37 58.07 359.10 5858.56 5794.86 4619.61 -240.18 5953650.08 697766.26 4583.48 0.75 MWD+IFR+ ~ • ~ • ~~*@~ BP Alaska A~ R m W ~~~.~ ~~~~~ ~~A~ ~ Baker Hu hes INTE Surve Re ort g Q Y P ~~v~rcc~ Company: BP Amoco Date: 8/20f2007 Time: 15:29:47 Page: ' 7 Field: Prudhoe' Bay Co=ordinate(NE) Reference: ' Wel1: 05 28, TtuG North ' Sike: ~ PB DS 05 Vertical ('I~1)) Reference: -~ ~~ 05-28Bi 63.7 WeIL• 05- 28 Section (~'S) Referenee: Well (O.OQN,O_Q(}~,~49.2fsAzij Wellpath: _05- 28BPB1 _ Survey Calculation Method: Minimum Curvatur~ I?b: _~r3Cle ', Survey MD Incl ` Azim TYI3 , Sys TYD N!S E/W Mapl~i ; MapE VS l~T.~ '. Tool ft deg deg ft ft' ff ft ft '! ft ft d~glltt~Jft ;. 807724 57.98 359.71 5907.74 5844.04 4698.38 -241.00 5953728.80 697763.37 4661.03 0.57 MWD+IFR+ 8171.14 56.24 358.63 5958.73 5895.03 4777.22 -242.14 5953807.58 697760.16 4738.70 2.09 MWD+IFR+ 8264.74 58.26 0.06 6009.36 5945.66 4855.93 -243.03 5953886.23 697757.20 4816.19 2.51 MWD+IFR+ 8358.12 59.38 359.13 6057.71 5994.01 4935.81 -243.59 5953966.07 697754.53 4894.79 1.47 MWD+IFR+ 8452.62 58.04 359.51 6106.79 6043.09 5016.56 -244.55 5954046.76 697751.44 4974.30 1.46 MWD+IFR+ 8544.70 58.33 359.42 6155.33 6091.63 5094.80 -245.28 5954124.95 697748.65 5051.31 0.33 MWD+IFR+ 8638.43 57.78 1.14 6204.92 6141.22 5174.33 -244.90 5954204.46 697746.95 5129.37 1.66 MWD+IFR+ 8732.54 55.70 358.16 6256.54 6192.84 5253.01 -245.36 5954283.09 697744.42 5206.76 3.45 MWD+IFR+ 8825.80 56.71 357.61 6308.42 6244.72 5330.45 -248.22 5954360.43 697739.52 5283.38 1.19 MWD+IFR+ 8919.70 56.97 357.82 6359.78 6296.08 5409.00 -251.35 5954438.86 697734.32 5361.14 0.33 MWD+IFR+ 9012.69 58.50 358.39 6409.42 6345.72 5487.58 -253.95 5954517.35 697729.66 5438.83 1.73 MWD+IFR+ 9106.47 58.23 358.85 6458.60 6394.90 5567.41 -255.87 5954597.09 697725.63 5517.61 0.51 MWD+IFR+ 9198.53 58.16 1.90 6507.13 6443.43 5645.63 -255.36 5954675.29 697724.09 5594.37 2.82 MWD+IFR+ 9295.12 57.56 2.18 6558.52 6494.82 5727.36 -252.45 5954757.07 697724.84 5674.13 0.67 MWD+IFR+ 9385.71 57.98 359.95 6606.83 6543.13 5803.97 -251.03 5954833.68 697724.25 5749.13 2.13 MWD+IFR+ 9479.24 55.44 359.66 6658.17 6594.47 5882.15 -251.29 5954911.82 697721.93 5825.99 2.73 MWD+IFR+ 9573.20 55.94 359.64 6711.13 6647.43 5959.76 -251.77 5954989.39 697719.41 5902.33 0.53 MWD+IFR+ 9666.05 56.44 358.40 6762.80 6699.10 6036.89 -253.09 5955066.45 697716.06 5978.36 1.23 MWD+IFR+ 9760.37 56.92 357.97 6814.61 6750.91 6115.67 -255.59 5955145.13 697711.49 6056.22 0.64 MWD+IFR+ 9853.99 56.13 357.65 6866.24 6802.54 6193.70 -258.57 5955223.06 697706.46 6133.44 0.89 MWD+IFR+ 9947.14 52.09 356.77 6920.84 6857.14 6269.06 -262.23 5955298.29 697700.82 6208.16 4.40 MWD+IFR+ 10040.82 50.05 353.37 6979.71 6916.01 6341.64 -268.46 5955370.68 697692.68 6280.64 3.57 MWD+IFR+ 10134.58 46.03 349.32 7042.41 6978.71 6410.54 -278.87 5955439.28 697680.46 6350.27 5.36 MWD+IFR+ 10228.00 44.09 348.34 7108.39 7044.69 6475.41 -291.67 5955503.79 697665.96 6416.39 2.21 MWD+IFR+ 10321.47 41.24 344.24 7177.13 7113.43 6536.93 -306.61 5955564.89 697649.40 6479.62 4.26 MWD+IFR+ 10415.86 39.08 341.11 7249.27 7185.57 6595.04 -324.70 5955622.49 697629.79 6540.08 3.13 MWD+IFR+ 10509.82 37.32 336.43 7323.12 7259.42 6649.18 -345.68 5955676.06 697607.39 6597.18 3.60 MWD+IFR+ 10602.83 36.55 328.72 7397.51 7333.81 6698.72 -371.35 5955724.91 697580.43 6650.63 5.05 MWD+IFR+ 10695.02 35.03 321.95 7472.31 7408.61 6743.04 -401.92 5955768.40 697548.70 6699.87 4.60 MWD+IFR+ 10788.56 32.20 315.52 7550.23 7486.53 6781.98 -435.95 5955806.43 697513.67 6744.47 4.86 MWD+IFR+ 10883.08 30.00 3Q7.64 7631.19 7567.49 6814.40 -472.33 5955837.88 697476.45 6783.10 4.89 MWD+IFR+ 10975.86 28.97 299.31 7711.99 7648.29 6839.57 -510.30 5955862.05 697437.83 6814.91 4.55 MWD+IFR+ 11069.15 27.86 290.72 7794.07 7730.37 6858.35 -550.41 5955879.76 697397.24 6840.83 4.54 MWD+IFR+ 11162.42 28.42 283.28 7876.34 7812.64 6871.17 -592.41 5955891.47 697354.92 6861.24 3.81 MWD+IFR+ 11256.53 29.61 278.73 7958.65 7894.95 6879.84 -637.19 5955898.96 697309.93 6878.11 2.66 MWD+IFR+ 11347.70 30.92 280.92 8037.40 7973.70 6887.70 -682.46 5955905.62 697264.48 6894.26 1.88 MWD+IFR+ 11441.85 31.19 275.78 8118.07 8054.37 6894.74 -730.47 5955911.39 697216.29 6910.12 2.83 MWD+IFR+ 11534.92 30.19 274.70 8198.10 8134.40 6899.08 -777.77 5955914.49 697168.90 6923.20 1.23 MWD+IFR+ 11628.83 29.67 275.10 8279.49 8215.79 6903.08 -824.46 595591726 697122.13 6935.83 0.59 MWD+IFR+ 11660.00 29.67 275.10 8306.57 8242.87 6904.45 -839.83 5955918.23 697106.73 6940.04 0.00 MWD 11705.60 28.36 272.70 8346.45 8282.75 6905.97 -861.89 5955919.16 697084.64 6945.64 3.84 MWD 11736.60 27.23 268.12 8373.87 8310.17 6906.08 -876.33 5955918.90 697070.19 6948.44 7.79 MWD 11766.66 26.20 263.20 8400.73 8337.03 6905.07 -889.80 5955917.53 697056.76 6949.95 8.11 MWD 11797.77 25.67 258.69 8428.71 8365.01 6902.93 -903.23 5955915.04 697043.40 6950.36 6.56 MWD 11828.69 24.11 264.96 8456.76 8393.06 6901.07 -916.09 5955912.84 697030.59 6950.92 9.91 MWD 11857.52 24.92 274.09 8483.00 8419.30 6900.98 -928.01 5955912.44 697018.67 6953.06 13.42 MWD 11887.12 26.50 274.84 8509.67 8445.97 6901.98 -940.82 5955913.10 697005.85 6956.43 5.45 MWD 11921.21 30.89 276.95 8539.57 8475.87 6903.68 -957.09 5955914.38 696989.53 6961.13 13.21 MWD 11956.60 34.89 281.95 8569.28 8505.58 6906.88 -976.02 5955917.07 696970.53 6967.80 13.65 MWD 11986.03 37.10 288.62 8593.10 8529.40 6911.46 -992.67 5955921.21 696953.76 6975.40 1528 MWD 12016.82 39.80 293.07 8617.22 8553.52 6918.29 -1010.55 5955927.57 696935.71 6985.44 12.55 MWD 12046.01 45.02 300.88 8638.78 8575.08 6927.26 -1028.03 5955936.08 696918.00 6997.51 25.38 MWD Company: iBP ,4m~eo Datg: 812(362iJ07 Time: 15:29'47 ' Page: ` 8 Field: Prudho~ Bay Cb=6rdinaYe(~tE) Reterence: Weil: 0~ 28, T~ue Notth Si~e: ~PB DS ~5 ~~ ~~ ~ ~~ ~ Vertical(TV4~} Reference: r 05-28B` 63.7 Well: i05 28 Section {~S) Reference: Well (O,OON,O.OQE,349.26Azi} T'~'etlpath: 'Q5 286f~B1 Sur~ey Calculat3on Metl~od: MinimuCn Curuafure bb: Ofacle Survey (( Mb Incl ' Azim TuD Sys TvD NtS ~l'W 1l~agN MapE ' VS bLS ' Tool ft deg deg ft ft fE [ ft ft' ft ft deg/100ft ' 12075 .25 47. 54 302. 32 8658. 98 8595 .28 6938. 34 -1046 .02 5955946 .67 696899 72 7011. 74 9 .32 MWD 12103 .06 49. 76 303. 62 8677. 36 8613 .66 6949. 70 -1063 .53 5955957 .57 696881. 92 7026. 17 8 .72 MWD 12134 .56 54. 18 304. 93 8696. 76 8633. 06 &963. &8 -1084 .03 5955971 .00 696861. 07 7043. 72 14 .41 MWD 12164 .35 57. 93 306. 63 8713. 39 8649. 69 6978. 13 -1104 .06 5955984 .92 696840. 66 7061. 65 13 .45 MWD 12193 .91 60. 27 303. 83 8728. 57 8664 .87 6992. 75 -1124 .78 5955998 .99 696819. 56 7079. 88 11 .34 MWD 12226 .37 62. 89 300 29 8744. 02 8680 .32 7007. 89 -1148 .98 5956013 .49 696794. 98 7099. 26 12 .53 MWD 12257 .98 66. 04 297. 08 8757. 65 8693 .95 7021. 57 -1174 .00 5956026 .50 696769. 61 7117. 36 13 .54 MWD 12288 .30 68. 45 294. 68 8769. 38 8705 .68 7033. 77 -1199 .15 5956038 .04 696744. 15 7134. 03 10 .79 MWD 12321 .14 71. 74 293. 33 8780. 56 8716 .86 7046. 32 -1227 .35 5956049 .84 696715. 62 7151. 62 10 .74 MWD 12352 .78 75. 53 292. 56 8789. 47 8725. 77 7058. 15 -1255 .30 5956060 .93 696687. 37 7168. 45 12 .20 MWD 12382 .45 79. 50 291. 87 8795. 88 8732. 18 7069. 10 -1282 .12 5956071 .17 696660 28 7184. 20 13 .57 MWD 12409 .52 83. 23 291. 78 8799. 95 8736 25 7079. 05 -1306 .96 5956080 .46 696635. 19 7198. 60 13 .78 MWD 12451 .00 82. 23 291. 78 8805 20 8741 .50 7094. 32 -1345 .17 5956094 .72 696596. 59 7220. 72 2 .41 MWD ~ ~ • ~ ~ ~~~~ BP Alaska ~~~~`~` ' Baker Hughes INTEQ Survey Report ~° ~~K~ ~~ z~v~r~~~.c~ --- ~ Gompany: BP Amoeo Date: 8/20/2007 Time: 15:32:54 ' Page: ~ ~ Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 05 28, TfuB Norfh '', SiCe: ~PB DS (75 Verticat (TVD) Reference: 05-288:: 63.7 ~ Well: 05-28 Section (VS) Ret'erence: ', WeU (O,QQN,O.Q4E,3t~5.93Azi) ~ Wetlpath: 05 28B ' --- _ - Survey Calculation Method: - -- ' Minimum Gurvature - . llb: Oracle _; ~ Field: Prudhoe Bay --- - I North Slope i UNITED STATES Map System:US State Plane Coordin ate Syste m 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Wefl Centre Sys Datum: Mean Sea Level Geomagnetic Mode1: bggm2007 ~ Site: PB DS 05 TR-11-15 UNITED STATES : Nort h Slope Site Position: Northing: 5947204J0 ft Latitudc: 70 15 35.696 N ~ From: Map Easti ng: 697428.91 ft Longitude: 148 24 14.424 W Position Uncertainty: 0.00 ft North Reference: True ~ Ground Level: 0.00 ft Grid Convergence: 1.50 deg ( Well: OS-28 Slot Name: 05-28 Well Nosition: +N/-S 1815.10 ft Northing: 5949038.65 ft Latitude: 70 15 53.547 N +E/-W 746.88 ft Easti ng : 698127.91 ft Longitude: 148 23 52.687 W Positioo Uncertainty: 0.00 ft Wellpath: 05-28B Drilled From: 05-286P61 i Tie-on Depth: 12134.56 ft ~ Current Datum: OS-28B: Height 6370 ft Above System Datum; Mean Sea Level ( Magnetic Data: 1/31/2007 Declination: 24.07 deg ~ ~ Field Strength: 57652 nT Mag Dip Angle: 80.91 deg ~ i Vertical Section: Depth From (TVD) +N/-S +E/-~V Direction ft - ft ft deg --- ~ ~ 28.50 _ 0.00 _--- - -_ - - 0_00 305.93 _ ~ _ Survey Program for llefinitive Wellpa th Date: 8/20/2007 Validated: No Version: 5 Actual From 7'o Survey I'oulcode To ol Name ~ ft ft i 12162.00 13655.00 05-28B MWD Coil D rillout (1216 MWD MWD - Standard ~ Annotation _ MD T~D ' i ~ ft ft , ~ i 12134.56 8696.76 TIP 12162.00 8712.14 KOP 13655.00 8774.14 TD __ --__ -- Survey: OS-28B MWD Coil Drillo --- ut -- - _. _ _ _ __--- Start Date: ___ _._ 8/20/2007 - _ - --_ Company: Baker Hughes INTEQ Engincer: Tool: MWD;MWD - Standard Tied-to: From: Definitive Path Survey Mb Tnc1''~~ Azim 1'VD ~'~ &~sTVD NfS E/W 1VIap~1 '~-Ma~E `~,' VS 7]LS Toctl ; ft deg deg ' ft ft; ft ~I ft ft: ft ft deg/10Uft ' ~ 12134.56 54.18 304.93 8696.76 8633.06 6963.68 -1084A3 5955971.00 696869.07 4963.82 0.00 MWD 12162.00 57.63 306.50 8712.14 8648.44 6976.95 -1102.47 5955983.78 696842.29 4986.54 13.44 MWD 12193.24 61.72 309.76 8727.91 8664.21 6993.60 -1123.66 5955999.87 696820.66 5013.47 15.89 MWD 12226.23 67.35 308.74 8742.09 8678.39 7012.43 -1146.72 5956018.09 696797.12 5043.19 17.29 MWD 12253.65 70.13 308.21 8752.03 8688.33 7028.33 -1166.72 5956033.45 696776.70 5068.72 10.30 MWD 12283.33 74.14 306.37 8761.14 8697.44 7045.44 -1189.20 5956049.96 696753.79 5096.95 14.74 MWD 12314.91 78.04 305.12 8768.73 8705.03 7063.34 -1214.07 5956067.20 696728.45 5127.60 12.93 MWD 12348.56 81.99 303.41 8774.56 8710.86 7081.99 -1241.46 5956085.12 696700.59 5160.72 12.76 MWD ~ 12372.80 86.75 302.49 8776.94 8713.24 7095.11 -1261.69 5956097.70 696680.02 5184.80 20.00 MWD i 12408.26 90.28 301.29 8777.86 8714.16 7113.83 -1291.79 5956115.63 696649.44 5220.16 10.51 MWD I 12434.21 89.32 298.17 8777.95 8714.25 7126.70 -1314.32 5956127.90 696626.58 5245.95 12.58 MWD 12465.51 89.82 296.24 8778.18 8714.48 7141.00 -1342.15 5956141.47 696598.38 5276.89 6.37 MWD ~ ` ~~~~~ ~~~~ BP Alaska ~'~~~~~~~ Baker Hughes INTEQ Survey Report ~'~ ~~~~~~ t_:v~r~:t~ ; Company: BP Amoco Date: 8/20f20Q7 Time: M15:32:54 ' ~ Page: 2 ~ Field: '~Prudhoe Bay Co~-artlinate(NE) Reference: We1t: 05-2$, True Nt~Yth ~ ~ ~~ ' Site: PB DS 05 ~~~~ VerHcal (7 V~T) Retere~ce: `~~ 05-28B: 63.7 ~~ il V1ze1L• 05 28 Section (VS) ~teference: Well (O:D~N,{7_t~0E,3Q5.93Azi) Wellpath: D5 28B ` Survey Calcu latiun Method: : Minimum Curvature Db: Or3Cle Survey MD lncl ' Azim '~'~'D ' ', 5ys TVD N/S E/W MapN MapE ' VS DLS Toot ' ' ~ ae~ ae9 ~t ~t ,n n ~r ' ' ft ~ ae~l~ao~ ', ii 12495.07 88J1 292.88 8778.56 8714.86 71b3.29 -1369.03 5956153.04 696571.19 5305.86 11.97 MWD 12527.84 86.66 288.41 8779.89 8716.19 7164.83 -1399.66 5956163.77 696540.27 5337.44 15.00 MWD ' 12565.13 87.45 283.84 8781.80 8718.10 7175.17 -1435.43 5956173.16 696504.24 5372.47 12.42 MWD 12598.12 92.27 282.30 8781.88 8718.18 7182.63 -1467.55 5956179.77 696471.94 5402.85 15.34 MWD 12629.00 93.84 279.29 8780.24 8716.54 7188.40 -1497.84 5956184.75 696441.51 5430.77 10.98 MWD 12656.99 94.15 278.10 8778.29 8714.59 7192_62 -1525.44 5956188.24 696413.81 5455.59 4.38 MWD 12689.38 91.41 282.34 8776.72 8713.02 7198.36 -1557.27 5956193.14 696381.84 5484.73 15.57 MWD I 12720.46 91.10 287.71 8776.03 8712.33 7206.42 -158727 5956200.40 696351.64 5513.75 17.30 MWD i ! 12747.29 91.47 292.04 8775.43 871173 7215.53 -1612.49 5956208.85 696326.19 5539.52 16.19 MWD ~ 12777.82 91.44 296.72 8774.66 8710.96 7228.13 -1640.28 5956220.71 696298.08 5569.42 15.32 MWD 12802.35 90.71 299.88 8774.20 8710.50 7239.75 -1661.87 5956231.76 696276.19 5593.72 13.22 MWD 12832.52 90.03 304.03 8774.00 8710.30 7255.72 -1687.46 5956247.05 696250.19 5623.81 13.94 MWD 12860.14 89.72 308.38 8774.06 8710.36 7272.03 -1709.74 5956262.76 696227.49 5651.43 15.79 MWD I 12889.69 89.05 312.03 8774.38 8710.68 7291.10 -1732.30 5956281.23 696204.44 5680.89 12.56 MWD I 12920.20 91.17 316.66 8774.32 8710.62 7312.42 -1754.12 5956301.97 696182.07 5711.06 16.69 MWD 12955.02 93.50 320.35 8772.90 8709.20 7338.47 -1777.16 5956327.40 696158.35 5745.01 12.53 MWD 12987.74 93.93 324.95 8770.78 8707.08 7364.42 -1796.97 5956352.82 696137.87 5776.27 14.09 MWD ~ 13021.80 92.07 330.40 8769.00 8705.30 7393.15 -18T5.14 5956381.06 696118.94 5807.85 16.89 MWD i ! 13057.24 90.55 33475 8768.19 8704.49 7424.59 -1831.46 5956412.06 696101.81 5839.51 13.00 MWD I 13099.75 90.18 340.79 8767.92 8704.22 7463.92 -1847.53 5956450.95 696084.70 5875.60 14.23 MWD 13131.78 90.55 344.41 8767J1 8704.01 7494.48 -1857.11 5956481.25 696074.33 5901.29 11.36 MWD ~ ~ 13158.38 89.35 339.47 8767.73 8704.03 7519.76 -1865.35 5956506.30 696065.42 5922.79 19.11 MWD I 13187.51 90.43 339.78 8767.79 8704.09 7547.07 -1875.50 5956533.33 696054.57 5947.03 3.86 MWD I ~ 13215.64 90.15 336J6 8767.65 8703.95 7573.19 -1885.91 5956559.17 696043.47 597079 1078 MWD ~ ' 13243.41 89.17 334.58 8767.81 8704.11 7598.50 -1897.35 5956584.16 696031.37 5994.90 8.61 MWD ! 13284.99 89.60 330.47 8768.26 8704.56 7635.38 -1916.53 5956620.52 696011.23 6032.07 9.94 MWD 13324.06 89.78 326.45 8768.47 8704.77 7668.67 -1936.96 5956653.26 695989.93 6068.15 10.30 MWD ~ 13355.19 91.17 323.50 8768.21 8704.51 7694.16 -1954.82 5956678.27 695971.40 6097.57 10.48 MWD 13391.21 89.10 320.47 8768.13 8704.43 7722.53 -1977.00 5956706.05 695948.48 6132.18 10.19 MWD 13423.93 88.46 315.74 8768.82 8705.12 7746.87 -1998.84 5956729.81 695926.01 6164.15 14.58 MWD 13450.33 88.46 312.87 8769.53 8705.83 7765.30 -2017.72 5956747.74 695906.65 6190.25 10.87 MWD 13478.52 88.68 308.83 8770.24 8706.54 7783.73 -2039.04 5956765.60 695884.86 6218.33 14.35 MWD 13508.17 89.32 306.46 8770.76 8707.06 7801.84 -2062.51 5956783.08 695860.92 6247.96 8.28 MWD 13536.08 87.14 304.56 8771.62 8707.92 7818.04 -2085.22 • 5956798.68 695837.80 6275.85 10.36 MWD 13565.80 86.80 302.42 8773.19 8709.49 7834.41 -2109.96 5956814.39 695812.63 6305.50 7.28 MWD 13596.28 88.71 299.41 8774.38 8710.68 7850.06 -2136.09 5956829.34 695786.10 6335.83 11.69 MWD 13616.53 90.55 297.82 8774.51 8710.81 7859.76 -2153.87 5956838.57 695768.08 6355.92 12.01 MWD 13655.00 90.55 297.82 8774.14 8710.44 7877.71 -2187.89 5956855.62 695733.60 6394.00 0.00 MWD 05-28B DRLG DRAFT 10 3/4", 45.5#, .~55, L-80, csg ID = 9.950" 3,896 WHIPSTOCK 4,119 GBP 4,152 PYe-rig tbe cut. 3 t/2", s2rt, 13-CR-80 4,300 3-1/2" 9.2#, 13Cr-80 Vam Top Tubing ~ 1!2" liner top g,$37 7 5/8", 29.7#, L-80. 10~,~ ~ csg ID = 6.875" 3 3l16" x 2 7/8" crossover PBTD=13,625' 51 f2", 178, 13CR- so, ~ner io = 4.ss2' 10,923 ~ ~ ~5~~~ 4-1/2" 12.6#, 13Cr80 Vam Top Tubing 2,184' 4 t/2"'X' 13CR80 landing nipple, ~= 3.813" GAS LIFf MANDREIS ST MD ND DEV TYPE VLV LATCH PORT DATE 2 1 3488 7314 3186 5499 36 57 KBG2-9 KBG2-9 DOME SO INT INT 16 20 09/12!07 09!12~07 3 ~ ' TOL 5 1 /2" 3969' 7-5/8 X 5-1/2" BOT ZXP packer 11,137' 3 1/2" 'X' landmg nipple. D= 2.813. 11,158 Baker S 117' X 3 1/2" SABL-3 pkr, Speciat ~ = 2.77" 11,216' 3 1/2...X' landing nipple, ID= 2.75.. 11, 253' BOT G2 set sleeve ~4.0" OD=4 3/8" NO SEALS ~ ~,278' 3 1/2" 'X' landng nipple, ID = 2.75" 11656' S-1/2", 17#, L-80 Hyd 521 liner ~D = 4.892" Note - There were 2 special clearance X nipples used on this well. The first is in the top of the 3-3/16" liner, the second was the upper X nipple in the tubing completion. These are 2.75" profile X nipples. DATE REV BY CONMENTS DATE REV BY C014MENfS 09108191 ORIGINAL COMPLETION 10l30/01 CTD SIDETRACK (OS-28A) 11l22/02 CFUTLP CORRECTIONS 08/02/07 NORDIC2 CTD SIDETRACK (OS-286) 09/12/07 KSB/TLH GLV G'O PRUDHOE BAY UNff WE1L: 05-28B PERMff No: 206-689 A PI No: 50-029-22208-02 SEC 32, T11 N, R15E, 2431' SNL 8 4220' WEL BP Exploration (Alaska) ~ . INTEQ To Whom It May Concern: r~.r BAKER HUGNES 7260 Homer Drive Anchorage, Alaska 99518 Te1907-267-6600 Faac 907-267-6623 September 20, 2007 Please find enclosed directional survey data for the following wells: E-11BT 1PB1 E-19B E-11BL1PB2 E-11BL1 E-11BL1-Ol G-25BPB 1 02-16CPB 1 G-25B 02-16C OS-28BPB 1 OS-28B Enclosed for each well is: 2ea copies of directional survey reports 1 ea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration(Alaska)Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. '' ~ . ' ~ '+ ~ RECEIVED BY. `_!.~,~---~~'%~ , State of Alaska AOGCC DATE: - Cc: State of Alaska, AOGCC oZ.l~ Cfl - ~~ °! ~ Maunder, Thomas E (DOA) Page 1 ofx ~ ~ ~~~ From: Hubble, Terrie L [Terrie.Hubble@bp.com} Sent: Thursday, August 30, 2007 3:15 PM To: Maunder, Thomas E (DOA) Cc: Fleckenstein, Robert J(DOA); Stewman, Sondra D Subject: FW: PBU E-18B (204-139) and PBU 05-28B (206-089} Hi Tom, I'm finally trying to get to some of my backlog of "questions". E-18B Yes, this is a problem well. When CTD was on the well and placed the 3-1/2" Liner it apparently either split or collapsed, causing an obstruction. The only recourse then was to turn it over to Rotary to drill a sidetrack. At that time, it was thought that we would move on that well in the somewhat near future. All logging that had been done was labeled as PB because we would have to sidetrack around the mess and still planned on obtaining the same target that was identified in the Permit to Drill. Further, just as you suspected, I didn't catch it that I should do follow-up paperwork. I have spoken with the Pad Engineer and found that it is a low priority as a future sidetrack because it will be expensive. We do not want to abandon the location so I assume you would like me to do a 10-407 changing the status to Suspended? Is this how you would you like me to proceed? --.~ 05-28B a Q (g -- Q ~~ It appears that you are missing a crucial document in your file for this one. :-) We submitted a 10-403 in April 2007 to Restart Operations (& Change Approved Program), and it was approved on 05/03/07. The subsequent form to be submitted is a 10-407. Nordic #2 just released from the well yesterday and is now in line for a Completion Report. You are correct, we have misunderstood the requirements on when reports are due on these Ops Shutdown wells. We'll try to do better. Thanks for your help and understanding. Terrie From: Maunder, Thomas E (DOA) [mailto:tam.maunder@alaska.gov} Sent: Friday, August 03, 2007 9:09 AM To: Hubble, Terrie L Cc: Fleckenstetn, Robert J (DOA) Subject: PBU E-18B (204-139) atid PBU 05-28B (206-089) Terrie, Bob and I have some questians on these welts. 10/22/2007 DS OS-28 Sundry Application 1~2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, August 29, 2007 10:11 AM To: 'Sarber, Greg J' Subject: RE: OS 05-28 Sundry Application 1 of 2 Thanks very much Greg. Again, not sure what happened to our file copy. Tom From: Sarber, Greg 7 (maiito:SarberJG~BP.com] Sent: Wednesday, August 29, 2007 8:57 AM To: Maunder, Thomas E (DOA) Subject: DS 05-28 Sundry Application 1 of 2 ~ Page i of 1 ~~~-~ ~~ ~-~ 3d`1 ° ~'-l~ Z ~~vc~ S ~~ ~ ~1 Tom, Here is a scanned version of the sundry approval for DS 05-2$. It is a big file, so ! had to break it into 2 pieces to send it. It is also compressed. I hope it makes it thru ok. Let me know if there are any problems. Cheers, Greg «DS 05-28 sundry 1 ofi 2.ZIP» Ph: (907) 564-4330 Cell: (907) 242-8000 Email: sarberjg@bp.com 8/29/2007 ~ Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, Augwst 29, 2007 8:32 AM To: 'Sarber, Greg J` Subject: RE: DS 05-28B (206-089) Thanks Greg. Was there any procedure attached to the 403? If so, please send as weil. Tom ^~ ~q i/~J~~ V~ From: Sarber, Greg ) [mailto;Sarber7G@BP.com) Sent: Wednesday, August 29, 2007 8:ifl AM To: Maunder, Thomas E (DOA) Cc: Hubble, Terrie L Subject: RE: DS 05-286 (206-089) Hi Tom, Here it is. I will call to discuss. Cheers, Greg From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, August 29, 2007 7:28 AM To: Sarber, Greg ) Cc: Hubble, Terrie L Subject: DS 05-28B (206-089) Greg and Terrie, I was looking in our file over here and 1 cannot locate a copy of the sundry (307-143) that was issued to re-enter the weil. I was wondering if you might be able to send on over. Thanks. Not sure what happened to our copy. I# is not in the 05-28A or 05-28 files. Fax or scan is fine. Tom 8/29/2007 ~ ~ Maunder, Thomas E (DOA) Page 1 of 2 From: Sent: To: Cc: NSU, ADW Drig Nordic 2 Toolpusher (nsuadwdrignordic2toolpu@bp.com] Wednesday, August 29, 20Q7 8:16 AM Maunder, Thomas E (DOA) N5U, ADW Drig Nordic 2 Superoisor; Sarber, Greg J Subject: RE: Nordic #2 BOPE test on DS5-28B on 8/25/07 Attachments: Nordic 2 BOP 8-25-07.xis Resubmitted with the PTD # REH ~~--o~s~ From: Maunder, Thomas E (DOA) [mailto:torrt.maunder@alaska.gov] Sent: Wednesday, August 29, 2007 7:24 AM To: NSU, ADW Drlg Nordic 2 Toolpusher Subject: RE: Nordic #2 BOPE test on DS5-286 on 8/25/07 Thanks much. I know that the various approval numbers and permit numbers can get confusing, but the permit number is how we file well information. Tom From: NSU, ADW Drlg Nordic 2 Toolpusher [mailto:nsuadwdrtgnordic2toolpu@bp.com] Sent: Wednesday, August 29, 20(?7 7:20 AM To: Maunder, Thomas E (DOA) Cc: Sarber, Greg 7; NSU, ADW Drlg lVordic 2 Supervisor; NSU, ADW Drlg Nordic 2 Tourpusher Subject: RE: Nordic #2 BOPE test on DS5-2$B on 8/25J07 Tom, The town engineer's are Greg Sarber, Sean McLaughlin & John McMullen. We will use the PTD # from now on to ID the well's. Again sorry for any confusion that this has caused. REH From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, August 29, 2007 7:08 AM To: NSU, ADW Drlg Nordic 2 Toolpusher Subject: RE: Nordic #2 BOPE test on D55-28B on 8/25/07 REH, Who is the town engineer for the well? I am not able to find a copy of the sundry (307-143) listed on the BOP test form. Regardless, the permit to drill number is what should be listed in the block we are referring to on the test form. That is one of the ways we "numerically" identify a well. In some cases the work you do on a well may be covered by a sundry or not or a permit, but in all cases the proper number for the BOP test form is the permit to drill number. Hope this helps, Tom Maunder, PE AOGCC From: NSU, ADW Drlg Nordic 2 Toolpusher [mailto:nsuadwdrlgnordic2toolpu@bp.com] Sent: Tuesday, August 28, 2007 5:21 PM 8/29/2007 ~ Page 2 of 2 ~ To: Maunder, Thomas E (DOA) Subject: RE: Nordic #2 BOPE test on DS5-28B on 8/25/07 Thomas, The # for the PTD is 206-Q89, but we ND the coil 7 1/16" stack & NU the 13 5/8" stack & at that time since we were running the completion on this well we assumed that the Application for Sundry Approval # wouid apply. There was a scope of work change & the report that I sent in did have the "Workover" box checked. If this is not correct please let me know. Sorry for any inconviencence. REH From: Maunder, Thomas E (DOA) [maiito:tom.maunder@alaska.gov] Sent. Tuesday, August 28, 2007 3:28 PM To: NSU, RDW Drlg Nordic 2 Toolpusher; NSU, ADW Drig Nordic 2 Supervisor Subject: RE: Nordic #2 BOPE test on DS5-286 on 8/25/07 Gary and Chuck, You may have already gotten a note from Bob Fleckenstein on this. The number you have for the permit to drill is your sundry number that approved restarting operations. The correct PTD for DS 05-28B is 206-089. The prior two BOP reports were filed with the correct information. Also, has the work scope changed? The two other BOP reports that have been sent in show the operation to be drilling. I'd appreciate the correct information on this. If Mr. Fleckenstein has already contacted you, sorry #or the additional questions. If not, it may be necessary to resubmit the report. Look forward to your reply. Tom Maunder, PE AOGCC From: NSU, ADW Drlg Nordic 2 Toolpusher {mailto:nsuadwdrlgnordic2toolpu@bp.com] Sent: Monday, August 27, 2007 6;33 PM To: aogcc_prudhoe_bay@admin.state.ak.us; Ben Wedin; Fleckenstein, Robert J(DOA); Scheve, Charles M (DOA); Regg, lames B(DOAj; noeltherrien@nordic-calista.com; NSU, ADW Drlg Nordic 2 Supervisor; NSUadwdrlgnordic2tou@BP.com; Maunder, Thamas E(DOA); Udo Cassee Cc: slaporte@nordic-calista.com Subject: Nordic #2 BOPE test on DSS-28B on 8/25/07 8/29/2007 ~ STATE OF Alr4SKA "~0~~04 OIL AND GAS CONSERYATIO~V Ct?MMISSION BOPE Test Report sUbmit to: ~ ~ . _ ._ , . Contractor. Nordic Rig No.: Z DATE: 8/25i2007 Rig Rep.: Holmes Rig Phane: 659-4393 Rig Fax: 659-4356 Operator: BPX Op. Phone: 65~3-4398 Op_ Fax: 659-4356 Rep.: Goodrich / Sevcik Field/Unit & Well No.: PBU d5-28B PTD # 206-089 Operation: Drig: Test: InitiaL- )OCX Test Pressure: Rams: 250/3500 MISC. INSPECTIOWS: Test Result Location Gen.: P Well Sign Housekeeping: P D~l. Rig PTD On Location NA Hazard Sec. Standing Order Posted P BOP STACK: Quantitv Size Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Worlcover. )00C Explor.: Weekly: Bi-Weskly Annular.250f3500 Valves:250/3500 TEST DATA FLOOR SAFETY VALYES: Test Result Quantity Test ~tesu P Upper Kelly NT P lower KeAy NT P BaN Type 1 P Inside BOP NT Test Result 1 13 5/8" P 1 2 7/8"-51/2" P 1 13 5/8" P 1 3 1i8" P 2 31/8" P 1 31/8" P 0 NA CHOKE MANIFOLD: Quantity Test R No. Valves 14 P Manuat Chokes 1 P Hydrautic Chakes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test R System Pressure 3000 P Pressure After Closure 1800 P MUD SYSTEM: Visual Test Alarrn Test 2U0 ~i Attained 40sec P Trip Tank P P Fult Rressure Attained 2min 50 sec P Pit Level Indicators P P Blind Swwitch Covers: Alt stations P Flow Indicator P P Nitgn. Bottles (avg}: 4~ 21Q0 Meth Gas Detector P P H2S Gas Detector P P _ Test Results Number of Failures: 0 Test Time: 6 Haurs Companerrts tested 25 Repair or replacement of equipmerrt witl be macfe within days. Notify the North Slope Inspector 659-3607, follaw v~rith wriiten con#irma#ion to Superviser at: "' . "".~'-: _ Remarks: The VBR's where tested with both a 3 i12" 8 4 1/2" test it_ 24 HOUR NOTICE GI YES )00C NO Test start 18:~ Finish Date 08123/07 Time ???? By John Witness James Lott BOP Test (for rigs) BFL 11/09/04 Nondic 2 BOP 8-25-07.x1s ~ ~ ~~iosio4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BQ PE Test Report Submit to: Contractor. Nordic . , .. _ _ .... Rig No__ 2 DATE: 8/16/07 Rig Rep.: Sloan/McKeiman R~ Phone: 859-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone= fi59-4393 Op. Fa~c: 659-4356 ~ Rep.: GoodrichMildreth E-Mail t ' ~ ~ ~ ~ ~ _ ~.._ .N.... ._ _, _ . . . . _ _ ,__ ,_._ Well Name: PBU 05-28B PTD #~ Operation: Drlg: )OCX Workover. Expior.: Test: Initial: Weekly: Bi-Weekly XXX Test Pressure: Rams: 250-35Q0 Annular 25Q-~ Valves: 250-3500 MISC. INSRECTIONS: TEST DATA FLOfJR SAFETY VALVES: Test Resuft Test Resuft Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NA Housekeeping: P D~I. Rig P Lower Kelly NA PTD On Location P HazarcJ Sec. P Ball Type 2 P Standing Order Posted P Inside BOP NA BOP STACK: Quantity Size/Type Test Resuft MUD SYSTEM: ~sual Alarm Stripper 1 2 3/8" P Trip Tank P P Annular Prevente~ 1 7 1/16" P Pit Level indicators P P #1 Rams 1 Blind 1 Shea~ P Flow lndicator P P #2 Rams 1 2 3/8"combi'~ P Meth Gas Detector P P #3 Rams 1 2 3/8"x31/2" P H2S Gas De#ector P P #4 Rams 1 2 3/8"combi'~ P #5 Rams WA NA Quantity Test Result Choke Ln. Valves 1 31/8" P Inside Reel valves 1 P HCR Valves 2 31/8" P Kill Line Valves 1 31t8" P ACCUMULATOR SYSTEM: Check Valve Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 22Q0 P Quantity Test Result 200 psi Attained 12 sec P No. Valves 14 P Full Pressure Attained 78 sec P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P I~itgn. Botties (avg): 4 2200 Test Resufts Number of Failures: 0 Test Time: 5.0 Hours Components tested 29 Repair or replacement of equipment will t~e made within 0 days. Notify the N orth Slope Inspector 659-3607, foilow with written confiRnation to Superviser afi _ . . . ,.~_ .. ._.. _ . ... Remarks: Distribution: 24 HOUR NOTIC€ GIVEN orig-Well File YES )OOC NO c- OperJRig Waived By Chuck Sheave c - Database pate $/14/07 Time c- Trip Rpt File Witness Goodrich/Meinhold c- Inspector Test start Z000 Finish 01~ Coil Tubing BFL 11/09/04 Norciic 2 BOP 8-16-07p.xls Page 1 of 1 ~ ~ Maunder, Thomas E (DOAj From: Maunder, Thomas E (DOA) Sent: Friday, August 03, 2007 9:09 AM To: 'HubbCe, Terrie L' Cc: Fleckenstein, Robert J (DOA) Subject: PBU E-1$B (204-139} and R!~ ~~) ~ Terrie, Bob and I have some questions on these wells. E-186 - This wetl was granted aperationat SD via sundry 304-402 dated Nov~mber 16, 2~44 due #o an obstruction in the newfy cemented 3-1/2" finer. Sundry 305-144 was issued June 13, 2005 ta re-start operations. We have 2 transmittat letters in the fife labeled E-18B RB. One is LWD data and the other survey data received in late 2005. There is no other information in the file. ff operations were completed around late November 2005 the completion repart should have been submitted some time aga Would you ptease advise us of the welf condition and submit ~e appropriate reports? Any report should also include the operations information from the activities conducted around November 2d04. Atso, see comment be[ow. '~'~~ 05-286 -- This well was granted operational SD via sundry 306-277 dated August 22, 2d06. The sundry is the most recent information in the flle. Woufd you please advise us af the welf condition? See carr~ment betow. There seems to be some confusion about fiting reports when an operational SD is granted far a wett. A report is required by 20 AAC 25.072 (b) whir,h states, "The operator shall fite wit~ the commission, within 30 days after operation shutdow, a complete well recard on ... [Form 10-4Q4} ..." The regulatian further states that "If well operations are not resumed within 'f 2 months, the operator shall ... proceed to abandon or suspend the welt. Upon apptication ... the commission wilt extend the 12-month period, if the operator shows that aperational circumsEances beyond the operator"s controE prevent resumpion ..." Thanks in advance, Tom Maunder, PE AOGCC 8/3/200'7 ` J ~ 11/09/04 STATE ~F ALASKA OIL AND GAS CONSERVIQtT10-N COM~AtSS14N BOPE Test Report Submitto. ~ ~-.~~ ,, Contractor: Nordic _._ _.__ ...... ..,..... R~ No.: 2 DATE: 8/1/07 Rig Rep.: Holmes ! Sloan Rig Phone: fi59-4398 Rig Fa~c: 659-4356 Operator: BPX Op_ Phcme. 659-4393 Op_ Fau: 659-4356 Rep.: Secvik / Ross E-Mail _ Well Name: PBU 05-Z8B PTD # 2Q6-489 Operation: D-ig: X)Ot Workover. Explar._ Test: Initia1:70CX Weekly: Bi-Weekly Test Pressure: Rams: 25Q-35t~ Annular. 25~-35fIa Valves: 250-3500 MfSC. INSPECTIONS: TEST D/iTA FLOOR SAFETY VALVES: Test Resuft Test Resutt Quantity Test Result Location Gen.: P Well S~n P llppef Keily NA Housekeeping: P Dri. Rig P Lc7wer Kelly NA PTD On Loca#ion P Hazand Sec. P Bal1 Type 1 P Standing Onder Posted P Inside BOP NA BOP STACK: Quarrtity Sizeffype Test Resul~ MUD SYSTEM: Visual Alarm Strip~r 1 2 3/8" P 7rip Tank P P Annular Preventer 1 7 1/16" P Pit Level lrxiicators P P #1 Rams 1 Blind / Sttear P Fiow Ir~icafor P P #2 Rams 1 2 3f8"cambi'~ P Meth Gss Detedar F P #3 Rams 1 2 3/8"~c31/2" P HZS Gas Detedor P P #4 Rams 1 2 318"comt~'~ P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 31/8" P Insaie Reei vatves 7 P HCR Valves 2 3118" P Kill Line Valves 1 31/8" P ACCUMUlATOR SYSTEM: Check Valve 2 21/16" P Time/Pressure Test Result Sy~ern Pressure 3000 P CHOKE MANIFOLD: Pressure After Glasure 24Q0 P Quantity Test Res~1t 200 psi At#ained 21 sec P Ido. Valves 14 P Fuit Pressure Attained '1 min ! 6sec P Manual Chokes 1 P B4isid Switr.h CovErs: A11 stations Y Hydraulic Chokes 1 P Nitgn. ~CCrtftes (avg): 4 2100 Test Results Number of Failures: 0 Test Time: 5.5 Naurs CarrtponeMs tested 30 Repair or repiacement of equipmeM wiil be made within 0 days. Notify the N orth Slope Inspector 659-3607, follow with wr~tten confirmaticm to Su iser at: „ Remarks Distribution: 24 HOUR NOTlCE GIVEN orig-Well File YES a0C)C NO c - Oper./Rig Waived By ??? c- Database Date 7/3U/07 Time 2-3 #imes c- Trip Rpt File VV'dness Ross / Daniell c- Ins ector Test start 21:30 Finish 03:00 Coil Tubing BFL 11/09/04 NoMic 2 BOP 8-01-07p.xls u ~ ~ ~ ~ ~~ ~ ~~ ~ ~ "`~.. ~ ~.0 ~ ~ SARAH PAUN, GOVERNOR ~~~ O~+t ~~ 333 W. 7thAVENUE, SUITE 100 C011TSERQA~`I011T C01-II~I15SI011T ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 FAX (907) 276-7542 Greg Sarber CT Drilling Engineer BP Exploration (Alaska) Inc. . PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 05-28B Sundry Number: 30'7-143 Dear Mr. Sarber: Enclosed is the approved Application for'Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, conta.ct the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this~ day of May, 2007 Dan T. Seamount Commissioner Encl. -~~ ' ~ ~~~~ STATE OF ALASKA . s~ ~` ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~.,~ ~~~Ei~~'E~ ~~ ~;~ a ~, 6 2007 APPLICATION FOR SUNDRY APPROVAL i~~sk~ ~i~ g~ ~~S Cons• Cotr-miss't~(t 20 AAC 25.280 . . _,~_....,e . 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ~Re-En ~-~usoended Well ~~~~~ ~ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ~ Other Re-Start O erations with Coil Tubin 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 206-089 - 3. Address: ^ Stratigraphic ^ Service 6. API Number: ~ P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22208-02-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: 35,905' PBU 05-28B _ Spacing Exception Required? ^ Yes ~ No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): - ADL 028321 Plan 63.7' Prudhoe Bay Field / Prudhoe Bay Pool 12~ " RRESENT WELL'CONDITION SUM MARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11666 8312 11572 8230 None None Casin Len th Size MD TVD Burst Colla se Stru~tural Condu or 110' 20" 110' 110' 1490 470 Surface 3916' 10-3/4" 3896' 3516' 3580 2090 Intermediate 4119' 7-5/8" 4119' 3698' 6890 4790 Production Liner 7699' S-1/2" 3957' - 11657' 3566' - 8304' 7740 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None Kill String: 4-1/2", 12.6# L-80 2487' Packers and SSSV Type: None Packers and SSSV MD (ft): None 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal ^ BOP Sketch ^ Exploratory ~ Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: June 1, 2007 ~ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Greg Sarber, 564-4330 Printed Name g Sarber Titie CT Drifling Engineer G r~S a~ Prepared By Name/Number: 564-4628 ~ errie Hubble , Signature Phone 564-4330 Date Commission Use Onl . Sundry Number: ~ .~ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ~OP Test ^ Mechanical Integrity Test ^ Location Clearance Other: 3 '~r~' ~~ ~S ~ ~d~ ~ ~" Subsequent Form Required: ~ APPROVED BY A roved B: COMMISSIONER THE COMMISSION Date Form 10-403 Re~d~b6/2006 ~ ~ ''° ~~> Su6mit In bu~dficate , ~'~ ~ : ~ C ~ ..,;~~~'..t~... . ~ ~ ~~ ~, ~~~7 ~ ~~~~~.~~:~~~~~ ' ~ ~~ ~ b p To: Tom Maunder - AOGCC Date: 4-25-2007 From: Greg Sarber - BPXA Coil Tubing Drilling Subject: 05-28B Application for Sundry Approval - Resume Operations after Rotary Sidetrack was Reference: Suspended API # 50-029-22208-02 Approval is requested to resume drilling operations on well DS 05-28B. Well 5-28A was completed as a Z1 CTD sidetrack in November 2001 and produced steadily until April 2002 when a Cretaceous casing and tubing leak developed. The well was SI in 1/03 until a rotary sidetrack was performed, commencing on July 22, 2006. During decompletion of the well, the cement top behind the 7-5/8" casing was discovered at 1000' MD, which prevented removal of the 7-5/8" casing. The inability to remove the 7-5/8" casing caused a change in the well scope. A window was milled in the 7-5/8" casing and a 5-1/2" intermediate liner was set in the Sag River. The rotary rig then suspended operations and moved off the well. The current plan is to resume drilling operations with the Nordic 2 CTD rig beginning mid July 2007. The well target remains the same. The well will target the same lower zone 1A/1 B interval as approved by the original rotary PTD (PTD # 206-089). The pre-rig work to be completed is minimal, and will commence after sundry approval is received. Attached to this document you will find current and proposed wellbore schematics, a proposed directional plan and BOP's for both the drilling and completion phases of operations. Note that the directional plan is substantially the same as the plan that was submitted for the original rotary permit to drill. The bottom hole location only changes by 80', to the southeast, and is deepened by 53' while still staying in the original target interval of lower zone 1A. Also note that due to the change of scope of operations the casing program is substantially different than that specified in the original permit to drill application. Current Condition: Suspended with a 4-1/2" kill string run down to 2487'. (See attached schematic) Scope Pre-Riq Operations 1. Pull BPV. 2. Perform MIT-OA to 2000 psi. CMIT-TxIA to 3000 psi. 3. Bleed OA, IA and tubing pressures to zero. 4. Test the IC (7 5/8") pack-off to 3,000 psi. 5. Function all LDS, repair or replace as necessary. 6. Set BPV. Riq Operations: 1. MI/RU Nordic 2. 2. Pull BPV. 3. Monitor the OA, IA and tubing for pressure. Verify the well is dead. 4. Install a TWC. Nipple down the production tree and adapter flange. 5. Nipple up the 13-5/8" BOPE and test to permit requirement. Pull the TWC. 6. Circulate out the freeze protection fluids and displace the well to seawater. 7. Pull the 4 1/2" tubing kill string. (2,487') 8. RU E-line. RIH and set an WRP in the 5-1/2" liner at ~4,000'. 9. Confirm OA, IA and T are at 0 psi. 10. ND 13-5/8" BOP stack. 05-286 Application for Sundry . ~ ~ II'' ' ~ ~~~ ~ ~~~ 11. NU adapter flange to tubing spool and NU a new/rebuilt 4-1/2" production tree. PT wellbore and tree to 3000 psi. (Confirm WRP holding pressure) 12. NU 7-1/16" BOPE to top of tree. ~ 13. PT BOPE against a closed swab valve. Set TWC if needed. 14. RU slickline, pull WRP. ~ ~ 15. PU motor and 4.75" D331 on 2-3/8" E-coil tubing. 16. Mill out float equipment in 5-1/2" liner. 17. PU MWD, 3.75" x 4.125" Bi-center bit. Drill to planned TD of 14,530'. 18. Run 3-1/2" x 3-3/16" x 2-7/8° combination cemented/slotted liner. (Bonsai completion) r~~~ 19. PT liner lap to 2000 psi. 20. Clean out to TOL, polish seal bore, packer set depth, clean out inside CT liner to guide shoe. ~~`~'~, h 21. Run Memory CNL logs on coil tubing. ~ 22. Perforate ~1000'. ', ~ ~~~, 23. Set plug in 3-1/2" X nipple in CT liner and PT. ~~~""'~ 24. Set WRP in 5-1/2" liner above coil tubing liner @-4,000'. 25. ND 7-1/16" stack, production tree and adapter flange. ~(~ ~~ 26. NU 13-5/8" BOPE. 27. Set Test plug, and PT BOPE. ~~~ 28. Slickline pull WRP and plug in 3-1/2" X nipple in CT liner. 29. Slickline run gauge ring -junk basket in 5-1/2" 17# liner to top of CT liner. > 30. Run 4-1/2" x 3-1/2" production tubing with GLM's, and 3-1/2" x 5-1/2" production packer. ~, ~ 31. Land tubing circulate the well to inhibited fluid. 32. Set and test the production packer. 33. Shear the DCR valve, and circulate in diesel FP fluid on tubing and IA. 34. Set TWC. 35. N/D the 13-5/8" BOPE. N/U the adapter flange and new tree. Test the tree and adapter to S,OOOpsi. 36. Pull the TWC. 37. Install a BPV and test. Secure the well. I 38. RD/MO. Post-Rip Work: 1. Install well-house and flow-line. 2. Pull BPV. 3. MI/RU slickline. Pull the ball and rod / RHC plug from `X' nipple below the new production packer. 4. Pull sheared DCR valve. Run live gas lift design. 5. POP Well. Timina: Estimated Pre-rig operations start date: 06/01/2007 Estimated Rig operations: 07/15/2007 Reservoir Pressure: • The estimated maximum reservoir pressure is 3,250 psi at 8,800' MD (7.1 ppg EMW) • The maximum anticipated surface pressure with gas (0.10 pis/ft) to surface is 2,370 psi. Mud Proqram: • Well kill: Seawater or 8.4 ppg KCL brine • Window milling/Drilling: 8.7 ppg Flo-pro drilling mud. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind and Inject. • All Class 1 wastes will go to Pad 3 for disposal. 05-28B Application for Sundry u ~ ,~ Hole Size: • 4-1/8" for the build section of hole from 11,666' -12,750' • 4-1/8" or 3.75" for the lateral section of hole from 12,750' -14,530'. Casinp/Tubinq Proqram: Cemented 3-1/2" x 3-3/16" liner with uncemented slotted 2-7/8" liner (Bonsai Completion) • CTD Production liner 3-1/2" STL, L-80 x 3-3/16" TCII, L-80 solid liner 11,280' MD -12,700' MD x 2-7/8", STL, L-80, slotted liner 12,700' MD -14,530' MD • A minimum of 14.5 bbls of Class G cement will be used for the production liner cementing for the 3-1/2" and 3-3/16" sections only. (Annular volume + 40% excess in open hole) • TOC for the production liner is planned at the top of liner at 11,280' MD. • The production tubing will be 4-1/2", 12.6# 13Cr80 Vam Top x 3-1/2", 9.2#, 13Cr-80 Vam Top Well Control: • BOP diagram for both drilling and completion phases is included. • Pipe rams, blind rams, inner reel valves, and the CT packoff 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 the attached directional plan. The maximum planned hole angle is 91.65 deg. @ 12,500' MD. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 35,905'. • Distance to nearest well within pool - 490 ft. (DS 18-30) Loqqinq: • MWD directional, and Gamma Ray will be run over all open hole sections. • A cased hole CNL-GR-CCL log will be run from PBTD to 11,000'. Hazards: • DS 5 is not designated as an H2S drillsite. The maximum recorded H2S level on DS 5 is 27 ppm on well DS 5-05B. • The lost circulation risk is low. No fault crossings expected. Attachments 1. Current well Schematic (Post Rotary Sidetrack) 2. Proposed well schematic (After Coil Sidetrack) 3. 13-5/8" BOP sketch for completion operations 4. 7-1/16" BOP sketch for CT drilling operations. 5. Directional Plan Greg Sarber CT Operations Drilling Engineer 564-4330 sarberiaCa~bp.com 05-286 Application for Sundry ~ ~ ~~~n= ~v = V= igle = MD = Tvn = TRA SLp~A HOLE O ~ _~ ~ ~ FAAC - ~"`-`~;a Suspended 08/09/06 1 b3/4' CSG, 45 S!, J-55, BTC, ID = 9 95D" I-{ 3896' ~ ~ FM C R~tra G~n 5 11"x4 J/2"^~^IImn s ban ~ Iry H 4" c,ov ~ Adapter 11 ° 5000# x 4 1/'!6" SOOOtk Tree 4 1/i6" Z~~, 4 5" tbg, 12 6M, IBT, 3.958' ID, ki1 shing w dh mule s Froe cut 1 hcl@ TO L(5 1/2') 35deg 795T H~-sra x ~-~n^ B0T2XPpacker 4150' 7 5!8" ¢ dril BP 1 ? 572' Landing co~lar s~cl@ PBTD 3C czeq ~B-~se ofKingak 11620' 11666' TD 5-112", 17#. L-BO Fyd 521 liner 4.892" ( ~_. ~__~ ~-- - -H----~ - -- ---- ~ r _ -._ 1U923' I 9423' TOC (tayped) 8784~ 7-5/8' X 3-1l2' BAKER SB-3A PKR 9872' 2 70" BKR DEROYMENT SLV, D= 225" .~,. ~ D4TE REV BY CAMMRJTS D4TE REV BY CAMVENTS 09109191 ORlqNAL COM PLETION 10130101 CTDSIDETRACK 11/22/02 CFVTLP CARRECTIONS 01/15/04 KSB/KK PULL PATCH; SET ITTP 01ID9I06 JF~MS Drill sidetracklset liner PFtUDI-IOE BAY UNR WELL: OS-28A P@2MT No: 2011960 AR No: 50-029-2710~07 SEC 32, T11 N, R15E, 2431' SNL & 4220' WFl BP Expfontion (Alaska) 05-286 Application for Sundry ~ ~ 05-28B Proposed Completion 2. 200 ~ 112.' 'X' 13CR80 landinp npDk, ID = 3 B ~ 3' ~m ~yp = p~q Detum ND = 8800' SS 3,000 atl2•x3112"crossover GAS L~T MANDFiE1S ST fuU ND DEV TYf~ VLV LATCH PORT D4TE 2 3508 3200 3 1R" X 1" KBG2-9 DCK BK 10 3/4', 45.5N, J-55. 3~896 1 7317 5500 3 1!2" X 1" KBG2-9 OMY BK L-80, cag D= 9.950" ? ~5; i0~ 5 tr2.. 3969' 7-5/8 X 5-1/2" BOT ZXP peCker ~ 11.225 3 112" 'X' lendinp nipple, ~= 2 813' WHIPSiOCK 4,119 11,246 Baker 5 1/Y X 3 1/2' SABL-3 pkr 11,265 3 1/2"'X' landing nipple. ID = 2 813" CIBP 4,152 11280~ BOT G2 set sleave ID=4 0' OD=1 318" NO SEALS Pre-rg tbe cut. 3 v2", 4,300 11,300 3 ia• ~x iar,d~r,q nipple ID = 2 873' 9.2#. 13-CR-60 5-1I2", 17M, L-80 Fyd 521 Iner ID = 4.892'. e i rz• i z st x s in°, 11656' NOTE. SET 1oF7 OFF BOTTOM, CBuNET N 920.13-CR-80,VAM 11,280 ~ ~ ' CENEfYtFORLOSSES TOP 5 1!2" liner top 9,837 7 5/8". 29 7#. L-80. , O', ~ csg ID=6.875" 3 1/2 x 3 3l18" x 2 7!8" L-80 14,530' combmat~on cemented and slotted liner ( Bansai Completion) 5 1/2" 17ft. '13CR- 10,923 GKXxXxX~ ~ SO,hnerl0 = 4 892" •" ' '~'•'•'•' '•' - -- 12,700 ~ -._. . . _ . _ _ ,. 3:16" a 2 7%8" crossover dATE REV BY COMVEWTS DATE REV BY COMNFr7TS 09/08191 OPoGINAL COMPLETION 08119/03 CMD/TLP ~ATIX~A ND CARRECTION 10I30101 CTD SIDETRACK 09l14103 BJMcUTL ECL~SE PA ~CH 11l22/02 CFUTLP CORRECTIONS 10122f03 MlAlTLH NW D CORRECTION 09128102 NWKAK GLVCJO 12l28l03 JBNVPAG LNRDCORRECTION OSI08/03 JJlKAK PULL FISH 01/15/04 KS8lKK PI~L PATp-1. SET LTTP 07/30/03 7~/IV~K PATCH 8 fuN ID CARRECTION PRUOhIOE BAY t1WT WE1L: OS-28A PEPo1fiT No: 2011950 AR No: 50-029-22208-01 T11N. R15E. 2431' SNL 8 4220' WH. BP 6cploratio~ (Alaska) 05-286 Application for Sundry - . ~ _ . b BP Alaska ~ B ~ ~ p Baker Hu hes INTE Plannin Re ort s g Q g P INTEQ Company: BP Amoco Dste: 3/30/2007 . Time: 15:d5:00 Page: 1` Field: Prudhce Bay Co-ordinate(NE) Referenee: WeIL• 05-28, True Nortir Site: PB DS 05 VerNcal (TVD) Referencec 05-28B: 63.7 WeiL• 05-28 Sec6oo (VS) Referonce: Weli (O.OON,O.OOE,315.OOAzi) Wellpat6: Plan 6, 05-28B Snrvey Calcul~tion Method: Minimum Curvature Db: Orade 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: bggm2006 Site: PB DS 05 TR-11-15 UNITED STATES : North Slope Site Position: Northing: 5947204.70 ft Latitude: 70 15 35.696 N From: Map Easting: 697428.91 ft Longitude: 148 24 14.424 W Position Uocertainty: 0.00 ft Nort6 Reference: True Ground Level: 0.00 R Grid Convergence: 1.50 deg Well: 05-28 Slot Name: 05-28 Well Position: +N/-S 1815.10 ft Northing: 5949038.65 ft Latitude: 70 15 53.547 N +E/-W 746.88 ft Easting : 698127.91 ft Longitude: 148 23 52.687 W Position Uncertainty: 0.00 ft Wellpath: Plan 6, 05-28B Drilled From: 05-28B Tie-on Depth: 11628.83 ft Current Datum: 05-28B: Height 63.70 ft Above System Datum: Mean Sea Level MagneNc Data: 1/31/2007 Declination: 24.19 deg Field Strength: 57667 nT Mag Dip Angle: 80.94 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.50 0.00 0.00 315.00 Plan: Plan #6 Date Composed: 1/31/2007 copy Lamar's plan 6 Version: ' 8 Principai: Yes Tied-to: From: Definitive Path Targets Name Description Dip. Dir. TVD ft +N/-S ft +E/-W ft Map Northing ft Map Easting ft <- Latitude --> Deg Min Sec <_-- Longtnde ,-a Deg Min Sec 05-28B Fault 1 63.70 6863.53 -1497.90 5955860.00 696450.00 70 17 1.048 N 148 24 36.320 W -Polygon 1 63.70 6863.53 -1497.90 5955860.00 696450.00 70 17 1.048 N 148 24 36.320 W -Polygon 2 63.70 6979.81 -1354.78 5955980.00 696590.00 70 17 2.192 N 148 24 32.152 W 05-28B Plan 6 Polygon 63.70 6920.48 -1571.43 5955915.00 696375.00 70 17 1.608 N 148 24 38.463 W -Polygon 1 63.70 6920.48 -1571.43 5955915.00 696375.00 70 17 1.608 N 148 24 38.463 W -Polygon 2 63.70 7730.52 -2510.49 5956700.00 695415.00 70 17 9.573 N 148 25 5.825 W -Polygon 3 63.70 8487.93 -2590.59 5957455.00 695315.00 70 17 17.021 N 148 25 8.166 W -Polygon 4 63.70 8506.22 -2335.01 5957480.00 695570.00 70 17 17.202 N 148 25 0.720 W -Polygon 5 63.70 7827.46 -2012.74 5956810.00 695910.00 70 17 10.527 N 148 24 51.325 W -Polygon 6 63.70 7114.50 -1151.16 5956120.00 696790.00 70 17 3.517 N 148 24 26.221 W 05-286 Fault 3 63.70 8222.49 -2767.65 5957185.00 695145.00 70 17 14.410 N i48 25 13.322 W -Polygon 1 63.70 8222.49 -2767.65 5957185.00 695145.00 70 17 14.410 N 148 25 13.322 W -Polygon 2 63.70 8636.84 -2736.73 5957600.00 695165.00 70 17 18.485 N 148 25 12.426 W 05-286 Fault 2 63.70 7246.85 -2758.32 5956210.00 695180.00 70 17 4.815 N 148 25 13.040 W -Polygon 1 63.70 7246.85 -2758.32 5956210.00 695180.00 70 17 4.815 N 148 25 13.040 W -Polygon 2 63.70 7139.77 -2110.88 5956120.00 695830.00 70 17 3.764 N 148 24 54.179 W 05-28B Fault 4 63.70 8803.50 -2417.22 5957775.00 695480.00 70 17 20.126 N 148 25 3.118 W -Polygon 1 63.70 8803.50 -2417.22 5957775.00 695480.00 70 17 20.126 N 148 25 3.118 W -Polygon 2 63.70 8666.04 -2325.80 5957640.00 695575.00 70 17 18.774 N 148 25 0.453 W 05-28B Target 2 8783.70 7682.93 -2184.61 5956661.00 695742.00 70 17 9.105 N 148 24 56.331 W 05-28B Target 3 8793.70 8489.12 -2445.50 5957460.00 695460.00 70 17 17.034 N 148 25 3.939 W ~ BP Alaska ~ ~ bp Baker Hughes INTEQ Planning Report ~~r ~s INTEQ Company: BP Amoco Datr. 3/30/2007 Tiree: 15:45:00 ' Page: 2 Field: Prudhoe Bay Go-ordiaate(NE)References Welf: 05-28, True North Site: PB DS 05 Vertieai (TVD) Referencec 05-28B: 63.7 WeII: 05-28 SecNon (V5) References WeU (O.OON,O .OOE,315.OOAzi) Wellpath: Plan 6, 05-28B Survey Calculaqoo Method: Minimum Curvature Db: Orade Targets Map Map <-- Latitude -~ ~--- Loagitude '---~ Name Description 1'VD +N/-S +E/-W Northiog EASting Deg Min Sec Deg Min Sec , Dip. Dir. ft ft ft ft ft 05-288 Target 1 8802.70 7072.23 -1331.34 5956073.00 696611.00 70 17 3.101 N 148 24 31 .470 W AnnotaHon MD '1'VD ft ft 11628.83 8279.49 TIP - Tie to 05-28B 11656.00 8303.09 KOP 11781.00 8413.22 3 11831.00 8457.72 4 11851.00 8475.68 5 12486.80 8802.64 6 12611.80 8799.09 7 13136.80 8787.25 8 13586.8Q 8784.09 9 14011.60 8787.35 10 14530.80 8793.57 TD Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 11628.83 29.67 275.10 8279.49 6903.08 -824.46 0.00 0.00 0.00 0.00 11656.00 29.67 275.10 8303.09 6904.28 -837.85 0.00 0.00 0.00 0.00 11781.00 27.98 243.88 8413.22 6894.06 -895.33 12.00 -1.35 -24.98 250.00 11831.00 26.49 256.60 8457.72 6886.30 -916.72 12.00 -2.99 25.45 110.00 11851.00 25.76 261.80 8475.68 6884,65 -925.36 12.00 -3.65 25.98 110.00 12486.80 91.65 314.56 8802.64 7124.42 -1353.77 12.00 10.36 8.30 55.00 12611.80 91.59 329.57 8799.09 7222.69 -1430.37 12.00 -0.04 12.00 90.00 13136.80 90.72 266.56 8787.25 7457.30 -1870.56 t 2.00 -0.17 -12.00 270.00 13586.80 90.02 320.55 8784.09 7630.56 -2267.95 12.00 -0.16 12.00 90.50 14011.80 89.16 11.55 8787.36 8029.53 -2367.05 12.00 -0.20 12.00 91.10 14530.80 89.61 309.27 8793.57 8494.72 -2532.64 12.00 0.09 -12.00 270.00 Survey MD Incl Azim SS TVD N/S E/W MapN MapE DLS VS 1'FO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg ' 11628.83 29.67 275.10 8215.79 6903.08 -824.46 5955917.26 697122.13 0.00 5464.20 0.00 MWD 11650.00 29.67 275.10 8234.18 6904.01 -834.90 5955917.92 697111.67 0.00 5472.23 0.00 MWD 11656.00 29.67 275.10 8239.39 6904.28 -837.85 5955918.10 697108.71 0.00 5474.51 0.00 MWD 11675.00 28.96 270.67 8255.96 6904.75 -847.14 5955918.33 697099.41 12.00 5481.41 250.00 MWD 11700.00 28.26 264.58 8277.91 6904.26 -859.09 5955917.53 697087.48 12.00 5489.52 253.86 MWD 11725.00 27.84 258.26 8299.98 6902.51 -870.70 5955915.48 697075.92 12.00 5496.49 259.21 MW~ 11750.00 27.72 251.83 8322.11 6899.51 -881.94 5955912.18 697064.76 12.00 5502.32 264.79 MWD 11775.00 27.90 245.40 8344.22 6895.26 -892.79 5955907.65 697054.03 12.00 5506.98 270.48 MWD 11781.00 27.98 243.88 8349.52 6894.06 -895.33 5955906.38 697051.53 12.00 5507.93 276.17 MWD 17800.00 27.28 248.56 8366.36 6890.50 -903.38 5955902.61 697043.57 12.00 5511.11 110.00 MWD 11825.00 26.60 255.01 8388.65 6886.96 -914.12 5955898.79 697032.92 12.00 5516.20 105.85 MWD 11831.00 26.49 256.60 8394.02 6886.30 -916.72 5955898.06 697030.34 12.00 5517.57 100.10 MWD 11850.00 25.79 261.53 8411.08 6884.71 -924.93 5955896.25 697022.18 12.00 5522.25 110.00 MWD 11875.00 27.50 266.91 8433.43 6883.60 -936.06 5955894.86 697011.08 11.83 5529.34 57.03 MWD 11900.00 29.50 271.61 8455.41 6883.47 -947.98 5955894.40 696999.17 12.00 5537.67 50.43 MWD 11925.00 31.64 275.74 8476.93 6884.29 -960.66 5955894.90 696986.47 12.00 5547.22 46.30 MWD 11950.00 33.90 279.40 8497.95 6886.09 -974.07 5955896.34 696973.03 12.00 5557.97 42.73 MWD 11975.00 36.25 282.63 8518.41 6888.84 -988.16 5955898.72 696958.87 12.00 5569.88 39.66 MWD 12000.00 38.68 285.52 8538.26 6892.55 -1002.90 5955902.04 696944.03 12.00 5582.93 37.01 MWD 12025.00 41.18 288.12 8557.43 6897.20 -1018.26 5955906.29 696928.56 12.00 5597.08 34.72 MWD ~ BP Alaska ~' ~ bp Baker Hughes INTEQ Planning Report ~ar s ~~s INTEQ Gompaay: BP Amoco Date: 3/30/2007 Timt: 15:45:00 Page: 3 Field: Prudhoe Bay Co-ordioate(NE) Reference: We11: 05-28, Tkue North Site: P8 DS 05 Vertical (TVD) Referener. 05-28B: 63.7 Well: 05-28 Secdon (VS) Refereoce: Welt'(O.OON,O.OOE,315.OOAzi) Wellpat6: Pla n 6, 05-28B Survey CalcalaHon Method: Minimum Gurvature Db: Orade Survey MD Incl Azim SS 1'VD N!S FJW MapN MapE DLS VS 1'FO Tool ft de9 de9 ft ft ft ft ft deg/100ft ft deg 12050.00 43.73 290.46 8575.87 6902.79 -1034.18 5955911.45 696912.50 12.00 5612.28 32.73 MWD 12075.00 46.32 292.60 8593.54 6909.28 -1050.62 5955917.51 696895.89 12.00 5628.50 31.00 MWD 12100.00 48.95 294.56 8610.39 6916.68 -1067.55 5955924.45 696878.78 12.00 5645.70 29.49 MWD 12125.00 51.61 296.36 8626.37 6924.95 -1084.90 5955932.26 696861.21 12.00 5663.82 28.17 MWD 12150.00 54.29 298.04 8641.43 6934.07 -1102.64 5955940.92 696843.24 12.00 5682.81 27.01 MWD 12175.00 57.00 299.61 8655.53 6944.02 -1120.72 5955950.39 696824.91 12.00 5702.63 26.00 MWD 12200.00 59.72 301.08 8668.65 6954.78 -1139.08 5955960.66 696806.27 12.00 5723.22 25.12 MWD 12225.00 62.46 302.48 8680.73 6966.31 -1157.68 5955971.69 696787.37 12.00 5744.53 24.34 MWD 12250.00 65.22 303.80 8691.75 6978.57 -1176.47 5955983.46 696768.27 12.00 5766.49 23.67 MWD 12275.00 67.98 305.07 8701.68 6991.55 -1195.39 5955995.93 696749.02 12.00 5789.04 23.08 MWD 12300.00 70.76 306.29 8710.49 7005.20 -1214.39 5956009.08 696729.67 12.00 5812.12 22.58 MWD 12325.00 73.54 307.47 87f 8.15 7019.48 -1233.42 5956022.85 696710.27 12.00 5835.68 22.15 MWD 12331.67 74.28 307.78 8720.00 7023.39 -1238.50 5956026.63 696705.09 12.00 5842.04 21.79 05-28B 12350.00 76.33 308.62 8724.65 7034.35 -1252.43 5956037.22 696690.87 12.00 5859.64 21.70 MWD 12375.00 79.12 309.73 8729.96 7049.78 -1271.36 5956052.15 696671.54 12.00 5883.94 21.49 MWD 12400.00 81.92 310.83 8734.08 7065.73 -1290.17 5956067.59 696652.32 12.00 5908.51 21.25 MWD 12425.00 84.72 311.91 8736.99 7082.14 -1308.80 5956083.50 696633.27 12.00 5933.29 21.07 MWD 12450.00 87.52 372.99 8738.68 7098.97 -1327.20 5956099.84 696614.43 12.00 5958.20 20.95 MWD 12475.00 90.33 314.06 8739.15 7116.18 -1345.33 5956116.57 696595.86 12.00 5983.19 20.87 MWD 12486.80 91.65 314.56 8738.94 7124.42 -1353.77 5956124.59 696587.20 12.00 5994.99 20.85 MWD 12500.00 91.65 316.15 8738.56 7133.81 -1363.04 5956133.72 696577.69 12.00 6008.18 90.00 MWD 12525.00 91.64 319.15 8737.84 7152.27 -1379.87 5956151.74 696560.38 12.00 6033.14 90.05 MWD 12550.00 91.64 322.15 8737.13 7171.60 -1395.72 5956170.64 696544.03 12.00 6058.01 90.13 MWD 12575.00 91.62 325.15 8736.42 7191.72 -1410.53 5956190.36 696528.70 12.00 6082.71 90.22 MWD 12600.00 91.60 328.15 8735.71 7212.59 -1424.27 5956210.86 696514.42 12.00 6107.18 90.30 MWD 12611.80 91.59 329.57 8735.39 7222.69 -1430.37 5956220.80 696508.05 12.00 6118.63 90.39 MWD 12625.00 91.59 327.98 8735.02 7233.97 -1437.21 5956231.89 696500.92 12.00 6131.45 270.00 MWD 12650.00 91.59 324.98 8734.32 7254.80 -1451.01 5956252.35 696486.58 12.00 6155.94 269.96 MWD 12675.00 91.58 321.98 8733.63 7274.88 -1465.88 5956272.04 696471.18 12.00 6180.65 269.87 MWD 12700.00 91.57 318.98 8732.95 7294.16 -1481.78 5956290.89 696454.78 12.00 6205.52 269.79 MWD 12725.00 91.55 315.98 8732.27 7312.58 -1498.67 5956308.85 696437.42 12.00 6230.49 269.71 MWD 12750.00 91.53 312.98 8731.59 7330.08 -1516.49 5956325.88 696419.13 12.00 6255.48 269.63 MWD 12775.00 91.50 309.98 8730.93 7346.63 -1535.22 5956341.93 696399.98 12.00 6280.42 269.55 MWD 12800.00 91.47 306.97 8730.29 7362.18 -1554.78 5956356.96 696380.02 12.00 6305.24 269.47 MWD 12825.00 91.44 303.97 8729.65 7376.68 -1575.13 5956370.92 696359.29 12.00 6329.89 269.39 MWD 12850.00 91.40 300.97 8729.03 7390.10 -1596.21 5956383.78 696337.87 12.00 6354.28 269.31 MWD 12875.00 91.36 297.97 8728.43 7402.40 -1617.97 5956395.49 696315.80 12.00 6378.36 269.24 MWD 12900.00 91.31 294.97 8727.85 7413.53 -1640.34 5956406.04 696293.14 12.00 6402.06 269.17 MWD 12925.00 91.26 291.97 8727.29 7423.49 -1663.26 5956415.39 696269.97 12.00 6425.30 269.10 MWD 12950.00 91.21 288.97 8726.75 7432.23 -1686.67 5956423.51 696246.33 12.00 6448.04 269.03 MWD 12975.00 91.15 285.97 8726.23 7439.73 -1710.51 5956430.38 696222.31 12.00 6470.20 268.96 MWD 13000.00 91.10 282.97 8725.74 7445.98 -1734.71 5956435.99 696197.95 12.00 6491.73 268.90 MWD 13025.00 91.03 279.97 8725.27 7450.95 -1759.21 5956440.37 696173.34 12.00 6512.56 268.84 MWD 73050.00 90.97 276.97 8724.84 7454.63 -1783.93 5956443.34 696148.53 12.00 6532.65 268.79 MWD 13075.00 90.90 273.97 8724.43 7457.01 -1808.81 5956445.07 696123.60 12.00 6551.92 268.73 MWD 13100.00 90.83 270.97 8724.05 7458.09 -1833.78 5956445.49 696098.61 12.00 6570.34 268.69 MWD 13125.00 90.76 267.97 8723.71 7457.86 -1858.77 5956444.60 696073.63 12.00 6587.86 268.64 MWD 13136.80 90.72 266.56 8723.55 7457.30 -1870.56 5956443.73 696061.86 12.00 6595.79 268.60 MWD 13150.00 90.71 268.14 8723.39 7456.69 -1883.74 5956442.77 696048.70 12.00 6604.68 90.50 MWD 73175.00 90.68 271.14 8723.08 7456.53 -1908.74 5956441.96 696023.72 12.00 6622.25 90.52 MWD 13200.00 90.65 274.14 8722.79 7457.68 -1933.71 5956442.45 695998.73 12.00 6640.72 90.56 MWD 13225.00 90.62 277.14 8722.52 7460.14 -1958.58 5956444.25 695973.80 12.00 6660.04 90.59 MWD 13250.00 90.59 280.14 8722.25 7463.90 -1983.29 5956447.36 695949.00 12.00 6680.17 90.62 MWD ~ bp ~ BP Alaska ~ B~R ~ ~~~s Baker Hughes INTEQ Planning Report LNTEQ Company: ` BP Amoco Datec 3/30/2007 Time: 15;45:00 Page: 4 Field: P~udhoe Bay , Co-ordinate(NE) Rtferencr. We11: 05-28, True North. Site: PB DS 05 Vertical (TVD) Refertnce: 05-2$B: 63.7 WeIL• 05-28 Section (VS) Reference: Well (O.OON,O.OOE,315.QOAzi) Wellpat6: Pla n 6,05-28 B Survey Caleulation Method: Minimum Curvature Db: Oraele Survey MD Incl Azim SS 7'VD Pi/S E/W MapN. MapE ` DIS VS ` TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft, , deg 13275.00 90.55 283.14 8722.01 7468.94 -2007.77 5956451.76 695924.40 12.00 6701.05 90.66 MWD 13300.00 90.51 286.14 8721.77 7475.26 -2031.96 5956457.44 695900.06 12.00 6722.62 90.69 MWD 13325.00 90.48 289.14 8721.56 7482.84 -2055.78 5956464.38 695876.05 12.00 6744.82 90.71 MWD 13350.00 90.44 292.14 8721.36 7491.65 -2079.17 5956472.57 695852.43 12.00 6767.59 90.74 MWD 13375.00 90.40 295.14 8721.18 7501.67 -2102.07 5956481.99 695829.28 12.00 6790.87 90.76 MWD 13400.00 90.35 298.14 8721.01 7512.88 -2124.41 5956492.61 695806.65 12.00 6814.59 90.79 MWD 13425.00 90.31 301.14 8720.87 7525.24 -2146.14 5956504.39 695784.61 12.00 6838.70 90.80 MWD 13450.00 90.27 304.14 8720.74 7538.72 -2167.19 5956517.32 695763.21 12.00 6863.11 90.82 MWD 13475.00 90.22 307.14 8720.63 7553.29 -2187.50 5956531.34 695742.52 12.00 6887.78 90.84 MWD 13500.00 90.18 310.14 8720.54 7568.90 -2207.03 5956546.43 695722.59 12.00 6912.62 90.85 MWD 73525.00 90.13 313.14 8720.48 7585.51 -2225.71 5956562.54 695703.48 12.00 6937.58 90.86 MWD 13550.00 90.09 316.14 8720.43 7603.07 -2243.49 5956579.63 695685.24 12.00 6962.57 90.87 MWD 13575.00 90.04 319.14 8720.40 7621.54 -2260.34 5956597.65 695667.92 12.00 6987.54 90.87 MWD 13586.80 90.02 320.55 8720.39 7630.56 -2267.95 5956606.46 695660.08 12.00 6999.30 90.88 MWD 13600.00 89.99 322.14 8720.39 7640.87 -2276.19 5956616.55 695651.56 12.00 7012.42 91.10 MWD 13625.00 89.93 325.14 8720.41 7661.00 -2291.01 5956636.28 695636.22 12.00 7037.13 91.10 MWD 13650.00 89.88 328.14 8720.45 7681.88 -2304.76 5956656.79 695621.93 12.00 7061.62 91.10 MWD 13675.00 89.82 331.14 8720.52 7703.44 -2317.39 5956678.02 695608.73 12.00 7085.80 91.09 MWD 13700.00 89.76 334.14 8720.61 7725.64 -2328.88 5956699.91 695596.66 12.00 7109.62 91.09 MWD 13725.00 89.71 337.14 8720.72 7748.41 -2339.20 5956722.40 695585.75 12.00 7133.02 91.07 MWD 13750.00 89.65 340.14 8720.87 7771.69 -2348.30 5956745.43 695576.04 12.00 7155.92 91.06 MWD 13775.00 89.60 343.13 8721.03 7795.42 -2356.18 5956768.93 695567.54 12.00 7178.26 91.04 MWD 13800.00 89.54 346.13 8721.22 7819.52 -2362.80 5956792.85 695560.29 12.00 7199.99 91.02 MWD 13825.00 89.49 349.13 8721.43 7843.94 -2368.15 5956817.12 695554.29 12.00 7221.04 91.00 MWD 13850.00 89.44 352.13 8721.66 7868.60 -2372.22 5956841.66 695549.58 12.00 7241.35 90.98 MWD 13875.00 89.39 355.13 872t.91 7893.44 -2374.99 5956866.42 695546.15 12.00 7260.88 90.95 MWD 13900.00 89.35 358.13 8722.19 7918.39 -2376.46 5956891.33 695544.03 12.00 7279.56 90.92 MWD 13925.00 89.30 1.13 8722.49 7943.39 -2376.62 5956916.31 695543.21 12.00 7297.35 90.88 MWD 13950.00 89.26 4.13 8722.80 7968.36 -2375.47 5956941.30 695543.70 12.00 7374.19 90.85 MWD 13975.00 89.22 7.13 8723.13 7993.23 -2373.02 5956966.22 695545.50 12.00 7330.05 90.81 MWD 14000.00 89.18 10.13 8723.48 8017.94 -2369.27 5956991.02 695548.60 12.00 7344.87 90.77 MWD 14011.80 89.16 11.55 8723.66 8029.53 -2367.05 5957002.67 695550.51 12.00 7351.49 90.73 MWD 14025.00 89.16 9.96 8723.85 8042.50 -2364.59 5957015.69 695552.63 12.00 7358.92 270.00 MWD 14050.00 89.16 6.96 8724.22 8067.22 -2360.91 5957040.50 695555.66 12.00 7373.80 270.02 MWD 14075.00 89.17 3.96 8724.58 8092.10 -2358.53 5957065.43 695557.39 12.00 7389.71 270.07 MWD 14100.00 89.17 0.96 8724.94 8117.07 -2357.45 5957090.42 695557.80 12.00 7406.61 270.11 MWD 14125.00 89.18 357.96 8725.30 8142.07 -2357.69 5957115.40 695556.91 12.00 7424.44 270.15 MWD 14150.00 89.19 354.96 8725.66 8167.01 -2359.23 5957140.30 695554.71 12.00 7443.18 270.20 MWD 14175.00 89.21 351.96 8726.01 8191.84 -2362.07 5957165.04 695551.22 12.00 7462.75 270.24 MWD 14200.00 89.22 348.96 8726.35 8216.49 -2366.21 5957189.58 695546.43 12.00 7483.10 270.28 MWD 14225.00 89.24 345.96 8726.69 8240.89 -2371.64 5957213.82 695540.36 12.00 7504.19 270.32 MWD 14250.00 89.26 342.96 8727.01 8264.97 -2378.33 5957237.72 695533.04 12.00 7525.96 270.36 MWD 14275.00 89.28 339.96 8727.33 8288.67 -2386.28 5957261.20 695524.47 12.00 7548.33 270.40 MWD 14300.00 89.31 336.96 8727.64 8311.92 -2395.46 5957284.20 695514.69 12.00 7571.26 270.44 MWD 14325.00 89.33 333.96 8727.93 8334.66 -2405.84 5957306.65 695503.71 12.00 7594.68 270.48 MWD 14350.00 89.36 330.96 8728.22 8356.82 -2417.39 5957328.50 695491.58 12.00 7618.52 270.51 MWD 14375.00 89.39 327.96 8728.49 8378.35 -2430.09 5957349.69 695478.31 12.00 7642.73 270.55 MWD 14400.00 89.42 324.96 8728.75 8399.19 -2443.90 5957370.15 695463.96 12.00 7667.22 270.58 MWD 14425.00 89.45 321.96 8729.00 8419.27 -2458.79 5957389.83 695448.56 12.00 7691.95 270.61 MWD 14450.00 89.49 318.96 8729.23 8438.55 -2474.70 5957408.69 695432.14 12.00 7716.83 270.64 MWD 14475.00 89.52 315.96 8729.44 8456.97 -2491.60 5957426.65 695414.77 12.00 7741.80 270.67 MWD i4500.00 89.56 312.96 8729.64 8474.47 -2509.44 5957443.68 695396.47 12.00 7766.80 270.69 MWD , b ~ BP Alaska ~ ~ p Baker Hughes INTEQ Planning Report ~.r sNAUe i~~ INTEQ Gompany: BP Amoco Dste: 3/30/2007 Timr. 15:45:OQ Page: S- Field: Prudhoe Bay Co-ordinate(NE) Reference: Weil: 05-28, True North Site: PB DS 05 Vertieal (7'VD) Referenee: 05-28B: 63J We1L• 05-28 Section (VS) Re[erence: Well (O.OON,O.OOE,315.OOAzi) Wellpath: Plan 6, D5-286 " SurvegCalculation Method: Minimum Cunrature Db: : Oracte Survey MD Inel Azim SS 1'VD N/S E/W MapN M~pE DLS VS 1'FO ,Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 14525.00 89.60 309.96 8729.83 8491.02 -2528.17 5957459.73 695377.31 12.00 7791.75 270.72 MWD 14530.80 89.61 309.27 8729.87 8494.72 -2532.64 5957463.31 695372.75 12.00 7797.52 270.74 3 1/2" ! ~ ~ a i~ $g t~Tr 1 ~:.~ ~{~. 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NIl110011 4]dea IQ~q~S an~y ~ BP Alaska ~ bp Anticollision Report ~ s~ .r Nuc,~s iNTEQ Companyt BP Amoco Date: 3/30/2007 Tiroe: 15:41:58 Pagec 3 Field: Prudhoe Bay Referenee Site: PB DS 05 Co-ordinate(NE) Reference: WeIL' 05-28, True North Reference WetL• 05-28 Vertical (TVD) Reference: 05-28B: 63.7 ` Reference WeOpath: Pian $, 05-28B Dbc Orade GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There are'~aeells in this9iettCipal Plan 8~ PLANNED PROGRAM Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 11628.83 to 14530.80 ft Scan l~iethod: Trav Cylinder North Maximum Radius: 3000.00 ft Error Surface: Ellipse + Casing Survey Program for DeSnitive Wellpath Date: 1/3 1/2007 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 55.40 4106.70 1: Schlumberger GCT multishot GCT-MS Schlumberger GCT multishot 4119.00 11628.83 05-286 IIFR (411 9.00-11628.83) MWD+IFR+MS MWD + IFR + Multi Station 11628.83 14530.80 Planned: Plan #6 V8 MWD MWD - Standard Casing Points MD 7'VD Diameter Hole Size Name ft ft in in 14530.80 8793.57 3.500 4.125 31l2" Summary <- --- Offset Wellpat6 - ------> Reference Offset Ctr-Ctr No-Co AOowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB DS 05 05-16 05-16 V5 13292.91 11696.70 1031.00 182.71 548.29 Pass: Major Risk PB DS 05 05-16 05-16A V1 13335.06 12229.70 464.48 204.88 259.60 Pass: Major Risk PB DS 05 05-16 05-16B V3 13486.74 12300.00 766.19 249.27 516.92 Pass: Major Risk PB DS 05 05-28 05-28 V3 11993.93 10921.70 1284.04 152.06 1131.98 Pass: Major Risk PB DS 05 05-28 05-28A V3 12441.01 12228.70 465.57 239.23 226.34 Pass: Major Risk PB DS 05 05-28 05-28APB1 V1 12280.31 11963.70 562.57 220.02 342.55 Pass: Major Risk PB DS 05 05-28 05-286 V5 11666.00 11666.00 0.10 100.62 -100.51 FAIL: Major Risk PB DS 18 18-13 18-13 V3 14515.98 11082.70 598.90 393.63 205.26 Pass: Major Risk PB DS 18 18-13 18-13A V4 14513.03 11100.00 854.99 412.53 442.46 Pass: Major Risk PB DS 18 18-13 18-13PB2 V3 14505.96 11100.00 594.20 395.98 198.22 Pass: Major Risk PB DS 18 18-14 18-14A V4 Out of range PB DS 18 18-14 18-14AP61 V4 Out of range PB DS 18 18-156 18-156 V9 Out of range PB DS 18 18-21 18-21 V1 14375.00 10000.00 1110.27 371.23 739.04 Pass: Major Risk PB DS 18 18-21A 18-21A V1 14375.00 10000.00 1110.27 371.38 738.89 Pass: Major Risk PB DS 18 18-22 18-22 V1 13684.83 11865.40 765.19 387.70 377.50 Pass: Major Risk PB OS 18 18-22 18-22A V1 13955.18 11649.40 557.92 284.39 273.53 Pass: Major Risk PB DS 18 18-30 18-30 V1 14232.14 10300.00 385.94 329.66 56.28 Pass: Major Risk Site: PB DS 05 Well: 05-16 Rule Assigned: Major Risk Wellpath: 05-76 V5 Inter-Site Error: 0.00 ft Reference Offset Semi-Niajor Axis Ctr-Ctr No-Go Allowable MD TVD MD 7'VD Ref O1Tset TFO+AZI TFO-HS Casing/H~istanee Area Deviation Waroing ft ft ft ft ft ft deg deg in ft ft ft 11814.44 8442.92 9500.00 7483.55 25.44 27.34 215.51 323.26 4.000 2650.18 152.20 2497.98 Pass 11825.00 8452.35 9600.00 7546.87 25.44 27.89 216.61 321.60 4.000 2572.29 155.91 2416.38 Pass 11831.00 8457.72 9700.00 7609.70 25.44 28.42 217.62 321.02 4.000 2495.59 159.12 2336.47 Pass 11844.45 8469.78 9800.00 7672.40 25.52 29.05 218.85 318.79 4.000 2420.02 163.64 2256.38 Pass 11864.12 8487.44 9900.00 7735.26 25.38 29.46 220.22 315.56 4.000 2345.70 167.43 2178.28 Pass 11902.05 8520.89 10000.00 7798.51 24.85 29.44 221.93 309.96 4.000 2272.14 170.85 2101.29 Pass 11943.50 8556.24 10100.00 7861.85 24.30 29.12 223.62 305.13 4.000 2197.88 173.52 2024.35 Pass 11988.35 8592.79 10200.00 7925.18 23.77 28.55 225.28 301.07 4.000 2123.21 175.60 1947.62 Pass 12036.81 8629.94 10300.00 7988.88 23.31 28.03 226.91 297.66 4.000 2048.97 177.64 1871.33 Pass 12087.88 8666.03 10400.00 8052.70 23.03 27.60 228.47 294.84 4.000 1974.81 179.72 1795.09 Pass 12140.48 8699.50 10500.00 8116.36 23.02 27.33 229.92 292.51 4.000 1900.70 181.91 1718.79 Pass 12193.33 8728.95 10600.00 8179.94 23.31 27.28 231.23 290.53 4.000 1826.60 184.32 1642.28 Pass 12244.20 8752.99 10700.00 8243.85 23.87 27.47 232.27 288.77 4.000 1751.68 186.98 1564.71 Pass 12292.60 8771.70 10800.00 8307.69 24.59 27.86 233.07 287.13 4.000 1676.75 189.95 1486.80 Pass 12338.66 8785.55 10900.00 8371.49 25.41 28.45 233.60 285.51 4.000 1603.02 193.37 1409.65 Pass ~ BP Alaska ~ bp Anticollision Report r s~ ~~ Nu~~s iNTEQ Compaoy: BP Amoco Date: 3/30/2007 " Time: 1541:58 Page: 2. Field: Prudhoe Bay Reference Site: PB DS 05 Co-ordinate(NE) Reference: ; WeIL A5-28, True North Reference Wellc 05-28 Vertical (1'VD) Reference: 05-28B: 63.7 Refereoce Wellpath: Plan &, 05-28 6 Db: Orade Site: PB DS 0 5 Well: 05-16 Rule Assigned: Major Risk WellpatA: 05-16 V5 Inter-Site Error: 0.00 ft Reference OfPsefi Semi-MajorAais Ctr-Ctr No-Go Allowabk MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Gasing/H9)istance Area DeviaNon Warning ft R ft ft ft ft deg deg in ft ft ft 12381.96 8794.93 11000.00 8435.87 26.26 29.21 233.82 283.78 4.000 1531.43 197.33 1334.10 Pass 12422.08 8800.41 11100.00 8501.01 27.09 30.12 233.66 281.87 4.000 1462.71 201.87 1260.85 Pass 12458.64 8802.68 11200.00 8566.48 27.86 31.15 233.10 279.74 4.000 1396.95 206.98 1189.98 Pass 13275.00 8785.71 11300.00 8632.30 28.56 18.16 199.81 276.66 4.000 1324.01 169.77 1154.24 Pass 13275.00 8785.71 11400.00 8698.14 28.56 18.35 197.18 274.03 4.000 1245.15 171.49 1073.67 Pass 13275.00 8785.71 11500.00 8763.22 28.56 18.56 194.24 271.09 4.000 1169.o4 973.93 995.91 Pass 13286.03 8785.60 11600.00 8827.91 29.20 19.51 192.25 267.79 4.000 1096.57 178.81 917.75 Pass 13292.91 8785.54 11696.70 8890.49 29.60 20.28 189.45 264.16 4.000 1031.00 182.71 848.29 Pass Site: PB DS 05 Well: 05-16 Rule Assigned: Major Risk Wellpath: OS-16A V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowab[e NID 'I'VD MD TVD Ref Otfset 1'FO+AZI 1'FO-HS Casing/H~istance Area Deviatioo Waraing ft ft ft ft ft ft deg deg in ft ft ft 11814.44 8442.92 9500.00 7483.55 25.44 27.34 215.51 323.26 7.000 2650.18 152.32 2497.86 Pass 11825.00 8452.35 9600.00 7546.87 25.44 27.89 216.61 321.60 7.000 2572.29 156.04 2416.26 Pass 11831.00 8457.72 9700.00 7609.70 25.44 28.42 217.62 321.02 7.000 2495.59 159.25 2336.34 Pass 11844.45 8469.78 9800.00 7672.40 25.52 29.05 218.85 318.79 7.000 2420.02 163.77 2256.26 Pass 11864.12 8487.44 9900.00 7735.26 25.38 29.46 220.22 315.56 7.000 2345.70 167.55 2178.15 Pass 11902.05 8520.89 10000.00 7798.51 24.85 29.44 221.93 309.96 7.000 2272.14 170.97 2101.17 Pass 11943.50 8556.24 10100.00 7861.85 24.30 29.12 223.62 305.13 7.000 2197.88 173.65 2024.23 Pass 11988.35 8592.79 10200.00 7925.18 23.77 28.55 225.28 301.07 7.000 2123.21 175.72 1947.49 Pass 12036.81 8629.94 10300.00 7988.88 23.31 28.03 226.91 297.66 7.000 2048.97 177.77 1871.20 Pass 12087.88 8666.03 10400.00 8052.70 23.03 27.60 228.47 294.84 7.000 1974.81 179.84 1794.97 Pass 12140.48 8699.50 10500.00 8116.36 23.02 27.33 229.92 292.51 7.000 1900.70 182.04 1718.67 Pass 12193.33 8728.95 10600.00 8179.94 23.31 27.28 231.23 290.53 7.000 1826.60 184.44 1642.16 Pass 12244.20 8752.99 10700.00 8243.85 23.87 27.47 232.27 288.77 7.000 1751.68 187.10 1564.58 Pass 12292.60 8771.70 10800.00 8307.69 24.59 27.86 233.07 287.13 7.000 1676.75 190.08 1486.67 Pass 12338.66 8785.55 10900.00 8371.49 25.41 28.45 233.60 285.51 7.000 1603.02 193.50 1409.52 Pass 12381.96 8794.93 11000.00 8435.87 26.26 29.21 233.82 283.78 7.000 1531.43 197.46 1333.98 Pass 12422.08 8800.41 11100.00 8501.01 27.09 30.12 233.66 281.87 7.000 1462.71 201.99 1260.72 Pass 12458.64 8802.68 11200.00 8566.48 27.86 31.15 233.10 279.74 7.000 1396.95 207.10 1189.85 Pass 13275.00 8785.71 11300.00 8632.30 28.56 18.16 199.81 276.66 7.000 1324.01 169.89 1154.12 Pass 13275.00 8785.71 11400.00 8698.14 28.56 18.35 197.18 274.03 7.000 1245.15 171.61 1073.54 Pass 13275.00 8785.71 11500.00 8763.22 28.56 18.48 194.24 271.09 7.000 1169.04 175.06 993.98 Pass 13286.14 8785.60 11600.00 8800.05 29.21 19.11 193.71 269.23 7.000 1080.30 185.41 894.88 Pass 13291.51 8785.55 11700.00 8807.83 29.52 19.45 193.82 268.70 7.000 982.48 187.73 794.74 Pass 13300.00 8785.47 11800.00 8795.25 30.02 19.99 195.51 269.37 7.000 884.62 190.87 693.75 Pass 13304.17 8785.44 11900.00 8790.47 30.25 20.26 196.28 269.63 7.000 786.45 192.65 593.80 Pass 13312.69 8785.36 12000.00 8790.00 30.74 20.82 197.28 269.61 7.000 688.83 196.00 492.84 Pass 13321.51 8785.29 12100.00 8789.87 31.23 21.40 198.28 269.56 7.000 590.99 199.48 391.51 Pass 13331.73 8785.20 12200.00 8790.33 31.80 22.09 199.35 269.40 7.000 493.42 203.62 289.80 Pass 13335.06 8785.18 12229.70 8789.52 31.98 22.32 199.81 269.46 7.000 464.48 204.88 259.60 Pass Site: PB DS 05 Well: 05-16 Rule Assigned: Major Risk Wellpath: 05-16B V3 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowabk MD T~'D MD TVD Ref Offset TFO+AZI TF0.HS Casing/EI~istanee Area Deviation Warning ~ BP Alaska ~ bp Anticollision Report ~ BAI~R r ~s INTEQ Company; ' BP Amoco Date: 3/30/2007 Time: 15:41:58 Page: 3 Field: Prudhoe Bay Refereoce Site: PB DS 05 Co-ordinate(NE) Referenct: Well: D5-28, Tnie North' Reference We1L• 05-28 Vertical (TVD) Referencr. 05-2$B: 63.7 ' Reference Weilpathc Pian 6, 05-28 6 Db: Oracle Site: PB DS 05 Well: 05-16 Rule Assigned: Major Risk Wellpath: 05-16B V3 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Asis Ctr-Ctr No-Go Allowable MD TVD MD 'fVD Ref Offset 1'FO+AZI TFO-HS Casing/H~istance Area Deviation Waroing ft ft ft ft ft ft deg deg in ft ft ft 11814.44 8442.92 9500.00 7483.55 25.44 27.34 215.51 323.26 7.000 2650.18 152.32 2497.86 Pass 11825.00 8452.35 9600.00 7546.87 25.44 27.89 216.61 321.60 7.000 2572.29 156.04 2416.26 Pass 11831.00 8457.72 9700.00 7609.70 25.44 28.42 217.62 321.02 7.000 2495.59 159.25 2336.34 Pass 11844.45 8469.78 9800.00 7672.40 25.52 29.05 218.85 318.79 7.000 2420.02 163.77 2256.26 Pass 11864.12 8487.44 9900.00 7735.26 25.38 29.46 220.22 315.56 7.000 2345.70 167.55 2178.15 Pass 11902.05 8520.89 10000.00 7798.51 24.85 29.44 221.93 309.96 7.000 2272.14 170.97 2101.17 Pass 11944.54 8557.71 10100.00 7861.53 24.29 28.93 223.70 305.06 7.000 2199.92 173.34 2026.58 Pass 11995.82 8598.68 10200.00 7929.46 23.69 28.28 225.49 300.43 7.000 2133.44 175.52 1957.92 Pass 12053.16 8641.85 10300.00 8005.80 23.19 27.63 226.96 296.22 7.000 2070.50 177.45 1893.05 Pass 12110.41 8680.85 10400.00 8083.71 22.99 27.13 228.15 292.83 7.000 2007.71 179.37 1828.34 Pass 12164.98 8713.70 10500.00 8162.78 23.12 26.83 228.99 290.00 7.000 1944.79 181.37 1763.42 Pass 12214.79 8739.62 10600.00 8243.20 23.52 26.74 229.41 287.49 7.000 1881.84 183.48 1698.36 Pass 12259.99 8759.55 10700.00 8323.49 24.09 26.82 229.49 285.17 7.000 1819.55 185.79 1633.75 Pass 12302.50 8775.01 10800.00 8402.34 24.76 27.02 229.35 282.94 7.000 1759.86 188.40 1571.46 Pass 12341.55 8786.28 10900.00 8481.26 25.47 27.31 228.89 280.66 7.000 1703.78 191.25 1512.53 Pass 12378.60 8794.33 11000.00 8557.83 26.19 27.67 228.27 278.37 7.000 1651.49 194.35 1457.14 Pass 12414.21 8799.58 11100.00 8629.05 26.92 28.09 227.61 276.16 7.000 1599.91 197.69 1402.23 Pass 12447.60 8802.27 11200.00 8690.47 27.63 28.52 227.05 274.16 7.000 1542.71 201.05 1341.66 Pass 13285.41 8785.61 11300.00 8731.04 29.17 17.85 196.54 272.15 7.000 1453.05 173.00 1280.05 Pass 13291.80 8785.55 11400.00 8747.67 29.54 18.27 196.76 271.60 7.000 1357.55 185.52 1172.03 Pass 13300.00 8785.47 11500.00 8756.29 30.02 18.69 197.47 271.33 7.000 1261.52 188.57 1072.94 Pass 13307.76 8785.40 11600.00 8768.17 30.46 19.10 197.92 270.85 7.000 1166.98 191.67 975.31 Pass 13318.21 8785.31 11700.00 8780.68 31.05 19.67 198.57 270.25 7.000 1074.06 195.59 878.47 Pass 13332.13 8785.20 11800.00 8791.79 31.82 20.45 199.61 269.62 7.000 985.12 200.76 784.36 Pass 13350.00 8785.06 11900.00 8795.57 32.79 21.50 201.47 269.33 7.000 908.04 207.09 700.95 Pass 13375.00 8784.88 12000.00 8803.48 34.08 22.99 203.87 268.73 7.000 840.90 215.65 625.25 Pass 13411.58 8784.64 12100.00 8809.20 35.83 25.18 207.76 268.23 7.000 793.32 227.40 565.91 Pass 13450.00 8784.44 12200.00 8810.72 37.50 27.50 212.19 268.05 7.000 771.10 238.99 532.12 Pass 13486.74 8784.29 12300.00 8805.43 38.88 29.73 216.97 268.42 7.000 766.19 249.27 516.92 Pass 13525.00 8784.18 12400.00 8804.82 40.13 31.92 221.63 268.49 7.000 781.45 258.86 522.59 Pass 13559.22 8784.12 12500.00 8804.91 41.03 33.79 225.79 268.54 7.000 818.13 266.54 551.59 Pass 13589.31 8784.09 12600.00 8801.23 41.68 35.31 229.73 268.88 7.000 873.10 272.34 600.77 Pass 13613.21 8784.10 12700.00 8802.18 42.07 36.44 232.63 268.90 7.000 944.99 276.31 668.68 Pass 13632.27 8784.12 12800.00 8806.18 42.33 37.28 234.78 268.77 7.000 1026.09 279.12 746.97 Pass 13650.00 8784.15 12900.00 8809.69 42.52 37.92 236.82 268.69 7.000 1114.25 281.13 833.12 Pass 13660.09 8784.17 13000.00 8806.33 42.58 38.41 238.29 268.94 7.000 1203.17 282.42 920.75 Pass 13675.00 8784.22 13100.00 8805.98 42.68 38.90 240.17 269.03 7.000 1292.43 283.72 1008.71 Pass 13683.88 8784.25 13200.00 8804.47 42.69 39.30 241.36 269.16 7.000 1382.66 284.63 1098.03 Pass 13700.00 8784.31 13300.00 8802.70 42.72 39.62 243.42 269.28 7.000 1474.69 285.32 1189.37 Pass 13700.00 8784.31 13400.00 8801.82 42.72 39.98 243.50 269.36 7.000 1566.08 286.11 1279.97 Pass 13712.86 8784.37 13500.00 8804.00 42.69 40.28 245.00 269.32 7.000 1657.00 286.52 1370.48 Pass 13725.00 8784.42 13600.00 8805.00 42.67 40.53 246.46 269.32 7.000 1747.40 286.83 1460.57 Pass 13725.00 8784.42 13700.00 8809.53 42.67 40.89 246.36 269.22 7.000 1839.75 287.65 1552.10 Pass 13737.75 8784.49 13800.00 8810.72 42.58 41.02 247.89 269.22 7.000 1932.63 287.45 1645.18 Pass 13750.00 8784.57 13900.00 8809.02 42.50 41.09 249.44 269.30 7.000 2026.00 287.08 1738.93 Pass 13750.00 8784.57 14000.00 8807.38 42.50 41.40 249.52 269.38 7.000 2120.02 287.81 1832.21 Pass 13750.00 8784.57 14100.00 8806.78 42.50 41.72 249.57 269.43 7.000 2214.88 295.46 1919.42 Pass 13758.60 8784.62 14133.70 8806.74 42.40 41.59 250.60 269.44 7.000 2246.87 303.57 1943.31 Pass - . b BP Alaska ~ s ~~ ~ p Anticollision Report INTGQ Gompany: BP Amoca Date: 3/30J2007 Tiroe: 15:41:58 Page: 4 Field: Prudhoe Bay Reterence Site: PB DS 05 Co-ordioate(PiE) Referencr. We11: 05-28, Tnte North - Refereoce We1L• A5-28 Vertical (1'VD) Refcrence: 05-286: 63.7 Reference Wellpath: Plan 6,A5-28 B Dbc OraCle Site: PB DS 05 Well: 05-28 Rule Assigned: Major Risk Wellpath: 05-28 V3 Ioter-Site Error: 0.00 ft Reference Offset Semi-MajorAacis Ctr-Gtr No-Go Aliowable ' MD T~'D MD TVD Ref Offset TFO+AZI TF0.HS Casing/H9)istance Area Deviation ' Warnipg ft ft ft ft: ft ft deg deg in ft ft ft 11826.05 8453.29 10100.00 8315.63 25.44 37.19 175.60 280.31 1718.65 128.29 1590.37 Pass 11841.18 8466.84 10200.00 8393.14 25.50 37.64 175.04 275.83 1650.88 131.31 1519.58 Pass 11858.72 8482.61 10300.00 8471.54 25.45 37.89 174.41 270.90 1586.94 134.11 1452.83 Pass 11875.00 8497.13 10400.00 8550.30 25.23 37.90 173.57 266.66 1526.45 136.44 1390.01 Pass 11900.00 8519.11 10500.00 8629.45 24.88 37.76 172.76 261.16 1469.78 139.91 1329.87 Pass 11925.00 8540.63 10600.00 8709.13 24.54 37.50 171.76 256.01 1417.55 143.01 1274.53 Pass 11943.31 8556.08 10700.00 8789.22 24.31 37.35 170.40 251.94 1370.00 145.33 1224.67 Pass 11965.94 8574.77 10800.00 8869.88 24.03 37.09 168.94 247.43 1327.90 148.05 1179.85 Pass 11988.92 8593.24 10900.00 8950.83 23.76 36.93 167.29 243.01 1291.28 151.33 1139.95 Pass 11993.93 8597.20 10921.70 8968.40 23.71 36.90 166.90 242.05 1284.04 152.06 1131.98 Pass Site: PB DS 05 Well: 05-28 Rule Assigned: Major Risk Wellpath: 05-28A V3 Inter-Site Error: 0.00 ft Reference Offsef Semi-MajorAxis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/H~istance Area Devi$tioo Warning' ft ft ft ft ft ft deg deg in ft ft ft 11826.05 8453.29 10100.00 8315.63 25.44 37.19 175.60 280.31 1718.65 128.29 1590.37 Pass 11841.18 8466.84 10200.00 8393.14 25.50 37.64 175.04 275.83 1650.88 131.31 1519.58 Pass 11858.72 8482.61 10300.00 8471.54 25.45 37.89 174.41 270.90 1586.94 134.11 1452.83 Pass 11875.00 8497.13 10400.00 8550.30 25.23 37.90 173.57 266.66 1526.45 136.44 1390.01 Pass 11900.00 8519.11 10500.00 8629.45 24.88 37.76 172.76 261.16 1469.78 139.91 1329.87 Pass 11925.00 8540.63 10600.00 8707.59 24.54 37.39 171.91 256.17 1415.94 142.94 1273.00 Pass 11950.00 8561.65 10700.00 8772.66 24.22 36.79 172.18 252.78 1359.81 145.58 1214.22 Pass 11964.89 8573.91 10800.00 8796.16 24.04 36.45 174.08 252.71 1294.21 147.38 1146.83 Pass 1 i 983.40 8588.85 10900.00 8802.11 23.82 36.02 176.97 253.33 1233.69 150.41 1083.28 Pass 12000.00 8601.96 11000.00 8806.76 23.64 35.65 180.28 254.76 1185.89 154.33 1031.56 Pass 12025.00 8621.13 11100.00 8801.84 23.40 35.09 184.24 256.12 1142.21 160.56 981.66 Pass 12050.00 8639.57 11200.00 8803.80 23.21 34.63 187.90 257.44 1095.48 167.36 928.12 Pass 12075.00 8657.24 11300.00 8805.56 23.07 34.38 191.47 258.87 1045.28 174.52 870.76 Pass 12103.78 8676.56 11400.00 8804.24 22.99 34.43 195.02 260.19 987.30 182.27 805.03 Pass 12132.46 8694.66 11500.00 8802.12 23.00 34.84 198.43 261.55 923.34 189.75 733.58 Pass 12167.55 8715.13 11600.00 8797.84 23.13 35.40 202.63 263.48 876.16 197.94 678.23 Pass 12204.36 8734.53 11700.00 8787.21 23.41 36.20 207.12 265.79 826.95 205.96 620.99 Pass 12246.52 8753.98 11800.00 8789.64 23.90 37.19 210.68 267.06 768.82 213.39 555.43 Pass 12288.15 8770.15 11900.00 8788.35 24.52 38.20 214.13 268.41 701.81 220.06 481.75 Pass 12329.78 8783.18 12000.00 8784.58 25.25 39.21 217.56 269.87 629.19 226.01 403.18 Pass 12370.13 8792.72 12100.00 8777.50 26.02 40.1 S 221.13 271.61 551.03 231.04 319.99 Pass 12424.05 8800.60 12200.00 8783.98 27.13 41.42 223.85 271.98 483.45 237.30 246.15 Pass 12441.01 8801.91 12228.70 8785.12 27.49 41.81 224.67 272.07 465.57 239.23 226.34 Pass Site: PB DS 05 Well: 05-28 Rule Assigned: Major Risk Wellpath: 05-28APB1 W [nter-Site Error: 0.00 ft Reference Affset Semi-Major Axis Ctr-Ctr No-Go Allowabie MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/H~istance Area Deviatioo Warning ft ft ft ft ft ft deg deg in ft ft ft 11826.05 8453.29 10100.00 8315.63 25.44 37.19 175.60 280.31 1718.65 128.29 1590.37 Pass 11841.18 8466.84 10200.00 8393.14 25.50 37.64 175.04 275.83 1650.88 131.31 1519.58 Pass 11858.72 8482.61 10300.00 8471.54 25.45 37.89 174.41 270.90 1586.94 134.11 1452.83 Pass 11875.00 8497.13 10400.00 8550.30 25.23 37.90 173.57 266.66 1526.45 136.44 1390.01 Pass 17900.00 8519.11 10500.00 8629.45 24.88 37.76 172.76 261.16 1469.78 139.91 1329.87 Pass 11925.00 8540.63 10600.00 8707.59 24.54 37.39 171.91 256.17 1415.94 142.94 1273.00 Pass ~ BP Alaska ~ bp Anticollision Report ~ B~R r ~s INTEQ Compaoy: BP Amoco Date: 3/30/2007 Time. 15:41:58 Page: 5 Fieid: Prudhoe Bay Reference Sitec PB DS 05 Co-ordinste(NE)Reference: WeIL 05-28, True North Reference We1L• 05-2$ Vertical (TVD) Reference: 05-28B: 83.7 Reference Welipath: Plan 6, 05-286 Db: Orade Site: PB DS 05 Well: 05-28 Rule Assigned: Major Risk Wellpath: 05-28AP61 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Aa~is CtrvCtr No-Go Allowable MD TVD MD TVD Ref Offset 7'FO+AZI TF0.HS Casing/H~istance Area DeviaHon Warning ft ft ft ft ft ft deg deg in ft ft ft 11950.00 8561.65 10700.00 8772.66 24.22 36.79 172.18 252.78 1359.81 145.58 1214.22 Pass 11964.89 8573.91 10800.00 8796.16 24.04 36.45 174.08 252.71 1294.21 147.38 1146.83 Pass 11983.40 8588.85 10900.00 8802.11 23.82 36.02 176.97 253.33 1233.69 150.41 1083.28 Pass 12000.00 8601.96 11000.00 8806.76 23.64 35.65 180.28 254.76 1185.89 154.33 1031.56 Pass 12025.00 8621.13 11100.00 8801.84 23.40 35.09 184.24 256.12 1142.21 160.56 981.66 Pass 12050.00 8639.57 11200.00 8803.80 23.21 34.63 187.90 257.44 1095.48 167.36 928.12 Pass 12075.00 8657.24 11300.00 8805.56 23.07 34.38 191.47 258.87 1045.28 174.52 870.76 Pass 12103.78 8676.56 11400.00 8804.24 22.99 34.43 195.02 260.19 987.30 182.27 805.03 Pass 12132.15 8694.47 11500.00 8801.75 23.00 34.86 198.41 261.56 922.61 189.74 732.87 Pass 12160.28 8711.05 11600.00 8795.73 23.09 35.53 201.76 263.06 851.15 196.88 654.27 Pass 12191.99 8728.26 11700.00 8799.23 23.30 36.33 204.48 263.86 775.79 203.64 572.14 Pass 12224.43 8744.17 11800.00 8804.28 23.62 37.19 206.85 264.41 696.13 209.91 486.22 Pass 12257.63 8758.60 11900.00 8806.76 24.05 38.08 209.27 265.08 614.25 216.00 398.24 Pass 12280.31 8767.35 11963.70 8806.29 24.39 38.68 211.07 265.74 562.57 220.02 342.55 Pass Site: PB DS 05 Well: 05-28 Rule Assigned: Major Risk Wellpath: 05-28B V5 Inter-Site Error: 0.00 ft Reference Offset Semi-MajorAxis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TF0.HS Casing/H~istance Area Deviation Waraing ft ft ft ft ft ft deg deg in ft R ft 11666.00 8311.80 11666.00 8311.78 24.96 24.99 344.80 72.01 5.500 0.10 100.62 -100.51 FAIL Site: PB DS 18 Well: 18-13 Rule Assigned: Major Risk Wellpath: 18-13 V3 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowabie MD TVD MD 1'VD Ref Offset TFO+AZI TFO-HS Casing/H~istance Area Deviation Warning fF ft ft ft ft ft deg deg in ft ft ft 14515.98 8793.46 11082.70 8826.25 50.68 65.42 44.18 93.14 598.90 393.63 205.26 Pass Site: PB DS 18 Well: 18-13 Rule Assigned: Major Risk Wellpath: 18-13A V4 Inter-Site Error: 0.00 ft Reference Oftset Semi-Major A1cis Ctr-Ctr No-Go Altowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/H~istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 14513.03 8793.44 11100.00 8760.94 50.72 71.75 39.22 87.82 854.99 412.53 442.46 Pass 14475.00 8793.14 11200.00 8769.69 51.09 72.68 44.42 88.46 874.85 415.94 458.91 Pass 14450.00 8792.93 11300.00 8771.12 51.18 73.48 47.60 88.64 911.25 417.85 493.40 Pass 14417.21 8792.62 11400.00 8772.37 51.09 73.59 51.69 88.80 963.53 417.33 546.20 Pass 14390.16 8792.35 11500.00 8776.47 50.88 73.59 55.25 89.11 1018.76 415.99 602.77 Pass 14364.60 8792.08 11600.00 8779.30 50.54 73.38 58.53 89.32 1076.37 413.64 662.73 Pass 14340.11 8791.81 11700.00 8781.99 50.11 72.98 61.65 89.50 1134.63 410.43 724.21 Pass 14317.13 8791.54 11800.00 8783.09 49.60 72.43 64.50 89.60 1195.87 406.55 789.31 Pass 14300.00 8791.34 11900.00 8784.08 49.16 72.16 66.64 89.68 1260.54 403.70 856.84 Pass 14275.00 8791.03 12000.00 8784.94 48.42 70.93 69.70 89.74 1328.71 397.13 931.57 Pass 14257.52 8790.81 12100.00 8783.05 47.82 70.24 71.74 89.68 1398.56 392.63 1005.93 Pass 12875.00 8792.13 12200.00 8783.26 28.48 88.96 27.62 89.65 1415.51 413.05 1002.45 Pass 12850.00 8792.73 12300.00 8781.65 29.09 91.01 30.53 89.56 1477.12 421.04 996.07 Pass 12825.00 8793.35 12400.00 8778.27 29.65 92.80 33.37 89.40 1422.88 428.01 994.87 Pass 12800.00 8793.99 12500.00 8773.78 30.16 94.32 36.18 89.20 1434.56 433.92 1000.64 Pass 12775.00 8794.63 12600.00 8775.24 30.61 95.57 39.22 89.24 1450.19 438.79 1011.40 Pass ~ BP Alaska ~ bp Anticollision Report ~ s~ a~ Nuc~s INTEQ Compsnys BPAmoco Date: 3/30/2007 Time: Y5:41:5$ Page: 6 Fieldc Prudhoe Bay Reference Site: PB DS 05 Co-ordinate(NE) Refereocr._ WeIL 05-28, True North Refereoce We1L• 05-28 Vertical (TVD) Referenee: 05-28B: 63.7 Reference Wellpath: Plan 6, 05-28B ' Db: Orade Site: P8 DS 1 8 Weil: 18-13 Rule Assigned: Major Risk Weilpath: 18-13A V4 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go ` Atlowable MD TVD MD 1'VD Ref Offset TFO+AZI 1'F0.HS Casing/H~ist~nce Area Deviatioo Warning ft ft R ft ft ft deg deg in ft ft ft 12750.00 8795.29 12700.00 8779.35 31.00 96.55 42.37 89.39 1469.40 442.56 1026.84 Pass 12725.00 8795.97 12800.00 8781.12 31.33 97.23 45.43 89.45 1492.10 445.20 7046.91 Pass 12700.00 8796.65 12900.00 8780.04 31.60 97.60 48.38 89.40 1518.33 446.66 1071.67 Pass 11714.36 8354.28 13000.00 8780.14 25.17 97.41 27.11 126.14 1538.73 409.80 1128.93 Pass 11700.00 8341.61 13100.00 8780.64 25.11 99.26 31.00 126.43 1526.78 417.76 1109.02 Pass 11700.00 8341.61 13110.90 8780.71 25.11 99.34 31.38 126.81 1525.81 418.06 1107.75 Pass Site: PB DS 1 8 Well: 18-13 Rule Assigned: Major Risk Wellpat6: 18-13PB2 V3 Inter-Site Error: 0.00 ft Refe reace Offset Semi-Major Axis Ctr-Ctr No-Go Allowable ` MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistanec Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 14505.96 8793.39 11100.00 8784.30 50.81 66.12 41.37 89.12 594.20 395.98 198.22 Pass 14461.92 8793.03 11200.00 8793.96 51.14 67.20 47.62 90.09 601.76 399.39 202.37 Pass 14456.39 8792.98 11212.70 8795.28 51.16 67.30 48.41 90.22 603.37 399.58 203.79 Pass Site: PB DS 1 8 Well: 18-21 Rule Assigned: Major Risk Welipath: 18-21 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-MajorAxis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI 1'FO-HS Casing/H~istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 14525.00 8793.53 9500.00 8076.55 50.56 68.36 2.65 52.69 1182.89 327.90 855.00 Pass 14492.63 8793.29 9600.00 8127.98 50.95 69.26 8.65 54.80 1154.17 338.49 815.68 Pass 14463.73 8793.05 9700.00 8178.17 51.13 69.98 14.42 57.11 1132.34 348.48 783.86 Pass 14435.20 8792.79 9800.00 8227.77 51.16 70.45 20.36 59.62 1117.36 357.60 759.76 Pass 14407.20 8792.52 9900.00 8276.66 51.03 70.68 26.40 62.30 1109.79 365.57 744.22 Pass 14375.00 8792.19 10000.00 8324.58 50.71 70.40 33.04 65.08 1110.27 371.23 739.04 Pass 14350.00 8791.92 10100.00 8371.30 50.31 70.25 38.87 67.91 1118.87 376.09 742.78 Pass 14325.00 8791.63 10200.00 8415.59 49.79 69.87 44.62 70.66 1136.07 378.89 757.18 Pass 14300.00 8791.34 10300.00 8457.44 49.16 69.26 50.25 73.28 1161.54 379.57 781.97 Pass 14275.00 8791.03 10400.00 8497.46 48.42 68.40 55.72 75.76 1194.62 378.17 816.45 Pass 14257.73 8790.81 10500.00 8535.46 47.83 68.06 60.10 78.06 1234.72 377.63 857.09 Pass 14236.67 8790.54 10600.00 8570.98 47.05 67.17 64.70 80.13 1281.36 374.22 907.14 Pass 12892.37 8791.72 10700.00 8603.62 28.02 85.47 17.33 81.44 1264.76 393.80 870.96 Pass 12866.05 8792.34 10800.00 8632.86 28.70 87.71 21.68 82.64 1245.05 403.37 841.69 Pass 12839.10 8793.00 10900.00 8659.12 29.34 89.73 26.04 83.76 1231.12 411.92 819.20 Pass 12811.70 8793.69 11000.00 8682.87 29.92 91.50 30.37 84.80 1223.30 419.31 803.98 Pass 12784.05 8794.40 11100.00 8704.10 30.45 92.97 34.65 85.76 1221.48 425.45 796.04 Pass 12756.36 8795.13 11200.00 8722.48 30.90 94.14 38.82 86.60 1226.40 430.24 796.16 Pass 12725.00 8795.97 11300.00 8736.28 31.33 94.85 43.23 87.25 1237.56 433.47 804.09 Pass 12700.00 8796.65 11400.00 8744.90 31.60 95.42 46.62 87.64 1254.81 435.51 819.31 Pass 12675.00 8797.33 11500.00 8750.37 31.80 95.69 49.87 87.89 1278.85 436.50 842.35 Pass 11730.51 8368.55 11600.00 8754.85 25.24 94.62 27.69 130.84 1266.82 396.27 870.55 Pass 11725.00 8363.68 11700.00 8761.17 25.22 96.33 32.21 133.95 1252.54 405.60 846.94 Pass 11711.44 8351.70 11800.00 8768.11 25.16 98.43 37.02 135.32 1246.06 414.15 831.91 Pass 11700.00 8341.61 11900.00 8775.36 25.11 100.43 41.78 137.20 1247.47 419.79 827.69 Pass 17687.83 8330.91 12000.00 8783.96 25.05 102.45 46.51 138.93 1256.66 422.80 833.86 Pass 11673.99 8318.78 12100.00 8793.15 24.99 104.53 51.19 140.28 1272.28 423.39 848.89 Pass 11656.62 8303.63 12200.00 8799.83 24.92 106.75 55.79 140.83 1293.96 421.85 872.11 Pass ~ BP Alaska ~ bp Anticollision Report * ~.r s N~uc~s INTEQ Company: BP Amoca Date: 3/30/2007 Time: 15:41:58 Page: 7 Field: Prudhoe Bay Reference Site: PB DS Q5 Caordinate(NE) Reference: Welf: 05-28, True North Refereoce We1L• 05-28 Vertical (1'VD) Referencr. 05-286: 63.7 Reference Wellpathe Plan $, 05-28B Db: O[aCle Site: PB DS 1 8 Well: 18-21A Rule Assigned: Major Risk Wellpath: 18-21A V1 Inter-Site Error: 0.00 ft Reference Ofiset Semi-MajorAais Ctr-Ctr No-Go Allowable MD TVD MD 1'VD Ref ` Offset 1'FO+AZI TFO-HS CasinglH~istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 14525.00 8793.53 9500.00 8076.55 50.56 68.36 2.65 52.69 9.625 1182.89 328.15 854.74 Pass 14492.63 8793.29 9600.00 8127.98 50.95 69.26 8.65 54.80 9.625 1154.17 338.75 815.42 Pass 14463.73 8793.05 9700.00 8178.17 51.13 69.98 14.42 57.11 9.625 1132.34 348.73 783.60 Pass 14435.20 8792.79 9800.00 8227.77 51.16 70.45 20.36 59.62 9.625 1117.36 357.86 759.50 Pass 14407.20 8792.52 9900.00 8276.66 51.03 70.68 26.40 62.30 7.000 1109.79 365.72 744.08 Pass 14375.00 8792.19 10000.00 8324.58 50.71 70.40 33.04 65.08 7.000 1110.27 371.38 738.89 Pass 14350.00 8791.92 10100.00 8371.30 50.31 70.25 38.87 67.91 7.000 1118.88 376.24 742.64 Pass 14325.00 8791.63 10200.00 8415.59 49.79 69.87 44.62 70.66 7.000 1136.07 379.04 757.03 Pass 14300.00 8791.34 10300.00 8457.44 49.16 69.26 50.25 73.28 7.000 1161.54 379.72 781.82 Pass 14275.00 8791.03 10400.00 8497.46 48.42 68.40 55.72 75.76 7.000 1194.62 378.32 816.31 Pass 14257.73 8790.81 10500.00 8535.47 47.83 68.06 60.10 78.06 7.000 1234.72 377.78 856.94 Pass 14236.67 8790.54 10600.00 8570.98 47.05 67.17 64.70 80.13 7.000 1281.36 374.36 907.00 Pass 12892.37 8791.72 10700.00 8603.62 28.02 85.47 17.33 81.44 7.000 1264.76 393.94 870.82 Pass 12866.05 8792.34 10800.00 8632.86 28.70 87.71 21.68 82.64 7.000 1245.05 403.51 841.54 Pass 12839.10 8793.00 10900.00 8659.12 29.34 89.73 26.04 83.76 7.000 1231.12 412.06 819.06 Pass 12811.70 8793.69 11000.00 8682.87 29.92 91.50 30.37 84.80 7.000 1223.30 419.46 803.84 Pass 12784.05 8794.40 11100.00 8704.10 30.45 92.97 34.65 85.76 7.000 1221.48 425.59 795.89 Pass 12756.36 8795.13 11200.00 8722.48 30.90 94.14 38.82 86.60 7.000 1226.40 430.39 796.02 Pass 12725.00 8795.97 11300.00 8736.28 31.33 94.85 43.23 87.25 7.000 1237.56 433.61 803.94 Pass 12700.00 8796.65 11400.00 8744.90 31.60 95.42 46.62 87.64 7.000 1254.81 435.65 819.16 Pass 12675.00 8797.33 11500.00 8750.37 31.80 95.69 49.87 87.89 7.000 1278.85 436.65 842.20 Pass 11730.51 8368.55 11600.00 8754.85 25.24 94.62 27.69 130.84 7.000 1266.82 396.42 870.41 Pass 11725.00 8363.68 11700.00 8761.17 25.22 96.33 32.21 133.95 4.500 1252.54 405.65 846.90 Pass 11711.44 8351.70 11800.00 8768.11 25.16 98.43 37.02 135.32 4.500 1246.06 414.19 831.87 Pass 11700.00 8341.61 11900.00 8775.36 25.11 100.43 41.78 137.20 4.500 1247.47 419.83 827.64 Pass 11687.83 8330.91 12000.00 8783.96 25.05 102.45 46.51 138.93 4.500 1256.66 422.84 833.81 Pass 11673.99 8318.78 12100.00 8793.15 24.99 104.53 51.19 140.28 4.500 1272.28 423.43 848.85 Pass 11656.62 8303.63 12200.00 8799.83 24.92 106.75 55.79 140.83 4.500 1293.96 421.89 872.07 Pass Site: PB DS 1 8 Well: 18-22 Rule Assigned: Major Risk Wellpath: 18-22 V1 Inter-Site Error: 0.00 ft Refereoce Offset Semi-Major Axis Gtr-Gtr No-Go Allowable MD 1'VD MD 1'VD Ref Offset TFO+AZI TFO-HS Casing/H~istaoce Area Deviation Warning R ft R ft ft R deg deg in ft ft ft 13900.00 8785.89 11200.00 8762.13 39.28 57.94 269.50 271.36 4.500 1005.61 324.56 681.05 Pass 13875.00 8785.61 11300.00 8761.63 40.07 60.83 266.58 271.45 4.500 952.29 335.59 616.69 Pass 13850.00 8785.36 11400.00 8761.24 40.76 63.54 263.66 271.53 4.500 902.93 345.79 557.14 Pass 13815.67 8785.05 11500.00 8759.48 41.53 66.62 259.72 271.70 4.500 860.17 357.34 502.83 Pass 13781.94 8784.78 11600.00 8755.65 42.12 69.46 255.99 272.03 4.500 824.19 367.54 456.65 Pass 13750.00 8784.57 11700.00 8750.87 42.50 71.99 252.56 272.42 4.500 795.63 376.15 419.48 Pass 13709.53 8784.35 11800.00 8744.42 42.70 74.42 248.23 272.95 4.500 774.62 383.90 390.73 Pass 13684.83 8784.25 11865.40 8739.46 42.69 75.75 245.67 273.36 4.500 765.19 387.70 377.50 Pass Site: PB DS 1 8 Well: 18-22 Rule Assigned: Major Risk Wellpath: 18-22A V1 Inter-Site Error: 0.00 ft Reference Offset Seroi-Major Axis Ctr-Gtr No-Go Allowabte MD TVD MD TVD Ref Offset TFO+AZI TFO-AS Casing/H~istanee Area Deviation: Warning ft ft ft ft ft ft deg deg in ft ft ft 13975.00 8786.83 11600.00 8790.92 36.37 43.90 276.73 269.60 575.23 276.30 298.94 Pass 13955.18 8786.57 11649.40 8796.42 37.21 46.10 273.74 268.99 557.92 284.39 273.53 Pass ~ BP Alaska ~ bp '~'~ Anticollision Report • BA ~R ~ Nu~~s INTEQ Compaoy; BP Amoco Date: 3/30/2007' Timr. 15:41:58 Page: 8 Fietd: Prudhoe Bay Referenee8ite: PB DS 05 Co-ordinate(NE)`Reference: Welt: 05-28, Trus North Refereoce WeIL• 05-28 Vertical (TVD) Refereoce: 05-28B: 63.7 " Reference Wellpsth: Plan 6, 05-286 Dbt Oracle Site: PB DS 1 8 Well: 18-30 Rule Assigned: Major Risk Wellpath: 18-30 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-MajorAxis Gtr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TF0.HS Casing/Fl~istance Area Deviatioo Warniqg ft ft ft ft ft ft deg deg in R ft ft 14494.00 8793.30 9600.00 8088.96 50.94 68.81 325.20 11.51 7.625 718.83 133.42 585.41 Pass 14449.98 8792.93 9700.00 8169.80 51.18 68.63 332.90 13.94 7.625 642.06 145.52 496.54 Pass 14408.38 8792.54 9800.00 8250.55 51.04 67.97 341.63 17.67 5.500 568.85 164.01 404.84 Pass 14368.97 8792.13 9900.00 8330.50 50.61 66.93 351.73 23.04 5.500 501.68 190.41 311.27 Pass 14332.01 8791.72 10000.00 8409.11 49.94 65.57 3.72 30.60 5.500 444.55 225.44 219.11 Pass 14297.33 8791.31 10100.00 8485.44 49.08 63.96 17.95 40.66 5.500 403.25 266.63 136.62 Pass 74265.41 8790.91 10200.00 8558.88 48.09 62.23 33.99 52.87 5.500 384.44 305.83 78.61 Pass 14232.14 8790.48 10300.00 8628.26 46.87 60.18 50.25 65.14 5.500 385.94 329.66 56.28 Pass 14196.10 8790.00 10400.00 8690.36 45.35 57.65 65.23 75.80 5.500 406.25 335.43 70.83 Pass 14161.66 8789.52 10500.00 8735.99 43.69 54.98 76.83 83.27 5.500 456.74 328.25 128.49 Pass 14130.93 8789.09 10600.00 8767.94 42.07 52.38 84.94 87.69 5.500 524.97 316.43 208.54 Pass 14102.84 8788.69 10700.00 8778.32 40.48 49.80 89.64 89.01 5.500 602.69 303.69 299.00 Pass 13034.20 8788.81 10800.00 8779.17 23.66 74.35 7.96 89.09 5.500 609.34 351.00 258.34 Pass 12993.34 8789.57 10900.00 8782.31 25.01 78.70 13.04 89.27 5.500 568.39 368.59 199.80 Pass 12950.00 8790.45 11000.00 8785.20 26.38 82.74 18.41 89.44 5.500 534.97 385.07 149.89 Pass 12903.37 8791.47 11100.00 8787.55 27.73 86.33 24.13 89.56 5.500 509.59 399.73 109.86 Pass 12855.35 8792.60 11200.00 8789.89 28.96 89.20 30.02 89.68 5.500 491.37 411.77 79.61 Pass 12806.02 8793.83 11300.00 8789.55 30.04 91.25 35.74 89.49 5.500 483.60 420.56 63.04 Pass 12756.45 8795.12 11400.00 8786.55 30.90 92.33 41.19 88.99 5.500 485.30 425.53 59.77 Pass 12707.86 8796.43 11500.00 8786.85 31.52 92.48 46.94 88.90 5.500 500.85 426.67 74.18 Pass 12661.77 8797.70 11600.00 8790.45 31.88 91.77 52.78 89.22 5.500 529.46 424.33 105.12 Pass 12618.66 8798.89 11700.00 8786.39 32.02 90.34 57.48 88.74 5.500 566.85 419.04 147.81 Pass 12291.30 8771.25 11800.00 8780.54 24.57 98.97 36.86 90.98 5.500 575.72 432.22 143.50 Pass 12137.46 8697.69 11900.00 8769.60 23.01 99.67 36.29 99.08 5.500 571.29 427.64 143.65 Pass 12033.71 8627.64 12000.00 8766.53 23.34 99.99 40.47 111.51 5.500 565.46 423.54 141.93 Pass 11963.58 8572.84 12100.00 8762.21 24.05 100.47 46.88 125.68 5.500 563.73 418.27 145.45 Pass 11917.10 8533.88 12200.00 8760.15 24.65 101.25 54.58 140.09 5.500 573.59 408.81 164.79 Pass 11884.03 8505.12 12300.00 8758.24 25.10 102.20 62.50 153.83 5.500 596.72 393.95 202.78 Pass 11859.53 8483.34 12400.00 8756.29 25.44 103.30 70.03 166.35 5.500 632.69 374.73 257.96 Pass 11818.79 8446.80 12500.00 8751.14 25.44 102.58 76.30 182.92 5.500 677.18 348.34 328.84 Pass 11787.57 8419.04 12600.00 8743.87 25.46 101.89 82.07 196.60 5.500 728.69 322.31 406.39 Pass 11779.37 8411.78 12631.25 8741.54 25.47 101.94 83.84 199.55 5.500 746.45 314.44 432.02 Pass ~ • N2 13" Comp BOP I Well: DS-5-28B Riser 7-11 ft scope - -[Ll __~_:~',--~ Input disiance from ri,q - floor to top of Nydri! HYDRIL "GK" C~Hydril --+~ 13-5:8" 5k Annular 31!8" Sk, R•35 API Ri~s y CHOKE LINE bp \ 4.67 ft ~ BX160 API Ring ~ _,i ~ 1.50 ft 13-5~8"5k Shaffer SL BOP Blind Rams ,~ `~ ^ ~'y j _ BX160 API Ring ~! API Ring KILL LINE 1.83 ft Sk, R35 1.50 ft 13-5:8"5k Shafier 5-1:2" 2-7:8" VBR's ~ ~~, BX160 API Ring 2.67 ft ~ BX160 API Ring ~ 13-5:8"5k Tubing Hanger Base Flange to RiQ FI oor 05-286 Application for Sundry ~ • BOPE Configuration Rig Floor to Top of Wel I DS 5-286 2.25 9.23 5.00 ` ~ ' ~ ~ ~' ~;co F~i ~X-~6 21ind Shaers 12.65 •~~ rr.;r -~ 2 1 16' 5000 psi . R-~~ ~ ,~~„ ......., ~,..~ ~,.-,,, Mud ~;;oss A9u~Croes - HCR 14.89 HCR ~hoke Line Kill Line ~ 16.10 ~ : z =~ - , ...~.. Vr,r~attd- -;an-~ 2 ~ ~i6^ r[iCr,~ psi =ix-2-3 -:i'N' c::cn-~,ti 16 66 ` . f- T~;- i 1i16'bC,~00p=,i •:RX-46: .~ 7 1 16' X+ 1 8' Flanced Ad.~'er ~_,... 20.04 ~ ~ ~ Swab Valve Tree Size ~ ~ Flar Line -~ 22.$8 ~ ;~ ~} 1 SSV ; 24.86 ---~ ~'~~ Master Valve 26.68 _~ Lock Down Screws 31.00 ~ Ground Level 05-286 Application for Sundry Re: OS-28B • Sarber, Greg J wrote, On 5/3/2007 9:37 AM: . Hi Tom, The liner for DS OS-28B will be run as show in the table attached. The length of 3-1/2" STL will be about 25.7'. There will be 2, 10' pump joints, an X nipple, and a 4' pup on the bottom of the deployment sleeve. Let me know if you need any additional information. Cheers, Greg -----Original Message----- From: Thomas Maunder [r°iail~o.tom m~u~~er~s~admiz~.sta~e.ak.as] Sent: Thursday, May 03, 2007 8:15 AM To: Sarber, Greg J Subject: 05-28B Hi Greg, I am reviewing the sundry to re-enter and finish drilling this well. A request: l. You do provide some length information for the combination liner and have broken it into solid and slotted portions. I know the 3-1/2" section is not long, but could you provide me with that length? Thanks, Tom Maunder, PE AOGCC 1 of 1 5/3/2007 9:49 AM Thanks Greg. This will do just fine. I suspected that the 3-1/2" section would be short. Tom • i DS 05-28B Liner Summary _ ~ -~~ ~~~ ~ ~ ~ ~ : ~ ~ .,:~~ ~~.~ : ~~~u~ 2-7/8" STL 6.16 #, L-80 erforated liner with cementralizers 14,530--12,850' MD 2-7/8" STL 6.16 #, L-80 solid liner for cement slum 4'oints 2-7/8" STL 6.16 #, L-80 baffle late 2-7/8" STL 6.16 #, L-80 erforated u 4 feet in len th 2-7/8" STL 6.16 #, L-80 float collar Brass bod floats 2-7/8" STL 6.16 #, L-80 10' solid u'oints 2 20 feet in len th 2-7/8" O-rin sub X-O, 3-3/16" TCII box x 2 7/8" STL in, L-80 12,700' MD 3-3/16" TCII, 6.2# L-80 solid liner with cementralizers X-O, 3-1/2" STL box x 3-3/16" TCII in, L-80 3-1/2" STL, 9.2#, L-80 10' Pu 'oint 3-1/2" X ni le (3.7" OD, 2.813" rofile 3-1/2" STL, 9.2# , L-80 10' Pu Joint Baker C-2 de lo ment sleeve 4" OD STL with 4' u 400' of liner la , To ~T 1,250' ~ FRANK H. MURKOWSKI, GOVERNOR 333 W. 7"' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU OS-28B Sundry Number: 306-277 Dear Mr. Wesley: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager}. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this~i~day of August, 2006 Encl. Ci n rerPlv ' ~~ ~ ~6 'Z~~~ ~ ~/ ~~~ ~~I~/fl6 G!~'~ g. Zl.v STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM SION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 `~~c~~~~D AUG Y ~ 20Q6 Alaska Oi! & Gas Cons. Cort~nission 1. Type of Request: ^ Abandon ^ Suspend ~ Operation Shutdown ^ Perforate ^ Time Extension orage ^ Alter Casing ^ Repair Weil ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ~ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 206-089 ° 3. Address: ^ Stratigraphic ^ Service 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22208-02-00 7. If perforating, closest app~oach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 05-28B ~ Spacing Exception Required? ^ Yes ~ No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): ADL 028321 Plan 63.7' Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT 1MELL C~NDITION SUM MARY ` Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11666 8312 11572 8230 None None Casin Len th Size MD TVD Burst Colla se Structural Conductor 110' 20" 11 ' 110' 1490 470 Surface 3916' 10-3/4" 3916' 3534' 3580 2090 Intermediate 4119' 7-5/8" 4119' 3698' 6890 4790 Production Liner 7699' S-1/2" 3957' - 11657' 3566' - 8304' 7740 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None Kill String: 4-1/2", 1~6# ~-80 2487' ~ Packers and SSSV Type: None Packers and SSSV MD (ft): None 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal ^ BOP Sketch ^ Exploratory ~ Development ^ Service ^ Detailed Operations Program ; 15. Estimated Date for ~~ 16. Well Status after proposed work: Commencin O erations: Aug 't 9, 006 ~ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal App~oval: at . ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dave Wesley, 564-5153 Printed Name Dave Wesley Title Senior Drilling Engineer / Prepared By Name/N~mber: Signature ~~~ ~~L~ L. f Phone 564-5153 Date ~'~.~1d~ Terrie Hubble, 564-4628 4' Commission Use Onl Sundry Number: _ ~ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integ~ity Test ^ Location Clearance Other: r (7 r Yv!/ ~ ~ ~t/ J~ ~ l~ ~ ~(~/r/ r/l. ~ " ~ ~ Subsequent Form Required: ~~~V'~~ ~°r`~'"'" ~ 3 Y~~ APPROVED BY /y~ ~ Z "x/ A roved B: CO SSIONER THE COMMISSION Date Form 10-403 Revised 06/2006 V - ~Submi~ ln Duplicate ( ~ ; " ~ : ° ~ ~ ' ~ ' ° R~$ ~~ AUG 2 5 2006 ~ ~~~' .~ ~ ~..3 i t`~ ~ i..~. • ~ 05-28B Operations Summarv Pre-Rip Operations: 1. Bleed the OA, IA and tubing pressures to zero. Test the IC (7 5/8") pack-off to 3,000 psi, test the tubing pack-off to 5,000 psi. Function all LDS, repair or replace as necessary. 2. MIT the OA to 2,000 psi. 3. RU E-line. RIH and jet cut the 3-1/2" tubing in the middle of a joint - 4,300'. 4. Circulate the well to SW. Freeze protect the IA and tubing with diesel to - 2,200'. 5. Bleed all pressures to zero. Set BPV. Secure well. 6. Remove the well house and flow-line. If necessary, level the pad. Riq Operations: 1. MI/RU Nabors 2ES. 2. Pull BPV. Circulate out freeze protection and displace the well to SW. 3. Monitor the OA, IA and tbg for pressure. Verify the well is dead. 4. Install a TWC. Nipple down the tree and adapter flange. 5. Nipple up the BOPE and test per Permit requirement. Pull the TWC. 6. Pull the 4 1/2" X 3 1/2" tubing from the pre-rig cut at - 4,300'. 7. M/U drift assembly and RIH to the tubing stump, P/U 5" drill pipe singles. POOH. 8. M/U and RIH with a 7 5/8" HES CIBP, on 5" drill pipe. Set the CIBP at --4,150'. Test CIBP to 3,500psi. 9. R/U. RIH and log, with USIT, from --4,100' to surface. Determined there was cement in the 7 5/8" X 10 3/a" annulus which would make it impossible to cut and pull the 7 5/8" casing. 10. M/U whip stock assembly. RIH and set whip stock on bridge plug. Displaced to 8.8ppg milling fluid. Milled window from 4,119' to 4,149'. 11. Performed FIT to 11.3ppg EMW. Perform LOT. Pressured up to 740psi, closed in and bled off to 400psi. Held for 5 minutes. POOH. 12. M/U 6 3/4" drilling assembly. RIH; drilled ahead intermediate section to 10,650'. Weight up system to 10.5ppg with spike fluid. 13. Drilled ahead to section TD at 11,666'md. Condition hole for liner. POOH. 14. R/U and run 5~/z", 17#, L-80, Hydril 521 liner. 15. Run liner in hole on drill pipe to 11, 'md. 16. R/U and cement 5%2" liner with t 3 Is 11.Oppg lead slurry, followed by 35bbls 15.8ppg tail slurry. Bump plug on schedule~- et hanger and packer. No cement returned to surface. POOH and UD cementing equipment. 17. R/U and run 4~h", 12.6#, L-80, IBT kill string to 2,486'md. Freeze protect well. / 18. N/U adapter and tree. Install BPV and secure well. 19. Suspend operations for Coiled tubing drilling operations to drill production interval and run completion. 20. Move off of well 05-28B on August 10, 2006. Post-Riq Work: / ~ Dave Wesley, Jr. Senior Drilling Engineer Office: 564-5153 Cell: 440-8631 TRE~ = FMC ULTRA SLIM HOLE V~/IFIL,HEAD"- FMC ACTUATOR = BAKER C KB. ELEV = 70' BF. ELEV - _ NA KOP = 1300' Max Angle = 99 @ 11613' Datum MD - NA Datum ND = 8800' SS 10-3/4" CSG, 45.5#, J-55, ID = 9.950" 3896~ TOW in 7 5/8" casing 4119' 7-5/8" X 5-1/2" BKR LNR HGR 9837~ TOP OF 2-3/8" LNR, 4.7#, ID = 1.995" g$$2' 3-1/2" TBG, 9.2#, 13-CR-80, 9910~ .0087 bpf, ID = 2.992" 7-5/8" CSG, 29.7#, L-80, ID = 6.875" 10150~ 5-1/2" LNR MILLOUT WINDOW 10565' - 10570' (OFF CMT RAMP) 2486' 4-1/2", 12.6#, L-80, IBT kill string 3969~ 7-5/8 X 5-1(2" BOT ZXP packer -4,500 TOC 11666' Section TD 11660' 5-1/2", 17#, L-80 Hyd 521 liner 9784' 7-5/8" X 3-1/2" BAKER SB-3A PKR 9872~ 2.70" BKR DEPLOYMENT SLV, ID = 2.25" 9$72' LTfP (SET 01/15/04) 9899' 3-1/2" OTIS XN NIP, MILLED TO 2.80" ID 9911' 3-1l2" WLEG (SOS) 9896' ELMD TT LOGGED 09/22/91 12197~ PBTD 5-1/2" LNR, 17#, 13-CR-80, ID = 4.892" 10923~ 2-3l8" LNR, 4.7#, L-80, .0039 bpf, ID = 1.920" 12235~ DATE REV BY COMMENTS DATE REV BY COMMENTS 09/08/91 ORIGINAL COM PLETION 08/19/03 CMO/TLP DATUM MD CORRECTION 10/30/01 CTD SIDETRACK 09/14/03 BJMcL/TL ECLIPSE PATCH 11/22/02 CH/TLP CORRECTIONS 10/22/03 MJA/TLH MIN ID CORRECTION 09/28/02 MWKAK GLV GO 12/28/03 JBNUPAG LNR ID CORRECTION 05/08/03 JJ/KAK PULL FISH 01/15/Q4 KSB/KK PULL PATCH; SET LTTP 07/30/03 ??/KAK PATCH & MIN ID CORRECTION PF2UDHOE BAY UNff WELL: 05-286 PERMff No: API No: 50-029-22208-02 SEC 32, T11 N, R15E, 2431' SNL & 4220' WEL BP Exploration (Alaska) ~ Tem ra Sus ension 05-28B ry p ~ ~ 17-Aug-06 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 05-28B Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 4,106.70' MD Window / Kickoff Survey 0.00' MD (if applicable) Projected Survey: 11,666.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ~ ~ ~ _ ~ ~ , Date ~ 4 ~ Signed ~~~~`~W~~~~~,~,~ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) a..~~-4~~ 05-28B Revised Cement Volumes Winton, Here are the revised cement volumes for 05-28B: Cementinq Proqram: Casing String: 7-5/8", 29.7#, L-80, BTC-M Intermediate Liner Slurry Design Basis: 1 St stage: 85' of 7-5/8", 29.7# shoe track, 1408' of 7-5/8" X 9-7/8" annulus with 40% excess, planned TOC 10,200' MD. 2nd stage: 5,200' of 7-5/8" X 9-7/8" annulus with 40% excess, planned TOC 5,000' MD. Fluids Sequence / Volume: 1St Stage Pre-Flush None planned Spacer 40 bbls MudPUSH at 11.0 ppg Lead Slurry None planned Tail Slurry 79.3 bbl / 444.9 cf / 384 sxs Class 'G', 15.8 ppg; 1.16 cf/sk. 2nd Stage Pre-Flush 20 bbls CW100 Spacer 40 bbls MudPUSH II at 11.0 ppg Lead Slurry 241.1 bbl / 1352.6 cf / 588 sxs LiteCrete, 11.5 ppg; 2.3 cf/sk. Tail Slurry 20 bbl / 112.2 cf / 97 sxs Class `G', 15.8 ppg; 1.16 cf/sk. Casing String: 4-1/2", 12.6#, L-80, IBT-M Production Liner Slurry Design Basis: Lead slurry: none planned Tail slurry: 85' of 4-1/2", 12.6# shoe track, 2853' of 4-1/2" X 6-3/4" annulus with 40% excess, 150' of 4-1/2" X 7-5/8" annulus and 200' of 4" DP X 7-5/8" annulus Fluids Sequence / Volume: Pre-Flush None planned Spacer 40 bbls MudPUSH II at 11.0 ppg Lead Slurry None planned Tail Slurry 110 bbl / 617.1 cf / 527 sxs Class 'G', 15.8 ppg; 1.17 cf/sk. Let me know if you have any further questions. ~eff Cutler BPXA - Alaska Drilling and Wells Operations Drilling Engineer Office: (907) 564-4134 CeIL• (907) 529-8092 Fax: (907) 564-4040 1 of 1 6/27/2006 10:40 AM ~ ~ ~ ~~ ~ ~ ~ ~~ ~~ ,~ ~ ~ ~ ; (;~y ~ a~~ '' i~ 1^ ~~ ~;~; ~~ + , ai a ~ ~ ~ •~ ~ ~ ~~' ~ C01~5ERQA ~ ~ ~; ~' '~ , ^~ ~~ ~°°~ ~~ '~', ~; '~; 4 ~°~~ ~~~ ~~i ~ ~ ~ ~~ ~ + ~~"'~~ ~ ~ ~ ~! ~ '~, ~~~ ~~ FRANK H. MURKOWSKI, GOVERNOR 1 ~ ~ ~ ~~~T 0~ ~~i/ a7[~a7 ~ 333 W. 7'" AVENUE, SUITE 100 ~~" COrgIIsSIO~ ~ ANCHORAGE, ALASKA 99501-3539 ~+ PHONE (907) 279-1433 FAX (907) 276-7542 Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 05-28B BP Exp~oration (Alaska) Inc. Permit No: 206-089 Surface Location: 2431' FNL, 4220' FEL, SEC. 32, T 11 N, R 15E, UM Bottomhole Location: 801' FSL, 1524' FEL, SEC. 19, T11N, R15E, UM Dear Mr. Wesley: Enclosed is the approved application for permit to redrill 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) C~-3607 (pager). DATED this~ay of June, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~-,~ (~[~~ V ~ STATE OF ALASKA ALA~~OIL AND GAS CONSERVATION COMfV~ON PERMIT TO DRILL 20 AAC 25.005 w~~- ~! L-~ 1 zbo~ ~~~EIV~,~ JUN 2 2 2nn~ 1 a. Type of work ^ Drill ~ Redriil ^ Re-Entry 1 b. Current Well Class O Exploratory p Development Gas ^ Service ~ Q Multiple Zone ^ Stratigraphic Test ~ Development Oil ^ Single Zone 1 c. Specify (~i~r ed for: ~ Coalbed Methane~~~~~~ ^ Shale Gas Anchor ~N 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ~ Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 05-28B 4~~ tom6 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 14461 TVD 8741 12. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Govemmental Section): Surface: 4220' FEL SEC T11 N R15E UM 2431' FNL 32 7. Property Designation: ADL 028321 Pool , , , . , , Top of Productive Horizon: 4563' FSL, 289' FEL, SEC. 30, T11 N, R15E, UM 8. Land Use Perm+t: 13. Approximate S d ate: Jul 10, 006 Totai Depth: 801' FSL, 1524' FEL, SEC. 19, T11 N, R15E, UM 9. Acres in Property: 2560 14. Distance to N rest Property: 39,905 4b. Location of WeA (State Base Plane Coordinates): Surface: x-698128 Y-5949039 Zone-ASP4 90. KB Elevation Plan (Height above GL): 63.7 feet 15. Distance to Nearest Well Within Pool: 475' 16. Deviated Wells: Kickoff Depth: 3950 feet Maximum Hole Angle: 94 de rees 17. Maximum Anticipated Pressures in psig (see 20 .035) Downhole: 3659 Surface: 283 18. Casin P ' ram: S e.cifications T- Settin Depttt - Boftom Quanti of +ent, c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD ND MD TVD Sb~ includin sta e data 9-7/8" 7-5/8" 29.7# L-80 BTC-M 11608' Surface Surface 11608' 8278' x LiteCrete, -~43sx Class 'G' 6-3/4" 4-1/2" 12.6# L-80 IBT-M 3003' 11458' 8147' 14461' 8740' sx Class'G' Z7 ~r,lG 19. PRESENT WELt GOPIDITION SUMMARY {To be completed for Redril f aod Re-entry Operations7 Total Depth MD (ft): 12235 Total Depth TVD (ft): 8791 Plugs (measured): 9872 Effective Depth MD (ft): 12198 Effective Depth TVD (ft). 8790 Junk (measured): None °Casing Length Size Cement Volume MD ND Conductor / Structural 110' 20" 11 ds Arcticset 110' 110' Surface 3916' 10-3/4" 1265 sx CS III, 350 sx 'G',Top Job: JO SX CSII 3916' 3534' Intermediate 10150' 7-5/8" 815 sx Class'G' 10150' 8356' Production Liner 728' 5-1/2" 95 sx Class'G' 9837' - 10565' 8113' - 8682' Liner 2363' 2-3/8" 113 sx Class'G' 9872' - 92235' 8140' - 8799' Perforation Depth MD (ft): 10835' - 12185' PerForation Depth TVD (ft): 8805' - 8789' - 20. Attachments ~ Filing Fee, $100 ^ BOP Sketch ~ Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch p 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. Contact Jeff Cutler, 564-4134 Printed Name ave Wesley Title Senior Drilling Engineer Prepared By Name/Number: Si nature Phone 564-5153 Date ~~Z~/~~ Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: - API Number: 50- 029-22208-OZ-00 Permit Approval Date: ' ~ See cover letter for other requirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas tes, or gas contained shales~ /`r~' Samples Req'd: ^ Yes~No Mud Log Req'd: ^ Yes~No ~--~ S~ ~~ t~ ~ 3 S~~ f0~ HZS Measures , No 'r tional Survey Req'd:~Yes ^ No Other: ~ ~ l?ctv suci.~c,t' ~`~ ZO /~~ ZS . 0 3 S~1~. ~ ~~~~ a~,~'ey e D~ ~e5~" ~ur~-e j s rx~~~1-U ~'ec~. Date f~~~ 7 i~ APPROVED BY TCOMM SSION R on / Form 10-401 Revised 12/2005 t./ ~.~..- 5upmit In uupucaie r,nt,^~-n~ n 1 ~ ~ Well Name: 05-28B Planned Well Summary We~~ Horizontal Target Ivishak Zone Well 05-28B Type Sidetrack Objective 1 A/ 1 B Producer AFE Number: PBD4P2486 Surface Northin Eastin Offsets TRS Location 5,949,039 698,128 2431' FNL / 1059' FWL 11 N, 15E, 32 API Number: 50-029-22208-02 Target Locations Northin Eastin Offsets TRS T1 5,955,995 696,573 716' FNL / 289' FEL 11 N, 15E, 30 T2 5,956,327 696,019 370' FNL / 832' FEL 11 N, 14E, 30 T3 5,957,074 695,388 4,887' FNL / 1,441' FEL 11 N, 15E, 19 Bottom Northin Eastin Offsets TRS Location 5,957,480 695,293 4,478' FNL / 1,524' FEL 11 N, 15E, 19 i' / % Planned KOP: 3,950' MD / 3,560' TVD Planned TD: 14,461' MD / 8,741' TVD Ri : Nabors 2ES CBE: 35.2' RTE: 63.7 Directional Proqram A roved Well lan: Wp08 Exit oint: 3,950' MD / 3,560' TVD Maximum Hole Inclination: ~92.6° in the lanned horizontal roduction section. 05-286 fails major risk with 05-16B. Ctr to ctr at the closest point is 296' C«3 Proximity Issues: 13,151' MD in 05-286 and ~ 12,200' MD in 05-16BB. The 05-16 parent well bore will be re-surveyed with Gyrodata s continuous casing multi-shot gyro. After re-surve in all wells ass a Ma'or Risk anti-collision surve . Survey Program: Standard MWD/IIFR/MS. Nearest Well within ool: Well 18-13, 475' awa BHL Nearest Pro ert Line ~39,905' 05-28B Rotary Sidetrack Page 1 ~ ~ Loqqinq Proqram Hole Section: Required Sensors / Service 8 1/2" intermediate: Real time MWD Dir/GR/Res with PWD throughout the interval, for tie-in purposes MAD ass with GR 250' above the kickoff oint. 6 1/8" roduction: Real time MWD DirGR/Res/Densi /Neutron Cased Hole: None Planned O en Hole: None lanned Mud Proqram Millingf fntcrmediate Intervaf - 9 7/8 °' Drilfing ~iuid ~ystem SNQ Milling / IMerme~dia~be intenral Fluid P~operties Flastic Yitld AP1 FWid Dep~ MD Mud MVt. Funieet Vi~cosity PoinE Los~ HTHP (~1 Ilb/ga~ ~fiscasify (cPsj (tb1100ft~ {m~t30min~ (mll3~tttminj pH M~'f Milling (F~4,OO~Q 8_£~- 9.fl~ 60-SU 15 - 22 35 - SO 6- 8 hl1C ~ 5 ~IfA 4 ,Q~i~ -~ 11, Q00 9.U -~.4 42 - 5Q S- t 2 24 - 26 6- B I~tfiC ~ 5 <~Q . 19,000 - 9 i F6E1~4 _~ ~45 - 5{~ 1B - 2Q 25 - 30 ~6.0 c42 ~~ ~2~ ~ Produation Interval - G-3t~'° C1~iINo~g ~~uid System Ft~PRC3 SF ~te~ervoar Drtl~in ~~od Production ~tterval AAud Properties Dept#~ M~ t#t) Mud Wt ~Iblg~l} ~Ias#ic ~~cosity ~c~ Yield Point (Ibltoaft~) tSRY L4rv Sttear Rat~ lfiscs~ity (cPy APl Ftua~ C~sa (mlf30tnin~ ~H 11,~4)S - 14,4fi 9 B_4 - 8.6 $-15 22 - 30 ~2~,{~QQ $- 9 ~.€} - 9_S Casinq / Tubinq Proqram Hole Size Casing/Tubing Size Wt. Grade ~ Connectiolq Length Top md / tvd Bottom md / tvd 9-7/8" 7-5/8" 29.7# L-80 BTC-M 11,608' Surface 11,608' / 8,278' 6-3/4" 41h" 12.6# L-80 IBT-M 3,003' 11,458' / 8,147' 14,461' / 8,740' Tubin 4 Y2" 12.6# L-80 IBT-M 11,458' Surface 11,458' / 8,147' 05-28B Rotary Sidetrack Page 2 ~ ~ Cementinq Proqram Casin Strin : 7-5/8", 29.7#, L-80, BTC-M Intermediate Liner Slurry Design Basis: 1 stage: 85' of 7-5/8", 29.7# shoe track, 1408' of 7-5/8" X 9-7/8" annulus with 40% excess, planned TOC 10,200' MD. 2~d ye: 5,200' of 7-5/8" X 9-7/8" annulus with 40% excess, planned TOC 5, 00',IVID. 1--_:Sta e Pre-Flush None lanned S acer 35 bbls MudPUSH at 12.0 Lead Slur None lanned Fluids Se / V l Tail Slur 79.3 bbl / 444.9 cf / sxs Class `G', 15.8 ;` 1.1 cf/sk. quence ume: o 2 Sta e Pre-Flush None lanned S acer 35 bbls MudPUSH at 12.0 Lead Slur SIL U IS• Tail Slur 278.4 bbl / 1562.4 cf / ,,sxs LiteCrete, 12 ;. f/sk. ~- 5 ~~ _.f Casin Strin : 4-1/2", 12.6#, L-80, IBT-M Production Liner Lead slurry: none planned Slur Desi n Basis: ~ g Tail slurry: 85' of 4-1/2", 12.6# shoe track, 2853' of 4-1/2" X 6-3/4" annulus " ' " " ' " with 40% excess, 150 of 4-1/2 annulus and 200 of 4 DP X 7-5/8 X 7-5/8 annulus Pre-Flush None lanned Fluids Se / V l S acer 35bbls MudPUSH at 12.0 quence o ume: ~ Lead Slur None lanned Tail Slur 110 bbl / 617.1 cf / 527,sxs Class `G', 15.8 ;.17 /sk. ~~,f ~::~ Casinq / Formation InteqritV Testinq Test Test Point Test Type Test pressure 10-3/4" casin Cement lu to surface 30 min recorded 3,500 si surface 10-3/4" casin shoe 20' new formation be ond LOT i i.3 EMW 7-5/8" casin Float e ui ment to surface 30 min recorded 3,500 si surface 7-5/8" casin shoe 20' new formation be ond FIT 9.2 EMW 4'h" roduction liner Float e ui ment to surface 30 min recorded 3,500 si surface Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 9-7/8" intermediate interval Maximum antici ated BHP: 3,659 Si at 8,278' TVD (based on seawater,8.5 ppg, gradient in CM1) Maximum surface ressure: 2,831 SI (based upon BHP and a full column of gas from TD c~ 0.10 psi/ft) Calculated kick tolerance: 111.7 bbls with 11.3 p EMW LOT Planned BOPE test ressure: 250 si low / 3,500 si hi h- 7 da test c cle Pre drillin hase wr~- 1' 05-286 Rotary Sidetrack Page 3 ~ ~ BOPE configuration for 7-5/8" The variable bore rams will be changed to 7-5/8" fixed bore rams while intermediate casing. running the 7-5/8" casing. Well Interval: 6-3/4" roduction interval Maximum antici ated BHP: 3,250 psi at 8,740' TVD Maximum surface ressure; 2,376 pSl (based upon BHP and a full column of gas from TD C~ 0.10 psi/ft) Calculated kick tolerance: Infinite with 9.2 EMW FIT. Planned BOPE test ressure: 250 si low / 3,500 si hi h-14 da test c cle Drillin o erations Planned com letion fluid: 8.4 seawater / 6.8 pp Diesel ~ i BPXA requests a variance to the provisions af 20 AAC 25.t13.5 (e)(10)G regarding the function pre~sure test requirement aftar the use of BOP equipment for o~er than weU cantrol or equivatent purposes, gxceat ~ when the routine use of BUP equipment may have campramised its effectiven~s. (E~m~le would be when pipe rams are inadvertenNy closed on a tool joint during routine operations.} The aci~ivities ass~iated w~h this request wi{I not compromise the irriegrity of the B~P equipment. Disposal Annular In'ection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo e Borou h. Fluid Handling• All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 ' for in ection. All Class I wastes are to be hauled to Pad 3 for dis osal. 05-28B Rotary Sidetrack Page 4 ~ ~ Geoloqic Proqnosis Formation To s and Estimated Pore Pressures Est. Formation To s Est. Formation To s Uncertain Commercial Hydrocarbon Bearin Est. Pore Press. Est. Pore Press. Formation MD TVD feet Yes/No Psi ~~ EMW SV4 Above KOP No KOP 3950 3496 SV3 4028 3621 0' No SV2 4320 3823 0' No SV1 5081 4246 0' No UG4 6077 4795 0' No UG4a 6155 4838 0' No UG3 6361 4952 0' No UG1 7604 5637 0' No WS2 8562 6165 0' No WS1 8938 6372 0' No CM3 9351 6600 0' No CM2 10172 7082 0' No CM1 10902 7667 0' No THRZ 11271 7987 0' No BHRZ 11492 8178 0' No LCU 11500 8185 0' No TSGR 11608 8278 0' Yes ~ TSHA 11654 8318 0' No TSAD 11724 8378 0' Yes 42S8 11804 8447 0' Yes TCGL 11872 8505 0' Yes BCGL 11942 8565 0' Yes 23S6 12021 8631 10' Yes 22TS 12058 8659 10' Yes 21TS 12118 8700 15' Yes TZ1 B/" 14N" 12165 8728 y 5' Yes TDF 12301 8784 20' Yes TD Criteria: TD well within target polygon to maintain standoff from surrounding wells perforated intervals. 800' of perforations in Zone 1 A and 200' in Zone 1 B is desired. 05-286 Rotary Sidetrack Page 5 ! ~ Operations Summarv Current Condition: / Tx1A comm, PC Leak - Secured by LTTP 1/15/04. / 12/06/05: MITOA Failed, LLR = 2 bpm @ 480 psi / 2-3/8'; 4.7#, L-80 production liner landed at 12,235'. / 4-1/2" OTIS HRQ SSSV nipple Q 2238' / 4-1/2"X3-1/2"XOC~2987' / 7-5/8" X 3-1/2" Baker SB-3 packer @ 9784. / LTTP @ 9872' Scope Pre-Riq Operations: 1. Bleed the OA, IA and tubing pressures to zero. Test the IC (7 5/8") pack-off to 3,000 psi, test the tubing pack-off to 5,000 psi. Function all LDS, repair or replace as necessary. 2. RU slickline. RIH and pull LTTP set at 9872'. 3. RU CT. RIH to the top of the 2-3/8" liner at 9872. P&A the wellbore by bullheading 10 bbls 15.8 ppg cement down the 2-3/8" liner after the cement is bullheaded into the liner lay another 4 bbls of 15.8 ppg cement on top of the liner in the 3-1/2" tubing. This should leave TOC at ~9410' MD above the completion packer at 9784'. Cement volumes based on the following: 2325' of 2-3/8", 4.7# liner C«~ 0.0039 bpf = 9.0 bbls 462' of 3-1 /2", 9.2# liner C«3 0.0087 bpf = 4.0 bbls 4. RU E-line. RIH and jet cut the 3-1/2" tubing in the middle of a joint ~ 4,300'. 5. Circulate the well to SW. Freeze protect the IA and tubing with diesel to ~ 2,200'. 6. Bleed all pressures to zero. Set BPV. Secure well. 7. Remove the well house and flow-line. If necessary, level the pad. Riq Operations: 1. MI/RU Nabors 2ES. 2. Pull BPV. Circulate out freeze protection and displace the well to SW. 3. Monitor the OA, IA and tbg for pressure. Verify the well is dead. 4. Install a TWC. Nipple down the tree and adapter flange. 5. Nipple up the BOPE and test per Permit requirement. Pull the TWC. 6. Pull the 4 1/2" X 3 1/2" tubing from the pre-rig cut at ~ 4,300'. 7. MU drift assembly and RIH to the tubing stump, PU 5" drill pipe singles. POH. 8. MU and RIH with a 7 5/8" HES CIBP, on 5" drill pipe. Set the CIBP at ~4,100'. Test CIBP to 3,500psi. 9. Displace the well to 8.8ppg milling fluid, per MIDF recommendation. Spot an 18ppg viscous pill from the CIBP to the planned casing cut depth of ~4,000'md. POH. 10. CO to 7 5/8" pipe rams and test. 11. MU a Baker Multi-string cutter. RIH and cut the 7 5/8" at 4,000' MD. Attempt to circulate through the cut to confirm a`free' annulus. POH. LD multi-string cutter. 12. MU a casing spear, per Baker recommendation. BOLDS and pull the 7 5/8" casing free. LD the 7 5/8" casing from the cut. 13. MU a 3~h" cementing stinger assembly. RIH to CIBP, spot a~45 bbl, balanced 17.0 ppg kick-off cement plug, calculated on a gauge 9-7/8" hole behind the 7-5/8" casing this should leave cement ~315' inside the 10-3/4" surface casing. POH above the cement and circulate string clean. POH, UD stinger assy. 05-286 Rotary Sidetrack Page 6 ~ ~ 14. CO to 3 1/2 X 6" VBR and test. WOC as required. 15. MU a 9 7/8" drilling assembly with DIR/GR/RES/PWD. 16. RIH to tag cement top. Confirm a solid cement plug. Test the 10 3/a" casing to 3,500psi for 30 minutes. Record the test. 17. Dress the cement down to the surface shoe. 18. Drill 20' of new hole and conduct a LOT. 19. Kick off and drill the 9 7/8" intermediate interval, per directional plan, to the top Sag River. / 20. Circulate and condition hole. POH, UD 5" drill pipe and drilling assembly. 21. Install and test 7-5/8" fixed bore rams to run the 7-5/8" long string / 22. Run a 7 5/8", 29.7#, BTC-M long string. Cement the 7 5/8" via 2 stages, uti ~~ a HES ES-cementer. /'~ ~ The first stage TOC will be ~10,200'md. The second stage TOC will be ~,000' d. ~ 23. Install and test the variable bore rams in place of the 7-5/8" fixed bore ra ~ 24. MU sufficient 4" drill pipe to reach planned TD of 14,461'md. ~ 25. MU a 6 3/4" DIR/GR/Res drilling assembly. ~ 26. RIH to the ES-Cementer equipment. Test the 7 5/8" casing to 3,500psi. Drill out the ES-Cementer ~ equipment and continue in hole to the float equipment. 27. R/U and test the 7 5/8" casing to 3,500psi for 30 minutes. Record the test. /~ .~,,. 28. Drill the float equipment and cement to the shoe. Q 29. Displace the well to the 8.5ppg Flo-Pro system. Q' 30. Drill out the shoe and 20' of new formation. Circulate to consistent mud pro ies and attempt to ~ perform a FIT to 10.0 ppg EMW, the minimum FIT for infinite kick tolerance i~P9 EMW. Q 31. Drill ahead, per directional proposal, to the planned horizontal landing point in ne 1 A. CBU. / " 32. POH for bit / bha. ~` 33. MU a 6 3/4" DIR/GR/Res/Den/Neu drilling assembly. RIH, acquire MAD pas data, per rig site ~ geologist, through the build interval. 34. Drill the horizontal section to TD, estimated at 14,461'md. ~' 35. CBU, S/T as needed, and circulate hole in preparation of running the 4'h" liner. Spot a liner running pill. POH, VD XS drill pipe and drilling assembly. 36. Run and cement a 4 1/2", 12.6#, L-80 liner to approximately 150' into the 7 5/8" casing. ~~ 37. Set the liner top packer and displace the well to clean seawater above the liner top. POH and UD LRT. 38. Test the casing X liner to 3,500psi for 30 minutes. Record the test. /~ 39. MU Schlumberger 2 7/8" Power-jet tcp guns, at 6spf, and 2 7/8" drill pipe. RIH, tag, space, and fire guns. Perforation interval(s) to be determined by subsurface team. POH, UD all drill pipe and tcp / guns. ~ 40. Run a 4 1/2", 12.6#, L-80 completion, tying into the 4 1/2" liner top. Space and land the completion. RILDS. 41. Reverse circulate sea water/corrosion inhibitor per MIDF representative. 42. Drop the ball/rod to seat. Set the production packer. 43. Individually test the tubing and the annulus to 3,500psi for 30 minutes. Record each test. 44. Shear the `DCK' valve in the #5 GLM. Confirm shear with adequate flow in each direction. 45. Install a TWC and test. ~ 46. N/D the BOPE. N/U the adapter flange and tree. Test the tree and adapter to 5,OOOpsi. 47. Pull the TWC. 48. R/U LRHOS. Reverse in sufficient volume of diesel to freeze-protect both the tubing and annulus to ~2,200'. Allow the diesel to U-tube to equilibrium. 49. Install a BPV and test. Remove secondary annulus valve. Secure the well. 50. RD/MO. Post-Riq Work: 1. Install well-house and flow-line. 2. MI/RU slickline. Pull the ball and rod / RHC plug from `X' nipple below the new production packer. 05-28B Rotary Sidetrack Page 7 ~ ~ Job 1: Move In / Riq Up / Test BOPE Planned Job Time Planned Job Cost 60.0 hours $341,500 includes $210K re-ri costs Reference RP •"Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP tssues and Potential Hazards - No wells will be required to be shut in to move the rig onto 05-28, there is no well to the North and 05-01 is 35' to the South. Check the spacing and notify the pad operator prior to moving onto the well. Care should be taken while moving onto the well. Spotters should be employed at all times. - During MI/RU operations, the 05-28 well bore will be secured with the following barriers: o Tubing: kill weight fluid, a BPV, and P&A cement across the perforated interval. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. - Prior to pulling the tree, verify there is a static column of seawater to surface and that no pressure exists. - During ND/NU BOPE operations, the 05-28 well bore will be secured with the following barriers: • Tubing: kill weight fluid, a TWC / blanking plug, and &A cement across the perforated interval. •3 IA: Annulus valves and kill weight fluid. • OA: Annulus valve and kili weight fiuid. Drill Site 5 is no esignated as a H2S Site. Standard Operating Procedures for H2S ~'' precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading 05-01 B 9 18-30 9 05-32 1 18-22A 4 The maximum level recorded of H2S on the pad was~27~pm in 05-05B on 11/01/1990. ~~.~' - Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud 05-28B Rotary Sidetrack Page 8 i~ i Job 2: De-complete Well Planned Job Time Planned Job Cost 91.0 hours $339,400 Reference RP :• "De-completions" RP •"Casing and Cutting Pull with Baker Back-Off Tool" RP •"Setting a Kick-off or Abandonment Plug in Open Hole" RP Issues and Potential Hazards - Monitor the well to ensure the fluid column remains static, prior to pulling the completion. - Have all wellhead and completion equipment NORM-tested, following retrieval. - 05-28 has a FMC Slimhole Thrubore wellhead. It is an 11" thrubore with a 4-1/2" completion. The 7-5/8" intermediate string is set on a mandrel hanger. The landing joint will be a 9" LH ACME thread. Once the tree has been nippled down, verify the hanger thread and type in preparation for de-completion. Be prepared with the appropriate tubing spear, in the event it becomes necessary. - There is a 4-~h" Otis HRQ SSSV set at 2,238'. - Run GR/CCL Log from the bridge plug setting depth to the 10-3/4" surface casing shoe after setting the EZSV. - Spot an 18 ppg viscous pill from the EZSV to 4,000' MD, the planned cut depth of the 7-5/8" csg. - Cut the 7-5/8" casing in the center of a joint at ~4,000' MD. After cutting attempt to establish circulation through the cut. - When pumping the balanced plug the maximum pump rate for the last 20 bbls is 2 bpm. Displacement the plug with mud leaving ~80' of cement in the DP above the balance point. - After displacing POH to ~300' above the top of the plug and circulate the hole clean. Job 5: Drill 9-7/8" Intermediate Hole Interval Planned Job Time Planned Job Cost 156.0 hours $858,000 Reference RP •"Shale Drilling, Kingak and HRZ" RP • "Prudhoe Bay Directional Guidelines" SOP •"Leak-off and Formation Integrity Tests" SOP •"Lubricants for Torque and Drag Management" RP Issues and Potential Hazards - Tie MWD - GR back to PDC log from parent wellbore. - Tag cement and test the 10-3/4" surface casing to 3,500 psi for 30 minutes. - After kicking off of the cement plug the directional plan has the wellbore building to 56° through the Colville and then dropping to 30° by the THRZ and holding this angle to the 7-5/8" casing point. 05-28B Rotary Sidetrack Page 9 ~ ~ - Polar plots show of mud weight of 10.4 ppg is required to provide HRZ stability, increase the mud weight to 10.5 ppg ~100' above the THRZ. Follow all shale drilling practices to minimize potential problems. - KICK TOLERANCE: In the worst-case scenario of 8.5 ppg pore pressure, a fracture gradiey~-e# ~ 11.3 ppg at the 10-3/4" casing shoe, and 10.5 ppg mud in the hole, the kick tolerance is (111.7i bbls. ~ - '• A The above kick tolerance is based on an LOT of 11.3 ppg EMW, contact the ODE if a LOT of 11.3 ppg EMW is not reached. - The 05-28B wellbore is prognosed to cross one fault in the HRZ at ~11,300' MD, the throw is predicted to be less than 5' and no loss of section is anticipated. As with all faults in the HRZ care should be taken after crossing the fault to establish stratigraphic position prior to the 7-5/8" casing point. Phase 6: Run and Cement 7-5/8" Intermediate Casinq Planned Phase Time Planned Phase Cost 40.0 hours ~ $736,000 Reference RP •"Intermediate Casing and Cementing Guidelines" RP •"Freeze Protecting an Outer Annulus" RP •"Shale Drilling, Kingak and HRZ" RP Issues and Potential Hazards - Swab and surge pressure should be minimized with controlled casing running speeds and by breaking circulation slowly. Excessive swab / surge pressures could initiate HRZ / Kingak instability problems. - Differential Sticking is potentially a problem if fost circulation occurs or if the casing is left stationary across permeable formations. Job 7: Drill 6-3/4" Production Hole Interval Planned Job Time Planned Job Cost 145.0 hours $832,000 Reference RP •"Standard Operating Procedure: Leak-off and Formation Integrity Tests" •3 "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards - KICK TOLERANCE: In the worst-case scenario of 3,250 psi pore pressure in the Ivishak, a fract gradient 9.2 ppg at the 7" casing shoe, and 8.4 ppg mud in the hole, the kick tolerance is i finit . - The`at5ove kick tolerance is based on an FIT of 9.2 ppg EMW, this is the minimum FIT specidied in the permit to drill, attempt an FIT to 10.0 ppg EMW for an extra margin of safety. Contact the ODE if a 9.2 ppg EMW FIT is not reached. 05-28B Rotary Sidetrack Page 10 ~ ~ - The directional plan has the wellbore entering the Sag River at 30°, then building to 32° through the Zone 3 conglomerate. The well will then be landed in Zone 1A and drilled horizontally with a toe-up into Zone 1 B prior to TD at 14,461' MD - The production interval is planned to be drilled with two bits. An insert bit will be utilized to drill the conglomerate and land the well in Zone 1 B, a PDC bit will then be used to drill the horizontal section. - 05-28B is prognosed to cross one fault in Zone 1 at 12,875' MD with a throw of less than i0'. This fault is at the limit of seismic resolution and losses are not expected. Job 9: Run and Cement 4~/2" Production Liner Planned Job Time Planned Job Cost 28.0 hours $273,000 Reference RPs • Running and Cementing a Liner Conventionally Issues and Potential Hazards - The completion design is to run a 4~h", 12.6#, L-80, IBT-M liner over the production interval. - Differential sticking is possible. The 8.4 ppg Flo-Pro will be ~594 psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. - Sufficient 4-~/a" liner will be run to extend ~150' back up into the 7-5/8" liner shoe. - Ensure the 4-~h" liner top packer is set prior to POH. Job 10: DPC Perforate Well Planned Job Time Planned Job Cost 30.0 hours $300,500 Reference RPs • DPC Perforating RP • Schlumberger DPC Perforating Guidelines Hazards and Contingencies - The production interval of the well will be DPC perforated prior to running the completion. Be prepared for losses upon firing guns. Ensure all responsibilities are clearly communicated with respect to perforating guns safety. Watch hole fill closely while POH with perf guns. - The Asset will provide a minimum clean out depth. This will define how far off depth the guns can be and still be fired without coming out of the hole to perform a clean out trip in the event the guns cannot reach tag the landing collar due to cemenUfill. 05-286 Rotary Sidetrack Page 11 i ~- Job 12: Run 4~/2" L-80 Completion Planned Job Time Planned Job Cost 24.0 hours $415,000 Reference RP • "Completion Design and Running" RP • "Tubing connections" RP Issues and Potential Hazards - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is -- 0.1 psia at 100° F. - The completion will be a 4'/2", 12.6#, L-80, IBT-M production tubing string, stinging into the 4'h" liner tieback sleeve. Job 13: ND/NU/Release Riq Planned Job Time Planned Job Cost 9.0 hours $34,000 Reference RP •"Freeze Protecting an fnner Annulus" RP Issues and Potential Hazards - No wells will be required to be shut in to move the rig off of 05-28, there is no well to the North and 05-01 is 35' to the South. 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J0~0_^..^.JC~.'~.-J ~ ~^. ~G ~D t~ ~l h1 'J ~C J' '~1 ~ ~ rr v`~iv~innMr'lb'T'S TTT?'J` T p oor~v~p _yea~oorar ~ ~ ,-, ~ xr omn~Mr _ °_ ~. . ~ -°_ N ,,, ,, ..r_.. ,., ...:~°~ 'T . ~~ ° ^ r ~ MM~'°=~=x=^..j._ .YT INt`I~+'.NiM~YCK ~ VI - ri r, Y~n .: ~~G T~~~~ r~ Y~n _ t~ }^ 7 ; ~ ~ 3 ~ G m ~ ~,~ j ~ t :33'J~~~ ~ a- ~ ' ~E~"~ ;_ ~ --- J '~~~`t~ s 0 ° ~ ~ ~ S er -Sun ~ P rY BP Planning Report Company: BP Amoco Date: 11/17/2005 Time: 14:43:01 Page: 1; Field: Prudhce Bay Co-ordinate(NEjReference: Well: 05-28, True North Site: PB DS 05 Vertical (TVD) Reference: 28.5+352 63.7 Well: 05-28 SecHon {VS) Reference: Well (O.OON;O.OOE,342.94Azi) Wellpat6: Plan 05-28B Survey Calculation Method: Minimum Curvature Db: Oracle Plan: 05-286 wp08 Date Composed: 10/5/2005 Version: 33 Principal: Yes Tied-to: From: Definitive Path Fieid: Prudhce 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: W ell Centre Sys Datum: Mean Sea Levei Geomagnetic Model: bggm2005 Site: PB DS 05 TR-11-15 UNITED STATES : North Slope Site Position: Northing: 5947204.70 ft Latitude: 70 15 35.696 N From: Map EasHng: 697428.91 ft Longitude: 148 24 14.424 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.50 deg Well: 05-28 Slot Name: 05-28 Well Position: +N/-S 1815.10 ft Northing: 5949038.65 ft Latitude: 70 15 53.547 N +E/-W 746.88 ft Easting : 698127.91 ft Longitude: 148 23 52.687 W PosiHon Uncertainty: 0.00 ft Casing Points MD 1'VD Diameter Hole Size Name ft ft in in 11608.06 8277.70 7.625 8.500 7 5/8" 14461.00 8740.74 4.500 . 6.125 4 1/2" FormaHons MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 0.00 SV4 0.00 0.00 4027.92 3620.70 SV3 0.00 0.00 4320.16 3822.70 SV2 0.00 0.00 5080.64 4245.70 SV1 0.00 0.00 6076.63 4794.70 UG4 0.00 0.00 6154.64 4837.70 UG4a 0.00 0.00 6361.46 4951.70 UG3 0.00 0.00 7604.18 5636.70 UG1 0.00 0.00 8562.07 6164.70 WS2 0.00 0.00 8937.61 6371.70 WS1 0.00 0.00 9351.24 6599.70 CM3 0.00 0.00 10172.55 7081.70 CM2 0.00 0.00 10901.55 7665.70 CM1 0.00 0.00 11271.56 7986.70 THRZ 0.00 0.00 11492.42 8177.70 BHRZ 0.00 0.00 11500.52 8184.70 LCU 0.00 0.00 11608.06 8277.70 TSGR 0.00 0.00 11654.31 8317.70 TSHA 0.00 0.00 11723.69 8377.70 TSAD 0.00 0.00 11803.58 8446.70 42S6 0.00 0.00 11871.59 8504.70 TCGL 0.00 0.00 11941.96 8564.70 BCGL 0.00 0.00 12021.22 8630.70 23S6 0.00 0.00 12058.00 8658.70 22TS 0.00 0.00 12117.83 8699.70 21TS 0.00 0.00 12165.09 8727.70 TZ1 B 0.00 0.00 12300.95 8783.70 TDF 0.00 0.00 0.00 BSAD 0.00 0.00 ~ S err -Sun ~ P Y BP Planning Report Company: BP Amoco Date: 11/17/2005 Time: 14:43:01 Page: 2 Field: Prudhce Bay Co-ordinate(NE) Reference: W ell: 05-28, True North Site: PB DS 05 Vertical (TVD) Reference: 28.5+352 63:7 Well: 05-28 SecHon(VS)Referen ce: Weli{O:OON,O.OOE,342.94Azi) Wellpath: Plan 05-28B Survey CalculaNon Method: Minimum Curvature Db: Oracle Targets Map Map <-- Latitude --> <= Longitude => Name Description TVD +N/-S +E/-W Northing Easting Deg Min 8ec Deg Min Sec Dip. Dir. ft ft ft ft ft 05-286 TO 8429.70 6920.00 -920.00 5955931. 66 697026.18 70 17 1. 605 N 148 24 19.487 W 05-28B T4 wp06 8740.70 8513.51 -2611.93 5957480. 00 695293.00 70 17 17. 273 N 148 25 8.788 W 05-28B T3 wp06 8759.70 8105.12 -2527.64 5957074. 00 695388.00 70 17 13. 257 N 148 25 6.329 W 05-28B T2 wp06 8771.70 7341.73 -1916.48 5956327. 00 696019.00 70 17 5. 751 N 148 24 48.517 W 05-286 T1 wp06 8799.70 6995.50 -1371.70 5955995. 24 696572.67 70 17 2. 347 N 148 24 32.645 W 05-28B Poly 8799.70 8431.43 -2800.36 5957393. 00 695106.80 70 17 16. 465 N 148 25 14.278 W -Polygon 1 8799.70 8431.43 -2800.36 5957393. 00 695106.80 70 17 16. 465 N 148 25 14.278 W -Polygon 2 8799.70 8493.53 -2499.01 5957463. 00 695406.40 70 17 17. 077 N 148 25 5.498 W -Polygon 3 8799.70 7865.31 -2158.40 5956844. 00 695763.40 70 17 10. 899 N 148 24 55,569 W -Polygon 4 8799.70 7033.01 -1057.76 5956041. 00 696885.50 70 17 2. 716 N 148 24 23.500 W -Polygon 5 8799.70 6896.17 -1673.71 5955888. 00 696273.40 70 17 1. 369 N 148 24 41.442 W -Polygon 6 8799.70 7693.11 -2609.42 5956660. 00 695317.10 70 17 9. 204 N 148 25 8.707 W -Polygon 7 8799.70 8431.43 -2800.36 5957393. 00 695106.80 70 17 16. 465 N 148 25 14.278 W Plan Section [nformation MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/1001t deg 3950.00 35.77 354.42 3559.88 1337.71 -172.44 0.00 0. 00 0.00 0.00 3970.00 38.14 355.09 3575.87 1349.68 -173.54 12.00 11. 83 3.37 10.00 443627 56.55 359.22 3890.51 1690.65 -188.66 4.00 3. 95 0.88 10.82 9805.33 56.55 359.22 6850.00 6170.00 -250.00 0.00 0. 00 0.00 0.00 11226.15 30.14 278.89 7947.43 6876.73 -643.34 4.00 -1. 86 -5.65 -143.75 11783.82 30.14 278.89 8429.70 6920.00 -920.00 0.00 0. 00 0.00 0.00 05-286 TO 11810.95 31.50 278.94 8453.00 6922.16 -933.73 5.00 5. 00 0.20 1.20 11971.01 31.50 278.94 8589.47 6935.16 - 1016.34 0.00 0. 00 0.00 0.00 12405.69 88.00 280.00 8799.70 6995.50 - 1371.70 13.00 13. 00 0.24 1.27 05-28B T1 wp06 12606.84 93.68 305.54 8796.71 7072.64 - 1555.56 13.00 2. 82 12.70 77.49 12906.79 93.68 305.54 8777.48 7246.63 - 1799.13 0.00 0. 00 0.00 0.00 13058.06 90.70 312.50 8771.70 7341.73 - 1916.48 5.00 -1. 96 4.60 112.97 05-28B T2 wp06 13150.80 90.20 317.11 8770.97 7407.07 - 1982.27 5.00 -0. 55 4.97 96.24 13660.20 9020 317.11 8769.22 7780.28 -2328.96 0.00 0. 00 0.00 0.00 14043.67 92.61 340.00 8759.70 8105.12 -2527.64 6.00 0. 63 5.97 83.78 05-28B T3 wp06 14219.39 92.60 350.55 8751.69 8274.65 -2572.19 6.00 -0. 01 6.01 89.81 14461.77 92.60 350.55 8740.70 8513.51 -2611.93 0.00 0. 00 0.00 0.00 05-28B T4 wp06 Survey MD [ncl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE TooUComme t ft deg deg ft ft ft ft ft deg/100ft ft ft 3950.00 35.77 354.42 3559.88 3496.18 1329 .45 1337.71 -172. 44 0.00 5950371.28 697920 .33 Start Dir 12/10 3970.00 38.14 355.09 3575.87 3512.17 1341 .22 1349.68 -173. 54 12.00 5950383.22 697918 .92 Start Dir 4/100 4000.00 39.32 355.45 3599.27 3535.57 1359 .56 1368.39 -175. 09 4.00 5950401.88 697916 .88 MWD+IFR+MS 4027.92 40.42 355.76 3620.70 3557.00 1377. 02 1386.23 -176. 46 4.00 5950419.68 697915 .04 SV3 4100.00 43.26 356.51 3674.39 3610.69 1423. 82 1434.20 -179. 69 4.00 5950467.54 697910 .55 MWD+IFR+MS 4200.00 47.20 357.43 3744.81 3681.11 1492. 68 1505.08 -183. 42 4.00 5950538.30 697904 .96 MWD+IFR+MS 4300.00 51.16 358.24 3810.16 3746.46 1565. 79 1580.68 -186. 25 4.00 5950613.80 697900 .14 MWD+IFR+MS 4320.16 51.95 358.40 3822.70 3759.00 1581. 02 1596.47 -186. 71 4.00 5950629.56 697899 .26 SV2 4400.00 55.11 358.97 3870.15 3806.45 1642. 81 1660.65 -188. 18 4.00 5950693.68 697896 .10 MWD+IFR+MS 4436.27 56.55 359.22 3890.51 3826.81 1671. 63 1690.65 -188. 66 4.00 5950723.66 697894 .84 End Dir : 4436 4500.00 56.55 359.22 3925.64 3861.94 1722. 68 1743.82 -189. 39 0.00 5950776.79 697892 .71 MWD+IFR+MS 4600.00 56.55 359.22 3980.77 3917.07 1802. 77 1827.25 -190. 53 0.00 5950860.15 697889 .37 MWD+IFR+MS 4700.00 56.55 359.22 4035.89 3972.19 1882. 86 1910.68 -191. 67 0.00 5950943.52 697886 .04 MWD+IFR+MS 4800.00 56.55 359.22 4091.01 4027.31 1962. 96 1994.11 -192. 81 0.00 5951026.88 697882 .70 MWD+IFR+MS 4900.00 56.55 359.22 4146.13 4082.43 2043. 05 2077.54 -193. 96 0.00 5951110.25 697879 .36 MWD+IFR+MS ~ S err -Sun ~ P Y BP Planning Report Company: BP Amoco Date: 11/17/2005 Time: 14:43:01 Page: 3 Field: Prudhce Bay Co-ordinate(NE) Reference: WeIL• 05-28, True North Site: PB DS 05 Vertical (TVD) Reference: 28.5+35.2 63.7 Well: 05-28 SecHon (VS) Referenee: Well (O.OON,O.OOE,342.94Azi) Wellpath: Pian 05-286 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE TooUCornme t ft deg deg ft ft ft ft ft deg/100ft ft ft 5000.00 56.55 359.22 4201.25 4137.55 2123.15 2160.97 -195.10 0.00 5951193.61 697876.02 MWD+IFR+MS 5080.64 56.55 359.22 4245.70 4182.00 2187.74 2228.24 -196.02 0.00 5951260.84 697873.33 SV1 5100.00 56.55 359.22 4256.37 4192.67 2203.24 2244.40 -196.24 0.00 5951276.98 697872.69 MWD+IFR+MS 5200.00 56.55 359.22 4311.49 4247.79 2283.34 2327.82 -197.38 0.00 5951360.34 697869.35 MWD+IFR+MS 5300.00 56.55 359.22 4366.6~ 4302.91 2363.43 2411.25 -198.53 0.00 5951443.71 697866.01 MWD+IFR+MS 5400.00 56.55 359.22 4421.73 4358.03 2443.53 2494.68 -199.67 0.00 5951527.08 697862.67 MWD+IFR+MS 5500.00 56.55 359.22 4476.86 4413.16 2523.62 2578.11 -200.81 0.00 5951610.44 697859.34 MWD+IFR+MS 5600.00 56.55 359.22 4531.98 4468.28 2603.72 2661.54 -201.95 0.00 5951693.81 697856.00 MWD+IFR+MS 5700.00 56.55 359.22 4587.10 4523.40 2683.81 2744.97 -203.10 0.00 5951777.17 697852.66 MWD+IFR+MS 5800.00 56.55 359.22 4642.22 4578.52 2763.91 2828.40 -204.24 0.00 5951860.54 697849.32 MWD+IFR+MS 5900.00 56.55 359.22 4697.34 4633.64 2844.00 2911.83 -205.38 0.00 5951943.90 697845.99 MWD+IFR+MS 6000.00 56.55 359.22 4752.46 4688.76 2924.09 2995.25 -206.52 0.00 5952027.27 697842.65 MWD+IFR+MS 6076.63 56.55 359.22 4794.70 4731.00 2985.47 3059.19 -207.40 0.00 5952091.15 697840.09 UG4 6100.00 56.55 359.22 4807.58 4743.88 3004.19 3078.68 -207.67 0.00 5952110.63 697839.31 MWD+IFR+MS 6154.64 56.55 35922 4837.70 4774.00 3047.95 3124.27 -208.29 0.00 5952156.18 697837.49 UG4a 6200.00 56.55 359.22 4862.70 4799.00 3084.28 3162.11 -208.81 0.00 5952194.00 697835.97 MWD+IFR+MS 6300.00 56.55 359.22 4917.82 4854.12 3164.38 3245.54 -209.95 0.00 5952277.36 697832.64 MWD+IFR+MS 6361.46 56.55 359.22 4951.70 4888.00 3213.60 3296.82 -210.65 0.00 5952328.60 697830.59 UG3 6400.00 56.55 359.22 4972.94 4909.24 3244.47 3328.97 -211.09 0.00 5952360.73 697829.30 MWD+IFR+MS 6500.00 56.55 359.22 5028.07 4964.37 3324.57 3412.40 -212.24 0.00 5952444.09 697825.96 MWD+IFR+MS 6600.00 56.55 359.22 5083.19 5019.49 3404.66 3495.83 -213.38 0.00 5952527.46 697822.62 MWD+IFR+MS 6700.00 56.55 359.22 5138.31 5074.61 3484.76 3579.26 -214.52 0.00 5952610.82 697819.29 MWD+IFR+MS 6800.00 56.55 359.22 5193.43 5129.73 3564.85 3662.69 -215.66 0.00 5952694.19 697815.95 MWD+IFR+MS 6900.00 56.55 359.22 5248.55 5184.85 3644.95 3746.11 -216.81 0.00 5952777.55 697812.61 MWD+IFR+MS 7000.00 56.55 359.22 5303.67 5239.97 3725.04 3829.54 -217.95 0.00 5952860.92 697809.27 MWD+IFR+MS 7100.00 56.55 359.22 5358.79 5295.09 3805.14 3912.97 -219.09 0.00 5952944.28 697805.94 MWD+IFR+MS 7200.00 56.55 359.22 5413.91 5350.21 3885.23 3996.40 -220.23 0.00 5953027.65 697802.60 MWD+IFR+MS 7300.00 56.55 359.22 5469.03 5405.33 3965.33 4079.83 -221.38 0.00 5953111.01 697799.26 MWD+IFR+MS 7400.00 56.55 359.22 5524.15 5460.45 4045.42 4163.26 -222.52 0.00 5953194.38 697795.92 MWD+IFR+ppS 7500.00 56.55 359.22 5579.28 5515.58 4125.51 4246.69 -223.66 0.00 5953277.74 697792.59 MWD+IFR+MS 7600.00 56.55 359.22 5634.40 5570.70 4205.61 4330.12 -224.80 0.00 5953361.11 69778925 MWD+IFR+MS 7604.18 56.55 359.22 5636.70 5573.00 4208.96 4333.60 -224.85 0.00 5953364.59 697789.11 UG1 7700.00 56.55 359.22 5689.52 5625.82 4285.70 4413.54 -225.95 0.00 5953444.48 697785.91 MWD+IFR+MS 7800.00 56.55 359.22 5744.64 5680.94 4365.80 4496.97 -227.09 0.00 5953527.84 697782.57 MWD+IFR+MS 7900.00 56.55 359.22 5799.76 5736.06 4445.89 4580.40 -228.23 0.00 5953611.21 69777924 MWD+IFR+MS 8000.00 56.55 359.22 5854.88 5791.18 4525.99 4663.83 -229.37 0.00 5953694.57 697775.90 MWD+IFR+MS 8100.00 56.55 359.22 5910.00 5846.30 4606.08 4747.26 -230.52 0.00 5953777.94 697772.56 MWD+IFR+MS 8200.00 56.55 359.22 5965.12 5901.42 4686.18 4830.69 -231.66 0.00 5953861.30 697769.22 MWD+IFR+MS 8300.00 56.55 359.22 602024 5956.54 4766.27 4914.12 -232.80 0.00 5953944.67 697765.89 MWD+IFR+MS 8400.00 56.55 359.22 6075.37 6011.67 4846.37 4997.55 -233.94 0.00 5954028.03 697762.55 MWD+IFR+MS 8500.00 56.55 359.22 6130.49 6066.79 4926.46 5080.97 -235.09 0.00 5954111.40 697759.21 MWD+IFR+MS 8562.07 56.55 359.22 6164.70 6101.00 4976.18 5132.76 -235.80 0.00 5954163.14 697757.14 WS2 8600.00 56.55 359.22 6185.61 6121.91 5006.56 5164.40 -236.23 0.00 5954194.76 697755.87 MWD+IFR+MS 8700.00 56.55 359.22 6240.73 6177.03 5086.65 5247.83 -237.37 0.00 5954278.13 697752.54 MWD+IFR+MS 8800.00 56.55 359.22 6295.85 6232.15 5166.74 5331.26 -238.51 0.00 5954361.49 697749.20 MWD+IFR+MS 8900.00 56.55 359.22 6350.97 6287.27 5246.84 5414.69 -239.66 0.00 5954444.86 697745.86 MWD+IFR+MS 8937.61 56.55 359.22 6371.70 6308.00 5276.96 5446.07 -240.09 0.00 5954476.21 697744.61 WS1 9000.00 56.55 359.22 6406.09 6342.39 5326.93 5498.12 -240.80 0.00 5954528.22 697742.52 MWD+IFR+MS 9900.00 56.55 359.22 6461.21 6397.51 5407.03 5589.55 -241.94 0.00 5954611.59 697739.19 MWD+IFR+MS 9200.00 56.55 359.22 6516.33 6452.63 5487.12 5664.98 -243.08 0.00 5954694.95 697735.85 MWD+IFR+MS 9300.00 56.55 359.22 6571.45 6507.75 5567.22 5748.41 -244.23 0.00 5954778.32 697732.51 MWD+IFR+MS 9351.24 56.55 359.22 6599.70 6536.00 5608.26 5791.16 -244.81 0.00 5954821.04 697730.80 CM3 ~ S err -Sun • P Y BP Planning Report Company: BP Amoco Date: 11/17/2005 Time: 14:43:01 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 05-28, True North Site: PB DS 05 Vertical (TW) Reference: 28.5+35.2 63.7 Well: 05-28 Section (VS) Reference: Well (O.OON,O.OOE,342.94Azi} Wellpath: Plan 05-286 Survey Calculation Met6od: Minimum Gunrature Db: Oracle Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE Tool/Comme t ft deg deg ft ft ft ft ft deg/100ft ft ft 9400.00 56.55 359.22 6626.58 6562.88 5647.31 5831.83 -245.37 0.00 5954861.68 697729.17 MWD+IFR+MS 9500.00 56.55 359.22 6681.70 6618.00 5727.41 5915.26 -246.51 0.00 5954945.05 697725.84 MWD+IFR+MS 9600.00 56.55 359.22 6736.82 6673.12 5807.50 5998.69 -247.65 0.00 5955028.41 897722.50 MWD+IFR+MS 9700.00 56.55 359.22 6791.94 6728.24 5887.60 6082.12 -248.80 0.00 5955111.78 697719.16 MWD+IFR+MS 9800.00 56.55 35922 6847.06 6783.36 5967.69 6165.55 -249.94 0.00 5955195.15 697715.82 MWD+IFR+MS 9805.33 56.55 35922 6850.00 6786.30 5971.96 6170.00 -250.00 0.00 5955199.59 697715.65 Start Dir 4/100 9900.00 53.53 356.43 6904,25 6840.55 6046.91 6247.51 -252.91 4.00 5955276.99 697710.70 MWD+IFR+MS 10000.00 50.41 353.25 6965.86 6902.16 6123.95 6325.93 -259.95 4.00 5955355.20 697701.60 MWD+IFR+MS 10100.00 47.39 349.77 7031.60 6967.90 6198.43 6400.44 -271.02 4.00 5955429.38 697688.57 MWD+IFR+MS 10172.55 45.27 347.03 7081.70 7018.00 6250.65 6451.83 -281.54 4.00 5955480.48 697676.70 CM2 10200.00 44.48 345.94 7101.15 7037.45 6269.98 6470.66 -286.07 4.00 5955499.19 697671.68 MWD+IFR+MS 10300.00 41.72 341.71 7174.18 7110.48 6338.26 6536.27 -305.03 4.00 5955564.26 697651.00 MWD+IFR+MS 10400.00 39.13 337.01 7250.32 7186.62 6402.93 6596.93 -327.80 4.00 5955624.30 697626.64 MWD+IFR+MS 10500.00 36.74 331.78 7329.21 7265.51 6463.69 6652.35 -354.28 4.00 5955679.00 697598.71 MWD+IFR+MS 10600.00 34.62 325.96 7410.46 7346.76 6520.22 6702.26 -384.34 4.00 5955728.11 697567.35 MWD+IFR+MS 10700.00 32.80 319.54 7493.67 7429.97 6572.26 6746.43 -417.83 4.00 5955771.37 697532.72 MWD+IFR+MS 10800.00 31.33 312.52 7578.44 7514.74 6619.56 6784.62 -454.58 4.00 5955808.58 697494.98 MWD+IFR+MS 10900.00 30.28 304.98 7664.36 7600.66 6661.88 6816.66 -494.42 4.00 5955839.57 697454.31 MWD+IFR+MS 10901.55 30.27 304.86 7665.70 7602.00 6662.49 6817.11 -495.06 4.00 5955840.00 697453.66 CM1 11000.00 29.69 297.06 7751.01 7687.31 6699.01 6842.40 -537.15 4.00 5955864.17 697410.92 MWD+IFR+MS 11100.00 29.58 288.97 7837.96 7774.26 6730.78 6861.70 -582.56 4.00 5955882.26 697365.01 MWD+IFR+MS 11200.00 29.96 280.95 7924.79 7861.09 6757.04 6874.47 -630.44 4.00 5955893.77 697316.82 MWD+IFR+MS 11226.15 30.14 278.89 7947.43 7883.73 6762.98 6876.73 -643.34 4.00 5955895.69 697303.87 End Dir : 1122 11271.56 30.14 278.89 7986.70 7923.00 6772,95 6880.25 -665.87 0.00 5955898.61 697281.25 THRZ 11300.00 30.14 278.89 8011.29 7947.59 6779.20 6882.46 -679.98 0.00 5955900.45 697267.09 MWD+IFR+MS 11400.00 30.14 278.89 8097.77 8034.07 6801.17 6890.22 -729.59 0.00 5955906.90 697217.30 MWD+IFR+MS 11492.42 30.14 278.89 8177.70 8114.00 6821.48 6897.39 -775.44 0.00 5955912.86 697171.28 BHRZ 11500.00 30.14 278.89 5184.25 8120.55 6823.14 6897.98 -779.20 0.00 5955913.35 697167.50 MWD+IFR+MS 11500.52 30.14 278.89 8184.70 8121.00 6823.25 6898.02 -779.46 0.00 5955913.39 697167.25 LCU 11600.00 30.14 278.89 8270.73 8207.03 6845.11 6905.74 -828.81 0.00 5955919.80 697117.71 MWD+IFR+MS 11608.06 30.14 278.89 8277.70 8214.00 6846.88 6906.36 -832.81 0.00 5955920.32 697113.70 7 5/8" 11654.31 30.14 278.89 8317.70 8254.00 6857,04 6909.95 -855.75 0.00 5955923.31 697090.66 TSHA 11700.00 30.14 278.89 8357.21 8293.51 6867.08 6913.50 -878.42 0.00 5955926.25 697067.91 MWD+IFR+MS 11723.69 30.14 278.89 8377.70 8314.00 6872.28 6915.34 -890.17 0.00 5955927.78 697056.12 TSAD 11783.82 30.14 278.89 8429.70 8366.00 6885.49 6920.00 -920.00 0.00 5955931.66 697026.18 05-28B TO 11800.00 30.95 278.92 8443.63 8379.93 6889.09 6921.27 -928.13 5.00 5955932.72 697018.02 MWD+IFR+MS 11803.58 31.13 278.93 8446.70 8383.00 6889.90 6921.56 -929.95 5.00 5955932.96 697016.19 42S6 11810.95 31.50 278.94 8453.00 8389.30 6891.58 6922.16 -933.73 5.00 5955933.45 697012.39 End Dir : 1181 11871.59 31.50 278.94 8504.70 8441.00 &905.47 6927.08 -965.03 0.00 5955937.55 696980.98 TCGL 11900.00 31.50 278.94 8528.93 8465.23 6911.98 6929.39 -979.69 0.00 5955939.47 696966.26 MWD+IFR+MS 11941.96 31.50 278.94 8564.70 8501.00 6921.59 6932.80 -1001.35 0.00 5955942.31 696944.53 BCGL 11971.01 31.50 278.94 8589.47 8525.77 6928.24 6935.16 -1016.34 0.00 5955944.28 696929.48 Start Dir 13/10 12000.00 35.27 279.09 8613.68 8549.98 6935.25 6937.66 -1032.09 13.00 5955946.36 696913.67 MWD+IFR+MS 12021.22 38.02 279.18 8630.70 8567.00 6940.84 6939.67 -1044.59 13.00 5955948.04 696901.12 23S6 12058.00 42.80 279.31 8658.70 8595.00 6951.40 6943.50 -1068.13 13.00 5955951.25 696877.49 22TS 12100.00 48.26 279.43 8688.11 8624.41 6964.74 6948.38 -1097.68 13.00 5955955.35 696847.82 MWD+IFR+MS 12117.83 50.58 279.48 8699.70 8636.00 6970.78 6950.60 -1111.04 13.00 5955957.22 696834.41 21TS 12165.09 56.72 279.59 8727.70 8664.00 6987.81 6956.91 -1148.56 13.00 5955962.54 696796.74 TZ1B 12200.00 61.26 279.66 8745.68 8681.98 7001.25 6961.91 -1178.06 13.00 5955966.76 696767.12 MWD+IFR+MS 12300.00 74.26 279.84 8783.44 8719.74 7042.90 6977.56 -1269.08 13.00 5955980.01 696675.72 MWD+IFR+MS 12300.95 74.38 279.84 8783.70 8720.00 7043.32 6977.71 -1269.98 13.00 5955980.14 696674.82 TDF 12400.00 87.26 279.99 8799.46 8735.76 7087.57 6994.51 -1366.10 13.00 5955994.41 696578.29 MWD~IFR+MS 12405.69 88.00 280.00 8799.70 8736.00 7090.16 6995.50 -1371.70 13.00 595599524 696572.67 05-28B T1 wp0 ~ S err -Sun ~ P Y BP Planning Report Company: BP Amoco Date: 11/17/2~05 'lyme: 14:43:01 Paget 5 Field: Prudhce Bay Caordinate(NE) Reference: W ell: 05-28, True North Site: PB DS 05 Vertical (TVD) Reference: 28.5+35.2 63:~ Well: 05-28 Sectian (VS) Reference: W ell (O.OON,O.OOE,342.94Azi) Wellpath: Plan 05-28B Survey Calcuiahon Method: Minimum Curvature Db: Oracle Survey MD Incl Azim T'VD Sys T'VD VS N/S E/W DLS MapN MapE TooUGomme t ft deg deg ft ft ft ft ft deg/100ft ft ft 12500.00 90.68 291.97 8800.79 8737.09 7141.48 7021.42 -1462.19 13.00 5956018.77 696481.54 MWD+IFR+MS 12600.00 93.49 304.67 8797.14 8733.44 7212.44 7068.71 -1549.98 13.00 5956063.74 696392.54 MWD+IFR+MS 12606.84 93.68 305.54 8796.71 8733.01 7217.83 7072.64 -1555.56 13.00 5956067.51 696386.86 End Dir : 1260 12700.00 93.68 305.54 8790.74 8727.04 7291.68 7126.68 -1631.21 0.00 5956119.54- 696309.81 MWD+IFR+MS 12800.00 93.68 305.54 8784.33 8720.63 7370.95 7184.68 -1712.42 0.00 5956175.39 696227.11 MWD+IFR+MS 12900.00 93.68 305.54 8777.92 8714.22 7450.23 7242.69 -1793.62 0.00 5956231.23 696144.42 MWD+IFR+MS 12906.79 93.68 305.54 8777.48 8713.78 7455.61 7246.63 -1799.13 0.00 5956235.02 696138.80 Start Dir 5/100 13000.00 91.85 309.83 8772.99 8709.29 7531.61 7303.53 -1872.79 5.00 5956289.96 696063.68 MWD+IFR+MS 13058.06 90.70 312.50 8771.70 8708.00 7580.95 7341.73 -1916.48 5.00 5956327.00 696019.00 05-288 T2 wp0 13100.00 90.47 314.58 8771.27 8707.57 7617.49 7370.62 -1946.88 5.00 5956355.08 695987.85 MWD+IFR+MS 13150.80 90.20 317.11 8770.97 8707.27 7662.71 7407.07 -1982.27 5.00 5956390.58 695951.52 End Oir : 1315 13200.00 90.20 317.11 8770.80 8707.10 7706.99 7443.11 -2015.75 0.00 5956425.73 695917.10 MWD+IFR+~S 13300.00 90.20 317.11 8770.46 8706.76 7796.99 7516.38 -2083.81 0.00 5956497.17 695847.14 MWD+IFR+MS 13400.00 90.20 317.11 8770.11 8706.41 7887.00 7589.65 -2151.87 0.00 5956568.62 695777.18 MWD+IFR+MS 13500.00 90.20 317.11 8769.77 8706.07 7977.00 7662.91 -2219.93 0.00 5956640.06 695707.22 MWD+IFR+MS 13600.00 90.20 317.11 8769.42 8705.72 8067.01 7738.18 -2287,99 0.00 5956711.5'1 695637.26 MWD+IFR+MS 13660.20 90.20 317.11 8769.22 8705.52 8121.19 7780.28 -2328.96 0.00 5956754.52 695595.15 Start Dir 6/100 13700.00 90.46 319.48 8768.99 8705.29 8157.36 7809.99 -2355.44 6.00 5956783.52 695567.90 MWD+IFR+MS 13800.00 91.10 325.45 8767.63 8703.93 8250.99 7889.25 -2416.32 6.00 5956861.14 695504.95 MWD+IFR+MS 13900.00 91.73 331.42 8765.15 8701.45 8347.73 7974.39 -2468.63 6.00 5956944.87 695450.42 MWD+IFR+MS 14000.00 92.35 337.39 8761.59 8697.89 8446.51 8064.48 -2511.79 6.00 5957033.79 695404.91 MWD+IFR+MS 14043.67 92.61 340.00 8759.70 8696.00 8490.02 8105.12 -2527.64 6.00 5957074.00 695388.00 05-28B T3 wp0 14100.00 92.62 343.38 8757.13 8693.43 8546.27 8158.53 -2545.31 6.00 5957126.93 695368.92 MWD+IFR+MS 14200.00 92.60 349.39 8752.57 8688.87 8645.94 8255.58 -2568.82 6.00 5957223.31 695342.88 MWD+IFR+MS 14219.39 92.60 350.55 8751.69 8687.99 8665.16 8274.65 -2572.19 6.00 5957242.29 685339.OQ End Dir : 1429 14300.00 92.60 350.55 8748.04 8684.34 8744.98 8354.09 -2585.41 0.00 5957321.35 695323.70 MWD+IFR+MS 14400.00 92.60 350.55 8743.50 8679.80 8844.00 8452.63 -2601.80 0.00 5957419.42 695304.72 MWD+IFR+MS 14461.00 92.60 350.55 8740.74 8677.04 8904.40 8512.74 -2611.80 0.00 5957479.24 695293.14 41/2" 14461.77 92.60 350.55 8740.70 8677.00 8905.16 8513.51 -2611.93 0.00 5957480.00 695293.00 05-286 T4 wp0 _ ~ ~05-28B Propo~d Completion ; ~ 2,200 4 1/2" 'X' landing nipple, ID = 3.813" I 10 3/4", 45.5#, J-55, 3,896 L-80, csg ID = 9.950" 75r8'CIBP ~~~ ~ Pre-rig tb cut. 3 1/2", 9.2#, 13-CR-80 4,300 5 1/2" tiner top 9,837 ~ 5~s",~29.~#, ~-so, 10,150 csg ID = 6.875" TREE = FMC SLIM HOL WB.LHEAD = FMC ACTUATOR = BAKER C KB. El.EV = 70' BF. ELEV = NA KOP = 1300' Max Angle = 99 @ 11613' Datum N~ = NA Datum ND = 8800' SS GAS LIFf MANDRElS ST MD ND DEV TYPE VLV LATCH PORT DATE 5 TBD 3150 4 1/2" X 1" KBMG DCK BK 4 TBD 4750 4 1!2" X 1" KBAqG DMY BK 3 TBD 6000 4 1/2" X 1" KBMG DMY BK 2 TBD 7000 4 1/2" X 1" KBMG DMY BK 1 TBD 7900 4 1/2" X 1" KBMG DMY BK 11,376 41/2"'X'Iandingnipple,ID=3.813" 11,396 Baker 7 5/8" X 4 1/2" S-3 pkr 11,418 4 1/2" 'X' landing nipple, ID = 3.813" 11,438 4 1/2"'XN' landing nipple, ID = 3.725" Baker 7 5/8" X 4 1/2" HMC liner 11,458 hngr, ZXP pkr, w ith TBS 11,608 7 5/8", 29.7#, L-80, BTGM csg 14,375 PBTD 5 1/2", 17#, 13CR- 10,923 80, liner ID = 4.892" DATE REV BY COMMENTS DATE REV BY COMMENTS 09/08/91 ORIGINAL COMPLETION 08/19/03 CMO/TLP DATUM MD CARRECTION 10/30/01 CTD SIDETRACK 09/14/03 BJMcL/TL ECLIPSE PATCH 11/22/02 CWTLP CORRECTIONS 10/22/03 NUA/TLH MIN ID CORRECTION 09/28/02 MWKAK GLV C/O 12/28/03 JBIWPAG LNR ID CORRECTION 05/08/03 JJ/KAK PUL~ FISH 01/15/04 KSB/KK PULL PATCH; SET LTTP 07/30/03 ??/KAK PATCH & MIN ID CORRECTION 11/17/05 RP/dew 5-28B Wp08 BP 6cploretion (Alaska) 14,461 41/2", 12.6#, L-80, IBT-Mliner PRUDHOE BAY UNff WQL: 05-286 PEJ~MfT No: API No: 50-029-22208-02 SEC 32, T11 N, R15E, 2431' SNL & 4220' WEL ~ = FMC ULTRA SLIM HOLE WELLHEA,D = FMC ACTUATOR = BAKER C K~.ELEV= 70' BF. ELEV = ~ NA KOP = 1300' Max Angle = 99 @ 11613' Datum MD = NA Datum ND = 8800' SS ~ 05-28A I • ' ~4-1/2" OTIS HRQ SSSV NIP,1D = 3.813" ~ 4-1/2" TBG, 12.6#, 13-CR, 2985~ 2987' 4-1/2" X 3-1/2" XO, ID = 2.992" .0152 bpf, ID = 3.958" 10-3/4" CSG, 45.5#, J-55, ID = 9.950^ 3896` GAS LIFT MANDRELS Minimum ID =1.995" @ 9882' TOP OF 2-3/8" LNR ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3516 3140 36 FMHO DMY RK 0 09/28/02 2 5984 5119 37 FMHO DMY RK 0 09/28/02 3 7723 6473 41 FMHO DMY RK 0 09/28/02 4 8706 7211 44 FMHO DMY RK 0 09/28/02 5 9255 7601 43 FMHO DMY RK 0 09/28/02 6 9674 7918 40 FMHO DMY RKP 0 09/28/02 9784' -~7-5/8" X 3-1/2" BAKER SB-3A PKR ~ 7-5/8" X 5-1/2" BKR LNR HGR 9837~ 9872~ 2.70" BKR D~LOYMENT SLV, ID = 2.25" TOP OF 2-3/8" LNR, 4.7#, ID = 1.995" 9882~ 9872~ LTTP (SET 01l15/04) 9$99~ 3-1/2" OTIS XN NIP, MILLm TO 2.80" ID 3-1/2" TBG, 9.2#, 13-CR-80, " 9910' 9911~ 3-1/2" WLEG (SOS)~ .0087 bpf, ID = 2.992 9896~ ElMD TT LOGGm 09/22/91 7-5/8" CSG, 29.7#, L-80, ID = 6.875" ~-{ 10150~ PERFORATION SUMMARY REF LOG: SWS MEMORY CNL/GR/CCL ON 10/29/01 ANGLE AT TOP PERF: 85 @ 10835' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 10835 - 11090 O 10/28/01 1-11/16" 4 11350 - 11550 O 10/28l01 1-11/16" 4 11660 - 11745 O 10/28/01 1-11/16" 4 11970 - 12085 O 10/28/01 1-11/16" 4 12160 - 12185 O 10/28/01 5-1/2" LNR 17#, 13-CR-80, ID = 4.892" 5-1/2" LNR MlLLOUT WINDOW 10565' - 10570' (OFF CMT RAMP) 12197' H ~BT~ 2-3/8" LNR 4.7#, L-80, .0039 bpf, ID = 1.920" ~-j 12235~ DATE RE~/ BY COMMENTS DATE REV BY CAMMEMS 09/08/91 ORIGINAL COM PLETION 08l19/03 CMO/TLP DATUM MD CORRECTION 10/30/01 CTD SIDETRACK 09/14/03 BJMcL/TL ECLIPSE PATCH 11/22/02 CH/TLP CORRECTIONS 10/22/03 MJA/TLH MINIDCARRECTION 09/28/02 MH/KAK GLV GO 12/28/03 JBNUPAG LNR ID CORRECTION 05/08/03 JJ/KAK PULL FISH 01/15/04 KSB/KK PULL PATCH; SET LTTP 07/30/03 ??/KAK PATCH & MIN ID CORRECTiON PRUDHOE BAY UNIT WELL: 05-28A PERMff No: 2011950 API No: 50-029-22208-01 SEC 32, T11 N, R15E, 2431' SNL & 4220' WEL BP Exploration (Alaska) ~ 7erri Hubble BP`Exploration AK Inc. PO'Box 196612;Mg 7-5 Anchora9e, AK '99519 PAY TO THE ORDER OF y~--~ ~ I ! Y~n 1) _ n , "Mastercard 89-6j1252 2$2 Check" oATE a -22-0~ $ ~C~ , ~ _. ,.a~~~nai t~ank Alaska - Anchqra9e, AK , 99501 f~ DOLLARS MEMO V ~, 2 8 ~ ; ~:1 2 5 200060~:99i46227L . 556~~ 0282 ~ u • • TRANSMITTAL LETTER CHECKLIST WELL NAME - PTD# ~(~ '~'~ /~Development Service Exploratory Stratigraphic Test Non-Conventional Weil Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD-0NS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MiJLTI LATERAL The permit is for a new wellbore segment of existing we(I ~ (If (ast two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(~, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (SQ- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed We(1 for (name of well~ until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name~ must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C:\j ody\transmittal_checklist ~ ..~,~.,. .~~.~a... ~ ___. si. _ _____ - ~~~~ ~~~~~T ~~,~~~~,~~ ,Field & Pool PRUDHOE BAY, PRUDHOE OIL • 640150 _ ~ _ _Well Name: PRUDHOE BAY UNIT 05-286 Program DEV__ _ Well bore seg PTD#:206089D t- nmt~any BP EXPLORATION (ALASKi~)_WC _ _ ~nitial ClasstT;pe .-_ ~. _ . ~_ ~, ~ - ~.~. .~. , --- . DEVI 1-OIL GeoHrez 890 _ Unit 1 i650 _ _ OnlOff Shore On Annular Disposal '~ ~ ._ __~ _ , _,~-___.~,~., - --.,.T; _, . __ _ Administration 1 _ Permitfee attached . Yes _ _ '2 Lease number ap~i~opriate . Yes 3 Unique weil name and number . Yes . '4 ~Nelllocated in a definedpool . . . Yes ',5 Vl~ell located proper distance from drilling unit boundary . Yes 6 Well located proper distance from other wells. Yes _ . . ',7 Sufficient acreage available in. drilling unit _ . . . Yes . . _ . . '8 if deviated, is welibore plat included _ . Yes ,9 Operator only affected party . . YeS ',10 Operator has appropriate bond in force . . . No- - - , _ - - - 11 Pe[mit_can be issued without conseryation order . . Yes _ __ . . 12 Permit_can be issued without administrative approval .. . . Yes . Appr Date ,13 Can permit be approved before 15-day_wait_ . Yes . RPC 612312006 '14 Welllocated within area and strata authonzed by_ Injection 0[det #(put 10# in_comments)_(For NA. _ ',15 All wells_within 114_mile are_a of review identified (For seNice well only) _ _ _ _ NA_ _ . _ _ _ _ _ ',16 Pre-~roduced injectgr; duration of pre-p[oduction less_ than 3 months (For seruice well only) __ NA_ _ _ . I17 Nonconven. gas conforms to AS31,05.030~.1_.A),(~2.A-D) . NA_ _ _ - - - _ 1 S _ _ _ - - ---- Conduc#o[ stnng ptovided . _ _ _ . NA_ . _ _ .. _ __ ___ _ __ _ . _ . Engmeering ,19 Surface casing_proiects all known USDWs . . NA_ _ . '20 CMT vol adequate_to circulate on conductor_& surf csg . . . NA_ _ _ . . . . . 21 CMT vol adequate_to tie-in long string ko surf csg_ _ Yes _ _ _____ . . . ,22 CMT_will cover all know_n p[oductiye horizons ___ . Yes Adequate excess. 23 Casing designs adequate fo[ C, T, B & permafrost_ . _ . _ - - Yes - - - - - - - . . . . ',24 Adequa#e tankage or reserye pii . . Yes __ Nabo[s.2ES. . 25, If a re-drill, has_a 10-4D3 for abandon_ment been approved . . Yes _ .. 412812006. .. . ,26 Adequate wellbore separation proposed - . . Yes - - - - - - . . '27 If diverter required, does it meetregulations_ . . NA_ _ _ _ _ _ _ Sidetrack. . . . . '28 Drilling fluid program schematic & equip list adequate _ Yes _ ___. _ Max MW 10,4 ppg. . . .. Appr Date ',29 BOPEs, do they meet regula_tion . _ _ . Yes _ _ . . . WGA 6l2712006 '30 BOPE_press rating appropriate; test to_(pu_i psig in c4mments)_ _ _ _ _ _ _ _ Yes _ _ _ . _ _ _ Tesi to 3500_psi. MSP 2831 psi, . . . . ,31 Choke_manifold complies wlAPl_RP-53 (May 84). - - - - - - - - - - - - Yes - - , - - - - - - . . _ . . . . '32 Work will occur without operation shutdown- - - _ - - _ - - - _ Yes - - - - - - - - - - _ . _ . j33 Is qresence_of H2$ gas probabie _. ___._ No_ . . Not an H2S pad. . . . ~~34 Mechanical_condition of wells within AOR yenfied (For se[vice well only) _ _ _ . - --- . . -- ---- - - -- NA _ -__ _ . _ _ _ _ . . . _ __ _ _- _ --- __ _- -- ~,35 _ --- ---- - - -- Permitcan be issued w/o hydrogen sulfide measures _ . No_ _ _ _ _ _ _ _ . . . - _ - _._. Geology ,36 Data_presented on, potential overprgssuce zones. _ _ _ _ . NA_ . . . . i37 Seismic.analysis of shallow gas zones- - . - - - - - NA- - . . . . Appr Date '38 Seabed condition 3urvey_(if off shore) NA - . . .. RPC 612712006 i39 Contact namelphone for weekly_progress reports_[exploCatory only] . . . . NA_ . _ _ _ _ _ . . Geologic Date: Engineering Date Commissiooec _ _ Drs_-- -~I2)/~-- - Commis ioner: ---~~~.~,~-~~'~~-- Date 6•z~-~o,6' ~ ~ • Well History File APF'EI~IDIX Information of detailed nature that is not • particula~ly germane to the Weli Permitting Process but is part of the history file. To improve the readability of the Well History file and to sim.plify finding infoRnation, information of this nature is accumulated at the end oi the file under APPENDIX. No special effort has been made to chronologically __ organize this category of information. ' ~ ~ 0528BO080520065SN.txt sperry-sun ~rillin9 services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Jun 02 10:00:28 2008 Reel Header Service name .............LISTPE ~ate .....................08/06/02 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing ~ibrary. Scientific Technical Services Tape Header Service name .............LISTPE ~ate . ...................08/06/02 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 EOA MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 w-0004505187 M. LEAFSTEDT D. MASKELL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD ao~ ~`~ scientific Technical services 05-286 500292220802 BP Exploration (,4laska) znc. Sperry Drilling Services 02-JUN-08 MWD RUN 3 w-0004505187 M. LEAFSTEDT J. ROSE 32 T11 R15 2431 4220 63.70 35.20 Page 1 ~~~ ~~~ ~ ~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 05286008052006SSN,txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 4119.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 4119' MD/3698~TVD,IN THE 5-28 WELLBORE. THE WHIPSTOCK WAS POSITTONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 1. 4. MWD RUNS 2,3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR), UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY-PHASE 4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). UPHOLE MAD PASS SGRC TIE-IN DATA ACQUIRED WHILE RIH FOR MWD RUN 2 WERE MERGED WITH RUN 3 MWD DATA. NO OTHER DATA WERE ACQUIRED ON RUN 2 DUE TO AN INABILITY TO EXIT THE WINDOW. 5. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE SHIFTED TO A SCHLUMBERGER GAMMA RAY LOG RUN IN 5-28B ON 17 AUGUST 2007. ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. THESE PDC DATA WERE PROVIDED BY DOUG DORTCH (SAIC/BP) ON 30 MAY 2008, AS AUTHORIZED BY PRIYA MARAJ (BP). THIS SHIFTED MWD LOG BECOMES THE SDCL FOR 5-28B. 6. MWD RUNS 1-3 REPRESENT WELL 5-28B WITH API# 50-029-22208-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11666~MD/8312'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SNIOOTHED PHASE SHI~T-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 - DEEP RESISTIVITY. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name... .......STSLIB,001 Service Sub Level Name... Page 2 • ~ 0528BO08052006SSN.txt version Number. ........1.0.0 Date of Generatio n.......08/06/02 Maximum Physical Record..65535 File Type. .... ........LO Previous File Nam e.......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 3792.0 11610.0 RPD 4101.5 11617.0 RPM 4101.5 11617.0 RPS 4101.5 11617.0 RPx 4101.5 11617.0 FET 4101.5 11617.0 ROP 4121.0 11666.0 $ # BASELINE CURVE FOR S HIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 3792.0 3790.5 10924.0 10922.5 10928.0 10929.0 10937.5 10938.5 10951,0 10952.0 10957,0 10957.5 10977.5 10979.5 10986.0 10987.5 11000.5 1Z002.5 11002.5 11004.0 11004.0 11006.0 11020.5 11021.5 11026.0 11027.0 11037.5 11038.0 11047.0 11048.0 11056.0 11056.0 11071.0 11072.0 11080.0 11081.5 11081.5 11083.0 11089.0 11090.0 11110.5 11110.5 11114.0 11114.0 11125.0 11125.5 11127.0 11128.0 11132.5 11132.5 11140.0 11140.5 11142.5 11144.0 11162.5 11164.0 11164.0 11166.0 11176.5 11179.5 11182.0 11184.0 11187.0 11187.0 11200.5 11201.5 11202.0 11203.0 11206.0 11207.0 Page 3 11210.5 11216.0 11217.5 11223.5 11228.5 11231.5 11233.0 11237.0 11239.5 11241.0 11243.5 11259.5 11261.0 11267.5 11271.0 11274.0 11282.0 11294.5 11298.0 11308.0 11313.0 11322.0 11327.5 11335.0 11343.5 11362.0 11368.0 11370.0 11371.5 11377.5 11383.0 11400.0 11405.5 11411.5 11419.0 11423.5 11427.5 11432.5 11435.5 11440.0 11442.0 11452.0 11462.0 11469.5 11478.5 11483.0 11491.0 11498.5 11505.0 11511.0 11514.0 11518.5 11528.0 11530.0 11536.0 11539.5 11572.0 11582.5 11597.5 11606.5 11609.0 11666.0 S • 11211.0 11214.0 11216.5 11222.5 11229.0 11233.5 11235.0 11239.5 11241.5 11243.5 11245.5 11261.5 11263.0 11269.5 11273.0 11276.0 11283.0 11295.0 11298.5 11309.0 11314.0 11322.5 11328.0 11336.5 11345.0 11364.0 11368.5 11370.0 11372.5 11378.0 11383.5 11400.0 11407.0 11412.0 11419.5 11423.5 11427.5 11433.0 11435.5 11440.5 11442.5 11451.0 11462.0 11470.0 11479.0 11483.0 11491.0 11497.5 11503.5 11510.0 11514.0 11519.0 11528.5 11531.0 11536.0 11540.0 11573.0 11581.5 11596.0 11606.5 11609.0 11666.0 05286008052006ssN.txt Page 4 ~ ~ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 3 $ # REMARKS: MERGED MAIN PASS. $ 0528600805200655N.txt MERGE TOP MERGE BASE 4119.5 4149.0 4149.0 11666.0 # Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~iny Direction .................DOwn optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. . .. .. ..... ~atum Specification Block sub-type...0 ~ Name Service order units size Nsam ttep 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 $ First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3792 11666 7729 15749 3792 11666 RPD MwD OHMM 0.43 2000 7.46343 15032 4101.5 11617 RPM Mw~ OHMM 0.23 2000 6.48529 15032 4101.5 11617 RPS MwD OHMM 0.42 2000 3.88575 15032 4101.5 11617 RPx MwD OHMM 0.48 51.09 3.43864 15032 4101.5 11617 FET MwD HOUR 0.18 49.5 1.19177 15032 4101.5 11617 GR MwD API 9.39 473.39 90.9857 15461 3792 11610 ROP MwD FT/H 0.16 441.88 148.094 15091 4121 11666 First Reading For Entire File..........3792 ~ast Reading For Entire File...........11666 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......08/06/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF Page 5 ~ ~. 05286008052006SSN.txt File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 ~ate of ~eneration.......08/06/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 4119.5 4149.0 $ # LOG HEADER DATA DATE LOGGED: 29-~u~-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 4149.0 TOP LOG INTERVAL (FT); 4119.0 BOTTOM LOG INTERVAL (FT): 4149.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 34.4 MAXIMUM ANGLE: 34.4 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 4119.0 # BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.90 MUD VISCOSITY (5): 83.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 5000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 88.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): Page 6 ~ ~ EWR FREQUENCY (HZ): # 0528BO0805200655N.txt REMARKS: $ # Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~ing DireCtion .................DOwn opt~cal log depth units...........Feet ~ata tteference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined ,4bsent value ......................-999 Depth units. . .. .. ..... ~atum specification slock sub-type...0 Name service order units size -vsam rtep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWDO10 FT/H 4 1 68 4 2 Fi rst Las~t Name service unit Min Max Mean -vsam Reading Reading DEPT FT 4119.5 4149 4134.25 60 4119.5 4149 ROP Mw~010 FT/H 1.72 34.29 15.0043 60 4119.5 4149 First Reading For Entire File..........4119.5 ~ast Reading For Entire File...........4149 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......08/06/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF Fi12 Header Service name... .......STSLIB.003 Service Sub Level Name... version Number.. ........1.0.0 ~ate of Generation.......08/06/02 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: 3 DEPTH INCREMENT: .5000 # Page 7 ~ ~' 05286008052006SSN.txt FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3790.5 11610.0 RPD 4100.0 11617.0 RPM 4100.0 11617.0 RPS 4100.0 11617.0 RPx 4100.0 11617.0 FET 4100.0 11617.0 ROP 4149.5 11666.0 $ # LOG HEADER DATA DATE LOGGED: 05-AUG-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11666.0 TOP LOG INTERVAL (FT): 4149.0 BOTTOM LOG INTERVAL (FT): 11666.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 27.9 MAXIMUM ANGLE: 59.4 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 156401 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 4119.0 # BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.35 MUD VISCOSITY (S): 52.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 900 FLUID LOSS (C3): 5.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATUR E (MT): 3.800 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.340 118.0 MUD FILTRATE AT MT: 4.000 70.0 MUD CAKE AT MT: 2.600 70.0 # 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 ~ogging ~irection .................~own Page 8 ~ ~ 052860080520065SN.txt Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. . .. .. ..... ~atum specification 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 $ First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3790.5 11666 7728.25 15752 3790.5 11666 RPD MWD030 OHMM 0.43 2000 7.46135 15035 4100 11617 RPM MWD030 OHMM 0.23 2000 6.48336 15035 4100 11617 RPS MwD030 OHMM 0.42 2000 3.8843 15035 4100 11617 RPx MWD030 OHMM 0.48 51.09 3.43728 15035 4100 11617 FET MwD030 HOUR 0.18 49.5 1.19075 15035 4100 11617 GR Mw~030 API 9.39 473.39 91.0108 15464 3790.5 11610 ROP MwD030 FT/H 0.16 441.88 148.605 15034 4149.5 11666 First Reading For Entire File..........3790.5 ~ast Reading For Entire File...........11666 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......08/06/02 Maximum Physical Record..65535 File TyPe ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE ~ate . ................... 08/06/02 Origin ................... STS Tape Name...... ........ UNKNOWN Continuation Number...... 01 Next Tape Name........... UNKNOWN Comment5 ................. STS LIS writing ~ibrary. Scientific Technical Services Reel Trailer Service name .............LISTPE ~ate . ...................08/06/02 Origin ...................STs Page 9 ~ ~ 0528g008052006s5N.txt Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel wame...........UNKNOWN comments .................sTS ~zs writing ~ibrary. scientific Technical services Physical EOF Physical EOF End Of LIS File Page 10 5~ **** REEL HEADER **** MWD O8/10/31 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 07/08/15 1498749 O1 3.0" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!~~~!!! Extract File: ldwg.las ~7 ~Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame ~Well Information Block #MNEM.UNIT Data Type Information #--------- ------------- ------------------------------- STRT.FT 11287.0000: Starting Depth STOP.FT 13654.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 05-28B FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 70 deg 15' S3.547"N 148 deg 23' 52.687"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 15 Aug 2007 API . API NUMBER: 500292220802 ~Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 32 . TOWN.N T11N . RANG. R15E . PDAT. MSL . EPD .F 0 . LMF . KB . FAPD.F 63.7 . DMF . KB . EKB .F 0 , EDF .F 63.7 , EGL .F 0 , CASE.F N/A , OS1 . DIRECTIONAL , ~Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) Al1 depths are Measured Depths (MD) unless otherwise noted. ~6~ o~s~ 1~~~9 ~ ~~ (2) Al1 depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are SubSea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer pownhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by Schlumberger GR CCNL dated 17 Aug 2007 per Priya Maraj with BP Exploration (Alaska), Inc. (8) Tied into 05-28B at 11628 feet MD (8216 feet TVDSS). (9) The sidetrack was drilled from 05-28B through a float shoe at 11660 feet MD (8243 feet TVDSS) through a 5 1/2 inch liner. (10) The interval from 11572 feet to 11660 feet MD (8167 feet to 8243 feet TVDSS) was drilled though cement. (11) Open hole sidetrack at 12163 feet MD (8649 feet TVDSS) was drilled off of a cement plug. (12) The interval from 13626 feet to 13655 feet MD feet TVDSS) was not logged due to sensor to bit offset at well TD. (10) The interval from 11623 feet to 11651 feet MD 8235.05 feet TVDS S) was MAD Passed due to sensor offset between runs. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP AVG -> Rate of Penetration, feet/hour TVD -> True Vertical Depth (Subsea) CURVE SHIF T DATA BASELINE, MEASURED, DISPLACEINENT 11294.4, 11293.4, ! -1.03613 11297.5, 11295.9, ! -1.6582 11304.6, 11304.4, ! -0.207031 11305.8, 11306.2, ! 0.414062 11308.7, 11307.5, ! -1.24414 11310.8, 11309.3, ! -1.45117 11312.7, 11311, ! -1.6582 11314.5, 11313.3, ! -1.24316 11316.6, 11316.2, ! -0.415039 11323, 1 1321.8, ! -1.24316 11329.3, 11327.3, ! -2.07227 11331.4, 11329.6, ! -1.86523 11335.8, 11335.1, ! -0.62207 11341.4, 11339.9, ! -1.45117 11343.2, 11342.4, ! -0.830078 11345.9, 11345.5, ! -0.414062 11349.7, 11349, ! -0.62207 11351.7, 11351.1, ! -0.62207 11353.4, 11353, ! -0.415039 11356.3, 11355.7, ! -0.62207 11359.8, 11358, ! -1.86523 11362.1, 11361.1, ! -1.03613 11363.3, 11362.3, ! -1.03613 11365.2, 11364.4, ! -0.829102 11367.9, 11366.4, ! -1.45117 11369.1, 11367.9, ! -1.24316 11370.9, 11369.7, ! -1.24316 11372.1, 11371.3, ! -0.829102 11375.9, 11374.6, ! -1.24414 11378.1, 11377.3, ! -0.829102 (8711 feet to 8710 (8210.73 feet to ~~ 11381.5, 11381.3, 11384.2, 11382.9, 11388.5, 11389.1, 11391.4, 11391.6, 11394.3, 11393.7, 11397.8, 11396.6, 11401.4, 11400.1, 11404.3, 11403.4, 11407, 11405.5, 11408.8, 11408.2, 11412.1, 11411.5, 11417.7, 11416.9, 11420.4, 11419.2, 11423.3, 11422.9, 11426.3, 11425.1, 11428, 11427.4, 11429.7, 11428.8, 11433.2, 11431.9, 11435.7, 11435.5, 11438.6, 11438.1, 11440.8, 11439.8, 11441.9, 11441.3, 11495.2, 11445.4, 11447.1, 11447.9, 11452.2, 11451.6, 11455.4, 11454.7, 11460.3, 11459.1, 11462.2, 11461.8, 11464.1, 11464.9, 11469, 11468.2, 11473.4, 11472.8, 11475.7, 11475, 11479.2, 11477.9, 11482.3, 11480.4, 11484, 11482.9, 11485.8, 11485.4, 11486.9, 11487.3, 11491.8, 11491, 11498.7, 11498.7, 11499.9, 11500.1, 11503, 11503, 11508.6, 11507.4, 11511.1, 11510.9, 11514, 11514, 11517.3, 11517.5, 11518.4, 11519.2, 11522.7, 11522.5, 11525.8, 11526, 11527.5, 11527.7, 11530.4, 11529.8, 11531.8, 11531.8, 11534.4, 11535.2, 11540, 11539.3, 11555.9, 11554.4, 11571, 11570.2, 11573.9, 11572.9, 11607.7, 11607.7, 11612.3, 11611.3, 11615.6, 11614.9, 11617.9, 11617.7, 11621.8, 11621.4, 11623.5, 11622.9, 11626.2, 11625.6, 11628.3, 11627.2, 11663.4, 11665.5, 11664.4, 11666.9, 11670.4, 11670.2, 0 i 0 I i i -0.207031 -1.24414 0.62207 0.207031 -0.62207 -1.24414 -1.24316 -0.829102 -1.4502 -0.62207 -0.62207 -0.830078 -1.24414 -0.415039 -1.24316 -0.621094 -0.829102 -1.24316 -0.208008 -0.414062 -1.03613 -0.62207 0.207031 0.830078 -0.62207 -0.62207 -1.24414 -0.414062 0.829102 -0.829102 -0.62207 -0.62207 -1.24414 -1.86523 -1.03613 -0.415039 0.415039 -0.829102 0 0.208008 -1.24414 -0.207031 0.207031 0.829102 -0.207031 0.207031 0.208008 -0.62207 0 0.829102 -0.62207 -1.45117 -0.830078 -1.03613 0 -1.03613 -0.62207 -0.208008 -0.415039 -0.62207 -0.621094 -1.03613 2.07227 2.4873 -0.208008 ~ ~ 11675.6, 11674.8, 11679.6, 11679.3, 11682.2, 11681.4, 11684.5, 11683.9, 11687, 11686.2, 11688.7, 11687.8, 11691.6, 11692.8, 11699.7, 11698.8, 11701.1, 11700.3, 11702.4, 11701.9, 11703.8, 11703.2, 11705, 11704.6, 11710, 11708.8, 11711.7, 11711.3, 11713.7, 11713.3, 11720.4, 11719.6, 11722.7, 11721.6, 11725.1, 11724.9, 11727.6, 11727.2, 11730.5, 11729.7, 11732.6, 11731.3, 11744, 11743.1, 11747.3, 11746.4, 11750.8, 11749.8, 11759.9, 11759.9, 11768.2, 11767.4, 11770.9, 11770.5, 11779.6, 11779.3, 11785.1, 11784.5, 11792.2, 11793, 11799.7, 11800.1, 11804.6, 11803, 11807.1, 11805.9, 11810.9, 11811.7, 11814, 11814.2, 11819.4, 11820.1, 11831.7, 11831.9, 11839.8, 11839.8, 11843.9, 11844.5, 11851.4, 11851.8, 11854.3, 11855.7, 11857.2, 11858.8, 11862.6, 11863.6, 11868, 11869.2, 11875.1, 11876.3, 11880.1, 11881.3, 11886.7, 11887.5, 11955.3, 11955.5, 11966, 11966, 11980.9, 11981.1, 11985, 11986.3, 11993.7, 11993.5, 12001.8, 12002.2, 12009.5, 12008.2, 12013, 12012.6, 12018.8, 12019.4, 12021.3, 12021.9, 12026.7, 12026.1, 12029.4, 12029.2, 12031.9, 12032.3, 12034.6, 12035, 12036.9, 12038.3, 12042.7, 12042.7, 12046.8, 12047.4, 12052.2, 12052.4, 12054.1, 12054.1, 12056.3, 12056.3, i i I I 0 -0.830078 -0.208008 -0.829102 -0.62207 -0.829102 -0.829102 1.24414 -0.829102 -0.829102 -0.415039 -0.62207 -0.415039 -1.24316 -0.414062 -0.414062 -0.829102 -1.03711 -0.207031 -0.415039 -0.829102 -1.24316 -0.829102 -0.829102 -1.03613 0 -0.829102 -0.415039 -0.208008 -0.62207 0.829102 0.415039 -1.6582 -1.24414 0.829102 0.207031 0.62207 0.208008 0 0.62207 0.415039 1.45117 1.6582 1.03613 1.24316 1.24316 1.24414 0.829102 0.2~8~~8 0.208008 1.24316 -0.207031 0.414062 -1.24316 -0.415039 0.621094 Q.62207 -0.62207 -0.207031 0.414062 0.415039 1.45117 0 0.62207 0.207031 0 0 ~ ~ 12058.4, 12058.6, 12064.2, 12064, 12067.1, 12066.9, 12069.8, 12069.2, 12084.3, 12083.8, 12088.6, 12088.4, 12094.6, 12094.2, 12106, 12105, 12112.9, 12112.9, 12115.4, 12115.6, 12117.4, 12117, 12121.4, 12120.3, 12124.9, 12125.1, 12128.2, 12128.2, 12134.5, 12135.1, 12139, 12139.4, 12158.5, 12157.9, 12177.2, 12179, 12197.2, 12198, 12202.3, 12202.6, 12207.3, 12206.7, 12209.6, 12209.2, 12212.7, 12212.3, 12216, 12215.4, 12221.6, 12222.9, 12223.5, 12224.1, 12228.3, 12227, 12231.8, 12232.2, 12238.4, 12237.6, 12244, 12245.7, 12247.~, 12248.8, 12260.1, 12262.6, 12268.4, 12271.3, 12275, 12277.9, 12282.7, 12285.8, 12285.6, 12288.5, 12288, 12291.8, 12291.4, 12294.9, 12295.3, 12299.5, 12300.5, 12303.2, 12308.4, 12310.8, 12338,5, 12342.4, 12346.3, 12349.4, 12352.6, 12355.9, 12362.7, 12366.9, 12367.5, 12370.6, 12376.4, 12375.6, 12405.2, 12401.1, 12407.5, 12404.4, 12410.4, 12407.5, 12419.5, 12416.4, 12467.6, 12463.1, 12481.9, 12475.3, 12523.1, 12521.8, 12524.7, 12523.5, 12529.7, 12529.3, 12545.3, 12545, 12549, 12548.4, 12588.8, 12587.8, 12602.3, 12602.1, 12640.4, 12640.4, 12644.5, 12645.8, 12652.6, 12652.6, 12661.1, 12661.5, 12703.4, 12705, 12706.3, 12707.3, 12766.6, 12767.4, ! 0.208008 -0.207031 ! -0.208008 ! -0.62207 ! -0.415039 ! -0.207031 ! -0.414062 -1.03613 i p ! 0.208008 -0.415039 ! -1.03613 ! 0.207031 i p ! 0.62207 0.414062 ! -0.621094 1.86523 0.829102 ! 0.207031 ! -0.62207 ! -0.415039 ! -0.415039 -0.62207 ! 1.24414 ! 0.62207 -1.24414 ! 0.414062 ! -0.829102 1.6582 ! 1.03613 ! 2.4873 ! 2.90234 2.90234 ! 3.10938 ! 2.90137 3.73145 ! 3.52441 ! 4.14648 ! 2.69434 ! 2.4873 ! 3.93848 ! 3.10938 ! 3.31738 ! 4.14551 ! 3.10938 ! -0.829102 ! -4.14551 ! -3.10938 ! -2.90234 ! -3.10938 ! -4.56055 ! -6.63379 ! -1.24316 ! -1.24316 ! -0.415039 -0.207031 -0.62207 ! -1.03711 ! -0.207031 ! 0 ! 1.24414 i p ! 0.414062 1.6582 ! 1.03711 ! 0.829102 ~ ~ 12768.9, 12769.7, ! 0.829102 12776.1, 12777.4, ! 1.24414 12780.5, 12781.5, ! 1.03613 12814.8, 12811.9, ! -2.90234 12828.2, 12823.7, ! -4.56055 12832.2, 12827.2, ! -4.97559 12861.3, 12857, ! -4.35352 12868.4, 12863.8, ! -4.56055 12872.3, 12869.2, ! -3.11035 12883.1, 12879.6, ! -3.52441 12891.6, 12888.1, ! -3.52441 12903.2, 12900.3, ! -2.90234 12912.3, 12907.4, ! -4.97559 12914, 12909.9, ! -4.14648 12929.6, 12927.3, ! -2.28027 12931.7, 12930.2, ! -1.45117 12936.6, 12935.4, ! -1.24316 12938.5, 12937, ! -1.45117 12942.4, 12940.4, ! -2.07324 12944.3. 12942.2, ! -2.07227 12962.6, 12960.7, ! -1.86621 13010.6, 13009.5, ! -1.03613 13034, 13034, ! 0 13106.1, 13104.2, ! -1.86523 13113, 13111.1, ! -1.86523 13115.6, 13114.2, ! -1.45117 13119.6, 13117.7, ! -1.86523 13127.3, 13126.4, ! -0.829102 13128.9, 13128.1, ! -0.829102 13131.4, 13130, ! -1.4502 13132.9, 13131.8, ! -1.03613 13138.5, 13138, ! -0.415039 13146.1, 13144.3, ! -1.86621 13233.9, 13232.2, ! -1.6582 13253.8, 13252.3, ! -1.4502 13260.2, 13258.1, ! -2.07324 13264.8, 13262.1, ! -2.69531 13268.1, 13265.2, ! -2.90234 13275.5, 13272.2, ! -3.31641 13280.9, 13277.4, ! -3.52441 13283, 13280.3, ! -2.69434 13286.3, 13284.5, ! -1.86621 13297.3, 13294.2, ! -3.10938 13299.6, 13297.3, ! -2.28027 13306.8, 13304.1, ! -2.69531 13310.8, 13308.7, ! -2.07324 13312.9, 13311.8, ! -1.03613 13314.7, 13312.9, ! -1.86621 13320.7, 13320.1, ! -0.62207 13340.7, 13338.6, ! -2.07227 13343.6, 13341.5, ! -2.07324 13346.3, 13343.4, ! -2.90234 13349, 13346.1, ! -2.90234 13359.3, 13359.5, ! 0.207031 13394.9, 13393.8, ! -1.03711 13399, 13397.8, ! -1.24316 13428.7, 13428.2, ! -0.415039 13459, 13456.1, ! -2.90234 13467.9, 13465, ! -2.90234 13494.3, 13488.9, ! -5.38965 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 365 records... ~ Minimum record length: 10 bytes ~ Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 ~ *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN 05-28B 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN 05-28B APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDCL from Schlumgerger GR CNL dated 17 Aug 2007 per Priya Maraj with BP Exploration (Alaska), Inc. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 ~ Total Data Records: 57 Tape File Start Depth = 11287.000000 Tape File End Depth = 13654.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile; 2 66 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 ~ 8 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 05-28B.xtf LCC 150 CN BP Exploration (Alaska) WN 05-28B APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of £rames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 ~ FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 113 Tape File Start Depth = 11287.000000 Tape File End Depth = 13654.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 122 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 07/08/15 1498749 01 **** REEL TRAILER **** MWD 08/10/31 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes ~ ~ ~ Tape Subfile 1 is type: LIS ~ Tape Subfile 2 is type: LIS DEPTH GR ROP 11287.0000 109.8000 -999.2500 11287.5000 109.8000 -999.2500 11300.0000 153.3649 -999.2500 11400.0000 197.2559 -999.2500 11500.0000 199.3040 -999.2500 11600.0000 118.0213 113.6438 11700.0000 249.7556 21.8217 11800.0000 110.2986 78.4480 11900.0000 23.4962 14.3708 12000.0000 24.4670 47.3588 12100.0000 22.5561 36.0337 12200.0000 26.3528 1574.5657 12300.0000 138.0685 32.1155 12400.0000 59.5329 23.4412 12500.0000 70.4418 22.4860 12600.0000 36.7152 36.5283 12700.0000 60.9771 70.9771 12800.0000 46.0270 57.0681 12900.0000 91.2293 34.7889 13000.0000 55.9255 42.8234 13100.0000 43.5283 66.1712 13200.0000 29.8201 82.5107 13300.0000 71.4060 42.3966 13400.0000 70.5161 44.3910 13500.0000 120.1307 23.7195 13600.0000 58.0840 131.7598 13654.0000 -999.2500 -999.2500 Tape File Start Depth = 11287.000000 Tape File End Depth = 13654.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet ~ ~ ~ Tape Subfile 3 is type: LIS DEPTH GR ROP 11287.0000 -999.2500 -999.2500 11287.2500 -999.2500 -999.2500 11300.0000 155.0000 -999.2500 11400.0000 212.6000 -999.2500 11500.0000 204.3000 -999.2500 11600.0000 117.8000 110.9000 11700.0000 377.0000 20.8000 11800.0000 76.6000 77.8000 11900.0000 24.3000 6.1000 12000.0000 27.3000 40.5000 12100.0000 21.4000 36.1000 12200.0000 24.9000 1532.7000 12300.0000 102.1000 39.2000 12400.0000 45.3000 27.4000 12500.0000 68.0000 25.0000 12600.0000 35.0000 37.1000 12700.0000 60.5000 70.3000 12800.0000 46.2000 55.7000 12900.0000 107.9000 34.4000 13000.0000 59.5000 41.6000 13100.0000 49.8000 65.1000 13200.0000 34.2000 85.8000 13300.0000 60.3000 33.2000 13400.0000 72.0000 85.3000 13500.0000 129.8000 15.7000 13600.0000 52.7000 126.0000 13654.0000 -999.2500 321.0000 Tape File Start Depth = 11287.000000 Tape File End Depth = 13654.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet ~ ~ ~ Tape Subfile 4 is type: LIS ~ LJ **** REEL HEADER **** MWD 08/11/20 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 07/O8/06 1498749 O1 3.0" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las ~~ ~Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame ~Well Information Block #MNEM.UNIT Data Type Information #------- -- ------------- ------------------------------- STRT.FT 11287.0000: Starting Depth STOP.FT 12452.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 05-28BPB1 FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 70 deg 15' 53.547"N 148 deg 23' 52.687"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 06 Aug 2007 API . API NUMBER: 500292220871 ~Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 32 . TOWN.N T11N . RANG. R15E . PDAT. MSL . EPD .F 0 . LMF . KB . FAPD.F 63.7 . DMF . KB . EKB .F 0 . EDF .F 63.7 . EGL .F 0 . CASE.F N/A . OS1 . DIRECTIONAL . ~Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. ~ ~~o-b~`~ ~ ~~-~j 7~ . ~ (2) Al1 depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are SubSea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer pownhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log from 05-28B MWD dated 15 Aug 2007 per Priya Maraj with BP Exploration (Alaska), Inc. (8) Tied into 05-28B at 11628 feet MD (8216 feet TVDSS). (9) The sidetrack was drilled from 05-28B through a float shoe at 11660 feet MD (8243 feet TVDSS) through a 5 1/2 inch liner. (10) The interval from 11572 feet to 11660 feet MD (8167 feet to 8243 feet TVDSS) was drilled though cement. (11) The interval from 12415 feet to 12451 feet MD (8737 feet to 8739 feet TVDSS) was not logged due to sensor to bit offset at well TD. (12) The rate of penetration interval from 11572 feet to 11660 feet MD (8167 feet to 8243 feet TVDSS) was drilled through cement. MNEMONICS: GRAX -> Gamma Ray [MW D] (MWD-API units) ROP AVG -> Rate of Penet ration, feet/hour TVD -> True Vertical Depth (Subsea) CURVE SHIF T DATA BASELINE, MEASURED, DISPLACEMENT 11293.4, 11293.2, ! -0.208008 11296.3, 11295.9, ! -0.414062 11306, 1 1306.2, ! 0.207031 11309.3, 11309.1, ! -0.207031 11310.8, 11310.6, ! -0.207031 11313.9, 11313.5, ! -0.414062 11316.4, 11316.6, ! 0.207031 11319.9, 11319.5, ! -0.414062 11321.8, 11321.8, ! 0 11323.6, 11324.1, ! 0.415039 11327.4, 11327.6, ! 0.207031 11334.8, 11334.8, ! 0 11338.2, 11338.2, ! 0 11339.6, 11339.6, ! 0 11342.3, 11342.3, ! 0 11343.8, 11343.3, ! -0.414062 11345.6, 11345.4, ! -0.207031 11348.7, 11349.1, ! 0.414062 11351.6, 11352, ! 0.414062 11356.5, 11358, ! 1.4502 11360.9, 11361.5, ! 0.62207 11362.3, 11362.1, ! -0.207031 11364.2, 11364.2, ! 0 11366.5, 11366.3, ! -0.208008 11369.6, 11370, ! 0.414062 11371.5, 11371.7, ! 0.207031 11374.8, 11374.8, ! 0 11377.7, 11377.9, ! 0.208008 11381.2, 11381.4, ! 0.207031 11382.9, 11383.1, ! 0.207031 11389.3, 11389.7, ! 0.915039 11391.6, 11391.4, ! -0.207031 11393.8, 11393.8, ! 0 L_J 11399.9, 11400.3, ! 0.414062 11403.2, 11403.2, ! 0 11405.7, 11405.9, ! 0.207031 11408.6, 11408.1, ! -0.414062 11412.9, 11411.9, ! -1.03613 11416.9, 11417.5, ! 0.62207 11420.4, 11420.4, ! 0 11422.7, 11422.7, ! 0 11425.4, 11425.4, ! 0 11427.6, 11427.6, ! 0 11429.1, 11428.9, ! -0.207031 11431.8, 11432.4, ! 0.621094 11435.7, 11435.7, ! 0 11437.8, 11438, ! 0.207031 11440.1, 11440.1, ! 0 11441.5, 11440.9, ! -0.621094 11445.5, 11445.3, ! -0.208008 11448.2, 11449.2, ! 1.03613 11451.9, 11452.1, ! 0.207031 11455, 11455, ! 0 11459.4, 11459.4, ! 0 11461.6, 11461.8, ! 0.207031 11464.8, 11465, ! 0.208008 11468.5, 11468.1, ! -0.414062 11473.3, 11472.7, ! -0.62207 11475.4, 11475.6, ! 0.208008 11478, 11478, ! 0 11480.5, 11480.5, ! 0 11482.8, 11483.2, ! 0.415039 11485.7, 11485.7, ! 0 11487.4, 11487.4, ! 0 11491.1, 11490.9, ! -0.207031 11498.8, 11498.6, ! -0.207031 11500.4, 11500, ! -0.414062 11503.1, 11503.1, ! 0 11505.2, 11506, ! 0.829102 11507.5, 11507.3, ! -0.207031 11509.8, 11509.6, ! -0.207031 11510.8, 11510.8, ! 0 11514, 11514, ! 0 11519, 11518.6, ! -0.415039 11522.9, 11522.7, ! -0.207031 11524.6, 11524.6, ! 0 11526, 11526.2, ! 0.207031 11528.1, 11527.9, ! -0.207031 11530.2, 11529.3, ! -0.829102 11532, 11531.4, ! -0.62207 11536.2, 11536, ! -0.207031 11537.6, 11538, ! 0.415039 11539.3, 11539.5, ! 0.208008 11544.5, 11545.1, ! 0.62207 11554.2, 11554.6, ! 0.414062 11560.4, 11558.8, ! -1.6582 11566, 11567.1, ! 1.03613 11572.9, 11572.9, ! 0 11583.9, 11582.6, ! -1.24316 11595.7, 11597.2, ! 1.45117 11607.5, 11608.4, ! 0.829102 11611.3, 11611.3, ! 0 11614.6, 11615, ! 0.415039 11618,1, 11617.7, ! -0.415039 11621,6, 11621.2, ! -0.414062 11623,1, 11623.1, ! 0 11625.4, 11625.6, ! 0.208008 11627,4, 11627, ! -0.415039 11665,8, 11665.6, ! -0.207031 11670.1, 11670.3, ! 0.207031 ~J • 11675.1, 11675.5, 11679.2, 11679.5, 11681.7, 11681.9, 11684.2, 11684.6, 11686.5, 11686.3, 11688, 11688.4, 11690.9, 11690.2, 11692.8, 11692.8, 11699, 11699.4, 11700, 11700.4, 11701.7, 11701.7, 11703.3, 11703.1, 11704.8, 11704.6, 11706.6, 11706.6, 11708.5, 11708.9, 11711.2, 11711.6, 11713.1, 11713.7, 11717, 11717.4, 11719.5, 11719.7, 11721.6, 11721.6, 11724.9, 11725.1, 11728, 11728.2, 11729.9, 11729.5, 11731.5, 11731.9, 11743.4, 11743.4, 11747.1, 11747.1, 11749.8, 11749.8, 11760, 11759.6, 11767, 11767.8, 11770.1, 11770.1, 11772.4, 11771.8, 11779, 11779.2, 11784.4, 11784.6, 11793.3, 11793.3, 11800.1, 11799.9, 11803, 11802.8, 11805.2, 11805, 11811.7, 11811.7, 11820.4, 11820.2, 11825.6, 11825.4, 11831.8, 11832.4, 11839.9, 11839.7, 11844.2, 11844.2, 11851.9, 11852.1, 11855.8, 11856, 11858.3, 11858.5, 11861.6, 11862, 11863.9, 11863.9, 11868.9, 11868.9, 11876.3, 11876.1, 11881.1, 11881.5, 11887.9, 11887.7, 11891.1, 11892.3, 11912.4, 11910.3, 11924.6, 11924.4, 11949.1, 11944.9, 11955.5, 11955.5, 11965.8, 11965.8, 11981.2, 11981.4, 12986.1, 11986.1, 11993.4, 11993, 12002.1, 12001.9, 12008.6, 12008.1, 12012.3, 12012.7, 12019.6, 12019.1, 12022, 12022.2, 12026, 12026, 0.415039 0.208008 0.207031 0.414062 -0.207031 0.414062 -0.62207 0 0.414062 0.415039 0 -0.208008 -0.207031 0 0.415039 0.414062 0.62207 0.415039 0.207031 0 0.207031 0.207031 -0.414062 0.415039 0 0 0 -0.414062 0.830078 0 -0.621094 0.207031 0.207031 0 -0.207031 -0.207031 -0.207031 0 -0.208008 -0.208008 0.621094 -0.207031 0 0.207031 0.207031 0.208008 0.414062 0 0 -0.207031 0.414062 -0.207031 1.24316 -2.07227 -0.207031 0.829102 0 0 0.207031 0 -0.415039 -0.207031 -0.414062 0.415039 -0.415039 0.207031 0 ~~ • 12028, 12027.8, ! -0.207031 12029.1, 12029.3, ! 0.207031 12032.6, 12032.4, ! -0.208008 12035.1, 12034.1, ! -1.03613 12038.4, 12038.4, ! 0 12044.4, 12043.6, ! -0.829102 12047.3, 12047.7, ! 0.415039 12051.9, 12051.7, ! -0.207031 12054, 12053.8, ! -0.207031 12056.5, 12056.9, ! 0.414062 12064.4, 12064.2, ! -0.207031 12069.1, 12069.1, ! 0 12083.9, 12083.6, ! -0.207031 12088.8, 12088.8, ! 0 12093.8, 12094, ! 0.208008 12095.9, 12095.9, ! 0 12110.4, 12110.4, ! 0 12112.5, 12112.1, ! -0.414062 12117.1, 12I16.9, ! -0.207031 12120.4, 12120.8, ! 0.414062 12125.4, 12124.9, ! -0.414062 12135.5, 12135.1, ! -0.415039 12139.7, 12139.7, ! 0 12158.6, 12158.8, ! 0.208008 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 264 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN 05-28BPB1 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN 05-28BPB1 APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** C~ !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDCL from 05-28B above the KOP of 12162 feet MD dated 15 Aug 2007 per Priya Maraj wit BP Exploration (Alaska), Inc. • *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 28 Tape File Start Depth = 11287.000000 Tape File End Depth - 12452.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 37 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 05-28BPBl.xtf LCC 150 ~ • • CN BP Exploration (Alaska) WN 05-28BPB1 APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 56 Tape File Start Depth = 11287.000000 Tape File End Depth = 12452.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 65 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 07/08/06 ~ 1498749 O1 **** REEL TRAILER **** MWD 08/11/20 BHI 01 Tape 5ubfile: 4 2 records... ! Minimum record length: 132 bytes Maximum record length: 132 bytes ~ • Tape Subfile 1 is type: LIS • Tape Subfile 2 is type: LIS DEPTH GR ROP 11287.0000 109.8000 -999.2500 11287.5000 109.7794 -999.2500 11300.0000 149.9256 -999.2500 11400.0000 195.0290 -999.2500 11500.0000 204.1707 -999.2500 11600.0000 119.8600 67.4603 11700.0000 259.1947 23.9670 11800.0000 73.7457 78.0366 11900.0000 23.3972 8.4135 12000.0000 35.0916 32.7645 12100.0000 22.2446 35.8468 12200.0000 41.5578 80.6795 12300.0000 52.5809 86.0992 12400.0000 139.3385 81.1396 12452.0000 -999.2500 -999.2500 Tape File Start Depth = 11287.000000 Tape File End Depth = 12452.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet ~ ~ Tape Subfile 3 is type: LIS DEPTH GR ROP 11287.0000 -999.2500 -999.2500 11287.2500 -999.2500 -999.2500 11300.0000 155.0000 -999.2500 11400.0000 212.6000 -999.2500 11500.0000 204.3000 -999.2500 11600.0000 117.8000 110.9000 11700.0000 377.0000 20.8000 11800.0000 76.6000 77.8000 11900.0000 24.3000 6.1000 12000.0000 27.3000 40.5000 12100.0000 21.4000 36.1000 12200.0000 38.2000 79.9000 12300.0000 53.9000 84.9000 12400.0000 137.0000 80.6000 12452.0000 -999.2500 -999.2500 Tape File Start Depth = 11287.000000 Tape File End Depth = 12452.000000 Tape File Level Spacinq = 0.250000 Tape File Depth Units = feet • ~ ~ Tape Subfile 4 is type: LIS
