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Home My WebLink About209-1007. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU H-05B Mill CIBP, Chokes Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-100 50-029-20106-02-00 14044 Intermediate Tieback Tieback Liner Liner Liner 9026 7952 2102 10829 1233 2744 13725 13-3/8" x 9-5/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-3/16" x 2-7/8" 9025 30 - 7982 28 - 2130 26 - 10855 10716 - 11949 11300 - 14044 30 - 6409 28 - 2129 26 - 8548 8444 - 9024 8872 - 9026 14014 1950 4760 5410 7500 10530 13725 3450 6870 7240 8430 10160 11660 - 13979 4-1/2" 12.6# 13Cr80 24 - 10720 9029 - 9025 Surface 2276 18-5/8" 32 - 2308 32 - 2307 930 870 4-1/2" Baker S3 Packer 10665, 8406 10665 8406 Torin Roschinger Area Operations Manager Aras Worthington aras.worthington@hilcorp.com 907-564-4763 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028284 24 - 8447 N/A N/A 294 273 25048 18860 525 831 1000 1500 881 915 N/A 13b. Pools active after work:Prudhoe Oil No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.04.30 13:10:07 -08'00' Torin Roschinger (4662) By Grace Christianson at 3:17 pm, Apr 30, 2024 RBDMS JSB 043024 WCB 7-15-2024 DSR-4/30/24 ACTIVITY DATE SUMMARY 4/10/2024 CT 9 1.75" Coil Tubing .156 WT DuraCoil - Job Scope = Mill 2 CIBP's and 2 retainers/polar chokes Leave SLB yard, travel to location. Snow removal in front of wellhouse. MIRU. Partial BOP Test on well. Confirm EQ ports Closed. SI SSV. FP Flowline with 2 bbls 60/40 and 23 bbls Diesel. SI with 1500 psi trapped on F/L. ***Job Continued to 4/11/24*** 4/11/2024 CT 9 1.75" Coil Tubing .156 WT DuraCoil - Job Scope = Mill 2 CIBP's and 2 retainers/polar chokes Load and Kill well with 5 bbl 60/40 spear / 230 bbls KCL w/SafeLube. RIH with YJ 2.29" VBS Milling Assembly. Milled through CIBP and 2 retainers, pushed everything to lowest CIBP at 13,725 and POOH to inspect venturi/burnshoe. Recovered core, 5- 6 slip segments, polar choke and other small shavings/debris. M/U new burnshoe and RBIH. Attempt milling for 3 hours on deepest CIBP @ 13725'. Making no measurable progress. POOH to check BHA. ***Job Continued to 4/12/24*** 4/12/2024 CT 9 1.75" Coil Tubing .156 WT DuraCoil - Job Scope = Mill 2 CIBP's and 2 retainers/polar chokes POOH to check BHA. Revocered apx 1 cup of debris with 4-5 slip segment. L/D venturi/burnshoe, M/U 6 blade junk mill. RIH Mill on plug at 13,725 for 4 hours with mulitple stalls and motorwork. Hung up after a stall for 1 hour, multiple jars. Got free and POOH, FP CT. L/D YJ tools, wear in center ring of mill. Cut 150' CT. M/U YJ 1.69" milling BHA w/2.9" burnshoe. RIH. Tag at 13086', debris in Liner. PUH and Venturi across Perf Zones down to Milling depth. No issues with RIH weights. Begin MIlling with frequent Stalls at 13731'. ***Job Continued to 4/13/24*** 4/13/2024 CT 9 1.75" Coil Tubing .156 WT DuraCoil - Job Scope = Mill 2 CIBP's and 2 retainers/polar chokes Milling with frequent Stalls at 13731'. No Progress. POOH to check BHA after ~3 hours of milling/pushing attempts. FP Coil with 34 bbls diesel. Last depth reached 13735' CTM. Minimal plug debris in basket. Burn shoe wear on outside edge of cutting structure. No core recovered. FP Tubing with 38 bbls diesel. Begin RDMO at 0600. ***Job Complete*** 4/16/2024 ***WELL S/I ON ARRIVAL*** (Mill underream) RAN 4 1/2" BLB & 3.80" GAUGE RING TO BRUSH X NIPPLE AT 10,688' MD ***CONTINUED ON 4/17/24 WSR*** 4/17/2024 ***CONTINUED FROM 4/16/24 WSR*** (Mill underream) SET 4 1/2" ROCKSCREEN AT 10,688' MD RAN 4 1/2" CHECK SET TO ROCKSCREEN(Sheared) ***WELL S/I ON DEPARTURE, NOTIFY DSO OF WELL STATUS*** Daily Report of Well Operations PBU H-05B g RIH. Tag at 13086', debris in Liner. PUH andgg Venturi across Perf Zones down to Milling depth. No issues with RIH weights. Begin MIlling with frequent Stalls at 13731'. Attempt milling for 3 hours on deepest CIBP @ 13725'. Making no g measurable progress. POOH to check BHA. Milling with frequent Stalls at 13731'. No Progress. POOH to check BHA after ~3 g g hours of milling/pushing attempts. FP Coil with 34 bbls diesel. Last depth reached gg 13735' CTM. Minimal plug debris in basket. Burn shoe wear on outside edge ofgg cutting structure. No core recovered. FP Tubing with 38 bbls diesel. Begin RDMO Milled through CIBP and 2 retainers, pushed everything gy g yg to lowest CIBP at 13,725 and POOH to inspect venturi/burnshoe. Recovered core, 5- 6 slip segments, polar choke and other small shavings/debris. M/U new burnshoe gg and RBIH. g RIH Mill on plug at 13,725 for 4 hours withjg mulitple stalls and motorwork. Hung up after a stall for 1 hour, multiple jars. Got free and POOH The remaining CIBP is correctly shown on the new WBS, below. -WCB 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU H-05B Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-100 50-029-20106-02-00 14044 Intermediate Tieback Tieback Liner Liner Liner 9026 7952 2102 10829 1233 2744 13100 13-3/8" x 9-5/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-3/16" x 2-7/8" 9022 30 - 7982 28 - 2130 26 - 10855 10716 - 11949 11300 - 14044 30 - 6409 28 - 2129 26 - 8548 8444 - 9024 8872 - 9026 13584 1950 4760 5410 7500 10530 13100, 13725 3450 6870 7240 8430 10160 11660 - 13979 4-1/2" 12.6# 13Cr80 24 - 10720 9029 - 9025 Surface 2276 18-5/8" 32 - 2308 32 - 2307 930 870 4-1/2" Baker S3 Packer 10665, 8406 10665 8406 Torin Roschinger Area Operations Manager Josh Stephens Josh.Stephens@hilcorp.com 907.777.8420 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028284 24 - 8447 N/A N/A 251 552 7140 2125 36 1596 500 1200 1344 446 323-139 13b. Pools active after work:Prudhoe Oil No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Kayla Junke at 8:47 am, Apr 26, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.04.25 16:50:54 -08'00' Torin Roschinger (4662) DSR-4/26/23WCB 1-2-2024 RBDMS JSB 050223 ACTIVITY DATE SUMMARY 4/14/2023 CTU #6 1.75" CT 0.145" WT Job Scope: Extended Add Perf MIRU. Erect scaffolding. ***Job In Progress*** 4/15/2023 CTU #6 1.75" CT 0.145" WT Job Scope: Extended Add Perf S/I well and freeze protect flowline. MU HES GR/CCL logging tools and 2.25" nozzle. RIH. L&K well with 250 bbl Slick 1% KCL w/ Safelube. Pump 25 bbl freeze protect cap. Tag 2-7/8" CIBP at 13117' CTM / 13100' MD. Log OOH at 50 FPM to 10600'. RBIH to 13100' to circulate a bottoms up for a well kill (find the methanol injection manifold frozen). Paint blue flag at 11659.7' E / 11667' M / 11659.7' HES. POOH and confirm good data (+6'). Open hole deploy 500' of 2" HES Millenium perf guns (6 spf, 60 deg phasing) while circulating 60/40 across top of well with 50-60% returns. RIH. ***Job In Progress*** 4/16/2023 CTU #6 1.75" CT 0.145" WT Job Scope: Extended Add Perf RIH w/ 500' of 2" HES Millennium perf guns (6 spf, 60 deg phasing). RIH past flag. PUH and correct to top shot depth at flag. PUH to perforating depth. Perforate 11660' - 12160'. POOH, L&K the well with KCL, lay down perf guns. Freeze protect the well with 60/40. RDMO. ***Job Complete*** 4/18/2023 T/I/O/OO = 160/470/10/vac. Temp = 40° Tbg FL (Ops request). T FL @ 1370' (840, above X NIP, 73 bbls). SV, WV = C. SSV, MV = O. IA, OA, OOA = OTG. 10:15 4/22/2023 ***WELL S/I ON ARRIVAL*** SET 4-1/2" SLIP STOP CATCHER @ 5,902' SLM PULLED BK-DGLV'S FROM ST#4 (5,779' MD) & ST#5 (3,276' MD) SET BK-LGLV IN ST#5 (3,276' MD) SET BK-OGLV IN ST#4 (5,779' MD) PULLED 4-1/2" SLIP STOP CATCHER FROM 5,209' SLM ***WELL LEFT S/I*** Daily Report of Well Operations PBU H-05B The adperfs are shown correctly on the new WBS, below. -WCB Tag 2-7/8" CIBP at 13117' CTM / 13100' MD. Log OOH at 50 FPM to 10600'. g g RBIH to 13100' to circulate a bottoms up for a well kill (find the methanol injection(j manifold frozen). Paint blue flag at 11659.7' E / 11667' M / 11659.7' HES. POOH and )g confirm good data (+6'). Open hole deploy 500' of 2" HES Millenium perf guns (6 spf,g() y g( 60 deg phasing) while circulating 60/40 across top of well with 50-60% returns. RIH. RIH w/ 500' of 2" HES Millennium perf guns (6 spf, 60 deg phasing). RIH past flag.g (gg) g PUH and correct to top shot depth at flag. PUH to perforating depth. Perforate 11660' - 12160'. POOH, L&K the well with CTU #6 1.75" CT 0.145" WT Job Scope: Extended Add Perf 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU H-05B Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 209-100 50-029-20106-02-00 341J ADL 0028284 14044 Intermediate Tieback Tieback Liner Liner Liner 9026 7952 2102 10829 1233 2744 13100 13-3/8" x 9-5/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-3/16" x 2-7/8" 9022 30 - 7982 28 - 2130 26 - 10855 10716 - 11949 11300 - 14044 2320 30 - 6409 28 - 2129 26 - 8548 8444 - 9024 8872 - 9026 13584 1950 4760 5410 7500 10530 13100, 13725 3450 6870 7240 8430 10160 12380 - 13979 4-1/2" 12.6# 13Cr80 24 - 107209025 - 9025 Surface 2276 18-5/8" 32 - 2308 32 - 2307 930 870 4-1/2" Baker S3 Packer No SSSV Installed 10665, 8406 Date: Stan Golis Sr. Area Operations Manager Josh Stephens Josh.Stephens@hilcorp.com 907.777.8420 PRUDHOE BAY 3/21/2023 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov ocedure approved herein March 8, 2023 By Samantha Carlisle at 8:42 am, Mar 08, 2023 323-139 2320 MGR17MAR23 10-404 SFD 3/8/2023GCW 03/20/23JLC 3/20/2023 3/20/23Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.03.20 10:30:11 -08'00' RBDMS JSB 032023 Well Stage: Active Producer Well: H-05B PTD: 209-100 Well Name:H-05B API Number: 50-029-20106-02 Current Status:Operable Producer Rig:CTU Estimated Start Date:3/20/2023 Estimated Duration:2days Sundry #N/A Date Approval Rec’vd:N/A Regulatory Contact:Abbie Barker PTD Number:209-100 First Call Engineer:Josh Stephens 970-779-1200 (Cell) Current Bottom Hole Pressure: Max Bottom Hole Pressure: Max. Proposed Surface Pressure: Kill Weight Fluid Min ID: 3,190 psi @ 8,800’ TVD 3,200 psi @ 8,800’ TVD 2320 psi 7.2ppg 2.30” at 11,300’ MD (SBHP from 11/24/2000) (Based on highest case in the field) (Based on .1psi/ft gas gradient) Brief Well Summary: H-05B is a natural flow Ivishak producer. The well has seen a steady increase in GOR and is approaching MGOR. An adperf opportunity has been identified in the 2B that is estimated to bring in 239 IOR. Objective:Add 500’ of perfs. Notes On Wellbore Condition: Last down hole intervention in liner E-line tagged polar choke at 13,121’ with 2.20” bit on Miller tool. Procedure: Service Coil – Drift/Log: 1. MIRU CTU, MU PCE, 2. MU 2.20” logging carrier with GR/CCL and 2.25” nozzle 3. RIH and tag CIBP at 13,120’ a. Log OOH to 10,600’ b. Flag Pipe near top of perf interval at 11,660’ c. Send Log to OE to verify Tie in 4. POOH and prepare for open hole deployment of guns Service Coil – Extended AdPerf Sundry Procedure (Approval Required to Proceed) Coil Tubing – Extended Add Perf Notes Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perfs guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 1. Pull test the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 2. Bullhead 250 bbls of KWF, 1% KCL down the tubing to the formation. 2320 psi Well Stage: Active Producer Well: H-05B PTD: 209-100 a. This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS. b. Wellbore volume to TD =185 bbls a. TBG Volume to LTP = .0152x11,294’ =172 bbls b. 3-1/2” Liner Volume =(11,354’ -11,294’) x .0087 = .52 bbls c. 3-3/16” Liner Volume = (12,505’-11,354’) x .0076 = 8.75 bbls d. 2-7/8” Liner Volume to CIBP = (13,100’-12,505’) x .0058 = 3.4 bbls 3. Prepare for deployment of 2”, 60SPF, 60 degree phasing TCP guns. 4. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF as needed. Maintain continuous hole fill taking returns to tank until lubricator connection is re-established. a. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 5. Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. a. At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 6. Break lubricator connection at QTS and begin makeup of TCP guns. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Table 1: H-05B Proposed Ad-Perf Gun Runs 7. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per RE/OE. POOH. 8. Note any tubing pressure change in WSR. 9. After perforating, PUH to top of liner or into tubing tail to ensure debris do not fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary, before pulling to surface. 10. Pump pipe displacement while POOH. Stop at surface to reconfirm well dead and hole full. 11. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 12. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 13. Once guns are pulled, coordinate with operations to determine if a freeze protect is required or if the well will be brought online. FP well as required. 14. H-05B has no live GLVs, it is recommended that the well be loaded with diesel to help it kickoff. 15. RDMO CTU Gun Run # Perf Top Perf Bottom Perf Length 1 11,660’ 12,160’ 500’ Total 500’ Well Stage: Active Producer Well: H-05B PTD: 209-100 Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic 4. Standing Orders for Open Hole Well Control During Perf Gun Deployment 5. Equipment Layout Diagram 6. Tie in Log 7. Sundry Change Form Well Stage: Active Producer Well: H-05B PTD: 209-100 As-built Schematic (1 of 2): Well Stage: Active Producer Well: H-05B PTD: 209-100 As-built Schematic (2 of 2): Well Stage: Active Producer Well: H-05B PTD: 209-100 Proposed Schematic (1 of 2): Well Stage: Active Producer Well: H-05B PTD: 209-100 Proposed Schematic (2 of 2): Well Stage: Active Producer Well: H-05B PTD: 209-100 BOP Schematic Well Stage: Active Producer Well: H-05B PTD: 209-100 Well Stage: Active Producer Well: H-05B PTD: 209-100 Well Stage: Active Producer Well: H-05B PTD: 209-100 Tie in Log: Well Stage: Active Producer Well: H-05B PTD: 209-100 Well Stage: Active Producer Well: H-05B PTD: 209-100 Well Stage: Active Producer Well: H-05B PTD: 209-100 Well Stage: Active Producer Well: H-05B PTD: 209-100 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 David Dempsey Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.dempsey2@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/27/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20220927 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 3 31 500292283800 197227 12/13/2021 Baker CH RPM PBU 01-14A 500292028101 209129 7/29/2022 Baker CH SPN PBU 01-15B 500292028702 213190 8/2/2022 Baker CH SPN PBU 01-31 500292162600 186132 7/6/2022 Baker CH SPN PBU 06-04B 500292017902 216092 5/5/2021 Baker CH RPM PBU 06-16A 500292046001 212139 5/3/2021 Baker CH RPM PBU 06-21C 500292080203 221088 6/28/2022 Baker CH MRPM PBU 15-49C 500292265103 215129 8/13/2022 Baker CH MRPM PBU H-05B 500292010602 209100 6/29/2022 Baker CH SPN PBU H-26A 500292148701 214205 7/10/2022 Baker CH SPN PBU H-35A 500292260001 214045 7/4/2022 Baker CH SPN PBU H-38 500292340200 208167 7/19/2022 Baker CH SPN PBU P1-06A 500292269502 222009 7/17/2022 Baker CH MRPM PBU P2-43 500292325000 205024 8/5/2022 Baker CH SPN PBU U-09B 500292114402 214063 8/12/2022 Baker CH SPN PBU W-26A 500292196401 199081 7/23/2022 Baker CH SPN Please include current contact information if different from above. T37052 T37053 T37054 T37055 T37056 T37057 T37058 T37059 T37060 T37061 T37062 T37063 T37064 T37065 T37066 T37067 PBU H-05B 500292010602 209100 6/29/2022 Baker CH SPN Kayla Junke Digitally signed by Kayla Junke Date: 2022.09.29 16:24:46 -08'00' 3URSHUW\'HVLJQDWLRQ/HDVH1XPEHU 2SHUDWLRQV 3HUIRUPHG 2SHUDWRU1DPH $GGUHVV :HOO&ODVV%HIRUH:RUN3HUPLWWR'ULOO1XPEHU $3,1XPEHU :HOO1DPHDQG1XPEHU /RJV/LVWORJVDQGVXEPLWHOHFWURQLFGDWDSHU$$&)LHOG3RROV $EDQGRQ 6XVSHQG 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 3HUIRUDWH 3OXJ3HUIRUDWLRQV 5HHQWHU6XVS:HOO 2WKHU6WLPXODWH )UDFWXUH6WLPXODWH $OWHU&DVLQJ 3XOO7XELQJ 5HSDLU:HOO 2WKHU &KDQJH$SSURYHG3URJUDP 2SHUDWLRQVVKXWGRZQ 3UHVHQW:HOO&RQGLWLRQ6XPPDU\ &DVLQJ /HQJWK 6L]H 0' 79' %XUVW &ROODSVH ([SORUDWRU\ 6WUDWLJUDSKLF 'HYHORSPHQW 6HUYLFH $WWDFKPHQWVUHTXLUHGSHU$$& :HOO6WDWXVDIWHUZRUN ,KHUHE\FHUWLI\WKDWWKHIRUHJRLQJLVWUXHDQGFRUUHFWWRWKHEHVWRIP\NQRZOHGJH 2,/ *$6 :,1- :$* *,1- :'63/ *6725 6XVSHQGHG 63/8* $XWKRUL]HG1DPHDQG 'LJLWDO6LJQDWXUHZLWK'DWH $XWKRUL]HG7LWOH &RQWDFW1DPH &RQWDFW(PDLO &RQWDFW3KRQH 3%8+% +LOFRUS1RUWK6ORSH//& &HQWHUSRLQW'U6XLWH$QFKRUDJH$. ,QWHUPHGLDWH 7LHEDFN 7LHEDFN/LQHU /LQHU /LQHU [ [[ &U 6XUIDFH %DNHU63DFNHU 6WDQ*ROLV 6U$UHD2SHUDWLRQV0DQDJHU %URGLH:DJHV 'DYLG:DJHV#KLOFRUSFRP 358'+2(%$<358'+2(2,/ 7RWDO'HSWK (IIHFWLYH'HSWK PHDVXUHG WUXHYHUWLFDO IHHW IHHW IHHW IHHW PHDVXUHG WUXHYHUWLFDO PHDVXUHG PHDVXUHG IHHW IHHW IHHW IHHW PHDVXUHG WUXHYHUWLFDO 3OXJV -XQN 3DFNHU 0HDVXUHGGHSWK 7UXH9HUWLFDOGHSWK IHHW IHHW 3HUIRUDWLRQGHSWK 7XELQJVL]HJUDGHPHDVXUHGDQGWUXHYHUWLFDOGHSWK 3DFNHUVDQG6669W\SHPHDVXUHGDQGWUXHYHUWLFDOGHSWK 6WLPXODWLRQRUFHPHQWVTXHH]HVXPPDU\ ,QWHUYDOVWUHDWHGPHDVXUHG 7UHDWPHQWGHVFULSWLRQVLQFOXGLQJYROXPHVXVHGDQGILQDO 5HSUHVHQWDWLYH'DLO\$YHUDJH3URGXFWLRQRU,QMHFWLRQ'DWD 2LO%EO *DV0FI :DWHU%EO &DVLQJ3UHVVXUH 7XELQJ3UHVVXUH 3ULRUWRZHOORSHUDWLRQ 6XEVHTXHQWWRRSHUDWLRQ :HOO&ODVVDIWHUZRUN ([SORUDWRU\ 'HYHORSPHQW 6HUYLFH 6WUDWLJUDSKLF'DLO\5HSRUWRI:HOO2SHUDWLRQV &RSLHVRI/RJVDQG6XUYH\V5XQ (OHFWURQLF)UDFWXUH6WLPXODWLRQ'DWD 6XQGU\1XPEHURU1$LI&2([HPSW $'/ 1R6669,QVWDOOHG 1$ 1$ 1$ 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 5(32572)681'5<:(//23(5$7,216 6U3HW(QJ 6U3HW*HR )RUP5HYLVHG6XEPLW:LWKLQGD\VRU2SHUDWLRQV 6U5HV(QJ By Samantha Carlisle at 8:01 am, Apr 12, 2022 'LJLWDOO\VLJQHGE\6WDQ*ROLV '1FQ 6WDQ*ROLV RX 8VHUV 'DWH 6WDQ*ROLV $&7,9,7<'$7(6800$5< 32//$5'81,7:($7+(567$1'%<KLJKZLQGV :($7+(567$1'%<32//$5'81,7KLJKZLQGV :(//)/2:,1*21$55,9$/ 5$1 [67(0&(1772 6/067$//('287'8(72 '(9,$7,21 :(//)/2:,1*21'(3$5785( :(//)/:2,1*21$55,9$/ -2%6&23('5,)7 6(7&,%3: :(//7(& /56)3)/2:/,1(/2$'7%*:%%/6&58'( 581:&+:3:(//7(&75$&7250,//(5 %,7 '(9,$7('287$7 %(*,175$&725,1* 7$*32/$5&+2.($7 &255(/$7(726/%0(025<&2,/)/$* 6(37 322+/$<'2:1)257+(1,*+7 &217,18(-2%21 $VVLVW(OLQH352),/(02',),&$7,213XPSHGEEOVFUXGHGRZQ7EJIRUORDG 3XPSEEOVFUXGHGRZQ)/IRU)33UHVVXUHGXS)/WRSVL(/LQHLQFRQWURORI ZHOOSHU/56GHSDUWXUH,$2$ 27* &217,18(-2%)520 581:&+:3 :(//7(&75$&725 *$00$*816$)( 68% 0667 16&,%3 6(71257+(5162/87,216$/3+$&,%3# &&/720,' (/(0(17 &&/6723'(37+ -2%&203/(7(7851:(//29(572323 'DLO\5HSRUWRI:HOO2SHUDWLRQV 3%8+% STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS o.ar Cie P� 3 IVY 2 2 mo L Operations Performed �`.. ❑ Abandon ❑ Plug Perforations ❑ Fracture Stimulate D Pull Tubing ❑ Operetion,yyje�-h $$°�"�,. Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change A 0156h r % `"'�❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ® Exploratory ❑ 5. Permit to Drill Number 209-100 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 1 Strdtigraphic ❑ Service ❑ 1 6. API Number: 50-029-20106-02-00 7. Property Designation (Lease Number): ADL 028284 8. Well Name and Number: PBU H -05B 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 14044 feet Plugs measured 13725 feet true vertical 9026 feet Junk measured 13584, 14014 feet Effective Depth: measured 13725 feet Packer measured 10665 feat true vertical 9025 feet Packer true vertical 8405 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 81 301, 33-114 33-114 880 Surface 2276 18-5/8" 32-2308 32-2307 930 870 Intermediate 7952 13-3/8" x 9-5/8' 30-7982 30-6409 3450/6870 1950 / 4760 Intermediate 2227 9-5/8" 28-2255 28-2254 6870 4760 Liner 10829 7' 26-10855 26-8548 7240 5410 Liner 1244 4-1/2" 10705 - 11949 8435-9024 8430 7500 Liner 2750 3-1/2" x 3-3/18' x 2-7/8" 11294 - 14044 8868-9026 13450 13890 Perforation Depth: Measured depth: 12380 - 13979 feet True vertical depth: 9025-9025 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 24-10720 24-8446 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Packer 10665 8405 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: 382 20444 30 0 1040 Subsequent to operation: 406 7484 104 0 347 14. Attachments: (requires per20 nnc 25.07025.011, a 25283) 15. Well Class after work: Daily Report of Well Operations 121 Exploratory ❑ Development p Service ❑ Stratigraphic ❑ 16. Well Status after work: oil 0 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true antl correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WA Authorized Name: Wellman, Julie Contact Name: Wellman, Julie Authorized Title: Production Engineer Contact Email: Julie.Wellmanftbp.mm Authorized Signature: Date: 15/(91/19 Contact Phone: +1 9075644657 Form 10404 Revised 04/2017v / 1 �,,,�r�OYFA MS�MAY 2 3 2019 6ubmil Original Only CTU #8 1.75" CT Job Scope: Drift & Log/Polar Choke/ADPERF MIRU. FP flowline. Kill well. MU & RIH w/ 2.2" HES logging carrier & 2.25" JSN.. 4/20/2019 "'In Progress*** CTU #8 1.75" CT Job Scope: Drift & Log/Polar Choke/ADPERF Continue to RIH w/ 2.2" HES logging carrier & 2.25" JSN. Tag at 12,500ft. POH. MU 2.29" junk mill/motor and RIH. Tag at 13,584'. Polar choke has moved since being set in 2017. POOH. MU 2.2" HES logging carrier & 2.25" DJN and RIH. Log from 13550ft to 10300ft. POH, minus 5.5ft correction. MU & RIH w/ 2-7/8" WFT cement retainer w/ 0.25" orifice polar choke. 4/21/2019 "'In Progress' CTU #8 1.75" CT Job Scope: Drift & Log/Polar Choke/ADPERF Continue to RIH w/ 2-7/8" WFT cement retainer w/ 0.25" orifice polar choke. Set top of 2-7/8" WFD cement retainer w/ 0.25" polar choke at 13,120ft. POH. Change out packoffs. Cut 100f for chrome management. MU & RIH with HES 2" x 32' Maxforce pert gun #1. Tag polar choke and correct depth, PUH and perforate interval 12,576'- 12,608' (reference 12,578'- 12,610'). POOH. Shots fired & ball recovered. with H x orce perf gun #2. Tag polar choke and correct depth, PUH and perforate interval 12,488'- 12,520' (reference 12,490'- 12,522'). POOH. 4/22/2019 "'In Pro ress"' CTU #8 1.75" CT Job Scope: Drift & Log/Polar Choke/ADPERF Continue to POOH w/ pert gun #2. Shots fired & ball recovered. MU & RIH with HES 2" x 32' Maxforce perf gun #3. Tag polar choke and correct depth, PUH and perforate interval 12,410'- 2,412'-12,444'). POOH. Shots fired & Ball recovered. MU & RIH with HES 2" 12,442' (reference 12,412'- 12,4!±). x axforce perf gun . ag po ar Choke and correct depth. PUH and perforate interval 12,378' 12,410 (reference 12,380'- 12,412'). POOH. Shots fired & Ball recovered,. 4/23/2019 '*'Com tete'" WELLHEAD = MCEVOY ACTUATOR= OTB OKB. ELEV = 64.13' REF ELEV = 72" BF. ELEV = 45.18' KOP = 7982' Max Argle = S4-611745- 4' 11745'Datum DatumMD = 11301' Dakan TVD= 8800'SS 9 -WW CSG TIEBACK W/ Bar PBRH 2130' 13-3/8' CSG, 68#, K-55, D =12.415 2251' 18-5/8' CSG, 96.5#, K-55, D = 17.855' Minimum ID =0.25" @ 13120' 2-7/8" POLAR CHOKE ORIFICE 17" SCAB LNR 26', L-80, D = 6276' 1 19-518- CSG, 47#, L-80, D = 8.681' I i:' TBG, 12.68, 13 -CR -0152 bpf, D = 3.958' H 10720' 7- LNR, 26", L-80, .0383 bpf, D = 6276" 10855 LNR 8.818, L-80, STL, .0087 bpf, D = 2.992' 11353' /2' LNR, 12.6#, 13-CR,.0152bpf, D=3.958' 11949' 4-12' BKR MONOBORE WHPSTOr7r PERFORATION SUMMARY RE LOG: SLB MCAL ON 1020/09 ANGLE AT TOP PEW: 930 @ 12380' Note: Refer bo Roduction DB for historical cert data -SE PG 2 FOR PERF SLWAARY- H-056 13-3/16' LNR, 6.2#, L-80, TC0,.0076 bpf, D=2.80' I SAFETY NOTES: WELL ANGLE >70° 11552% MAX DLS: 52.5° @ 12155'. ***4-12" CHROME TBG & LNR*** I 22OW I 8" X 9-58' XO, D = 8.681' GAS LFT MAMIRR S ST MD I TVD I DEV I TYPE I VLV I LATCHI FORTI DATE 5 3276 3236 28 KBG-2 DOME- BK 16 11/01/09 4 5779 4929 50 KBG-2 SO BK 20 1110189 3 7929 6373 47 KBG2 DMY BK 0 02!11/04 2 9291 7371 44 KBG-2 DMY BK 0 02!11/04 1 10491 8276 41 KBG-2 OMY BK 0 02/11/04 4T I -i 9-58' X 7" BKR LNR TOP PKR 9-5/8' MLLOUT WINDOW (H -05A) 7982'- 7998' 1 4-1/2' HES X NP, D = 3.813" J 7- X 4-1/2" BKR S-3 PKI;, D = 3.875' )88' 4-12' HES X NP, D = 3.813- 14-1/2' WLBG. .813' 14-12'WLBG. D=3-958'1 11�-i3-12- DEPLOYMENT SLEEVE, D=2.30- 11364' =2.30'11364' 3-12X3-3/16' XO, D = 2.8P 412' MLLOUr WINDOW (H -05B) 11949--11958' 12606' �3l16 X 2-778' XO, D = 2.377' 1312WW 2-78" POLAR CHOKE 025' ORFICE (0422/19) 12505' 0058 bpf, DATE REV BY I COMMENTS DATE REV BY COMMENTS 02Mt1/77 ORIGINAL COMPLETION 02=7 BOVMD R94ORCORREC710N 02/1804 SRMAK RIG SIDETRACK(H46A) 1120/17 MR/JMD SETPOLARCHOKE&ADPERFS 102309 NORDIC2 CTD SDETRACK(H-05B) 0506/19 MR/JND RESETPOLARCHK,ADPERFS, FBI 0522/13 KJB/JMD SETCBP&SHOTADPERF 05/15/19 DD/JMD ADDEDOCB,REF,&BFELEV 9M 03M3 RMWJMD ADPERFS 09109!13 0489/14 LLVJMD CBP & FISH (04/04!14) 1 14014' 1 14044' PRUDHOE BAYUNfF WELL: H -05B PERMB No: x2091000 I APINo: 50-029-20106-02 SEC 21, T11 N, R13E, 773' FNL & 1265 BP Exploration (Alaska) WELLHEAD= MCEVOY ACTUATOR= 0718 OKB. ELEV = 64.13' REFELEV= 7293' BF. ELEV = 45.16' KOP =_ Max = _ 7962' 94" O 11745' Dahxn MD = 11301' Datum TVD = 6800' SS PERFORATION SUMMARY FIEF LOG: SLB MChI. ON 1020/09 ANGLEATTOPPERF: 930@12380' N1te: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpNSgz SHOT S 2' 6 12380 - 12444 O 04/23/19 1120117 2" 6 12490 - 12522 O 04/22/19 MRUMD 2" 6 12578 - 12610 O 04/22/19 ADDED OKB, REF, & BF ELEV 1.56" 6 12610 - 12640 O 05/11/13 ON09/14 2" 6 12655 - 12755 O 09/09/13 1.56" 6 12810 - 12840 O 05/10/13 2" 6 12885 - 12915 O 09/09/13 2" 6 12922 - 12954 O 11/17/17 2" 6 13048 - 13080 O 11/17/17 2-7/8" 6 13170- 13700 O 10/22/09 13800 - 13979 c 1022/09 SAFETY NOTES: WELL ANGLE > 70" @ 11552'. MAX H_� r B OLS: 52.5° @ 12155'. ""4-112" CHROME TBG & LNR"` DATE REVBY COMMENTS DATE REV BY COMMENTS 02118rr7 ORIGINAL COMPLETION 0220f17 BC9JMD MINORCORRECTION 00/111144 SRBA4AK RIGSIDE7RACK N4W 1120117 M7/JMD SET POLARCHOKE&ADPERFS 1023109 NORDIC2 CTD SIDETRACK -M) 05OW9 MRUMD RESET POLAR CHF(, ADPERFS, FBI 052P 13 KJB/JMD SET CBP & SHOTADPERF 05/15119 DD/JMD ADDED OKB, REF, & BF ELEV 09/13113 RMWJMD ADPERFS 9A9/13 ON09/14 LLPJMD CBP & FISH 14 PRUDHOE BAYUNIT WELL: H -05B PERMIT ND: x2091000 API No: 50-029-20106-02 BP Exploration (Alaska) ' STATE OF �LASKA OIL AND GAS CONSERVATION COMMIS* MAR 0 5 2018 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed AO G C C Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate H Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 209-100 3. Address: P.O.Box 196612 Anchorage, Development g1 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20106-02-00 7. Property Designation(Lease Number): ADL 028284 8. Well Name and Number PBU H-05B 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 14044 feet Plugs measured 13725 feet true vertical 9026 feet Junk measured 14014 feet Effective Depth: measured 13725 feet Packer measured 10665 feet true vertical 9025 feet Packer true vertical 8405 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 81 30" 28-109 28-109 880 Surface 2272 18-5/8" 27-2299 27-2298 930 870 Intermediate 7956 13-3/8"x 9-5/8" 26-7982 26-6409 3450/6870 1950/4760 Intermediate 10830 7" 25-10855 25-8549 7240 5410 Liner 1244 4-1/2" 10716-11949 8435-9024 8430 7500 Liner 2750 3-1/2"x3-3/16"x2-7/8" 11294-14044 8868-9026 Perforation Depth: Measured depth: 12610-13979 feet True vertical depth: 9021-9027 feet tkLd Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 23-10719 23-8446 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Pkr 10664 8405 true vertical depth) 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: 478 27705 108 0 949 Subsequent to operation: 510 12495 72 0 999 14.Attachments:(required per 20 AAC 25.070.25.071,&25.2831 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development II Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 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 Authorized Name: Wellman,Julie rOtikfr—(11141,4,1644/ Contact Name: Wellman,Julie c Authorized Title: Production Engineer Contact Email: Julie.Wellman@bp.com Authorized Signature: --"'- ? `�.) Date: 3 5(3- Contact Phone: +1 9075644657 Form 10-404 Revised 04/2017 Il T` `f lk6//D/ ( 1(�C2(1 n n l','",,,.7:, , 2018 I(* /� "��- -� w IT,,,: / `� Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary February 28, 2018 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Perforate for Well PBU H-05B, PTD #209-100. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • .111111 U) a / E / / b H0 2 \ k cv co co c 0 _J -Ic •Ct \ \ \ 0 E 0 \ £ c 0 0 / o » E E2 E2 I E \ L E _ 0) 2 $ fi •10 ° 2 CU o CO0 0 ° 0 � = $ / / / \ k / g � E I 22 22 \ 2 % ± \ 2 O co 2 ® B -a _7 §cn _cn m § R 2; 2- = c _t �t i`Ick ■ U_ L L o m ± % m L o 0 C LL < (Y ff a_� Cf a_a ± 3 ® a- o & ƒ 3 W 0_ 0_ ƒ � \ / CO ■ < 0a) 0 eta 211q 0E I §¥ � I / ¥ � � $ ® � $ / \ / E 0.W D °0 $ Elk Elk $ I �7 \ � - i t / • / / \ % t -0 \ t f [ § © 9 / � .¢ / / E / / % 2 0a / / 3 i E_ E 090 E9 � 7 _J 2 _1 & - - a < w a o k » § © / § ® \ § k 1 E -0 t / �• � � 't k \ 0. CL c o o CO= o I a aa) ._E = CC kO = % 6 = cc -0 E = k ® k k a E m a c co 0 >, , 0k o \_ ok \ 00 o \ % 2_ I % ® I o 2 I 2 $ I co In k / f k = kedk kco CO .- k £ / \ I- - ® K t ® '% o = - R K o \_ R » - • \ / [ ƒ % E Ou) c - °' 3coa2 / \ / ƒ t ® / . \ I § / _/ / 2 / \ y t § P r y ± § - $ 2 E/ D E r a 0 a) . o . 0 0) -- 0 o ® ' m _ 06 0 ° § \ '' @ § \ E P § = k E - @ § \ § -E \ I- / c k a_ 0_ c % I a 9 # I ,- _ ; * IL- _ CL c % c # co = % _ ce c c .... = Oct = O / .4. c f = O f 3 c CDC 0-s \ k £ _, R - m r o A 0 r o w O o r o R O o r o@ o R c) oo 0 0 » £ t O O � | 0 0 a. - | 0 O CL a. t 0 0 0 m a 0 | 2 Y L ¥ ¥ w w ¥ 0 a G a a 7 e e Q 5 5 co ¥ n CD w ¥ N- = dq2 > m R / e•-• e- e- e-- TREE= , 4-1/16" • WELLHEAD= MC EVOY SAFETY : WELL ANGLE>70° % 11552'.MAX ACTUATOR= OTIS H -0 5 B DLS:52.5°@ 12155'."'4-12"CHROME TBG&LW*** NEPAL KB.ELE 64.13' BF.ELEV= 44.68' KOP= 7982' Max Angle= 94'@ 11745' I Datum M)= 11301' ►' [ 1066' J—9_5/8'X 13-3/8"EST TOP OF CEMENTJ • Datum TV D= 8800'SS ►• • 1 2209' H4-1/2"10 3 X NP,D=3.813' •9-5/8"CSG TEBACK W/BOT PBR — 2130' � •• .• •. 13-3/8"CSG,68#,K-55,D=12.415" I— 2251' 1►� �� Q • 2251' —13-3/8'X 9-5/8'X0,D=8.681' • 18-5/8"CSG,96.5#,K-55,D=17.655" --I 2299' GAS LET MANDRELS Minimum ID =0.25" 13150' ST M) TVD DEV TYPE VLV LATCH FORT DATE L 5 3276 3238 28 KBG-2 DOME BK 16 11/01/09 2-7/8" POLAR CHOKE ORIFICE 4 5779 4929 50 KBG-2 SO BK 20 11/01/09 3 7929 6373 47 KBG-2 DO/ BK 0 02/11/04 ITOP OFCMT(ESTMATED) _I--I 6830' I 2 9291 7371 4-4 KBG-2 DMY BK 0 02/11/04 I__ 1 10491 8276 41 KBG-2 DMY BK 0 02/11/04 7"SCAB LNR,26',L-80, ID=6.276" — 7830' 7643' H9-5/8"X 7"BKR LNR TOP PKR 9-5/8"MLLOUT NTDOW(H-05A)7982'-7998' I 9-5/8'CSG,47#,L-80,ID=8.681' — 7982' / 10644' —4-1/2'I CS X NP,10=3.813' I X 10665' —7^X 4-1/2'BKR S-3 PKR,D=3.875' 10688' —4-1/2'I ISS PD X N , =3.813' ' , 10707' H4-1/2'HES XN NP,D=MLLED to 3.80" 4-1/2'TBG, 12.6#,13-CR .0152 bpf,ID=3.958" — 10720' I I 10713' —4-1/2'WLEG, D=3.958' 17"LNR,26",L-80, .0383 bpf, D=6.276" —I 10855' l 10716' —7^X 5'BKR LW ' 3-1/2'LNR,8.81#,L-80,STL,.0087 bpf,D=2.992" — 11353' 10733' —15"X 4-1/2"X0 4-1/2'LNR, 12.6#, 13-CR,.0152 bpf,13=3.958' H 11949' ►, ' 11294' -JBKR KB LT FKR,D=2.37' 4-1/2"BKR MONOBORE M-FSTOCK H 11950' 0 ► 11300' I—3-1/2"DEPLOYMENT SLEEVE,D=2.30' J 1 PERFORATION SUMAARY ��t ►� 11364' —13-1/2 X 3-3/16'XO,D=2-80' REF LOG: SLB Mal.ON 10/20/09 V• V• ANGLE AT TOP PERF: 91°@ 12610' ,4� ►$ 4-1/2"MLLOUT WPDOW(H-058) 11949'- 11958' • Note:Refer to FYoduction DB for historical perf data •. SIZE SPF INTERVAL C n/Sqz SHOT SQ414,'1 4 12505' —3-3/16 X 2-7/8'X0,D=2.377' 1.56" 6 12610- 12640 0 05/11/13 2" 6 12695-12755 0 09/09/13 1.56" 6 12810 12840 0 05/10/13 13150' —2-7/8'POLAR CHOKE 0.25' 2" 6 12885-12915 0 09/09/13 S ORFICE(11/17/17) 2" 6 12922- 12954 0 11/17/17 2" 6 13048- 13080 0 11/17/17 13725' —12-7/8^C1BP(04/04/13) 2-7/8" 6 13170- 13700 C 10/22/09 �/ 2-7/8" 6 13800- 13979 C 10/22/09 14014' —FISH:CEP MILLED PUSHED(04/04/14) 3-3/16"LNR,6.2#,L-80,TCtl,.0076 bpf,D=2-80' 12505' *i� ISTD H 14005' 2-7/8'LHR,6.16#,L-80,SNL, .0058 bpf,D=2-441' — 14044' DATE REV BY COPI.U4TS DATE REV BY (QTS PRU DHOE BAY UNIT 02/18177 ORIGINAL COMPLETION 05/22/13 KJB/JM) SET CBPB SHOT ADF$RFS(05109-1 WELL: H-05B 02/18/04 SR8/KAK FIG SIDETRACK(H-05A) 09/13/13 F A-YJWD ADFT3S(09/09/13) PE RMT No:"2091000 10/23/09 NORDIC2 CTD SIDETRACK(11-058) 04/09/14 LLVJM) 'CEP&ASH(04/04/14) API No: 50-029-20106-02 10/25/09 SV DWG HO CORRECTIONS 02/20/17 BO/JF&O MINOR(ACTION SEC 21,T11 N,R13E,773'FP&&1265'FEL 11/06/09 BSE/SV GLV CAD(11/01/09) 11/20/17 MR/JM) SET POLAR CHOKE&ADPERFS _ 08/02/10 FFYSV ANAL DRLG CORFECT1ONS BP Exploration(Alaska) III • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q 2 i - J 0 0 Well History File Identifier I Organizing (done) ❑ Two -sided 1 ❑ Rescan Needed 111 111111111! IJI 111 RE AN DIGITAL DATA OVERSIZED (Scannable) V Color Items: ❑ Diskettes, No. ❑ Maps: ❑ Greyscale Items: Other, No/T e: Yp CP NO 1 ❑ Other Items Scannable by ❑ Poor Quality Originals: a Large Scanner OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: y) 0 BY: Maria Date: l I I / /s/ Project Proofing 1111111111111 11111 BY: Maria Date: 11/1/ l MP J /s/ Scanning Preparation x 30 = tC2Q + a = TOTAL PAGES 6,9.- (Count does not include cover sheet) °� BY: Maria / VII l Date: ' /s/ I Production Scanning 11111111111111 II 111 1 Stage Page Count from Scanned File: g g 3 (Count does include covers eet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: /1/ II i / /s/ ill Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 1111 1111111111 Ill ReScanned 1111111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked 111 1 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA AL .A OIL AND GAS CONSERVATION COMM. ON REPORT OF SUNDRY WELL OPERATIONS `71-1-12It+ 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U MiII- I g -/-6/6/(jam Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time ExtensionD Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: BP Exploration(Alaska),Inc Name: Developments Exploratory ❑ ' 209-100-0 3.Address: P.O.Box 196612 Stratigraphit❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 • 50-029-20106-02-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028284 • PBU H-05B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured • 14044 feet Plugs measured 13725 feet w ''' true vertical 9026.14 feet Junk measured 14014 feet Effective Depth measured . 13725 feet Packer measured See Attachment feet true vertical 9025.21 feet true vertical See Attachment feet " t 1' Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 81 30"157.5#B Grade 28-109 28-109 880 0 Surface 2272 18-5/8"96.5#K-55 27-2299 27-2297.95 930 870 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production 7806 7"26#L-80 25-7831 25-6306.51 7240 5410 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12610-12640 feet 12695-12725 feet 12725-12755 feet 12810-12840 feet 12885-12915 feet 13170-13700 feet 13800-13979 feet True Vertical depth 9020.88-9020.58 feet 9020.68-9020.81 feet 9020.81-9021.52 feet 9021.63-9021.6 feet 9021.34-9021.27 feet 9024.65-9024.26 feet 9027.36-9025.23 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 23-10719 23-8445.8 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): RBDM MAY 16 2014 Treatment descriptions including volumes used and final pressure: N JUN 1 1 2014 SCO 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 97 4539 594 0 635 Subsequent to operation: 0 0 0 0 0 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 . U Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC❑ 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(p.BP.Com Printed Name Garry Catron Title PDC PE Signature 91 • ""a4.7-N._-__ Phone 564-4424 Date 4/24/2014 /71.--/= 572-Zi/Li- ,•it f/ //f' Form 10-404 Revised 10/2012 Submit Original Only m` U (B CL o U r O N 0.-a ▪ >, • S 1— u)N • c? m ch L- a) a) (0 CO CO N N A V E V 0) V) > vM N coo vv N co 00 O (/) -0 Q V) v co L Q co E O O � r V a 0_ Y >•UU Q Q d d E• mco (a (n Z o O S S Cl) CD N• 0 0 00 0 0 0 0 P- P) � � � o r• v� rnr.0-� vIn COvoLnIn Ln U 0 ` o o O o Nr CO �o 0 0 M oo COrV N CO NI- NCO O CO CO C` CO f� 00 O O CA 'Cr O co co ,— co O) o CO 00 CO CO r` co CO O , N LO Ln N O N N O C) N N LO O CA 0 0 CO N 67) N N N CO CA CO O O CO N „_01 , 111IIIIIII H I� CO CO LC) CO N CO CO CO O CO N- O6 co N- Cr) N N N N O (r) O O N N N N CO 'Cr co (T O CO CO 00 O C 0,M L.0 O) O O O O LC) LC) O Nr co O c- r N N c-0 co O N N O N N N f� N ✓ a Ln V CO L[) Q N CO O CO (� CO O O LC) O LC) C` CO COCD N N N N 0O0 N N N N N m▪lmf J Q a) 0 0 coaoo Loco ▪ Q ,T3aLoa UOOcocD YCj a) OY00ChJJJc0 C w m 4# N 4# J # ,# N N J LO it N N N CO t$ O CO �$ co O fA LO _ - _ CO 00 _ CO CO O N U tieo0\000N _ CO _ Nco i N ,- ti co N O , 4 co M N Co V t ' O V CO V VN O CO N CO Cil a- N- CO CO N V O Lf) CO O O C CO •-- N N O N LC) - LC) CO N CB N N N Cr) - - - N- N J W w w H H H Z 0 C OH 0 0 0 •- UW ww 0 U 0 CC CC CC Ct CC fY CC 0 w Z Z w w w W w W W W O m O H H H Z Z Z Z Z o 0 0 U Z Z Z J J J _! _.I CL U) H / % 2 2 ' \ > f _ _ 7 / % / � a) ƒ\ kRI c) -,:o -I eL c co�/ fct o 2 - te= Ird c � -o a I co / / I co / kIas 2 0 � / k ® \ � � � � c o _g $ « $ G o in 5 = � CO ® CO % c CO ^ - / 7 . & 7 ± 2 � ± nc o ^ - ® - k = CO - ° ° r$ o q / \ / _ \ \ / - .\ §|f|R o / \ / \ ® ƒ § -co / 0 kf / k@Eo 45. 52. @ re / \ JCU) CI / ƒ 0 N-0� � A 2 co @ \ - ± R , C \ TD- >+ k 2 ° © E & 0 0 / Ecce \ 5 2 2 5 2 E ? o a / - C 0 o ' \ .E '- a o '—a)N k § k 2 £ H a / (Ni O = 0- a £ o c y $ / •c y \ / 7 % / ./°/ / 1 \ gI-O 2 U ± t o ± o o o ± R E ± # t # 7 7 7 ® N N 2 9 .:1- NI- # TIS_. 4-1/16" WELLFEAD= MCEVOY ACTUATOR= ons H _0 5 B l SAFETY NOTES: •*"4-1/2"CHROME TBG&LNR**" INITIAL KB.ELE 64.13' BF.ELEV= 44.68' KOP= 7982' Max Angle= 94"a 11745' Datum MD= 11301' V 1065' H 9-5/8'X 13-3/8'EST TOP OF CEMBYT i • • Datum ND= 8800'SSOi ►. I I [ 2209' H4-1/2"IIS X MP,ID=3.813" • 9-5/8"CSG T1B3ACK W/BOT PBR 2130' t•• 13-3/8"CSG,68#,K-55,D=12.415" H 2251' iI ►j� 2251' -i 13-3/8"X 9-5/8"XO,N3=8.681" 18-5/8"CSG,96.5#,K-55,D=17.655' H 2299' GAS LFT MANDRELS Minimum ID =2.30" @ 11308' , I ST MD ND DEV TYPE VLV LATCH PORT DATE LINER BUSHING I1-{I 5 3276 3238 28 KBG-2 DOME BK 16 11/01/09 4 5779 4929 50 KBG-2 SO BK 20 11/01/09 3 7929 6373 47 KBG-2 DMY BK 0 02/11/04 TOP OF r SCAB LNR(ESTIMATED) —I 6830' 2 9291 7371 44 KBG-2 DMY BK 0 02/11/04 1 1 10491 8276 41 KBG-2 DMY BK 0 02/11/04 7"SCAB LNR 26",L-80, D=6.276" H 7830' ni 7843' —I9-5/8-X 7"BKR LNR TOP PKR / 9-5/8"MLLOUT WINDOW(H-05A)7982'-7998' 9-5/8"CSG,47#,L-80,D=8.68V H 7982' 10644'4-1/2"FES X NP,D=3.813" ' 10665' H7"X 4-1/2"BKR S-3 PICT;D=3.875" ' 10688' H4-1/2"HES X NP,D=3.813" 10707' H4-1/2"HES XN NP,D=MILLED to 3.80" 4-1/2"TBG, 12.6#,13-CR,.0152 bpf,D=3.958" H 10720' 10713' H4-1/2"WLEG, D=3.958" 7"LNR 26",L-80,.0383 bpf, D l=6.276" 10855' 10716' --17"X 5"BKR LIP 3-1/2"LNR,8.81#,L-80,STL,.0087 bpf,D=2.992'H 11353' 10733' S"X 4-i/2"XO 4-1/2"LNR, 12.6#,13-CR,.0152 bpf,D=3.958" H 11949' , I 11294' --I BKR KB LT PKR,13=2.37" I 11 1 4-1/2'BKR MONOBORE WHPSTOCK—{ 11950' 01 11300' 1-13-1/2"DEPLOYMENT SLEEVE,13=2.30" I 1 0 PERFORATION SUMMARY �� 011354' —I3-1/2 x 3-3/16'XO,D=2.80' I REF LOG: SLB MCNL ON 10/20/09 11 1�1 ANGLE AT TOP PEW: 91°@ 12610' �� 1/, 4-1/2"MLLOUT WHDOW(H-05B) 11949'-11958' Note:Refer to Production DB for historical pert data .4.. SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 4`*44 1.56' 6 12610-12640 0 05/11/13 I 12606' [—I3-3/16 x 2-7/8"XO,D=2.377" I 2" 6 12695-12755 0 09/09/13 1.56" 6 12810-12840 O 05/10/13 13726' J—I2-7/8"CEP(04/04/13)I 2' 6 12885-12915 0 09/09/13 AY 14014' FISH:CP N�LED& 2-7/8" 6 13170-13700 O 10/22/09 1EPUSHED(04/04/14) V2-7/8" 6 13800- 13979 C 10/22/09 4 3-3/16"LNR,6.2#,L-80,TCII,.0076 bpf,ID=2.80" 12505' PBTD —I 14005' 2-7/8"LNR,6.16#,L-80,SR,.0058 bpf,D=2.441' --I 14044' DATE REV BY COP1LU'TTS DATE REV BY COPE. TS I PRIOHOEBAY INT 02/18/77 ORIGINAL COMPLETION 05/22/13 KJB/JMD SET CEP&SHOT ADPERFS(05/09-1' WELL: H-05B 02118/04 SRB/KAK RIG SIDETRACK(H-05A) 09/13/13 F &YJM) ADF B S(09/09/13) PERMT No: 2091000 10/23/09 NORDIC2 CTD SIDETRACK(H-05B) 04/09/14 LLVJM) CEP&FISH(04/04/14) AR No: 50-029-20106-02 10/25/09 SV DRLG HO CORRECTIONS SEC 21,T11 N,R13E,773'FNL&1265'FEL. 11/06/09 BSE/SV GLV C/O(11/01/09) 08/02/10 PPISV FNAL DWG CORRECTIONE BP Exploration(Alaska) STATE OF ALASKA s ,.94 ', &KOMI 16.00 WKA OIL AND GAS CONSERVATION COM ION OCT 0 3 20113 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U '0 0 Cr 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 el Exploratory ❑ 209-100-0 . 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-20106-02-00 ' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028284 . PBU H-05B • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL • 11.Present Well Condition Summary: Total Depth measured 14044 feet Plugs measured 13089 feet true vertical 9026.14 feet Junk measured None feet Effective Depth measured 13089 feet Packer measured See Attachment feet, true vertical 9021.91 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 81 30"157.5#B Grade 28-109 28-109 Surface 2272 18-5/8"96.5#K-55 27-2299 27-2297.95 930 870 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production 7806 7"26#L-80 25-7831 25-6306.51 7240 5410 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12695-12725 feet 12725-12755 feet 12810-12840 feet 12885-12915 feet 13170-13700 feet 13800-13979 feet True Vertical depth 9020.68-9020.81 feet 9020.81-9021.52 feet 9021.63-9021.6 feet 9021.34-9021.27 feet 9024.65-9024.26 feet 9027.36-9025.23 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 23-10719 23-8445.8 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: q r)) r Intervals treated(measured): SCANNED ��0'r . f L0i3 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: 15 3744 60 0 703 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El ' Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil el . Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC-❑ 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 94a44,7_2147 Phone 564-4424 Date 10/3/2013 4 vLF /.y X00.0,3 RBDMS OCT 11 2 j0//5//3 Form 10-404 Revised 10/2012 Submit Original Only • . 0 Packers and SSV's Attachment ADL0028284 SW Name Type MD TVD Depscription H-05B PACKER 10664 8332.13 4-1/2" Baker S-3 Hydro Set Packer H-05B PACKER 10716 8370.73 4-1/2" Baker KB LT Packer Casing / Tubing Attachment ADLOO28284 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 30" 157.5# B Grade 28 - 109 28 - 109 880 INTERMEDIATE 2110 9-5/8"47# L-80 20 - 2130 20 - 2128.95 6870 4760 INTERMEDIATE 2234 13-3/8"68#K-55 26 - 2260 26 - 2258.95 3450 1950 INTERMEDIATE 2233 9-5/8"47#L-80 27 - 2260 27 - 2258.95 6870 4760 LINER 3024 7"26# L-80 7831 - 10855 6306.51 - 8548.44 7240 5410 LINER 1244 4-1/2" 12.6# 13Cr80 10705 - 11949 8435.37 - 9024.08 8430 7500 LINER 59 3-1/2" 8.81#L-80 11294 - 11353 8868.2 - 8907.86 0 LINER 1152 3-3/16" 6.2# L-80 11353 - 12505 8907.86 - 9023.66 LINER 1539 2-7/8"6.16# L-80 12505 - 14044 9023.66 - 9026.14 13450 13890 PRODUCTION 7806 7"26# L-80 25 - 7831 25 - 6306.51 7240 5410 SURFACE 2272 18-5/8" 96.5# K-55 27 - 2299 27 - 2297.95 930 870 TUBING 10696 4-1/2" 12.6# 13Cr80 23 - 10719 23 - 8445.8 8430 7500 0 Daily Report of Well Operations ADL0028284 CTU 8 w/ 1.75" CT. Scope;Add Perfs 9/7/2013 Rig up. Function test BOP's. **job continued on WSR 09-08-13** Continued from WSR 09-07-13 CTU 8 w/ 1.75" CT. Scope;Add Perfs RIH w/BHA; 1.75"ctc, 1.69" dfcv, disco, 1.97" crossover, 2.2" carrier with 1.375" memory GR,CCL inside (oal= 20.36'). Tag plug at 13089'. PUH and flag pipe at 13039'. Log 45 fpm to 10400'ctm, circ well to safe lube pooh. RIH w/BHA; 1.75"ctc, 1.69" dfcv, disco, CBF firing head 2.13", 2" perf guns, OAL = 39.09'. Stop at flag and correct depth to top shot. Shoot perf interval 12885-12915'. pooh. Recoved ball, all shots fired. 9/8/2013 **job continued on WSR 09-09-13** Continued from WSR 09-08-13. CTU 8 w/ 1.75" CT. Scope;Add Perfs RIH w/gun#2 BHA; 1.75"ctc, 1.69" dfcv, disco, CBF firing head 2.13", 2" perf guns, OAL= 39.09'. Tie into flag. Shoot 12725-12755 interval. pooh.all shots fired and recovered 1/2" ball, RIH w/gun#3 Tie into flag and shoot 12695' - 12725' md.Pooh. all shots fired, recovered ball, **Job complete** F/P well to 2500'w/40 bbls 50/50 meth. 9/9/2013 • TREE= ' 4-1/16" . .. _LHEAD= NICEVOY SAFETY NOTES: ***4-1/2"CHROME TBG&LNR*** ACTUATOR= OTIS -0 5 B INITIAL KB.Eli 64.13' BF.ELEV= 4468' KOP= 7982 Max Angle=_ 94° 11745'_ •► I 1065' J-19-518"X 13-3/8"EST TOP OF CBNENT Datum MD= 11301' ►�• trait,' atum TVD 8800 S S �� I L 2209' H 4-1/2"HES X NP,D=3.813"■ 9-518"CSG TEBACK W/BOT PBR —) 2130' �•�• 13-3/8°CSG,6811,K-55,D=12.415" --1 2251' N \ � 11 2251' I-113-3/Er X 9-518^XO,D=8.681" 118-518"CSG,96.5#,K-55,D=17.655" —1 2299' GAS LET MANDRB.S Minimum ID =2.30" 'a@ 11308' ST WD I) DEV TYPE VLV LATCH PORT DATE LINER BUSHING 5 3276 3238 28 KBG-2 00& BK 16 11/01/09 4 5779 4929 50 KBG-2 SO BK 20 11/01/09 3 7929 6373 47 KBG-2 DMY BK 0 02/11/04 TOP OF 7"SCAB LNR(ESTIMATED) —1 6830' 2 9291 7371 44 KBG-2 DMY BK 0 02/11/04 1 10491 8276 41 KBG-2 DMY BK 0 02/11/04 7"SCAB LNR 26",L-80, D=6.276" I—_7830' 7843' —19-5/8"X 7"BKR Lt 2 TOP PKR 9-5/8°MLLOUT WNDOW(H-05A)7982'-7998' 9-5/8"CSG,47#,L-80,ID=8.681" —1 7982' / 10644' H4-1/2"HES X NP,0=3.813" 10665" —{7"X 4-1/2"BKR S-3 PKR,D=3.875" rj r 10688' H4-1/2"HES X NIP,D=3.813" 10707' H4-1/2"FES XN NP,D=MLLED to 3.80" 1 14-1/2"TBG,12.6#,13-CR,.0152 bpf,ID=3.958" —1 10720' 10713' 1-14-112°WLEG, D=3.958" 7"LW,26",L-80,.0383 bpf, D=6.276" —I 10855' l M 10716' —17"X 5"BKR LTP 1 13-1/2"LNR,8.81#,L-80,STL,.0087 bpf,D=2.992" —1 11353' 10733' H5"X 4-1/2"XO I 14-112"LINZ,12.6#,13-CR.0152 bpf,D=3.958" H 11949' I I 11294' H BKR KB LT PKR,D=2.37" I 1/ /1 4-1/2"BKR MONOBORE W IPSTOCK-1 11950' �1 11 11300' H3-1/2"DEPLOYMENT SLEEVE,D=2.30" 1 ! PERFORATION SUMMARY 11 11 11364' —13-1/2 x 33116"XO,D=2.80' REF LOG: SLB M]'&ON 10/20/09 141 1•1 ANGLE AT TOPPERF: 91°©12610' �� 14, 4-1/2"MLLOUT WNDOW(H-05B) 11949'-11958' Note:Refer to Production DB for historical pert data •�;� SIZE SR INTERVAL Opn/Sqz SHOT SQZ 4`44 1.56" 6 12610-12640 0 05/11/13 [ 12606' ]—I 3-3/16 x 2-7/8"XO,D=2.377" I 2" r 6 12695-12755 0 09/09/13 1.56" 6 12810-12840 0 05/10/13 I 13089' 112-7/8'CDP(05/09113)I 2" ' 6 12885-12915 0 09/09/13 A Nit 2-7/8" ' 6 13170-13700 C 10/22/09 2-7/8" ' 6 13800-13979 C 10/22/09 4 13-3/16"LNR,6.2#,L-80,TCII,.0076 bpi,ID=2.80" — 12505' PBTD —1 14005' 2-7/8"LNR,6.16#,L-80,STL,.0058 bpf,D=2.441" IH 14044' DATE REV BY 001.6ENFS DATE REV BY COW f 'lTS I PRIJDHOE BAY UNIT 02/18/77 ORIGINAL COMPLETION 05/22/13 KJB/JMD SET CEP&SHOT ADFERFS(05/09-1' Wa.L. H-05B 02/18/04 SRB/KAK RIG SIDETRACK(H-05A) 09/13/13 RWWJM) ADPERFS(09/09/13) PvT No:" 091000 10/23/09 NORDIC2 CTD SIDETRACK(H-05B) AR No: 50-029-20106-02 10/25/09 SV DRLG HO CORRECTIONS SEC 21,T11 N,R13E,773'FTL&1265'Fa. 11/06/09 BSE/SV GLV C/O(11/01/09) 08/02/10 PP/SV FINAL DRLG CORRECT1014E BP Exploration(Alaska) STATE OF ALASKA All, KA OIL AND GAS CONSERVATION COMAOION REPORT OF SUNDRY WELL OPERATIONS 1.•Operations Abandon LI Repair Well [J Plug Perforations [d . Perforate [✓J , Other L 5 c e 1 13 a Performed: Alter Casing ❑ Pull Tubing Stimulate - Frac ❑ Waiver ❑ Time Extension❑ OA% Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ to / L ¢/ 1.3 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development IS . Exploratory ❑ 209 -100 -0 • 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029- 20106 -02 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028284 PBU H -05B • 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 14044 feet • Plugs measured None feet true vertical 9026.14 feet Junk measured None feet Effective Depth measured 13090 feet Packer measured See Attachment feet true vertical 9021.93 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 81 30" Conductor 19 - 100 19 - 100 0 0 Surface 2281 18 -5/8" 96.5# K -55 18 - 2299 18 - 2297.95 930 870 Intermediate 2234 13 -3/8" 68# K -55 17 - 2251 17 - 2249.95 3450 1950 Production 7985 9 -5/8" 47# L -80 17 - 7982 17 - 6409.37 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment (RECEIVED Perforation depth Measured depth 12810 - 12840 feet 13170 - 13700 feet 13800 - 13979 feet True Vertical depth 9021.63 - 9021.6 feet 9024.65 - 9024.26 feet 9027.36 - 9025.23 feet JUN 0 4 2 013 Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 15 - 10720 15 - 8446.55 ICC 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 JUN 19 2013 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 742 22438 252 0 1293 Subsequent to operation: 15 3744 60 0 703 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratorE❑ Development 0 ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Gas ❑ WDSPL[J GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC0 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.Summer •Printed Na - ■ -_ _ - - __ Title Petrotechnical Data Techncian Si.-- r, Lr. �� Phone 564 -4035 Date 6/4/2013 VL 04(9 RBDMS JUN -7 2013\ 4,1/4113 Form 10-404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028284 CTU #8 1.75" CT. Job Scope: Drift, PPROF /GH• V 1 orax, Contingent CIBP set & addperfs; AOL , Permit with Pad operator, RU, Double barrier no -flow test, Function test BOP's. MU Baker CTC 1.9 ", MHA 1.69 ", x -over 1.73 ", 2- MBT 2 ", 2 -MBT 1.75 ", x -over 2.150 ", JSN 2.2" (OAL 17.4), RIH with Drift. Tagged 13930 ft, PUH and flag pipe @ 13860' and POOH, L/D drift & Tag assy. Trouble shoot the eletronic counter, P/U PDS 24 -arm caliper assy. 5/5 /2013 * ** **Continued in WSR of 05/06/2013* * * ** * * ** *Continued from WSR of 05/05/2013 * * * ** CTU 8, 1.75" coil. Job scope: Drift, PPROF /GHOST & MCNL Borax, Contingent CIBP set & addperfs PT Lube, RI W/ PDS 24 -arm caliper assy to flag. PDS caliper log run tool failure data no good. RIH w /SLB PPROF w /GHOST & DEFT tools. BHA: Baker CTC 1.9 ", MHA 1.69 ", ported x -over 1.53 ", SL Knuckle joint 1.55 ", PPROF /GHOST & depth tools 1.69 ", (OAL 25.78). Performed up logging pass 40 fpm, Coil locked while RBIH, SI the well & RBIH, CT locked up before flag 13883', could not move the coil up or down until opened the well to production and pumped 15 bbls down the coil. Coil locked again at same depth (13883'), pumped 50 bbls of safe lube + 31 bbl freeze protect. well could not flow, unloaded the well, WHFP is going up. * * ** *Continued in WSR of 05/07/2013 * * * ** 5/6/2013 * * ** *Continued from WSR of 05/06/2013 * * * ** CTU 8, 1.75" coil. Job scope: Drift, PPROF /GHOST & MCNL Borax, Contingent CIBP set & addperfs Continued trials to get coil down to the flag depth to do the 2nd flowing pass, finally reached the flag depth, waited for 2:10 hrs to stabilize the rate, performed the 2nd up pass, had to SI the well to go back to the flag depth, opened the well and waited for another 2 hrs to stabilize the rate, performed the 3rd flowing up pass to 11200', recorded 7 stationary stops, flagged the pipe @ 13049.6 Electronic CTM, POOH & L/D PPROF tools, download data and sent to town, wait on decision, M/U MCNL tool & RIH, fluid Pack the well during RIH * * ** *Continued on WSR of 05/08/2013 * * * ** 5/7/2013 * * ** *Continued from WSR of 05/07/2013 * * * ** CTU 8, 1.75" coil. Job scope: Drift, PPROF /GHOST & MCNL Borax, Contingent CIBP set & addperfs: fluid packed the well while RIH with MCNL begin logging passes. 30 FPM baseline pass & repeat pass 60 FPM, MCNL log w /borax across perfs 60 FPM & repeat pass. POOH. Good data, FP flow line. flush borax, make up PDS caliper and rih 5/8/2013 * ** *continue on 5 -9 -13 WSR * * ** • • Daily Report of Well Operations ADL0028284 * * ** *Continued from WSR of 05/08/2013"* * ** CTU 8, 1.75" coil. Job scope: Drift, PPROF /GHOST & MCNL Borax, Contingent CIBP set & addperfs: RIH w/ PDS caliper sat down in station # 3 @ 7955'ctm, unable to work thru, pooh and reconfigure tools. RIH. Taking wgt in #3 GLM, many attempts varying pumprates running speeds etc, no success, POOH before Caliper opens. Discuss w /town, will not run caliper, will run jewellry log in 2.2" carrier for depth correlation & verify GLM #3 is good for running CIBP. RD Caliper, cut 100' pipe, change pack offs, chain inspection. MU BOT /PDS Jewelry logging string, 2.25" x 14.42' OAL, RIH. Past #3 station OK, RIH to 13,590' & log up to 11,200' @ 40 FPM. POOH. make up CIBP rih. 5/9/2013 * ** *continue on 5 -10 -13 WSR * ** * * ** *Continued from WSR of 05/09/2013 * * * ** CTU 8, 1.75" coil. Job scope: Drift, PPROF /GHOST & MCNL Borax, Contingent CIBP set & addperfs: Set 2 7/8" CIBP @ 13090'md mid ele, top of plug @ 13089'md, POOH RD setting tools, perform weekly BOP TEST. RU BOT MHA & SWS TCP 30' gun assembly, 1.56" x 6 spf x 1606 PJ, PT & RIH. Shoot first interval © 12,810'- 12,840',. POOH. noticed some cracks in the reel hub spokes, rig down for repairs. * *continue on 5 -11 -13 wsr ** 5/10/2013 * * * * ** *Continued from WSR of 5/10/2013 * * * * * * * ** Finish freeze protect and rig down. head to yard for reel repair 5/11/2013 * *job incomplete * ** CT U #3 - 1.75" Coil Job Scope: Add Perf MIRU CTU. Make up 30' of 1.56" HSD guns, 6spf. RIH, Tag the plug © 13093.4', rest the counter to 13088.3', PUH to the ball drop posiyion, dropped the ball, PUH to the shoot depth, Gun fired after 30.7 bbls...perforated 12610'- 12640', POOH, freeze protected 2500 ft of the well, confirmed the gun is fired, L/D the gun assy, RDMO 5/12/2013 * ** *Job complete * * ** FLUIDS PUMPED BBLS 37 METH 191 1% KCL W /SAFELUBE 481 60/40 METH 867 1% KCL 250 BORAX 1826 TOTAL Casing / Tubing Attachment ADL0028284 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 30" Conductor 19 - 100 19 - 100 INTERMEDIATE 2234 13 -3/8" 68# K -55 17 - 2251 17 - 2249.95 3450 1950 LINER 10839 7" 26# L -80 16 - 10855 16 - 8548.44 7240 5410 LINER 1236 4 -1/2" 12.6# 13Cr80 10713 - 11949 8441.33 - 9024.08 8430 7500 LINER 59 3-112"8.81#L-80 11294 - 11353 8868.2 - 8907.86 LINER 1152 3- 3/16" 6.2# L -80 11353 - 12505 8907.86 - 9023.66 LINER 1539 2 -7/8" 6.16# L -80 12505 - 14044 9023.66 - 9026.14 13450 13890 • PRODUCTION 7965 9 -5/8" 47# L -80 17 - 7982 17 - 6409.37 6870 4760 SURFACE 2281 18 -5/8" 96.5# K -55 18 - 2299 18 - 2297.95 930 870 TUBING 10705 4 -1/2" 12.6# 13Cr80 15 - 10720 15 - 8446.55 8430 7500 • . • Packers and SSV's Attachment ADL0028284 SW Name Type MD TVD Depscription H -05B PACKER 7843 6241.87 7" Top Packer H -05B PACKER 10665 8332.87 4 -1/2" Baker S -3 Perm Packer H -05B PACKER 10716 8370.73 5" Baker ZXP Top Packer H -05B PACKER 11294 8795.37 Baker Liner Top Packer TREE 4 -1/16" WELLHEAD = MCEVOY • SAS: ** *4 -112" CHROME TBG & LNR*** ACTUATOR N 1Y H-05B nAL KB.ELE 644.13' BF. EL-EV = 44.68' KbP = 7987 Max Angle = 94" € 11745' I�tumMD= 11301' • ■ •' I 1066' H9-5/8" X 13 -318" EST TOP OF CEMENT I • Datum IV ID = 8800' SS : I 1 •: I 2209' H 4-1/2" HES X NP, D = 3.813" I 19-518 CSG TIEBACK Wt BOT KIR H 2130' ■ • •� ■ • 113 -3/8" CSG, 68#, K -55, D = 12.415" H 2251' 1 ►� • � • ! � � • ' 2261' I–j 13 -3/8" X 9-518" XO, D = 8.681" I 118 -5/8" CSG, 96.5#, K-55, D = 17.655" H 2299' 1 1 GAS TYPE MANDRELS [1 ST MD TVD DEV TYPE VLV LATCH FORT DATE Minimum ID = 2.30" 11308' 5 3276 3238 28 KBG-2 DOME BK 16 11/01/09 LINER BUSHING 4 5779 4929 50 KBG•2 SO BK 20 11/01/09 3 7929 6373 47 KBG-2 DMY BK 0 02/11/04 2 9291 7371 44 KBG-2 OW BK 0 02/11/04 ITOPOF 7" SCAB LM (ESTNIATED) IH 6830' I 1 10491 8276 41 KBG-2 DMY BK 0 02/11/04 ■ ■ 17" SCAB LM2, 26", 1 -80, D = 8.276' H 7830' ■ 7843' H8-5/8" X 7" BKR LNR TOP PKR ! 9-5/8" MLLOUT WPDOW (H -05A) 7982' - 7998' I 9-5/8" CSG, 47 #, L-80, D = 8.681" H 7982' 10644' H4 -1/2' FIE a X NP, D = 3.813" I 10665' H7" X 4 -1/2" BKR S-3 PKR, D = 3.875" I ' I 10688' H41/2 "HE5X = 3.813' I 1070T H4-1/2" FtES XN NP, D = MILLED to 3.80' I 141/2" TBG, 12.6#, 13-CR, .0152 bpf, D= 3.958" 10720' 10713' H4- 1/2 "WLEG, D= 3.958' I 1 7" LNR, 26', L -80, .0383 bpf, D = 6.276" 10855' L 10716' H7" X 5" BKR LTP I3 -112" LMT, 8.81 #, 1-80, STL, .0087 bpf, D = 2.992" H 1 1363' 10733' 5" X 4 -1/2" XO 14 -1/2" LNR, 12.6#, 13-CR, .0152 bpf, D = 3.958" H 11949' , , 11294' BKR KB LT RCR, D = 2.37" I .I r 4-1/2" BKR MONOBORE W * STOCK 11950' �1 ►� 11300' -- 13-1/2' DEPLOY MENT SLEEVE, D = 2.30* I I !i ►• ►., 1 11354' H3 -1/2 -3116' XO, D= 2.80" I FERFORATI N SUMMARY ►• ►• REF LOG: SWS -MCNL ON 10/21/09 ► I ► , I ► • I • , 4-1/2" MLLOUT~OW (H-050) 11949' - 11958' 1 ANGLEAT TOP FEW: 91° c 12610' Note: Refer to Production DB for historical perf data '4`v4 (SIZE SW TERVAL Op 1 12606' I 3 -3/16 x 2 -7/8" XO, D = 2.377" 1.56" 6 12610 - 12640 O 05/11/13 , i 1 1.56" • 12810 - 12840 0 05/10/13 N. 13089' 1- -t2 -7/8' CBP (05/09/13) 2-/8 " 6 170- s i 1�l� "- `�♦ 2 -7/8' 6 13800 - 13979 C 10/22109 • 4 13- 3/16" LNR, 8.2#, 1-80, TCN,.0078 bpf, D = 2.80" H 12606' I R3TD 14006' I2 -7/8 LNR, 6.18 #, L -80, STL, .0058 bpf, D = 2.441" H 14044' I DATE REV BY COMI4 ITS DATE REV BY CONVENTS I PR DHOEBAY WIT 02/18177 ORIGINAL COMPLETION 05/22/13 KJB/JMD SET CBP & SHOT ADPERFS (05109 -1' WELL H-05B 02!18/04 SRB/KAK RIG SIDETRACK (H-05A) PERMT No: "2091000 10/23/09 NORDIC2 CTD SIDETRACK (11-050) AR No: 50 -029- 20106 -02 10/25/09 SV DRLG HO CORRECTIONS SEC 21, 711N, R13E, 773' FNL & 1265' Fla 11/06/09 BSEJSV GLV CJO (11/01/09) 08/02/10 RYSV FNAL DRLG L"TlOP BP Exploration (Alaska) • 1 bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18,2012 a /C O b- os Mr. Jim Regg �-4 t e /2 AGE � 10t�, Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB H -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad H 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) Date: 03/17/2012 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 na gal H -01A 1951100 50029200990100 0.7 NA 0.7 NA 5.10 2/17/2010 H -02A 2021600 50029201000200 0.5 NA 0.5 NA 5.10 2/16/2010 H -03 1710190 50029201030000 0.2 NA 0.2 NA 1.70 2/16/2010 H-04A 2031610 50029201040100 0.3 NA 0.3 NA 3.40 2/14/2010 H -05B 2091000 50029201060200 0.3 NA 0.3 NA 5.10 3/9/2010 H -06 1770020 50029202380000 0.1 NA 0.1 NA 0.85 2/16/2010 H -07A 2001280 50029202420100 0.6 NA 0.6 NA 3.40 2/15/2010 H -08 1770230 50029202470000 0.4 NA 0.4 NA 3.40 2/15/2010 H -09 1800640 50029204820000 21.6 5.0 0.8 7/12/2010 3.40 7/8/2011 H -10A 1971900 50029204870100 0.3 NA _ 0.3 NA 1.70 2/19/2010 H -11 1800680 50029204850000 0.3 NA 0.3 NA 1.70 2/18/2010 H -12 1800670 50029204840000 0.3 NA 0.3 NA 1.70 2/18/2010 H -13A 2090440 50029205590100 0.1 NA 0.1 NA Trace 2/18 /2010 H -148 2071160 50029205800300 0.1 NA 0.1 NA Trace 2/18/2010 H -15 1810610 50029205910000 0.4 NA 0.4 NA 3.40 2/18/2010 H -16 2000650 50029205920200 0 NA NA NA NA NA H -17A 1971520 50029208620100 21.5 6.0 0.4 7/12/2010 1.70 7/8/2011 H -18 1822100 50029208800000 0.1 NA 0.1 NA 0.50 2/27/2010 H -198 1980940 50029208830200 3.5 NA _ 3.5 NA 23.80 2/24/2010 H -20 1830070 50029208960000 6.7 NA 6.7 NA 47.60 2/22/2010 H -21 1860710 50029215750000 0.5 NA 0.5 NA 3.40 2/15/2010 H -22A 1970480 50029215880100 0.1 NA 0.1 NA 0.85 2/15/2010 H -23A 1950850 50029217940100 5 NA 5 NA 32.30 2/17/2010 H -24A 2071330 50029215120100 0.7 NA 0.7 NA 3.40 2/28/2010 H -25 1852680 50029214780000 0.1 NA 0.1 NA 0.85 2/26/2010 H -26 1852770 50029214870000 2.3 NA 2.3 NA 17.90 2/23/2010 H -27A 2030590 50029214560100 0.1 NA 0.1 NA 0.85 2/21/2010 H -28 1880440 50029218060000 0.5 NA 0.5 NA 3.40 2/17/2010 H -29A 1980380 50029218130100 5.2 NA 5.2 NA 57.80 2/16/2010 H -30 1880350 50029218000000 1.7 NA 1.7 NA 11.90 2/16/2010 H -31 1940140 50029224440000 0.7 NA 0.7 NA 5.10 2/18/2010 H -32 1940250 50029224490000 0.3 NA 0.3 NA 1.70 2/18/2010 H -33 1940380 50029224580000 0.1 NA 0.1 NA 1.70 2/16/2010 H -34 1971640 50029228030000 1.3 NA 1.3 NA 13.60 2/19/2010 H -35 1951490 50029226000000 1.7 NA 1.7 NA 15.30 2/16/2010 H -36A 2000250 50029226050100 1.3 NA 1.3 NA 11.90 2/17/2010 H -37A 2000970 50029227720100 1.2 NA 1.2 NA 10.20 2/20/2010 H -38 2081670 50029234020000 Dust cover NA NA NA NA 3/17/2012 DATA SUBMITTAL COMPLIANCE REPORT 1/13/2011 Permit to Drill 2091000 Well Name /No. PRUDHOE BAY UNIT H -05B Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 20106 -02 -00 MD 14044 TVD 9026 Completion Date 10/23/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey OP DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, RES, GR, CCL, MCNL (data taken from Logs Portion of Master Well Data Maint • Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / T e Med /Frmt Number Name Scale Media No Start Stop CH Received Comments Rpt LI Verification 11605 14039 Open 1/13/2010 LIS Veri, GR, ROP, RPS, L S RPD, RAS, RAD D C 1914 Induction /Resistivity 11605 14039 Open 1/13/2010 LIS Veri, GR, ROP, RPS, RPD, RAS, RAD g Induction /Resistivity 25 Col 11950 14044 Open 1/13/2010 MD MPR, GR og Induction /Resistivity 25 Col 11950 14044 Open 1/13/2010 MD GR og Gamma Ray 5 Col 11590 14090 Open 1/13/2010 Depth Shift Monitor Log og Neutron 2 Blu 10254 13771 Case 1/13/2010 MCNL, Mem LEE, CCL, GR, TNF, TNN D C Lis 192074utron 10247 13779 Case 1/13/2010 LIS Veri, GR, CNT D C Directional Survey 11933 14044 Open 11933 14044 Open • t Ne Directional Survey Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments 1 DATA SUBMITTAL COMPLIANCE REPORT 1/13/2011 Permit to Drill 2091000 Well Name /No. PRUDHOE BAY UNIT H -05B Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 20106 -02 -00 MD 14044 TVD 9026 Completion Date 10/23/2009 Completion Status 1 -OIL Current Status 1 -OIL UIC N ADDITIONAL. INFORMATION (� �� Well Cored? Y / j Daily History Received? 5 1111-- Chips Received? ?f?T7` Formation Tops Analysis �Gl# R • eceived? Comments: Compliance Reviewed By: _. 7 Date: _ . J d • Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 4® Alaska Oil & Gas Cons Comm Anchorage, AK 99503 - 2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD Z -08A B581-00015 PRODUCTION PROFILE / 93 -lai / di 10/25/09 1 1 3- 27/M -33 B8K5 -00012 PRODUCTION PROFILE / 1(o — •' /1.,91 1/18/09 1 1 2- 34/P -14 AWJI -00061 MEM INJECTION PROFILE 0.7, b{;(,, -�'3 /,91* 12/01/09 1 1 S -213A 881(5 -00007 GAS LIFT SURVEY ( :) , 0c/ — / / 10/26/09 1 1 V -227 B69K -00036 USIT C ZC aA9 - / / (o / 11/19/09 1 1 06 -18• 82ND -00033 MCNL 4{) c3 _ (,3 /aja cc/ 10/12/09 1 1 L3 -11 AP3Q -00065 RST — — a t 3 I' 10/31/09 1 1 Q -04B B2NJ -00036 MCNL � —/ 0 i /9 a at. 11/04/09 1 1 H -05B B2WY -00033 MCNL A . — ! 0 A „ • 10/20/09 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Ili Petrotechnical Data Center LR2-1 2525 Gam6ell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 1 a„ fi .., it , 4. i . \.N 13 010 • INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7 Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: H-05B 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) L 1 color print — MPR/Directional Measured Depth Log (to follow) LAC Job#: 2818465 _ . Sent by: Catrina Guidry Date: 01/11/10 Received by Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 1,42J 7260 Homer Drive BAKER Anchorage, Alaska 99518 Doq-IOC HUGHES Direct: (907) 267-6612 INTEQ FAX: (907) 267-6623 6374/ • / /111.1 BAKER FUJ U.UES Baker Atlas PRINT DISTRIBUTION LIST COMPANY BP EXPLORATION (ALASKA) INC COUNTY NORTH SLOPE BOROUGH WELL NAME H -05B STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 1/11/2010 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 2818465 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 CORAZON MANAOIS Address LR2 -1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 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 + a : ' £ Company Company A Ni Person Person ' Address Address qtr Data Disseminated By: BAKER ATLAS -PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed By: Page 1 of 1 6 STATE OF ALASKA 0 RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION NUV 1 8 2009 WELL COMPLETION OR RECOMPLETION REPORT 6491149§ Lofts. Commissioe la. Well Status: ® Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended 1b. Well Class: n pfp 20AAC 25.105 20AAC 25110 ® Developm C� LJ E ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other of Completions One ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Conip Susp., or Aband.: f 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 10/23/2009 209 - 100 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 10/8/2009 50 - 029 - 20106 - - 4a. Location of Well (Govemmental Section): 7. Date T.D. Reached: 14. Well Name and Number: 1 Surface: 10/18/2009 PBU H -05B 773' FNL, 1265' FEL, SEC. 21, T11N, R13E, UM 8. KB (ft above MSL): 72.83' Pool(s): Top of Productive Horizon: 15. Field /Pool s 3849' FSL, 3717' FEL, SEC. 16, T11N, R13E, UM GL (ft above MSL): Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): 1 Oil Pool 4200' FSL, 2904' FEL, SEC. 16, T11N, R13E, UM 14005' 9026' NA 27): 10. Total Depth (MD+TVD): 16. Property Designation: 4b. Location of Well (State Base Plane Coordinates, D 27 ) p ( ) Petty 9 Surface: x- 643313 y - 5960015 Zone- ASP4 14044' 9026' ADL 028284 TPI: x- 640762 y- 5964590 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 641568 Y 5964956 Zone- ASP4 None 18. Directional Survey: IS Yes ❑ No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: MWD DIR, GR, RES, GR / CCL / MCNL 11950' 9024' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE To ( BOTTOM To BOTTOM SIZE CEMENTING RECORD PULLED See Attached See Attached 24. Open to production or injection? _4 Yes ❑ No 25. TUBING RECORD If Yes, list each interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD / TVD) 2" Gun Diameter, 6 spf 4 -1/2 ", 12.6#, 13Cr80 10720' 10665' / 8406' , MD TVD MD TVD 13170' - 13700' 9025' - 9024' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13800' - 13979' 902T - 9025' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 2200' Freeze Protected w/ Diesel 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): November 7, 2009 Flowing Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: 11/6/2009 4 Test Period 4 309 706 207 176 2,287 Flow Tubing Casing Press: Calculated OIL -BBL: GAS-MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 240 820 24 - Hour Rate ♦ 1,852 4,235 1,242 38 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical resultspper 20 AAC 250.071. }•d ..., None - Form 10-407 Revised 07/2009 CONTINUED ON REVERSE l 1 Submit Original Only 29. GEOLOGIC MARKERS (List all formations and m rs encountered): 30. •ORMATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Zone 2A 13145' 9024' None Formation at Total Depth (Name): Zone 2A 13145' 9024' 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. / Signed: Terrie Hubble .A kJcJ 4 . J 6 <' Title: Drilling Technologist Date: PBU H -05B 209 -100 Prepared By NamelNumber. Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Ron Phillips, 564-5913 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service Wells: Gas Injection, Water Injection, Water- Altemating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing 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. Item 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 TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 07/2009 Submit Original Only 1 WELL NAME: H -05B 22. Attachment - Casing, Liner and Cementing Record Casing Setting Depth MD Setting Depth TVD Hole Size Wt. Per Ft. Grade Top Bottom Top Bottom Size Cementing Record 30" Conductor Surface 100' Surface 100' 36" 265 sx Permafrost II 18 -5/8" 96.5# K -55 Surface 2299' Surface 2299' 24" 6200 sx Permafrost II 13 -3/8" x 9 -5/8" 68# / 47# K -55 / N -80 Surface 7982' Surface 6407' 12 -1/4" 875 sx Class 'G' (& 465 sx AS I) 9 -5/8" x 10 -3/4" 47# / 55.5# L -80 / N -80 28' 2255' 28' 1942 12 -1/4" 9 -5/8" Tieback: 392 sx Arcticset I 7" 26# L -80 / N -80 26' 10855 26' 8548' 8 -1/2" 169 sx Class 'G', 140 sx Class 'G' 4 -1/2" 12.6# 13Cr80 10705' 11950' 8435' 9024' 6 -1/8" 225 sx Class 'G' 3 -1/2" x 3- 3/16" 9.3# / 6.2# / x 2 -7/8" 6.16# L -80 11294' 14044' 8868' 9025 4 -1/8" 155 sx Class 'G' BP EXPLORATION Page 1 of 15 Operations Summary Report Legal Well Name: H -05 Common Well Name: H -05 Spud Date: 9/27/1971 Event Name: REENTER +COMPLETE Start: 10/1/2009 End: 10/23/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/4/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 10/5/2009 00:00 - 02:00 2.00 MOB P PRE CONTINUE TO WAIT ON SECURITY. CLEAN UP AROUND WELL HEAD AREA. CONTINUE TO LOAD SUPPORT TRAILERS. 02:00 - 02:30 0.50 MOB P PRE PJSM REGARDING MOVING THE RIG W/ SECURITY. 02:30 - 06:00 3.50 MOB P PRE MOVE RIG FROM D PAD TO SPINE ROAD. TURN ONTO SPINE ROAD. HEAD TOWARDS GC2 ACCESS ROAD. 06:00 - 06:45 0.75 MOB P PRE CHANGE OUT CREWS AT GC2 -SPINE INTERSECTION. 06:45 - 09:00 2.25 MOB P PRE CONTINUE TO MOVE TO H -PAD. 09:00 - 12:00 3.00 MOB P PRE RIG ON LOCATION AT 0900. WAIT ON RIG MATS ETC. SPOT CAME AND PREP AROUND TREE. SPOTS HERCULITE AND MATS. 12:00 - 15:00 3.00 MOB P PRE MOVE RIG OVER WELLHEAD. PREP CELLAR. SET DOWN RIG. ACCEPT RIG AT 12:30. INSTALL TREE SCAFFOLD LADDER. RU PLYWOOD OVER CELLAR HOLE. 15:00 - 19:30 4.50 PRE PJSM REGARDING NU BOPE. ND TREE CAP. NU BOPE. RU ANNULI GAUGES. FILL BOP & SHELL TEST, 250PSI /3500PSI. 19:30 - 00:00 4.50 BOPSUF P PRE TIGHTEN CHOKE LINE GREY -LOC FITTING. TEST BOPE PER AOGCC REGS 250PSi /3500PSI. JEFF JONES FROM AOGCC WAIVED WITNESS TO TEST. 10/6/2009 00:00 - 03:00 3.00 BOPSUF P PRE CONTINUE TO TEST BOPE PER AOGCC REGS TO 250PSI /3500PSI - PASS. 03:00 - 03:15 0.25 BOPSUF P PRE PJSM REGARDING RU & PULL BPV. 03:15 - 04:45 1.50 BOPSUF P PRE OPEN SWAB. OPEN SSV & INSTALL FUSEABLE. RU DSM BPV. PRESSURE TEST 250PSI /1000PSI. OPEN MASTER - VAC. PULL 4" 'H' STYLE BPV. CLOSE MASTER. RD DSM. 04:45 - 04:55 0.17 BOPSUF P PRE PJSM REGARDING PU INJECTOR & STABBING ONTO WELL. 04:55 - 05:45 0.83 BOPSUF P PRE PU INJECTOR & STAB ONTO WELL. FILL COIL. SI & TEST PACKOFFS & INNER REEL VALVE PER AOGCC REGS, ADW SOP, DWOP, PERMIT TO DRILL, AND WELL PLAN 250PSI /3500PS1. 05:45 - 05:55 0.17 KILL P WEXIT PJSM REGARDING MU NOZZLE BHA. 05:55 - 06:20 0.42 KILL P WEXIT MU NOZZLE BHA. STAB ONTO WELL. 06:20 - 08:45 2.42 KILL P WEXIT RIH W/ NOZZLE BHA. ATTEMPT TO KILL WELL BY DUMPING DOWN BACKSIDE & CT, UNABLE WHP IS AT 2400PSI. RIH TO BOTTOM. CONTINUE TO RIH. REDUCE CIRC RATE TO 0.22 BPM. WHP: 720 PSI. 08:45 - 10:00 1.25 KILL P WEXIT BLEED WHP TO ZERO. NO FLOW. CIRC BTMS UP w/ KCL: 2.5 bpm in/ 2.4 bpm out at 2850 psi. Minimal losses. 10:00 - 12:40 2.67 KILL P WEXIT PULL OUT OF HOLE. CIRC AT MIN RATE. 12:40 - 12:50 0.17 KILL P WEXIT PJSM FOR LD OF NOZZLE 12:50 - 13:35 0.75 KILL P WEXIT LD NOZZLE 13:35 - 13:50 0.25 WHIP P WEXIT PJSM FOR PUMPING SLACK AND CUTTING COIL 13:50 - 15:40 1.83 WHIP P WEXIT PUMP SLACK OUT AND CUT 382 FT OF COIL TESTED WIRE -BAD - CLEANED CORROSION OFF OF WIRE TERMINALS IN JUNCTION BOX Printed: 11/2/2009 2:55:03 PM • BP EXPLORATION Page 2 of 15 Operations Summary Report Legal Well Name: H -05 Common Well Name: H -05 Spud Date: 9/27/1971 Event Name: REENTER +COMPLETE Start: 10/1/2009 End: 10/23/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/4/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 10/6/2009 13:50 - 15:40 1.83 WHIP P WEXIT TESTED WIRE - GOOD 15:40 - 18:30 2.83 WHIP P WEXIT INSTALL SLB CTC AND TEST 18:30 - 19:00 0.50 WHIP P WEXIT INSTALL BHI UQC AND TEST MU WHIPSTOCK BHA, 19:00 - 19:15 0.25 WHIP P WEXIT CREW CHANGE 19:15 - 21:35 2.33 WHIP P WEXIT RIH WITH WS BHA WITH EDC OPEN @ MIN RATE AND 75 FPM 21:35 - 22:35 1.00 WHIP P WEXIT LOG FOR GR TIE IN FROM 11,680 FT TO 11,812 FT MADE -42 FT CORRECTION 22:35 - 22:55 0.33 WHIP P WEXIT RIH TO 11,910 FT AND THEN MAKE CCL LOG TO 12,080 FT. 22:55 - 23:20 0.42 WHIP P WEXIT PU TO 11,900 FT AND EVALUATE LOG BEFORE SETTING WS. PU WT = 48,500 #'S TOP COLLAR CO 11,938 FT BOTTOM COLLAR @ 11,980 FT 23:20 - 23:30 0.17 WHIP P WEXIT RIH TO 11,966 FT WITH 30 DEG RT OF HS AND PU TO UP WT OF 48K. ZERO DHWOB CLOSE EDC AND WALK UP PUMP PRESSURE SHEARED OF @ 2000 PSI SET DOWH WITH 4,500 #'S DH WOB. PU CLEAN TOP OF WS SHOULD BE @ 11,950 FT WITH RA TAG 9 FT BELOW TOP OF WS 23:30 - 00:00 0.50 WHIP P WEXIT OPEN EDC AND POOH AT MIN RATE DUE TO FOAMING PROBLEMS WITH KCL IN PITS 10/7/2009 00:00 - 02:00 2.00 WHIP P WEXIT CONTINUE TO POOH @ MIN RATE 02:00 - 02:10 0.17 WHIP P WEXIT PJSM FOR LD BHA WHILE POOH 02:10 - 03:00 0.83 WHIP P WEXIT TAG UP AND FLOW CHECK WELL LD WHIPSTOCK SETTING BHA - TOOLS LOOKED GOOD FOR A NORMAL SETTING SEND OUT BTT WS RUNNING TOOLS 03:00 - 03:30 0.50 STWHIP P WEXIT PU WINDOW MILLING BHA WITH NEW 3.80" WINDOW MILL AND STRING REAMER 03:30 - 05:45 2.25 STWHIP P WEXIT OPEN EDC AND RIH WITH WINDOW MILLING BHA. 05:45 - 06:15 0.50 STWHIP P WEXIT LOG FOR GR TIE IN FROM 11,750 FT TO 11,827 ft MADE - 42 FT CORRECTION 06:15 - 19:30 13.25 STWHIP P WEXIT RIH. 2075 PSI FS AT 2.5 BPM IN /OUT. TAG TOWS AT 11,948.6'. TIME MILL WINDOW FROM 11,948.6' TO 11,956.4' MILL 10' OF NEW FORMATION TO 11968.4' MAKE SLOW PASSES THROUGH WINDOW WITH LITTLE TO NO MW MAKE DRY DRIFT THROUGH WINDOW - CLEAN 19:30 - 22:25 2.92 STWHIP P WEXIT BU SAMPLE HAD GOOD CUTTINGS IN IT. POOH WITH EDC OPEN @ 4 BPM 22:25 - 22:35 0.17 STWHIP P WEXIT PJSM FOR LD OF BHA WHILE POOH 22:35 - 23:10 0.58 STWHIP P WEXIT LD WINDOW MILLING BHA MILLS GAUGED AS 3.78 GO AND 3.79 NO GO 23:10 - 23:35 0.42 DRILL P PROD1 MU TURN BHA ( #3) WITH 3.3 AKO, NO RESS, AND REBUILT HCC BI CENTER WITH "CHEETAH" CUTTERS. Printed: 11/2/2009 2:55:03 PM 0 0 BP EXPLORATION Page 3 of 15 Operations Summary Report Legal Well Name: H -05 Common Well Name: H -05 Spud Date: 9/27/1971 Event Name: REENTER +COMPLETE Start: 10/1/2009 End: 10/23/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/4/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 10/7/2009 23:10 - 23:35 0.42 DRILL P PROD1 AND TEST 23:35 - 23:40 0.08 DRILL P PROD1 PJSM FOR PU OF BHA #3 23:40 - 00:00 0.33 DRILL P PROD1 PU BHA #3 AND STAB ON 10/8/2009 00:00 - 02:40 2.67 DRILL P PROD1 TEST TOOLS WHILE STABED ON RIH WITH BHA #3 WITH EDC OPEN AND AT MIN RATE 02:40 - 03:00 0.33 DRILL P PROD1 LOG FOR GR TIE IN FROM 11,700 FT TO 11,765 MADE -43 FT CORRECTION 03:00 - 03:15 0.25 DRILL P PROD1 PASS THROUGH WINDOW CLEAN AND TAG BOTTOM @ 11,965 FT PU ABOVE THE WINDOW 03:15 - 04:45 1.50 DRILL P PROD1 CIRCULATE IN GEOVIS TO BIT. 04:45 - 05:50 1.08 DRILL P PROD1 PASS THROUGH WINDOW AND SLOWLY DRILL AHEAD TO FEATHER IN BIT WITH 900 #'S DHWOB FS =2130 PSI @ 2.4 BPM WHILE SWAPING HOLE OVER TO GEOVIS CO 11,972 FT DRILL AHEAD NORMAL DHWOB= 1500 #'S & ROP =60 FPH Qp =2.42 BPM @ 2400 PSI SEVXYX =2's SOME 3's CONTINUED TO DRILL WITH ROP'S OF 10 FPH TO 90 FPH AND 300 PSI TO 700 PSI OF MW AND SOME STALLS IN HARD SPOTS DRILLED TO 12.040 FT 05:50 - 07:45 1.92 DRILL P PROD1 CONTINUE TO DRILL AHEAD FROM 12,040 FT. 2130 FS AT 2.45 BPM IN /OUT. ROP VERY SLOW. FREQUENT STALLS. SAMPLE IS 100% CHERT. ATTEMPT SURVEYS OFF BTM. ESTIMATE GETTING 40 DEG D -LEG. SUSPECT THE BIT IS WORN OUT. DRILL TO 12,047'. 07:45 - 10:30 2.75 DRILL P PROD1 PULL ABOVE WINDOW. OPEN EDC. CIRCULATE OUT OF HOLE. HOLD PJSM RE BHA CHANGE. 10:30 - 11:30 1.00 DRILL P PROD1 GET OFF WELL. UNSTAB COIL. REMOVE BIT. PILOT STRUCTURE IS GONE. MU REBUILD HYCALOG SRX3611M -B3 BICENTER ON SAME (3.3 DEG) MOTOR. STAB COIL. TEST TOOLS. GET ON WELL. 11:30 - 13:30 2.00 DRILL P PROD1 OPEN EDC. RUN IN HOLE. 13:30 - 14:30 1.00 DRILL P PROD1 Log gr tie in from 11,720'. Subtract 42' correction. Continue to log RA tag: TOW: 11,949.5' RA TAG: 11,958.5' BOW: 11,958.5' 14:30 - 17:00 2.50 DRILL P PROD1 DRILL AHEAD FROM 12,047'. 2950 PSI FS AT 2.48 BPM IN /OUT. 150 -250 PSI MTR WORK. DHWOB: 2.0- 3.0K #. TOOK OFF DRILLING AT 80 FPH ONCE ON BTM. SEVXYX: 2 17:00 - 18:30 1.50 DRILL P PROD1 WIPER TRIP TO WINDOW. Printed: 11/2/2009 2:55:03 PM BP EXPLORATION Page 4 of 15 Operations Summary Report Legal Well Name: H -05 Common Well Name: H -05 Spud Date: 9/27/1971 Event Name: REENTER +COMPLETE Start: 10/1/2009 End: 10/23/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/4/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT `'Phase Description of Operations 10/8/2009 17:00 - 18:30 1.50 DRILL P PROD1 OPEN EDC. CIRCULATE OUT OF HOLE. 18:30 - 18:45 0.25 DRILL P PROD1 RIG LOST POWER, RESTART GENERATORS AND GET POWER BACK 18:45 - 19:45 1.00 DRILL P PROD1 CONTINUE TO POOH 19:45 - 20:00 0.25 DRILL P PROD1 PJSM WHILE POOH ON LD OF BHA AND CHECKING LAST 200' OF PIPE 20:00 - 21:00 1.00 DRILL P PROD1 POP OF WELL AND INSPECT LAST 200 FT OF COIL LD BHA AND CHANGE PACK OFFS 21:00 - 21:15 0.25 DRILL P PROD1 PJSM FOR PU OF BHA 21:15 - 21:50 0.58 DRILL P PROD1 PU BHA #5 AND STAB ON TEST TOOLS AND HAVING PROBLEMS WITH POWER SUPPLY BREAKER TO MWD TOOLS TRIPING. 21:50 - 22:15 0.42 DRILL N DFAL PROD1 TOUBLE SHOOT PROBLEMS 22:15 - 22:25 0.17 DRILL N DFAL PROD1 PJSM FOR UNSTABING INJECTOR AND TESTING WIRE AND TOOLS. 22:25 - 23:40 1.25 DRILL N DFAL PROD1 UNSTAB INJECTOR AND BREAK OFF TOOLS. TEST E -LINE. GETTING INCONSISTANT RESULTS. TRACED PROBLEM BACK TO FLOW SUB WHICH HAD A BAD SPOT JUST ABOVE THE BOOT ON E -LINE CONECTION IN UQC. CUT AND MAKE NEW CONECTION IN FLOW SUB AND TEST STAB ON INJECTOR AND SURFACE TEST TOOLS 23:40 - 00:00 0.33 DRILL P PROD1 RIH WITH EDC OPEN 10/9/2009 00:00 - 01:45 1.75 DRILL P PROD1 CONTINUE TO RIH WITH EDC OPEN AT 4,000 FT MD START TO JET AT 4 BPM WHILE RIH 01:45 - 02:15 0.50 DRILL P PROD1 LOG FOR GR TIE IN FROM 11,730 FT TO 11,775 FT MADE -42 FT CORRECTION 02:15 - 03:00 0.75 DRILL P PROD1 MAD PASS TURN SECTION WITH RESS TOOL 03:00 - 05:00 2.00 DRILL P PROD1 DRILL AHEAD FROM 12,170 FT WITH FS =2560 PSI @ 2.5 FEATHERED IN BIT FOR FIRST 8 FT HARD SLOW DRILLING WITH 300 TO 500 PSI MW 1,500 TO 3,500 #'s DHWOB 20 TO 75 FPH SEVXYX 2's TO 4's DRILLED TO 12,250 FT 05:00 - 05:55 0.92 DRILL P PROD1 CBU SAMPLE FOR GEO 05:55 - 06:15 0.33 DRILL P PROD1 WAIT ON GEO TO EVAL SAMPLES AND DISCUSS WITH TOWN 06:15 - 09:00 2.75 DRILL P PROD1 DRILL AHEAD FROM 12,170'. 2650 PSI FS AT 2.48 BPM IN /OUT. BHP: 4612 PSI ECD: 9.93 PPG. SEVXYX: 3 -4 PVT: 397 BBLS. IA: 319 PSI, OA:323 PSI. 09:00 - 11:00 2.00 DRILL P PROD1 CONTINUE TO DRILL AHEAD FROM 12,328'. 2550 PSI FS AT 2.57 bpm in/out. SAMPLES SHOW MOSTLY SAND WITH VARYING AMOUNTS OF CHERT AND CEMENTATION. 11:00 - 11:45 0.75 DRILL P PROD1 WIPER TRIP TO WINDOW. 2.55 BPH AT 2.55 BPM. HOLE SMOOTH. 11:45 - 16:00 4.25 DRILL P PROD1 DRILL AHEAD FROM 12,400'. 2550 PSI FS AT 2.52 BPM IN /OUT. 100 -200 PSI MTR WORK 1.0 -2.0 K# DHWOB SEVXYX: 2 -3 ROP: 30 -50 FPH. Printed: 11/2/2009 2:55:03 PM • BP EXPLORATION Page 5 of 15 Operations Summary Report Legal Well Name: H -05 Common Well Name: H -05 Spud Date: 9/27/1971 Event Name: REENTER +COMPLETE Start: 10/1/2009 End: 10/23/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/4/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 10/9/2009 16:00 - 17:15 1.25 DRILL P PROD1 WIPER TRIP TO 10,000'. OPEN EDC. 2950 PSI FS AT 3.4 BPM. PVT: 350 BBLS 17:15 - 17:30 0.25 DRILL P PROD1 LOG GR TIE IN FROM 11,700'. ADD 2' CORRECTION. 17:30 - 17:55 0.42 DRILL P PROD1 CLOSE EDC. RUN IN OPEN HOLE. 17:55 - 22:20 4.42 DRILL P PROD1 DRILL AHEAD FROM 12,550 FT FS =2790 PSI @ 2.5 BPM ECD =10.2 PPG DRILLING @ 12625 FT Qp =2.5 BPM @ 3100 PSI ECD =10.3 PPG DH WOB= 4750 #'S ROP =30 FPH LOTS OF HARD DRILLING DRILLED TO 12,700 FT 22:20 - 23:20 1.00 DRILL P PROD1 WIPER TO WINDOW @ 2.8 BPM 23:20 - 00:00 0.67 DRILL P PROD1 DRILL AHEAD FROM 12,700 FT WITH FS =2700 PSI @ 2.5 BPM 300 -500 PSI OF MW 2500 #'S WOB AND ROP'S OF 20'S TO 60'S STILL KIND OF RATTY AND STACKING DRILLED TO 12,740 10/10/2009 00:00 - 01:00 1.00 DRILL P PROD1 CONTINUE TO DRILL AHEAD FROM 12,740 FT STAKING OUT SEVERAL TIMES AND MAKE BHA WIPERS, STILL GETTING GOOD MW WITH STALLS. DRILLED TO 12,764 FT 01:00 - 02:30 1.50 DRILL P PROD1 WIPER TO WINDOW @ 2.8 BPM @ 30 FPM SEVXYX =3 TO 5 PULL THROUGH WINDOW OPEN EDC AND JET TUBING TO 10,000 FT CO 4.3 BPM RIH @ 4.33/4.92 BPM AND STILL UNLOADING A LOT OF CUTTINGS. 02:30 - 02:45 0.25 DRILL P PROD1 LOG FOR GR TIE IN FROM 11,700 FT TO 11,735 FT MADE + 1 FT CORRECTION. 02:45 - 03:20 0.58 DRILL P PROD1 CONTINUE TO WIPER IN HOLE @ 2.75/3.0 BPM @ 2970 PSI ECD =10.18 PPG 03:20 - 05:00 1.67 DRILL P PROD1 DRILL AHEAD FROM 12,764 FT W/ FS =2970 PSI @ 2.75 BPM DRILL AHEAD @ 30 TO 40 FPH @ 2.8 BPM WITH SEVXYX OF 2 TO 4 DRILLING WITH 300 TO 500 PSI OF MW AND 1500 #'s TO 3500 #'s DH WOB WT'S ARE TRANSFERING MUCH BETTER MORE OF THE SAME WITH HIGH ROP's UP TO 100 FPH AND THEN SHORT HARD SPOTS WITH ROP's OF 10 FPH OR LESS. GENERALLY DRILLING ABOUT 60 FPH @ 12,806 FT APEARS THAT THE BIT IS FINALY DEAD DRILLED TO 12,806 FT 05:00 - 08:30 3.50 DRILL P PROD1 WIPER OUT OF HOLE @ 2.8 BPM IN OPEN HOLE PULL THROUGH WINDOW OPEN EDC AND CONTINUE POOH @ 4.3 BPM. JOG IN HOLE 300'. NO EXTRA CUTTINGS NOTED. HOLD PJSM. 08:30 - 11:00 2.50 DRILL P PROD1 GET OFF WELL. UNSTAB COIL. LD INTEQ TOOLS. HYCLOG "BUTTON" BIT 8 -8 -5. 11:00 - 15:00 4.00 DRILL P PROD1 CUT 114' COIL FOR CHROME MANAGEMENT (RUN #5). Printed: 11/2/2009 2:55:03 PM • • BP EXPLORATION Page 6 of 15 Operations Summary Report Legal Well Name: H -05 Common Well Name: H -05 Spud Date: 9/27/1971 Event Name: REENTER +COMPLETE Start: 10/1/2009 End: 10/23/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/4/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To, Hours Task Code NPT Phase Description of Operations 10/10/2009 11:00 - 15:00 4.00 DRILL P PROD1 TEST E -LINE. SHORT. CUT ADDITIONAL COIL AND WIRE. MU E- CONNECTOR. 15:00 - 16:00 1.00 DRILL P PROD1 MU 1.2 mtr on Inteq tools. Re -run Hyc RAZOR BICENTER. STAB COIL. tEST TOOLS. GET ON WELL. 16:00 - 18:00 2.00 DRILL P PROD1 RUN IN HOLE. OPEN EDC. CIRC AT 2.55 BPM AT 2256 PSI. 18:00 - 18:35 0.58 DRILL P PROD1 CONTINUE TO RIH FROM 9,275 ft WITH EDC OPEN AT 4.3 BPM & 3600 PSI 18:35 - 18:55 0.33 DRILL P PROD1 LOG FOR GR TIE IN FROM 11,700 MADE -43 FT CORRECTION 18:55 - 19:45 0.83 DRILL P PROD1 CONTINUE TO RIH CLOSE EDC PASS THROUGH WINDOW AND WIPER IN 2.7 BPM © 3000 PSI 19:45 - 23:20 3.58 DRILL P PROD1 TAG BOTTOM © 12,803 FT FS =3040 PSI @ 2.8 BPM FEATHER IN BIT TO GET STARTED DRILLED AHEAD GOOD WITH 200 TO 500 PSI OF MW ROP'S OF 50 FPH TO 90 FPH ANY FASTER AND WE STALL 1000 #'S TO 2000 #'S DH WOB SEVXYX OF 2 TO 3 WHILE DRILLING AND OFF BOTTOM IS 4's DRILLED TO 12.950 FT 23:20 - 00:00 0.67 DRILL P PROD1 WIPER TO WINDOW © 2.8 BPM & 3050 PSI 10/11/2009 00:00 - 00:50 0.83 DRILL P PROD1 CONTINUE WIPEER TRIP © 2.8 BPM & 3100 PSI 00:50 - 05:40 4.83 DRILL P PROD1 DRILL AHEAD FROM 12,950 FT WITH FS =3000 PSI © 2.8 BPM DRILLING WITH 300 to 600 PSI OF MW 1,700 TO 4000 #'S DHWOB ROP'S OF 35 TO 90 FPH - STILL MORE OF THE SAME WITH HARD SPOTS ECD =10.3 PPG AND SEVXYX OF 2's & 3's WHILE DRILLING AND 4'S WHILE OFF BOTTOM HIT A FEW REALLY HARD SPOTS © 13,009 AND 13,018 FT THAT MADE IT LOOK LIKE THE BIT WAS DEAD. EVENTUALLY BROKE THROUGH AND TOOK OFF DRILLING FAST. MORE REALLY HARD STUFF © 13,050 TO 13,052 AND HAVING PROBLEMS STAKING OUT AND NOT SLIDING. DRILLED TO 13,053 FT 05:40 - 06:30 0.83 DRILL P PROD1 WIPER TO WINDOW © 2.8 BPM & 3130 PSI ECD = 10.32 PPG 06:30 - 07:30 1.00 DRILL P PROD1 DRILL AHEAD TO 13,060'. HAVING A LOT OF PROBLEMS WITH SLIDING AND STALLING. BIT AND /OR MUD NEED CHANGING. 07:30 - 10:00 2.50 DRILL P PROD1 WIPER TO WINDOW. OPEN EDC. CIRC OUT OF HOLE AT 3.75 BPM © 3510 PSI. SOME EXTRA CUTTINGS OVER SHAKER, BUT NOT A LOT. HOLE CLEANING APPARENTLY ADEQUATE. 10:00 - 13:00 3.00 DRILL P PROD1 HOLD PJSM. GET OFF WELL. UNSTAB COIL. LD MOTOR AND BIT. MOTOR BEARING LOOSE, HYCALOG NON - BUTTON BIT RINGED OUT 8 -7 -1/4 MU NEW 1.2 DEG INTEQ X -TREME MTR, AND Printed: 11/2/2009 2:55:03 PM • • BP EXPLORATION Page 7 of 15 Operations Summary Report Legal Well Name: H -05 Common Well Name: H -05 Spud Date: 9/27/1971 Event Name: REENTER +COMPLETE Start: 10/1/2009 End: 10/23/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/4/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 10/11/2009 10:00 - 13:00 3.00 DRILL P PROD1 HYCLOGGED SECOND BUTTON BIT. THIS IS THE THIRD BACK TO BACK HYC RUN IN ZONE 2. BUTTON FOLLOWED BY NONBUTTON FOLLOWED BY BUTTON (DIMS BITS #4, #5, #6) STAB COIL. TEST TOOLS. GET ON WELL. 13:00 - 13:30 0.50 DRILL P PROD1 CIRC IN HOLE WITH EDC OPEN. 4.04 BPM IN/4.62 BPM OUT AT 3582 PSI. 13:30 - 14:05 0.58 DRILL N DFAL PROD1 MWD TOOL LOST POWER. UNABLE TO RE -BOOT. POOH WITH BHA. 14:05 - 14:15 0.17 DRILL N DFAL PROD1 PJSM ON UN STABING, TESTING, AND LD OF BHA IF NEEDED 14:15 - 14:40 0.42 DRILL N DFAL PROD1 TEST TOOLS IN WELL WITH TEST CABLE - NO GOOD 14:40- 19:10 4.50 DRILL N DFAL PROD1 LD BHA #7 TO DIAGNOSE TOOLS P &C # 10203755 (NEW) DOSN'T WORK MAKE UP NEW BHA #8 AND SURFACE TEST - PASS 19:10 - 19:20 0.17 DRILL N DFAL PROD1 PJSM WITH CREWS ON PU OF BHA 19:20 - 20:00 0.67 DRILL N DFAL PROD1 PU BHA #8 AND STAB ON SURFACE TEST TOOLS - PASS 20:00 - 21:55 1.92 DRILL P PROD1 RIH WITH EDC OPEN AND Q =4.2 BPM AT 3800 PSI SEVXYX = 0 21:55 - 22:15 0.33 DRILL P PROD1 LOG FOR GR TIE IN FROM 11,740 FT TO 11,775 FT MADE -45.5 FT CORRECTION 22:15 - 23:15 1.00 DRILL P PROD1 CONTINUE TO RIH Q =2.4 BPM WHIL IN OPEN HOLE SEVXYX =2 23:15 - 00:00 0.75 DRILL P PROD1 DRILLED AHEAD FROM 13,060 FT FS =2900 PSI (WITH MUD SWAP ON GOING) DRILLING WITH 300 TO 400 PSI OF MW ABOUT 1500 #'S DHWOB AND A LITTLE CLEANER DRILLING WITH ROP'S IN 75 TO 100 FPH SEVXYX OF 3'S AND 4'S DRILLED TO 13,125 FT 10/12/2009 00:00 - 01:35 1.58 DRILL P PROD1 CONTINUE DRILLING AHEAD FROM 13,125 FT NEW FS =2730 PSI @ 2.5 PSI (MUD SWAP COMPLETE) CONTINUED GOOD DRILLING @ 80 TO 90 FPH W/ 1500 #'s TO 2,500 #'s DHWOB 300 TO 500 PSI OF MW SEVXYX OF 3's AND 4's @13,143 FT MWD TOOLS SHUT DOWN AGAIN. PU OB AND RESET - GOOD TO GO AGAIN AND AGAIN AT 13,175 FT DRILLED TO 13,200 FT 01:35 - 03:10 1.58 DRILL P PROD1 WIPER TO WINDOW @ 2.6 BPM 03:10 - 06:15 3.08 DRILL P PROD1 FS =2850 PSI @ 2.5 BPM DRILLE AHEAD FROM 13,200 FT EASY BOP'S START OUT @ 80 FPH BUT SLOWING DOWN AS WE GO 200 TO 400 PSI OF MW WITH 2,000 TO 2500 #'S DHWOB SEVXYX STILL 3's AND 4's 06:15 - 08:00 1.75 DRILL P PROD1 MAKE WIPER TRIP TO WINDOW. , 2830 PSI AT 2.53 BPM IN. PVT: 391 BBLS. HOLE SMOOTH Printed: 11/2/2009 2:55:03 PM BP EXPLORATION Page 8 of 15 Operations Summary Report Legal Well Name: H -05 Common Well Name: H -05 Spud Date: 9/27/1971 Event Name: REENTER +COMPLETE Start: 10/1/2009 End: 10/23/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/4/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 10/12/2009 08:00 - 08:45 0.75 DRILL P PROD1 ATTEMPT TO DRILL AHEAD. BIT CONTINUES TO STALL AT ANY THING OVER 20 FPH. 08:45 - 11:30 2.75 DRILL P PROD1 CIRCULATE OUT OF HOLE. 3040 PSI FS AT 2.68 BPM IN. 11:30 - 13:00 1.50 DRILL P PROD1 GET OFF WELL. UNSTAB COIL. LD MOTOR AND BIT. HYCALOG "BUTTON" 2 -2 -1. REPLACE MOTOR. MU 1.2 EXTREME, HYCALOG SRX (NON - BUTTON) BICENTER. STAB COIL. TEST TOOLS. GET ON WELL. 13:00 - 15:00 2.00 DRILL P PROD1 RUN IN HOLE WITH EDC OPEN. CIRC AT 3300 PSI AT 4.0 BPM IN/4.6 OUT. 15:00 - 15:15 0.25 DRILL P PROD1 Log GR tie in. Subtract 43' correction. 15:15 - 16:15 1.00 DRILL P PROD1 RUN THROUGH WINDOW AND OPEN HOLE. HOLE SMOOTH. 16:15 - 18:30 2.25 DRILL P PROD1 DRILL AHEAD FROM 13,553'. , 2850 PSI FS AT 2.52 BPM IN /OUT. 250 PSI MTR WORK. 1.6K# DHWOB. INITIAL ROP WITH NEW HYC BI- CENTER: 40 -50 FPH. DRILLED TO 13,500 FT 18:30 - 20:20 1.83 DRILL P PROD1 WIPER TO WINDOW 20:20 - 23:40 3.33 DRILL P PROD1 DRILL AHEAD FROM 13,500 FT FS =2640 PSI CD 2.5 BPM DRILL WITH 2.5 TO 3.0 DHWOB 500 PSI OF MW ROP =80 + FPH DRII I FD TO 13.650 FT 23:40 - 00:00 0.33 DRILL P PROD1 WIPER TO WINDOW @ 2.5 BPM 10/13/2009 00:00 - 01:50 1.83 DRILL P PROD1 CONTINUE WIPER TO WINDOW @ 2.3/2.5 BPM 01:50 - 04:15 2.42 DRILL P PROD1 DRILL AHEAD FROM 13,650 FT FS =2750 PSI @ 2.45 BPM DHWOB= 1500 #'S & ROP'S OF 60'S REALLY HARD SPOT @ 13,680 CT WT STACKING OUT TRYING TO GET DH WOB. GOT 2600 #'s DHWOB WITH - 6,500 #'s CTWT BROUGHT PUMP RATE TO 2.7 BPM @ 3370 PSI AND LET WORK THROUGH REALLY SLOW SEVXYX =2'S FINALY BROKE THROUGH @ 13,692 AND TOOK OFF DRILLING. REDUCED PUMPS TO 2.4 TO TARGET VIBRATIONS OF CO 03:30/13,725 FT MWD TOOLS FAILED PU OF BOTTOM AND RESET- GO BACK TO DRILLING STALLING AND GRABING @ 13,748 FT WITH 6K OVER PULL. 04:15 - 04:40 0.42 DRILL P PROD1 SHORT WIPER BACK TO 13,450 FT @ 2.4 BPM (REDUCING RATES TO TRY AND CONTROL VIB's) 04:40 - 06:30 1.83 DRILL P PROD1 DRILL AHEAD FROM 13,748 FT WITH FS= 2630 ( 2.45 BPM DRILLING SLOW WITH 2,200 #'S WOB AND 200 TO 300 PSI OF MW. ROP's OF 30 to 50 FPH Printed: 11/2/2009 2:55:03 PM • BP EXPLORATION Page 9 of 15 Operations Summary Report Legal Well Name: H -05 Common Well Name: H -05 Spud Date: 9/27/1971 Event Name: REENTER +COMPLETE Start: 10/1/2009 End: 10/23/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/4/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 10/13/2009 04:40 - 06:30 1.83 DRILL P PROD1 IF WE PUSH IT MUCH HARDER IT STALLS. DRILL TO 13,795'. 06:30 - 09:30 3.00 DRILL P PROD1 WIPER TRIP TO WINDOW. 2688 PSI FS AT 2.49 BPM IN. PVT: 334 BBLS. 09:30 - 11:00 1.50 DRILL P PROD1 BACK ON BTM. ATTEMPT TO DRILL AHEAD. UNABLE TO KEEP FROM STALLING. 11:00 - 14:35 3.58 DRILL P PROD1 WIPER TRIP BACK TO WINDOW. OPEN EDC. CIRCULATE OUT OF HOLE FOR BIT CHANGE. 2860 PSI AT 3.01 BPM IN 14:35 - 15:25 0.83 DRILL P PROD1 PJSM FOR LD OF BHA. TAG UP FLOW CHECK WELL LD BHA. BIT WAS 7 -1 NOSE WAS RINGED OUT, WING WAS STILL GOOD WITH A FEW SMALL CHIPED CUTTERS. 15:25 - 15:45 0.33 BOPSUF P PROD1 FUNCTION TEST BOP's PER WELL PLAN AND AOGCC REGS. 15:45 - 00:00 8.25 DRILL C PROD1 BEGIN SAFETY STAND DOWN PER ADW LEADERSHIP INSTRUCTIONS ASK CREW MEMBERS FOR INPUT ON HOW TO IMPROVE OUR CONTROL OF WORK, HAZARDS /MITIGATIONS OF WORKING ALONE AND EMPHASIZING THAT THERE IS AN URGENCY TO CHANGE ACCEPTED BEHAVIORS FILL HOLE EVERY SIX HOURS W/ LOSS RATE OF -1 BBUHR 10/14/2009 00:00 - 06:30 6.50 DRILL C PROD1 CONTINUE ADW STANDDOWN GATHER INPUT FROM CREW MEMBERS. START TO DEVELOP A SAFE WORKING PLAN HOLE FILL WAS DONE @ 05:30 WITH 3.4 BBLS IN 06:30 - 12:00 5.50 DRILL C PROD1 CONTINUE STANDDOWN WITH DAY CREW yn• 12:00 - 12:15 0.25 DRILL C PROD1 FILL HOLE WITH 4 BBLS S��p F 12:15 - 00:00 11.75 DRILL C PROD1 CONTINUE STANDDOWN S {� r REVISE SAFE WORKING PLAN FILL HOLE AT LEAST EVERY SIX HRS. TOOK 17 BBLS IN 24 HRS 10/15/2009 00:00 - 06:00 6.00 DRILL C PROD1 FINISH REVISION OF SAFE WORKING PLAN BEGIN REVISION OF PROCEDURES FILL HOLE WITH 2 BBLS BFORE CHANGE OUT 06:00 - 18:00 12.00 DRILL C PROD1 CONTINUE WITH SAFETY STAND DOWN REVIEWED THE NORDIC SAFETY PLAN PROPOSAL WITH RIG TEAM AND APPROVED BY RIG CREW. FILLED HOLE WITH 3 BBLS AT 12:00 FILLED HOLE AGAIN @ 17:00 WITH 3.5 BBLS 18:00 - 00:00 6.00 DRILL C PROD1 TELECONFERENCE W/ NORDIC MANAGEMENT PROVIDE ADDITIONAL INFORMATION FOR SAFE WORK PLAN 10/16/2009 00:00 - 06:00 6.00 DRILL C PROD1 WORK ON SAFE WORK PLAN COW PROJECTS UPDATE RIG PROCEDURES FILLED HOLE @ 05:30 WITH 2.5 BBLS 06:00 - 17:30 11.50 DRILL C PROD1 CONTINUE WITH STAND DOWN Printed: 11/2/2009 2:55:03 PM BP EXPLORATION Page 10 of 15 Operations Summary Report Legal Well Name: H -05 Common Well Name: H -05 Spud Date: 9/27/1971 Event Name: REENTER +COMPLETE Start: 10/1/2009 End: 10/23/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/4/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 10/16/2009 06:00 - 17:30 11.50 DRILL C PROD1 ADDED 3 BBLS TO THE HOLE @ 13:45 17:30 - 18:15 0.75 DRILL C PROD1 IMPLEMENTNEW SAFETY PLAN TO SECURE OUR RIG SITE. 18:15 - 19:15 1.00 DRILL C PROD1 CREW CHANGE WEEKLY RIG LEADERSHIP MTG 19:15 - 22:30 3.25 DRILL C PROD1 FINISH PROJECTS RELATED TO START UP 22:30 - 23:10 0.67 DRILL C PROD1 CREW MEETING TO DISCUSS EXPECTATIONS AND LL FROM STAND DOWN 23:10 - 23:30 0.33 DRILL P PROD1 SAFETY MTG RE: ELSM REVIEW NEW PROCEDURE FOR CUTTING CT AND LOADING OUT 23:30 - 00:00 0.50 DRILL P PROD1 RU HYD CUTTER. BEGIN CUTTING CT 10/17/2009 00:00 - 02:00 2.00 DRILL P PROD1 FINISH CUT OFF 100' OF CT. RD CUTTER INSTALL CTC. PT 40K, 4K 02:00 - 03:00 1.00 DRILL P PROD1 INSTALL BHI UQC 03:00 - 04:00 1.00 DRILL P PROD1 MU DRILLING BHA PVT 200 04:00 - 06:05 2.08 DRILL P PROD1 RIH W/ BHA #9 (1.2 DEG W/ USED BI BIT) CIRC THRU BIT 0.30/1010 06:05 - 06:15 0.17 DRILL P PROD1 LOG TIE -IN DOWN FROM 11740' LOSS OF COMMUNICATION WITH HOT 06:15 - 09:10 2.92 DRILL N DFAL PROD1 POOH FOR MWD / HOT FAILURE WHILE POOH HELD SAFETY DISCUSSION WITH CREW TO INSURE UNDERSTANDING & COMPLIANCE WITH NEW C.O.W. PROGRAM ROLLED OUT DURING SAFETY STAND DOWN 09:10 - 09:30 0.33 DRILL N DFAL PROD1 PJSA FOR LD OF BHA & H.O.T. SWAP 09:30 - 10:30 1.00 DRILL N DFAL PROD1 LD BHA & SWAP H.O.T., D.P.S., & E.D.C. 10:30 - 10:45 0.25 DRILL N DFAL PROD1 PJSA FOR PU OF BHA 10:45 - 11:15 0.50 DRILL N DFAL PROD1 PU BHA 11:15 - 13:15 2.00 DRILL N DFAL PROD1 RIH W/ BHA #10 (1.2DEG MTR & USED BI BIT) CIRC THRU BIT 0.76/1500 13:15 - 13:30 0.25 DRILL P PROD1 LOG TIE -IN DOWN FROM 11750' TO 11772 -44.5' CORRECTION RESET DEPTH TO 11728.9 13:30 - 14:50 1.33 DRILL P PROD1 RIH RAN THROUGH WINDOW @ 11949' W/0 PUMPS, NO PROBLEMS RIH TO 12365 & STACKED WT, PU TO 12350' RIH PAST 12365' WITH NO PROBLEMS RIH TO 13794' PU TO 13785' 14:50 - 16:10 1.33 DRILL P PROD1 FRILL AHEAD FROM 13.794 FT FS= 2800 @ 2.5 BPM 1K - 2K WOB & 200 TO 800 PSI OF MW. ROP 20 to 60 FPH DRILL WITH ANYTHING MORE THAN ABOVE & THE MTR STALLS DRILL TO 13,817' 16:10 - 16:30 0.33 DRILL P PROD1 WIPER TRIP TO 13,600' 16:30 - 22:50 6.33 DRILL P PROD1 DRILL AHEAD FROM 13,817' FS= 2800 @ 2.3 BPM 1K - 2K WOB & 200 TO 800 PSI OF MW. ROP 20 to 60 FPH Printed: 11/2/2009 2:55:03 PM • BP EXPLORATION Page 11 of 15 Operations Summary Report Legal Well Name: H -05 Common Well Name: H -05 Spud Date: 9/27/1971 Event Name: REENTER +COMPLETE Start: 10/1/2009 End: 10/23/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/4/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 10/17/2009 16:30 - 22:50 6.33 DRILL P PROD1 DRILL WITH ANYTHING MORE THAN ABOVE & THE MTR STALLS DRILL TO 13,950' 90L 22:50 - 00:00 1.17 DRILL P PROD1 WIPER TO WINDOW WAS CLEAN 10/18/2009 00:00 - 00:30 0.50 DRILL P PROD1 WIPER TO TD WAS CLEAN 00:30 - 06:45 6.25 DRILL P PROD1 DRILL FROM 13950' 2.5313070180L W/ 300 -600 PSI DIFF, 1.3 -2.8K WOB W/ 10.55 ECD AT 90 DEG AT 8952' TVD AT 20-40'/HR ..,1/1 , DRILL TO 14.040' & CALL TD ('� 06:45 - 10:00 3.25 DRILL P PROD1 WIPER TRIP TO INSURE CLEAN WELLBORE FOR LINER RUN WIPER TO 11,935' @2.8BPM OPEN E.D.C. & WIPER UP TO 10,000' @ 4BPM RIH DOWN TO 11,700' 10:00 - 10:25 0.42 DRILL P PROD1 LOG TIE IN FROM 11,700' TO 11,724' +5' CORRECTION RESET DEPTH TO 11729' 10:25 - 12:00 1.58 DRILL P PROD1 CONTINUE WIPER DOWN TO 11,940' CP 4BPM CLOSE E.D.C. & RUN THROUGH WINDOW CONTINUE WIPER DOWN TO TD @ 2.5BPM C(1NFIRM Tn 14 044' 12:00 - 16:40 4.67 DRILL P PROD1 POOH TO 11,938' @2.5BPM OPEN E.D.C. POOH TO 11,278' @ 4BPM PAINT EOP FLAG @ 11,278' PJSM FOR LD OF LATERAL BHA WHILE POOH POOH TO SURFACE 16:40 - 17:40 1.00 DRILL P PROD1 STAND BACK INJECTOR & LD LATERAL BHA 17:40 - 18:30 0.83 DRILL P PROD1 PREP RIG FOR SLACK MANAGEMENT & CREW CHANGE OVER 18:30 - 20:50 2.33 CASE P RUNPRD PUMP SLACK OUT OF CT THREE TIMES AND RECOVER -300' INSTALL BTT CTC. PT 35K, 4K PSI 20:50 - 21:10 0.33 CASE P RUNPRD SAFETY MTG RE: LINER 21:10 - 21:30 0.33 CASE P RUNPRD RU TO RUN LINER 21:30 - 00:00 2.50 CASE P RUNPRD MU 2 -7/8" INDEXING GUIDE SHOE W/ TWO FC'S, LATCH COLLAR AND STAGE COLLAR. RUN A TOTAL OF 48 JTS 2 -7/8" 6.16# L -80 STL LINER W/ CEMENTRALIZERS, 36 JTS 3- 3/16" 6.2# TC11 L -80 LINER W/ CEMENTRALIZERS AND ONE JT OF 3 -1/2" 9.3# L -80 STL LINER 10/19/2009 00:00 - 02:00 2.00 CASE P RUNPRD FINISH MU LINER. MU BTT SELRT ASSY 02:00 - 03:00 1.00 CASE P RUNPRD MU MHA W/ 2 JTS PH6 03:00 - 04:40 1.67 CASE P RUNPRD RIH W/ LINER ON CT CIRC 0.43/900 04:40 - 05:35 0.92 CASE P RUNPRD 11900' 46.5k, 16.0k RIH WITH LINER (10.5K) TO TAG AT 14077' CTD 05:35 - 06:30 0.92 CASE P RUNPRD CIRC 1.53/2600. LOAD 5/8" STEEL BALL AND DISPLACE W/ MUD 2.38/3160 BALL ON SEAT @ 44BBLS, SHEAR @ 3,150PSI PU TO BREAKOVER WT OF 38K 06:30 - 10:00 3.50 CASE P RUNPRD DISPLACE FROM GEOVIS TO 2% SLICK KCL. WITH KCL ALL AROUND Qp= 1.5/1.5 BPM @ 840 PSI Printed: 11/2/2009 2:55:03 PM BP EXPLORATION Page 12 of 15 Operations Summary Report Legal Well Name: H -05 Common Well Name: H -05 Spud Date: 9/27/1971 Event Name: REENTER +COMPLETE Start: 10/1/2009 End: 10/23/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/4/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 10/19/2009 10:00 - 10:25 0.42 CEMT P RUNPRD PJSM WITH ALL CREWS FOR CEMENT JOB 10:25 - 11:20 0.92 CEMT P RUNPRD BATCH UP 15.8 PPG CLASS G CEMENT WITH 3HR 46 MIN PUMP TIME. CEMENT AT WEIGHT @ 11:20 11:20 - 11:50 0.50 CEMT P RUNPRD MOVE TRUCKS AROUND FROM DISPLACEMENT AND SPOT IN CONTAM TRUCK. HOOK UP CONTAM TRUCK AND BUILD VAC. AND PRE LOAD RIG LINES FROM PUMP TO COIL WITH BIO PT LINES CEMENT LINES TO 4,000 PSI. WITH RIG KCL 11:50 - 12:10 0.33 CEMT P RUNPRD LOAD COIL WITH 32 BBLS OF 15.8 CLASS G CEMENT COIL VOL =56 BBLS ZERO IN MM @ 13 PPG * ** (WILL NOT ZERO AGAIN UNTIL CEMENT IN PLACE) * ** ISOLATE COIL AND GIVE CEMENTERS BIO TO CLEAN OUT CEMENT LINE 12:10 - 12:35 0.42 CEMT P RUNPRD DISPLACE CEMENT WITH BIO @ 3 BPM UNTILL WE CATCH UP TO CEMENT. CONTINUE TO DISPLACE CO 2.5 BPM ONCE WE CAUGHT CEMENT @ 50 bbls in 2.5 BPM @ 2000 PSI CO 82 BBLS SLOW TO 1.5 BPM / CP = 980 PSI STOP AT 86 BBLS ON IN MM. FINAL CP = 1230 OPEN BAKER CHOKE 12:35 - 12:45 0.17 CEMT P RUNPRD PU TO BO WT THEN 13 FT CLOSE THE BAKER CHOKE EXHAUST 5 BBLS @ 1.5 BPM & 1100 PSI OPEN BAKER CHOKE AND STING INTO SELRT CLOSE THE BAKER CHOKE 12:45 - 13:00 0.25 CEMT P RUNPRD PUMP @ .7 BPM PLUG SHEARED @ 2500 PSI CONTINUE TO DISPLACE LINER @ 1.5 BPM SLOWING DOWN BEFORE BUMP UP PLUG BUMPED @ 108.7 BBLS PRESSURE UP TO 2700 PSI VS 2000 PSI CP CEMENT IN PLACE @ 13:00 13:00 - 13:15 0.25 CEMT P RUNPRD OPEN BAKER CHOKE WHP =0 PSI & AND CP =OPSI CLOSE BAKER CHOKE & PRESSURE UP TO 850 PSI UNSTING FROM LINER CIRCULATE 5 BBLS @ 1.0 BPM 13:15 - 15:40 2.42 CEMT P RUNPRD POOH KEEPING HOLE FULL WITH THE REST OF THE BIO THEN 2% KCL 15:40 - 15:55 0.25 CEMT P RUNPRD PJSM FOR LD OF LINER RUNNING BHA 15:55 - 16:20 0.42 CEMT P RUNPRD LD LINER RUNNING BHA 16:20 - 16:35 0.25 CEMT P RUNPRD PJSM FOR PASSING SELRT TO THE GROUND & PU MCNL TOOLS TO THE RIG FLOOR 16:35 - 17:00 0.42 CEMT P RUNPRD LD SELRT TO THE GROUND & PU MCNL TOOLS TO THE FLOOR 17:00 - 17:15 0.25 EVAL P LOWER1 PJSM TO RU FLOOR TO PU & RUN MCNL / CLEANOUT BHA Printed: 11/2/2009 2:55:03 PM BP EXPLORATION Page 13 of 15 Operations Summary Report Legal Well Name: H -05 Common Well Name: H -05 Spud Date: 9/27/1971 Event Name: REENTER +COMPLETE Start: 10/1/2009 End: 10/23/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/4/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 10/19/2009 17:15 - 18:00 0.75 EVAL P LOWER1 ( RU FLOOR TO PU & RUN MCNL / CLEANOUT BHA 18:00 - 18:30 0.50 EVAL P LOWER1 CREW CHANGE/SAFETY MTG 18:30 - 19:15 0.75 EVAL P LOWER1 MU 2.3" D331 MILL + 2 -1 /8" MOTOR MU 3 STDS ONTO MILUMOTOR LOAD ADDITIONAL 10 JTS CSH INTO PIPESHED 19:15 - 19:30 0.25 EVAL P LOWER1 SAFETY MTG RE: SOURCE 19:30 - 19:45 0.25 EVAL P LOWER1 MU SWS MCNL CARRIER + LOWER MHA 19:45 - 22:30 2.75 EVAL P LOWER1 MU 42 STDS CSH + 10 SINGLES + UPPER MHA + 2 JTS PH6 COMPRESSIVE STR =500 PSI 22:30 - 23:30 1.00 EVAL N DPRB LOWER1 START CIRC PRIOR TO RIH AND PRESSURED UP CT TO 1700 PSI W/ NO BLEED OFF W/ 1 BBL KCL. LD 2 JTS PH6 + UPPER MHA (WET) AND HAD NO BLOCKAGES 23:30 - 23:40 0.17 EVAL N DPRB LOWER1 SAFETY MTG RE: LD CSH SINGLES /STAND BACK THE REST 23:40 - 00:00 0.33 EVAL N DPRB LOWER1 LD 10 CSH SINGLES 10/20/2009 00:00 - 03:00 3.00 EVAL N DPRB LOWER1 FINISH POOH STANDING BACK CSH (WET STRING) REMOVE SOURCE. LD MOTOR AND MILL. MILL WAS PACKED FULL OF METAL SHAVINGS FROM CT (FROM CHROME TUBING). MILKED MOTOR AND MORE FUILD CAME OUT FROM DRIVE SUB THAN BIT BOX (WEAK MOTOR). ASSUME SOLIDS BACKFLOWED THRU WEAK MOTOR WHILE CSH WAS TIH, THEN PLUGGED MILL WHEN CIRC WAS STARTED 03:00 - 04:30 1.50 EVAL N DPRB LOWER1 WO REPLACEMENT MOTOR 04:30 - 06:30 2.00 EVAL N DPRB LOWER1 MU MILL ON MOTOR + 6 JTS CSH + MCNL IN CARRIER + LOWER MHA TIH W/ 42 STDS CSH 06:30 - 07:45 1.25 EVAL N DPRB LOWER1 CREW CHANGE OUT PJSM FOR MU & RUN OF MCNL / CLEANOUT ASSY 07:45 - 09:00 1.25 EVAL N DPRB LOWER1 FINISH MU OF MCNL / CLEANOUT BHA CUT 15' OF E -LINE THAT WAS HNGING OUT CT BEFROE STABBING INJECTOR 09:00 - 11:20 2.33 EVAL P LOWER1 ESTABLISH CIRCULATION PRIOR TO RIH RIH to 11,231' WT CHECK OF 41K RIH AND TAG TOP OF SELRT PROFILE @ 11,325' UNCORRECTED 11:20 - 12:30 1.17 EVAL P LOWER1 TIME MILL SELRT PROFILE 1'FPH FROM 11,324.9' AND GOT THRU AFTER 30 MIN FS- 2,500PSI 1.4BPM / 2,550PSI DRILL HARD SPOT AT 11327-11330' IN 20 MIN W/ TWO STALLS, THEN WAS CLEAN TO 11380' DUMP 75 BBLS OF CEMENT CONTAMINATED BIOZAN 12:30 - 13:00 0.50 EVAL P LOWER1 REAM AND BACKREAM OVER SELRT AREA. POOH TO LOGGING POINT 13:00 - 15:10 2.17 EVAL P LOWER1 LOG DOWN FROM 10500' 0.75/720 AT 30' /MIN WHILE CIRC PERF PILL TO MILL. TAG AT 14033' CTD 15:10 - 16:15 1.08 EVAL P LOWER1 LOG UP FROM 14033' TO 10500' AT 60' /MIN 0.55/700 WHILE LEAVING FRESH FLO PRO MUD IN LINER 16:15 - 18:00 1.75 EVAL P LOWER1 POH CIRC THRU MILL 18:00 - 18:30 0.50 EVAL P LOWER1 DROP BALL, OPEN CIRC SUB W/ 1400 PSI 18:30 - 22:15 3.75 EVAL P LOWER1 LD 2 JTS PH6 AND UPPER MHA. STAND BACK CSH IN DERRICK. RECOVERED 1/2" BALL. REMOVE SOURCE & Printed: 11/2/2009 2:55:03 PM • . BP EXPLORATION Page 14 of 15 Operations Summary Report Legal Well Name: H -05 Common Well Name: H -05 Spud Date: 9/27/1971 Event Name: REENTER +COMPLETE Start: 10/1/2009 End: 10/23/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/4/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 10/20/2009 18:30 - 22:15 3.75 EVAL P LOWER1 DOWNLOAD DATA. LD MOTOR & MILL. , PBTD = 13,981FT 22:15 - 23:40 1.42 BOPSUF P LOWER1 MU SWIZZLE STICK & JET STACK. 23:40 - 00:00 0.33 BOPSUF P LOWER1 OPEN LOWER BOP RAM DOORS. 10/21/2009 00:00 - 00:45 0.75 BOPSUF P LOWER1 CONTINUE TO OPEN BOTTOM BOP DOORS - CLEAN. CLOSE BOTTOM BOP DOORS. SHELL TEST SAME. 00:45 - 01:10 0.42 BOPSUF P LOWER1 ATTEMPT TO PRESSURE TEST LINER LAP TO 2000PSI - FAILED. LEAK OFF RATE OF 100PSI / 5MIN. RD TEST HOSE. 01:10 - 09:00 7.83 BOPSUF P LOWER1 PERFORM BI- WEEKLY BOPE TEST PER AOGCC REGS 250PSI /3500PSI - PASSED. JOHN CRISP WAIVED WITNESS TO TEST. PHZ 2 09:00 - 09:15 0.25 PERFOB P LOWER1 SAFETY MTG RE: LOAD PERF GUNS INTO PIPESHED 09:15 - 10:30 1.25 PERFOB P LOWER1 LOAD PERF GUNS IN PIPESHED /RU FLOOR TO RUN GUNS 10:30 - 10:45 0.25 PERFOB P LOWER1 SAFETY MTG RE: RUN PERF GUNS 10:45 - 11:00 0.25 PERFOB P LOWER1 START TO MU PERF GUNS AND RECEIVE CALL FROM CLARK OLSEN THAT PHZ 3 IS IMMINENT LD GUN, SI SWAB 11:00 - 11:20 0.33 PERFOB N WAIT LOWER1 SAFETY MTG RE: DISCUSS REMOVAL OF NON ESSENTIAL PERSONNEL (MUD MAN) WHEN LUNCH IS RECEIVED (IN TRANSIT) AND JOB RESPONSIBILITIES WHILE OPERATIONS ARE SD 11:20 - 12:20 1.00 PERFOB N WAIT LOWER1 WOW RECEIVE 2100 GAL LSD AT 1140 HRS 12:20 - 20:00 7.67 PERFOB N WAIT LOWER1 WOW. ALL FLIGHTS CANCELLED UPDATE RIG PROCEDURES MOVE SNOW 20:00 - 20:30 0.50 PERFOB P LOWER1 PJSM REGARDING MU PERF GUN BHA. 20:30 - 00:00 3.50 PERFOB P LOWER1 MU PERF GUN BHA. 39 PERF GUNS + 32 STANDS OF CSH FROM DERRICK, CHECK ALL CONNECTIONS. 10/22/2009 00:00 - 00:45 0.75 PERFOB P LOWER1 CONTINUE TO MU PERF BHA. 00:45 - 03:20 2.58 PERFOB P LOWER1 RIH WITH PERF BHA. PU WT = 43.5K AT TOL. PU WT = 52K AT PBTD & 18K RIW. TAG TWICE AT 14,038FT. CORRECT TO PBTD OF 13,981FT. 03:20 - 03:40 0.33 PERFOB P LOWER1 PERFORATE DRIVE BY STYLE. PERFORATE FROM 13,170FT- 13,700FT & 13,800FT- 13,979FT USING 2" W/ 6SPF GUNS. 8K OVERPULL. 03:40 - 06:30 2.83 PERFOB P LOWER1 POH. FLOW CHECK AT TOL - NO FLOW. CONTINUE TO POH. 06:30 - 09:30 3.00 PERFOB P LOWER1 LD 2 JTS PH6 AND UPPER MHA STAND BACK CSH. PHZ 2/L3 09:30 - 09:45 0.25 PERFOB P LOWER1 SAFETY MTG RE: LD PERF GUNS 09:45 - 13:10 3.42 PERFOB P LOWER1 LD PERF GUNS -ALL SHOTS FIRED LOSING 1 BPH TO FORMATION 13:10 - 14:20 1.17 PERFOB P LOWER1 LOAD OUT PERF GUNS, RD FARR TONGS, CLEAR FLOOR 14:20 - 14:35 0.25 PERFOB P LOWER1 SAFETY MTG RE: CUT CT PHZ 1 L2/3 14:35 - 15:50 1.25 PERFOB P LOWER1 RU HYD CUTTER AND CUT 100' OF CT AND WIRE. INSTALL BTT CTC. PT 35K, 3500 PSI Printed: 11/2/2009 2:55:03 PM • • BP EXPLORATION Page 15 of 15 Operations Summary Report Legal Well Name: H -05 Common Well Name: H -05 Spud Date: 9/27/1971 Event Name: REENTER +COMPLETE Start: 10/1/2009 End: 10/23/2009 Contractor Name: NORDIC CALISTA Rig Release: 10/4/2009 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 10/22/2009 15:50 - 16:00 0.17 PERFOB P LOWER1 SAFETY MTG RE: MU BHA 16:00 - 16:35 0.58 PERFOB P LOWER1 MU POLISH MILL ON 2 -7/8" BTT MOTOR 16:35 - 18:45 2.17 PERFOB P LOWER1 RIH W/ POLISH MILLING ASSY CIRC THRU MILL 0.36/280 18:45 - 19:30 0.75 PERFOB P LOWER1 WET TAG AT 11,312FT WITH 0.25BPM. SLIGHT STRINGER AT TOL. POLISH FROM 11,311.5FT WITH 2.2BPM/1150PSI USING 1% KCL. MAKE MULTIPLE UP & DOWN PASSES. 19:30 - 22:00 2.50 PERFOB P LOWER1 POH PUMPING 2.5BPM/1400PSI TO JET TUBING. RETURNS /BOTTOMS UP ARE CLEAN. 22:00 - 22:30 0.50 PERFOB P LOWER1 TAG UP. FLOW CHECK. POP OFF. SHORT CHAIN BHA. LD MOTOR & POLISH MILL, GOOD INDICATION ON NO -GO, MILK MOTOR. 22:30 - 23:00 0.50 PERFOB P LOWER1 MU KB PACKER BHA. STAB ONTO WELL. SET COUNTERS. 23:00 - 00:00 1.00 PERFOB P LOWER1 RIH WITH KB PACKER BHA, CIRC MIN RATE. 10/23/2009 00:00 - 01:30 1.50 PERFOB P LOWER1 CONTINUE TO RIH W/ KB PACKER BHA, CIRC MIN RATE 0.2BPM /130PSI. WT CK = 51K AT 11210FT, RIW = 18K. 01:30 - 02:30 1.00 PERFOB P LOWER1 INCREASE PUMP RATE TO 0.5BPM /200PSI & STING INTO TOP OF LINER AT 11,330FT. ,STACK 10K DOWN W/ 7FT OF TRAVEL TO 11,340FT. PU TO BREAKOVER, 11,332FT. PU & REPEAT - SAME RESULTS. PU & DROP 5/8" BALL. LANDED AT 58BBLS. RIH TO SETTING DEPTH. PRESSURE UP TO 2000PSI & ENGAGE RUBER ELEMENT. SET 10K DOWN. 02:30 - 03:15 0.75 PERFOB P LOWER1 PRESSURE TEST BACKSIDE TO 2000PSI FOR 30 MIN - PASS. PRESSURE UP TO 3500PSI & SET SLIPS. TOP OF KB PACKER = 11,330FT (UNCORRECTED) 03:15 - 06:00 2.75 PERFOB P LOWER1 POH, CIRC 1.25BPM /440PSI. 06:00 - 07:30 1.50 PERFOB P LOWER1 CREW CHANGE LD BHA AND LOAD OUT KB SETTING TOOL 07:30 - 08:00 0.50 WHSUR P POST MU NOZZLE BHA SAFETY MTG W/ LRS. RU LRS 08:00 - 09:30 1.50 WHSUR P POST JET STACK W/ SIDEJET NOZZLE RIH TO 2200'. POOH WHILE FP WELLBORE W/ DIESEL 09:30 - 10:30 1.00 WHSUR P POST PJSM. MIRU GREASE CREW. SERVICE TREE VALVES. RDMO 10:30 - 12:00 1.50 WHSUR P POST PJSM. MIRU DSM BPV CREW. DRY ROD BPV. RDMO 12:00 - 14:00 2.00 RIGD P POST CLEAN PITS, SUPER SUCK CUTTINGS BOX. (CHILL VAC TRUCKS AND BED TRUCKS WERE DELAYED UNTIL NOW DUE TO WEATHER/ROAD CONDITIONS) 14:00 - 17:30 3.50 RIGD P POST ND BOPE. NU TREE CAP AND PT a 4K 17:30 - 20:45 3.25 RIGD P POST JACK UP RIG. SKID CUTTINGS BOX OUT OF WAY. MOVE WELDING SHOP. IDENTIFY UTILIDOR PLACEMENT & SPOT RIG MATS OVER PAD CROSSING. RIG RELEASE AT 18:30. SAND GC -2 CORNER. 20:45 - 21:25 0.67 RIGD P POST BACK OFF OF WELL. 21:25 - 22:45 1.33 RIGD P POST MOVE RIG MATS & CLEAN UP AROUND WELLHEAD. 22:45 - 00:00 1.25 RIGD P POST MOVE RIG OFF OF H PAD. Printed: 11/2/2009 2:55:03 PM • • • rfr BAKER HUGHES 1NTEQ North America - ALASKA - BP Prudhoe Bay PB H Pad H -05 H -05B Design: H -05B Survey Report - Geographic 22 October, 2009 � bp . Willi • 0 BAICER MUCHIES Survey Report - Geographic 0 bp 1NTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well 1 Project: Prudhoe Bay TVD Reference: H -05A: @ 72.83ft (H -05A:) Site: PB H Pad MD Reference: H -05A: @ 72.83ft (H -05A:) Well: H - 05 North Reference: True Wel!bore: H - 058 Survey Calculation Method: Minimum Curvature Design: H -058 Database: EDM .16 - Anc Prod - WH24P Project Prudhoe Bay, North Slope, UNITED STATES Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB H Pad, TR -11 -13 I Northing: 5, 957,572.25 Site Position: 9� ft Latitude: 70° 17' 30.055 N i! 1 From: Map Easting: 641,366.07ft Longitude: 148° 51' 19.802 W Position Uncertainty: 0.00 ft Slot Radius: 0.000in Grid Convergence: 1.08 L Well H -05 API No 500292010600 Well Position +N / - 0.00 ft Northing: 5,960,015.36 ft Latitude: 70° 17' 53.718 Ni +E / - 0.00 ft Easting: 643,312.65 ft Longitude: 148° 50' 21.725 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Welibore H - 056 API No 500292010602 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( °) (°) (nT) BGGM2009 8/19/2009 22.47 80.91 57,664 Design H -05B Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 11,933.04 Vertical Section: Depth From (TVD) +N/-S +E/ -W Direction (ft) (ft) (ft) r) 28.15 0.00 0.00 341.63 Survey Program Date: 10/22/2009 From To (ft) (ft) Survey (Wel!bore) Tool Name Description 108.70 7,908.70 1 : Camera based gyro multisho (H -05) CB- GYRO -MS Camera based gyro multishot 7,982.00 11,933.04 H -05A MWD (1-1-05A) MWD MWD - Standard 11,949.50 14,044.00 MWD (H -05B) MWD MWD - Standard 10/22/2009 9 :46 :OOAM Page 2 COMPASS 2003.16 Build 71 53. BAILER MOMS Survey Report - Geographic bP 1NTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: ' Well H-05 Project Prudhoe Bay TVD Reference: H -05A: @ 72.83ft (H -05A) Site PB H Pad MD Reference: H -05A: @ 72.83ft (H -05A:) Well: H -05 North Reference: True Welibore: H -058 Survey Calculation Method: Minimum Curvature Design: H -058 Database: EDM .16 - Anc Prod - WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N /-S +E/ -W Northing Easting (ft) (°) ( ^) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 11,933.04 90.49 59.16 9,024.08 4,774.21 - 3,565.30 5,964,720.35 639,657.24 70° 18' 40.664 N 148° 52' 5.721 W TIP 11,949.50 89.48 62.80 9,024.09 4,782.19 - 3,550.91 5,964,728.61 639,671.47 70° 18' 40.742 N 148° 52' 5.301 W KOP 11,974.31 88.86 72.00 9,024.45 4,791.72 - 3,528.03 5,964,738.56 639,694.16 70° 18' 40.836 N 148° 52' 4.634 W 12,008.81 91.57 84.00 9,024.32 4,798.88 - 3,494.35 5,964,746.36 639,727.70 70° 18' 40.907 N 148° 52' 3.652 WI 12,039.28 91.84 94.76 9,023.41 4,799.21 - 3,463.94 5,964,747.27 639,758.09 70° 18' 40.910 N 148° 52' 2.765 W 12,070.92 89.17 108.07 9,023.13 4,792.96 - 3,433.00 5,964,741.62 639,789.14 70°18' 40.849 N 148° 52' 1.862 W 12,101.02 90.65 119.58 9,023.18 4,780.82 - 3,405.51 5,964,730.01 639,816.86 70° 18' 40.729 N 148° 52' 1.060 W 12,127.61 90.37 129.70 9,022.94 4,765.73 - 3,383.66 5,964,715.33 639,838.98 70° 18' 40.581 N 148° 52' 0.423 W 12,155.23 87.20 143.86 9,023.53 4,745.66 - 3,364.80 5,964,695.63 639,858.22 70° 18' 40.384 N 148° 51' 59.872 W 12,188.39 87.36 144.06 9,025.10 4,718.88 - 3,345.31 5,964,669.22 639,878.22 70° 18' 40.121 N 148° 51' 59.304 W 12,220.91 90.06 141.36 9,025.83 4,693.02 - 3,325.62 5,964,643.75 639,898.40 70° 18' 39.866 N 148° 51' 58.729 W 12,251.94 89.26 137.08 9,026.02 4,669.52 - 3,305.36 5,964,620.65 639,919.10 70° 18' 39.635 N 148° 51' 58.138 W 12,281.34 88.93 131.64 9,026.48 4,648.98 - 3,284.35 5,964,600.51 639,940.50 70° 18' 39.433 N 148° 51' 57.524 W 12,308.24 89.57 128.11 9,026.83 4,631.74 - 3,263.71 5,964,583.66 639,961.46 70° 18' 39.264 N 148° 51' 56.922 W 12,341.33 90.46 124.28 9,026.82 4,612.20 - 3,237.01 5,964,564.64 639,988.53 70° 18' 39.072 N 148° 51' 56.143 W 12,373.09 93.10 122.24 9,025.84 4,594.79 - 3,210.47 5,964,547.74 640,015.39 70° 18' 38.901 N 148° 51' 55.369 W 12,406.75 91.97 117.02 9,024.35 4,578.17 - 3,181.25 5,964,531.69 640,044.92 70° 18' 38.737 N 148° 51' 54.516 W 12,436.58 89.97 113.31 9,023.84 4,565.50 - 3,154.26 5,964,519.53 640,072.14 70° 18' 38.613 N 148° 51' 53.729 W 12,468.24 90.89 109.89 9,023.61 4,553.84 - 3,124.83 5,964,508.44 640,101.79 70° 18' 38.498 N 148° 51' 52.870 W 12,500.36 89.14 104.82 9,023.60 4,544.26 - 3,094.18 5,964,499.45 640,132.61 70° 18' 38.404 N 148° 51' 51.976 W 12,529.39 90.43 102.54 9,023.71 4,537.40 - 3,065.98 5,964,493.12 640,160.94 70° 18' 38.337 N 148° 51' 51.154 W 12,558.55 92.16 99.45 9,023.05 4,531.84 - 3,037.37 5,964,488.11 640,189.65 70° 18' 38.282 N 148° 51' 50.319 W 12,586.99 93.11 96.50 9,021.74 4,527.90 - 3,009.24 5,964,484.71 640,217.85 70° 18' 38.244 N 148° 51' 49.498 W 12,618.33 90.49 91.64 9,020.75 4,525.68 - 2,978.00 5,964,483.08 640,249.12 70° 18' 38.222 N 148° 51' 48.587 W 12,649.34 90.37 88.20 9,020.52 4,525.72 - 2,947.00 5,964,483.71 640,280.11 70° 18' 38.222 N 148° 51' 47.683 W 12,681.42 89.45 82.59 9,020.57 4,528.30 - 2,915.03 5,964,486.90 640,312.02 70° 18' 38.248 N 148° 51' 46.751 W 12,713.68 89.97 76.89 9,020.74 4,534.04 - 2,883.30 5,964,493.24 640,343.63 70° 18' 38.305 N 148° 51' 45.825 W 12,741.62 88.13 72.83 9,021.20 4,541.33 - 2,856.34 5,964,501.05 640,370.45 70° 18' 38.376 N 148° 51' 45.039 W 12,772.83 90.46 67.24 9,021.58 4,551.98 - 2,827.03 5,964,512.26 640,399.55 70° 18' 38.481 N 148° 51' 44.184 W 12,801.75 89.54 64.56 9,021.58 4,563.79 - 2,800.63 5,964,524.57 640,425.72 70° 18' 38.597 N 148° 51' 43.414 W', 12,835.43 90.31 69.23 9,021.63 4,577.00 - 2,769.66 5,964,538.37 640,456.43 70° 18' 38.728 N 148° 51' 42.511 W 12,866.78 90.34 74.41 9,021.45 4,586.78 - 2,739.88 5,964,548.71 640,486.01 70° 18' 38.824 N 148° 51' 41.643 W 12,897.00 90.37 79.06 9,021.26 4,593.71 - 2,710.48 5,964,556.20 640,515.27 70° 18' 38.892 N 148° 51' 40.785 W 12,929.26 88.96 82.85 9,021.45 4,598.79 - 2,678.63 5,964,561.88 640,547.02 70° 18' 38.942 N 148° 51' 39.856 W 12,965.03 90.03 87.46 9,021.77 4,601.81 - 2,643.00 5,964,565.58 640,582.58 70° 18' 38.972 N 148° 51' 38.817 W 12,994.17 90.83 87.92 9,021.55 4,602.98 - 2,613.88 5,964,567.31 640,611.67 70° 18' 38.984 N 148° 51' 37.967 W 13,027.57 89.85 85.37 9,021.35 4,604.93 - 2,580.54 5,964,569.90 640,644.96 70° 18' 39.003 N 148° 51' 36.995 W 13,060.66 89.66 83.47 9,021.49 4,608.15 - 2,547.61 5,964,573.74 640,677.82 70° 18' 39.035 N 148° 51' 36.034 W 13,090.86 88.59 80.85 9,021.95 4,612.27 - 2,517.70 5,964,578.43 640,707.65 70° 18' 39.075 N 148° 51' 35.162 W 13,120.48 87.24 78.36 9,023.03 4,617.61 - 2,488.59 5,964,584.32 640,736.65 70° 18' 39.128 N 148° 51' 34.313 W 13,152.37 88.49 75.39 9,024.22 4,624.85 - 2,457.56 5,964,592.15 640,767.54 70° 18' 39.199 N 148° 51' 33.408 W 13,185.91 88.83 69.92 9,025.00 4,634.84 - 2,425.56 5,964,602.75 640,799.33 70° 18' 39.297 N 148° 51' 32.475 W 13,218.23 89.23 66.75 9,025.55 4,646.77 - 2,395.54 5,964,615.25 640,829.12 70° 18' 39.415 N 148° 51' 31.599 W 13,251.32 88.53 63.21 9,026.20 4,660.76 - 2,365.56 5,964,629.80 640,858.82 70° 18' 39.553 N 148° 51' 30.725 WI 13,280.04 90.03 61.27 9,026.56 4,674.13 - 2,340.15 5,964,643.66 640,883.97 70° 18' 39.684 N 148° 51' 29.984 W' 13,308.04 90.40 57.52 9,026.45 4,688.38 - 2,316.06 5,964,658.37 640,907.79 70° 18' 39.824 N 148° 51' 29.281 W'', 13,342.04 91.35 53.27 9,025.93 4,707.69 - 2,288.08 5,964,678.20 640,935.39 70° 18' 40.014 N 148° 51' 28.465 W 13,381.66 87.27 51.61 9,026.41 4,731.83 - 2,256.68 5,964,702.93 640,966.32 70° 18' 40.252 N 148° 51' 27.550 W' 13,421.04 88.52 49.44 9,027.86 4,756.85 - 2,226.31 5,964,728.52 640,996.21 70° 18' 40.498 N 148° 51' 26.664 W 13,451.13 90.21 53.45 9,028.19 4,775.60 - 2,202.78 5,964,747.72 641,019.37 70° 18' 40.682 N 148° 51' 25.978 W 13,481.25 89.91 56.80 9,028.16 4,792.82 - 2,178.08 5,964,765.40 641,043.74 70° 18' 40.852 N 148° 51' 25.257 W 13,521.39 90.62 61.78 9,027.97 4,813.31 - 2,143.58 5,964,786.55 641,077.84 70° 18' 41.054 N 148° 51' 24.251 W 13,556.18 91.66 65.20 9,027.28 4,828.83 - 2,112.46 5,964,802.66 641,108.66 70°18' 41.206 N 148° 51' 23.344 W 10/22/2009 9:46:OOAM Page 3 COMPASS 2003.16 Build 71 /liAV • • HILIONES Survey Report - Geographic bp 1NTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well H-05 Project: Prudhoe Bay TVD Reference: H -05A: @ 72.83ft (H -05A:) Site: PB H Pad MD Reference: H -05A: @ 72.83ft (H -05A:) Well: H -05 North Reference: True Welibore: H -05B Survey Calculation Method: Minimum Curvature Design: H -05B Database: EDM .16 - Anc Prod - WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N /-S +E / -W Northing Easting (ft) (°) r) (ft) (ft) (ft) (ft) (ft) Latitude Longitude I 13,587.96 91.29 68.10 9,026.46 4,841.42 - 2,083.29 5,964,815.80 641,137.57 70° 18' 41.330 N 148° 51' 22.493 W 13,617.44 91.78 71.62 9,025.67 4,851.57 - 2,055.63 5,964,826.47 641,165.04 70° 18' 41.430 N 148° 51' 21.686 W 13,647.19 91.23 73.64 9,024.89 4,860.44 - 2,027.25 5,964,835.89 641,193.24 70° 18' 41.517 N 148° 51' 20.858 W 13,677.71 91.29 78.55 9,024.22 4,867.78 - 1,997.64 5,964,843.78 641,222.70 70° 18' 41.590 N 148° 51' 19.995 W 13,705.75 87.79 82.15 9,024.44 4,872.47 - 1,970.01 5,964,849.01 641,250.24 70° 18' 41.636 N 148° 51' 19.189 W 13,737.77 87.60 85.84 9,025.73 4,875.82 - 1,938.19 5,964,852.96 641,281.98 70° 18' 41.669 N 148° 51' 18.261 W 13,769.01 88.16 84.23 9,026.89 4,878.52 - 1,907.09 5,964,856.25 641,313.02 70° 18' 41.696 N 148° 51' 17.354 W 13,801.57 90.18 80.89 9,027.36 4,882.74 - 1,874.82 5,964,861.08 641,345.21 70° 18' 41.737 N 148° 51' 16.412 W 13,830.25 90.98 78.38 9,027.07 4,887.90 - 1,846.61 5,964,866.78 641,373.31 70° 18' 41.788 N 148° 51' 15.589 W 13,859.72 90.52 74.36 9,026.68 4,894.84 - 1,817.98 5,964,874.27 641,401.80 70° 18' 41.856 N 148° 51' 14.754 W 13,889.42 91.20 68.15 9,026.24 4,904.38 - 1,789.87 5,964,884.34 641,429.72 70° 18' 41.950 N 148° 51' 13.934 W 13,918.46 91.96 68.30 9,025.44 4,915.15 - 1,762.91 5,964,895.62 641,456.47 70° 18' 42.056 N 148° 51' 13.148 W 13,950.65 89.69 65.48 9,024.97 4,927.78 - 1,733.31 5,964,908.81 641,485.82 70° 18' 42.180 N 148° 51' 12.285 W 13,982.45 89.20 59.87 9,025.28 4,942.37 - 1,705.07 5,964,923.94 641,513.77 70° 18' 42.324 N 148° 51' 11.461 W 14,044.00 89.20 59.87 9,026.14 4,973.26 - 1,651.84 5,964,955.84 641,566.40 70° 18' 42.628 N 148° 51' 9.909 W TD -27/8" 10/22/2009 9:46:OOAM Page 4 COMPASS 2003.16 Build 71 r TREE= 4- 1/16" WELLHEAD = MCEVOY • H ACTUATOR = OTIS ® 5 B SAFETY NO : * * *4 - 1/2" CHROMETBG& LNR * ** KB. ELEV = 64.13' BF. ELEV = 44.68' KOP = 7982' DRLG DRAFT Max Angle = 94 @ 11745' r 1 1065' H9 -5/8" X 13 -3/8" EST TOP OF CEMENT 1 Datum MD = 11301' • Datum ND = 8800' SS ' , L 2209' I - - 1/2" HES X NIP, ID = 3.813" I • I9 -5/8" CSG TIEBACK W/ BOT PBR 1 2130' ■ • ■ 113 -3/8" CSG, 68 #, K -55, ID = 12.415" H 2251' �!, ■ 2251' —113-3/8" X 9-5/8" XO, ID = 8.681" 118 -5/8" CSG, 96.5 #, K -55, ID = 17.655" 1-1 2299' LIFT MANDRELS 2299' I ST MD ND DEV TYPE VLV LATCH PORT DATE NM 5 3276 3238 28 KBG -2 DMY BK 0 11/22/06 4 5779 4929 50 KBG -2 DMY BK 0 11/22/06 3 7929 6373 47 KBG -2 DMY BK 0 02/11/04 Minimum ID = 2.30" @ 11308' 2 9291 7371 44 KBG -2 DMY BK 0 02/11/04 LINER BUSHING 1 10491 8276 41 KBG -2 DMY BK 0 02/11/04 'TOP OF 7" SCAB LNR (ESTIMATED) H 6830' I 7843' H9-5/8" X 7" BKR LNR TOP PKR I 17" SCAB LNR, 26 ", L -80, ID = 6.276" I-1 7830' 1 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 7982' 10644' _I4 -1/2" HES X NIP, ID = 3.813" 1 9 -5/8" MILLOUT WINDOW (H - 05A) 7982' - 7998' I 10665' — 17" X 4 -1/2" BKR S -3 PKR, ID = 3.875" I r 1 10688' --I4 -1/2" HES X NIP, ID = 3.813" 1 I 4 -1/2" TBG, 12.6 #, 13 - CR, .0152 bpf, ID = 3.958" I - 1 10720' r..........--.1 10707' _)4 -1/2" HES XN NIP, ID = MILLED to 3.80" 1 1 7" LNR, 26 ", L -80, .0383 bpf, ID = 6.276" H 10855' 10713' —14-1/2" WLEG, ID = 3.958" I 10716' — 17" X 5" BKR LTP I 13-1/2" LNR, 8.81 #, L -80, STL, .0087 bpf, ID = 2.992" H 11353' 1 " -- -I 10733' — I5" X 4 -1/2" XO I I4 -1/2" LNR, 12.6 #, 13 - CR, .0152 bpf, ID = 3.958" I--I 11949' 1 1 11294' I — ) BKR KB LT PKR, ID = 2.37" 4 -1/2" BKR MONOBORE WHIPSTOCK 11 950' 1 � ► '' I 0 14 11300' H 3 -1/2" DEPLOYMENT SLEEVE, ID = 2.30" I j • 4 1 11354' H3-1/2 x 3- 3/16" XO, ID = 2.80" I PERFORATION SUMMARY ►1 ►1 REF LOG: SWS -MCNL ON 10/21/09 I ► i i ANGLE AT TOP PERF: 89° 0 13170' '• ► 4, 4 -1/2" MILLOUT WINDOW (H - 05B) 11949' - 11958' Note: Refer to Production DB for historical perf data • SIZE SPF INTERVAL Opn /Sqz DATE 4 Q, 2 -7I8' ' 6 13170 - 13700 0 10/22/09 12506' - -3/16 x 2 -7/8" X0, ID = 2.377" I 2 -7/8" F 6 13800 - 13979 0 10/22/09 (3- 3/16" LNR, 6.2 #, L -80, TCII,.0076 bpf, D = 2.80" I 12505' PBTD --I 14005' 1 1,1 12-7/8" LNR, 6.16 #, L -80, STL, .0058 bpf, ID = 2.441" H 14044' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/18/77 ORIGINAL COMPLETION WELL: H - 05B 02/18/04 SRB/KAK RIG SIDETRACK (H -05A) PERMIT No: 2091000 10/23/09 NORDIC2 CTD SIDETRACK (H -05B) API No: 50 - 029 - 20106 - 10/25/09 SV DRLG HO CORRECTIONS SEC 21, T11 N, R13E, 773' FNL & 1265' FEL BP Exploration (Alaska) Alaska Drillin g and Wells Saf tand Down Page 1 of 2 Maunder, Thomas E (DOA) From: Hobbs, Greg S (ANC) [Greg.Hobbs @bp.com] Sent: Thursday, October 15, 2009 4:55 PM To: Maunder, Thomas E (DOA) Cc: Schultz, Mikel Subject: RE: Alaska Drilling and Wells Safety Stand Down Tom - Doyon 14 - Z -25 - Operations shut down at 21:00 hours on 10/12/09. Cement Plug in place at 11,032'. Clean -out BHA hung off from floor to 3350' with circulation through the cement line while the shut -down is ongoing. Doyon 16 - Q -04A Had just tested BOP's and were preparing to pull tubing when operations were shut down. Two way check installed in tubing and tested. Kill lines blown down. Begin stand down at 22:30 on 10/12/2009. Nordic 1 - 06 -18A Finish logging run of newly run and cemented liner. Clear floor, Jet Stack, begin Stand Down at midnight, 10/12/09. ' o 0 Nordic 2 - H -05B Drill to 13,795' MD. Trip for bit. Test BOP's. Begin safety stand -down at 15:45 hours 10/14/09. Fill hole every six hours with a loss rate of 1 barrel per hour. Nabors 4es - Move to MPL -29. Incident occurred at approximately 12:00 hours on 10/10/09. Begin Safety Stand -down at 12:30 p.m. Still rigging up at time of incident. Rig over well, pits full, no wellwork started. Nabors 7es - L -223 7" casing run and cemented. Emergency slips set with pack -off. NU BOP. Test casing spool to tubing spool flange to 5000 psi and FMC pack -off with hand test pump. Change rams from 7" to VBR's, test. Freeze protect OA. Begin Stand Down at 0900 Hours 10/14/09. Nabors 9es - S -218 Currently finishing up running and cementing 7" longstring. Freeze protect OA. Anticipated start of Safety Shut -down- 10:00 hours 10/15/09. Hope that will suffice. Sorry about the delay- the computer has been acting up today - Thanks and don't hesitate to get back with me if you need more information - Greg From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, October 15, 2009 11:15 AM To: Hobbs, Greg S (ANC) Cc: Schultz, Mikel; DOA AOGCC Prudhoe Bay; Regg, James B (DOA); Aubert, Winton G (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Davies, Stephen F (DOA); Roby, David S (DOA) Subject: RE: Alaska Drilling and Wells Safety Stand Down Greg, Thanks for the information. Unfortunate that events have prompted this significant response. You indicate that the stand downs began with the wells at a "safe place" which is appropriate. With the wells secure and no 10/20/2009 Alaska Drilling and Wells Saftand Down Page 2 of 2 operations taking place, the need to accomplish BOP tests on the proscribed time interval is not necessary. You are correct that where the test time intervals have been exceeded that the BOP test will need to be accomplished as the first order of business when operations are resumed. For our records, would you please provide a summary of the wells associated with each rig and the wellbore conditions at the time of SD? Keep us informed as operations are resumed. Please call or message with any questions. Tom Maunder, PE AOGCC From: Hobbs, Greg S (ANC) [mailto:Greg.Hobbs @bp.com] Sent: Thursday, October 15, 2009 11:04 AM To: Maunder, Thomas E (DOA) Cc: Schultz, Mikel Subject: Alaska Drilling and Wells Safety Stand Down Tom - To follow up on our phone conversation yesterday, ADW is taking a safety stand down after a high potential incident over the weekend (Saturday) on Nabors 4es. Nabors 4es has been shut down since this event, Nabors 7es went down yesterday, and Nordic 1 and 2 and Doyon 14 and 16 started their stand -downs at a point in between. Nabors 9es is starting its stand -down today. This last incident, and our current safety statistics have created significant concern for ADW management that our current safety culture is not in the place it needs to be. The directive from Steve Robinson is that the stand down be used to address gaps in our safety culture that have allowed 50% of the incidents that have occurred to happen to employees with five years of experience or less. Of these incidents, 40% have occurred with employees working alone. By having every contractor and rig come up with a plan to address these issues, ADW management expects that occurrence of events at the top of the pyramid will be pushed out further into the future. Steve Robinson has asked that plans be presented to him, and they will require his approval. This stand down is unique in that each rig has shut down at a safe point, and there is no planned end time. Start-up on a rig by rig basis is dependent on contractors providing a plan that immediately adresses the above statistics which should defer more significant events. The plan also needs to address longer term changes to embed behaviors that will make a significant change in our current safety culture The reason for this mail is to make you aware that BOP tests could go beyond their timing requirements during the stand down. If this is the case, they will occur as the first operation following ADWE management's approval for a rig to re -start operations. We wanted to make you aware of this potential issue, and appreciate your support, and management wants everyone focuesd on their safety plans, not operations at this time. If you have any questions, feel free to get back with me. Thanks - Greg Hobbs 10/20/2009 Change to H -05A Sundry • Page 1 of 1 Schwartz, Guy L (DOA) �"� Q From: Schwartz, Guy L (DOA) Sent: Tuesday, September 29, 2009 1:26 PM To: 'Ron.Phillips @bp.com' Cc: Maunder, Thomas E (DOA) Subject: RE: Change to H -05A (203 -220) Sundry (309 -321) Ron, I concur with your approach. The primary liner cement job will isolate all the existing perfs anyway. No pre - squeeze of the 4 1 /" liner perfs is needed. I will make the change to the P & A procedure for our records. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Maunder, Thomas E (DOA) Sent: Tuesday, September 29, 2009 1:13 PM To: Schwartz, Guy L (DOA) Subject: FW: Change to H -05A (203 -220) Sundry (309 -321) From: Phillips, Ron [mailto:Ron.Phillips @bp.com] Sent: Tuesday, September 29, 2009 1:05 PM To: Maunder, Thomas E (DOA) Subject: Change to H -05A Sundry Tom, The H -05A Sundry requested permission to set a Baker Monobore whipstock and squeeze cement past it and into the open perforations. I thought since we would have open perforations above the whipstock that squeezing cement into these perforations would be the conservative approach. After the group talked it over and decided squeezing the perforations above the whipstock before drilling the well is not needed. I would like to change the plan to set a packer whipstock and cover the open perfs above the whipstock, after the H -05B sidetrack is drilled, with the primary liner cement job. Removing the down squeeze cement job will simplify the plan and save money. Thanks, Ron Phillips Coil Tubing Drilling Engineer Alaska Drilling & Wells Office (907) 564 -5913 Cell (907) 748 -7868 9/29/2009 • • �- Via ri „ - . 1 - ¢ E � � z 1 t., I /Liu, f SEAN PARNELL, GOVERNOR t3 1P3 L /E ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 k PHONE (907) 279 -1433 FAX (907) 276 -7542 Mr. John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU H -05B BP Exploration (Alaska), Inc. Permit No: 209 -100 Surface Location: 773' FNL, 12654' FEL, SEC. 21,T11N, R13E,UM Bottomhole Location: 4186' FSL, 2878' FEL, SEC. 16, T11N, R13E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re -drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not required conducting drilling operations until all other q uired p ermits and approvals have been issued. In addition, t he 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) 659 -3607 (pager). incerely, Daniel . Seamount, Jr. Chair DATED this ZZ day of September, 2009 cc: Department of Fish 86 Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATEOFALA8KA ^ ~ ^ ��" .�� ' |LANOGAGCONSER\�J|C�NCJK8K8��N `��_��~�� ~ PERMIT TO DRILL ^ -~'--'' '-- --'---- [� ` 0�n 2O/�\C26.005 � � �~ / 1 a. Type of work lb. Current Well Class 0 Exploratory 0 Development Gas lc. � ,� O om| @U R�m � | 0 0 Mu Zone u C�,o� Methane �� ann � *��n [] Re-Entry 0 Stratigraphic Tes El Development Oil 0 Single Zone 12 Shale Gas 2. Operator Name: 5. Bond: El Blanket [] Single We | 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 PBU H 3. Address: G. Proposed Depth: 12. Field /Poo|(u): PD. Box 1QGG12. Anchorage, Alaska 89519-6612 MD 14100' TVD 896600 Prudhoe Bay Field / Prudhoe Bay 4a. Location ofWell (Governmental Section): 7. Property Designation: Oil Pool Surface: ADLU282O4 773'FNL 1265' SEC. 21, T11N R13E UM FNL, FEL, � ' ' ' 8. 8 Land 13. ApproxmateSpud Date: Top ofPmdu��iveHoh � �on� October 37T8'FSL.5O11'FEL. SEC. 16.T11N.R13E.UK� ' 2000 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 418G'FSL.287D'FEL. SEC. 18.T11N.R13E.UK8 2580 23.500' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within P001: Surface: x- 643313 y- 5960015 Zone'ASP4 (Height above GL): 72.83' feet 750' 16. Deviated WelIs: Kickoff Depth: 11970 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 3200 Surface: 2320 18. CoeinoPmo,um: Specifications Top '8euino Depth 'o0¢pm Quantitv of Cement. c.f. or sacks Hole Cauing Weight Grade Coupling Length MD TVD MD TVD (includinq stage data) 4'1/8" *3/,6"`o-7/8' 6.2# / 6.5# L TCII / STL 2800' 11300' 8799'ss 14100' B8GO'os100ox Class 'G' . 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Dept MD (ft): Effective Depth TVD (ft): Junk (measured): 12470' 9018' None 12382' 0017' None Casing Length Size Cement Volume MD TVD Conductor/ Structural 100' 3D" 265 sx Permafrost 11 100' 100' Surface 2209' 18'50" O2OOox Permafrost || 2299' 2298' Intermediate 7982' 13'30^x9'50^ 875ox Class 'G' 7982' 6407' Production 10829' 7" 1OSox Class 'G'.14Oux Class 'G' 10855' 8548' Liner 1765' 4'1/2" 225ox Class 'G' 10705''12470' 8435''0018' Tieback 2227' 10'3/4''x9'50^ 392nxAncticoet| 2255' 1942' . Perforation Depth MD (ft): 1117I'12375' Perforation Depth TVD (ft): 8783'0017' 20. Attachments 0 Filing Fee, $100 0 BOP Sketch (El Drilling Program 0 Time vs Depth PIot 0 Shallow Hazard Analysis [] Property Plat 0 Diverter Sketc 0 Seabed Report 0 Drilling Fluid Program El 2OA\C25.O5ORequirements 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct. Contact Ron Phillips, ss4 Printed Name Joh" ' le .- Title Engineering Team Leader Prepared o,Name/Number � �'` ~' ~ / '/ Date � Terrie Signature- ' - ' ^ 7 +� Phone 564-4711 ato / //Q/«7 Hubble, na / Commission Use OnI 1 PamndTo API Number: Permit 6ppAval/ z., | See cover |e�arfor NumbeNumber: 50 Date: 7 other requirements Conditions o,Approval: c�� If checked, mo it 35 ��m� ��«�^� ��"�� Sampleonoq�: yen ,n Mud Log R�'d: []Yes c� o � — « � ' � t 0, Yes �'' — * 25�� A n�� FI,S Measures: EI Yes 0 No Directional Survey Req'd: VYes 0 No Other: aPp�OvsoaY THE COMMISSION � Date .DOMM|GG|OwsR Fvmn17/1,2 -- / - 5 « 1 �� Submd|nDup|ioo� ORI . 1 1.11.°1"#7Xf" 4f • • �bp BPXA Prudhoe Bay H -05B CTD Sidetrack September 02, 2009 CTD Sidetrack Summary Pre -Rig Work: (scheduled to begin September 15, 2009) 1. S Dummy WS drift to 12,100' (Hit obstruction at 11,606' at 78° inclination) 2. S Dummy GLV's 3. 0 MIT -IA 4. C Mill XN nipple at 10,707' with LH motor to 3.80 ", drift to 12,000'. 5. C Dummy WS drift to 12,100'. 6. 0 AC -LDS; AC- PPPOT -T 7. 0 PT MV, SV, WV 8. 0 Bleed gas lift and production flowlines down to zero and blind flange • 9. 0 Remove wellhouse, level pad 1 Rig Work: (scheduled to begin on October 15, 2009) a ft+ 1. MIRU and test BOPE to 250 psi low and 3500 psi high. 2. Set 4 -1/2" Monobore WS at 11,970' at 90° Inc. 3. Down squeeze cemenV&P &A — 20 bbls of 15.8 ppg 4. Mill 3.8" window at 11,970' and 10' of rathole. Swap the well to Geo -Vis. Tp 5. Drill Lateral: 4.25" OH, 2130' (15 deg/100 planned) with resistivity. 6. Run 3- 3/16" x 2 -7/8" L -80 liner leaving TOL at 11,300'. 06( ' " 51) 7. Pump primary cement leaving TOC at TOL (11,300'), 33 bbls of 15.8 ppg liner cmt planned 8. Cleanout liner and MCNL/GR/CCL log 9. Test liner lap to 2000 psi. 10. Perforate liner per asset instructions ( -800') 11. Freeze protect well, RDMO Post -Rig Work: 1. Re- install wellhouse and FL's. 2. Generic GLV's 3. RU test separator, flow test well • Mud Program: • Well kill: 8.6 ppg brine. • Milling /drilling: 8.6 ppg Geo Vis or biozan for milling, new 8.6 ppg Geo Vis for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3.75" x 4.25" (bi- center bits used) Casing Program: fully cemented liner • 3- 3/16 ", L -80, 6.2# TCII 11,300' and - 12,500' and • 2 -7/8 ", L -80, 6.5# STL 12,500' and — 14,100' and • A minimum of 33 bbls 15.8 ppg cement will be used for liner cementing. (Assuming TD @ 14,100' and planning on 40% excess in the open hole interval) • TOC planned at 11,300'. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 91°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property — 23,500' ft PBU North boundary • Distance to nearest well within pool — 750 ft. (H -30 North) Logging • MWD directional, Gamma Ray, and Resistivity will be run over all of the open hole section. • Cased hole GR/CCL/MCNL logs will be run. Anti - Collision • H -30: 598' ctr -ctr, low rate producer in the same reservoir.-/ Hazards • No fault crossings expected. • The maximum recorded H2S level on H pad was 180 ppm on well H -22A. H pad is considered an H2S pad. • Lost circulation risk is moderate for this well. Reservoir Pressure • The reservoir pressure on H -05B is expected to be 3,200 psi at 8,800' TVDSS. (7.0 ppg equivalent) • Max. expected surface pressure with gas (0.10 psi /ft) to surface is 2,320 psi. / MAST 2320 'lc: Ron Phillips CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble TREE= 4- 1/16" WELLHEAD = MCEVOY i H _0 5 B SAFETY GES: * * *4 -1/2" CHROME TBG & LNR* ** ACTUATOR = OTIS KB. ELEV = 64.13' Planned CTD Sidetrack BF. ELEV = 44.68' KOP = 7982' Max Angle = 94 @ 11745' Datum MD = 11301' ,� 1065' I-[ 9 5/ -1/2 X HES 13 -3/8X NIP" EST P CEMENT Datum TVD = 8800' SS ∎• ' ' 220 J I- 1 " , ID = 3.813 " I 9-5/8" CSG TIEBACK W/ BOT PBR I 2130' • ■ ■ • 13 -3/8" CSG, 68 #, K -55, ID = 12.415" H 2251' I . 4 I 2251' H13-3/8" X 9 -5/8" XO, ID = 8.681" I 18 -5/8" CSG, 96.5 #, K -55, ID = 17.655" H 2299' I GAS LIFT MANDRELS I L ST MD ND DEV TYPE VLV LATCH PORT DATE 5 3276 3238 28 KBG -2 DMY BK 0 11/22/06 4 5779 4929 50 KBG -2 DMY BK 0 11/22/06 3 7929 6373 47 KBG -2 DMY BK 0 02/11/04 Minimum ID = 3.725" @ 10707' 2 9291 7371 44 KBG -2 DMY BK 0 02/11/04 4-1/2" HES XN NIPPLE 1 10491 8276 41 KBG -2 DMY _ BK 0 _02/11/04 I TOP OF 7" SCAB LNR (ESTIMATED) H 6830' I ., Ii • 1 7" SCAB LNR, 26 ", L -80, ID = 6.276" I- I 7830' I F= N 7843' H9-5/8" X 7" BKR LNR TOP PKR ■ PERFORATION SUMMARY REF LOG: SWS -BHCS ON 10/21/71 ANGLE AT TOP PERF: 94 @ 11770 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 6 11600 - 11620 planned 2-7/8" 6 11770 - 11820 0 02/04/05 2 -7/8" 6 11845 - 11870 0 01/25/05 2 -7/8" 4 12020 - 12375 0 02/09/04 k_ 10011' H 9 -5/8" CSG, 47 #, L -80, ID= 8.681 " I MILLOUT WINDOW 7982' - 7998' i 44,, iMJ ii. »/EIii Parent "MMM /NNWIIIIII/II/I. WINNIIiiiiiMIO' , 10644' — 4 -1/2" HES X NIP, ID = 3.813" IIIMMMMMNMF 10665 — 7" X 4 -1/2" BKR S -3 PKR, ID = 3.875" gill iii �� 10688' — 4 -1/2 /2" HES X NIP ID = 3 'IN/ 10707' — 4 -1/2" HES XN NIP, ID = mill to 3.8" 4 -1/2" TBG, 12.6 #, 13 -CR, .0152 bpf, ID = 3.958" H 10720' 10713' H4 -1/2" WLEG, ID = 3.958" I 10716' I-17" X 5" BKR LTP I 1" 10733' H5" X 4-1/2" X01 17" LNR, 26 ", L -80, .0383 bpf, ID = 6.276" H 10855' I 11300' --ITop of Liner; Top of Cement � () I 11310' I -� Liner Bushing, ID = 2.3" I BKR4 -1/2" Mono -bore Whipstock) -1 11970' I B I 14100' HTD I I 4 -1/2" LNR, 12.6 #, 13 -CR, .0152 bpf, ID = 3.958" H 12470' I_ S �� I A 112500'I -� 3-3/16 X 2 7/8" XO • ��. — 'I 12382' H PBTD I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/18/77 ORIGINAL COMPLETION 11/22/06 DAV /PAG GLV C/O WELL: H -05B 02/18/04 SRB/KAK RIG SIDETRACK (H -05A) PERMIT No: 032200 02/27/04 RMH/KAK GLV C/O API No: 50- 029 - 20106 -01 02/09/05 MW/TLH TBG ID CORRECTION SEC 21, T11 N, R13E, 773' FNL & 1265' FEL 01/25/05 SGS /PJC PERFORATION 02/04/05 BMcLJPJC PERF /13 -C LNR CORRECTION BP Exploration (Alaska) • • All Measurements are from top of Riser 9/9/2009 i C/) CC H -05B top of bag Schlumberger BAG bttm of bag middle of slips Blind /Shears I TOTs middle of pipes I 2 3/8" combi ram /slips middle of flow cross Mud Cross Mud Cross middle of blind /shears variable bore pipe 3 1/2 " -2 7/8" TOTs middle of pipe /slips I 2 3/8" combi ram /slips • 1 I Swab Valve I I Flow Tee vpu BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB H Pad H -05 Plan 2, H -05B Plan: Plan 2 BP Coil Tubing Report ip 08 September, 2009 � bp rA.r li t5lifes BP Coil Tubing Report 0 bp INTEQ Company: North America - ALASKA - BP Local Co- ordinate. Reference: Well H-05 Project: Prudhoe Bay TVD Reference: H -05A: @ 72.83ft (H -05A:) Site: PB H Pad MD. Reference: ' H -05A: @ 72.83ft (H -05A:) Weil: H -05 North' Reference: True Wellbore: Plan 2, H -056 Survey Calculation Method: Minimum Curvature Design: Plan 2 Database ".EOM .16 Anc Prod - WH24P Project Prudhoe Bay, North Slope, UNITED STATES Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB H Pad, TR -11 -13 Site Position: Northing: 5,957,572.25 ft Latitude: 70° 17' 30.055 N From: Map Easting: 641,366.07 ft Longitude: 148° 51' 19.802 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 1.08 ° Well. 11-05, H-05 Well Position +■/ -S 0.00 ft Northing: 5,960,015.36 ft Latitude: 70° 17' 53.718 N +E/ -W 0.00 ft Easting: 643,312.65 ft Longitude: 148° 50' 21.725 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Welibore Plan 2, H-056 . Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2009 8/19/2009 22.47 80.91 57,664 Design Plan 2 Audit Notes: Version: Phase: PLAN Tie On Depth: 11,933.04 Vertical Section; Depth From (TVD) > : +M/ -S - +E/4N Direction (ft) (ft) (ft) ( °) 28.15 0.00 0.00 85.00 i 9/8/2009 2:40:53PM Page 2 COMPASS 2003.16 Build 71 Milli II 11 BP Coil Tubing Report 0 bp 1NTEQ Company: North America - ALASKA - BP .. . Local Co- ordinate Reference: Well I+05 Project . Prudhoe Bay TVD Reference: . s: H-05A: @ 72.83ft (H -05A:) Site:. . PB H Pad MD Refer [ H-05A: @ 72.83ft (H -05A:) Well H -05 North Reference:., True Weilbore; , Plan 2, I-1-05B , Survey Calculation Method: ' . Minimum Curvature -„'Design:.. . Plan 2 ` Database: < ' EDM .16 - Anc Prod - WH24P SunreY Tool Program „ Date 9/3/2009 From : To . : (ft) > (ft) : Survey (Weilbore) . '. . . ,. . " Toot Name i . ` Description 108.70 7,908.70 1 : Camera based gyro multisho (H -05) CB- GYRO -MS Camera based gyro multishot 7,982.00 11,933.04 H -05A MWD (H -05A) MWD MWD - Standard 11,933.04 14,100.00 Plan 2 ( Plan 2, H -05B) MWD MWD - Standard : Planned Survey ` MD Inc . Azi TVDSS N/S EMI Northing Easting. : DLeg . V. Sec TFBce.' (ft) (°) ` ( °) . (ft) (ft) (ft) (ft). (ft) ' ( ° / 1 00ft). ` (� . ' .( 11,933.04 90.49 59.16 8,951.25 4,774.21 - 3,565.30 5,964,720.35 639,657.24 0.00 - 3,135.63 0.00 TIP 11,950.00 89.45 62.91 8,951.26 4,782.42 - 3,550.46 5,964,728.84 639,671.91 22.95 - 3,120.14 105.50 KOP 11,970.00 91.01 63.81 8,951.18 4,791.39 - 3,532.59 5,964,738.15 639,689.61 9.00 - 3,101.55 30.00 End of 9 Deg /100' DLS 12,000.00 90.57 75.80 8,950.77 4,801.73 - 3,504.48 5,964,749.02 639,717.51 40.00 - 3,072.65 92.00 12,100.00 89.05 115.78 8,951.11 4,791.84 - 3,407.00 5,964,741.00 639,815.15 40.00 - 2,976.40 92.17 12,170.00 88.21 143.77 8,952.83 4,747.52 - 3,353.75 5,964,697.70 639,869.24 40.00 - 2,927.21 92.03 End of 40 Deg /100' DLS 12,185.00 86.26 144.90 8,953.55 4,735.35 - 3,345.01 5,964,685.70 639,878.20 15.00 - 2,919.57 150.00 ill 5 12,200.00 84.54 143.45 8,954.76 4,723.23 - 3,336.26 5,964,673.75 639,887.18 15.00 - 2,911.91 - 140.00 6 12,240.00 84.57 137.42 8,958.56 4,692.55 - 3,310.91 5,964,643.56 639,913.11 15.00 - 2,889.33 -90.00 7 12,290.00 87.77 130.62 8,961.91 4,657.91 - 3,275.06 5,964,609.61 639,949.62 15.00 - 2,856.63 -65.00 8 12,300.00 87.77 132.12 8,962.29 4,651.30 - 3,267.56 5,964,603.15 639,957.24 15.00 - 2,849.74 90.00 12,340.00 87.79 138.13 8,963.85 4,622.99 - 3,239.37 5,964,575.39 639,985.96 15.00 - 2,824.12 89.94 9 12,400.00 89.21 129.24 8,965.42 4,581.61 - 3,196.04 5,964,534.84 640,030.07 15.00 - 2,784.56 -81.00 9/8/2009 2:40 :53PM Page 3 COMPASS 2003.16 Build 71 s BP Coil Tubing Report by 1NTEQ Company: ` North America - ALASKA - BP Local Co- ordinate Reference: Well H-05 P ' .. ` Prudhoe Bay 7VD Reference : ., , H -05A: @ 72.83ft (H -05A:) .Sid . PB H Pad AMD Reference, . H -05A: @ 72.83ft (H -05A:) Well H -05 y "North Reference. :. . True Welibore: Plan 2, H -056 Survey.Calculation Method Minimum Curvature D ' .. -. Plan 2 '.: Database: EDM .16 - Anc Prod - WH24P Planned Survey . . . . .. MD ' ' `Inc .. Azi ' , : TVDSS ' N/S . ` EMI .. ' Northing .Easting ` DLeg. .:Y Seo TFace (ft): .. - (°) ( (ft), ''' ' (ft) '' (ft) ' (ft) (ft) ' , . ..(100ft)" (ft) : ' . {) . 12,440.00 90.18 123.31 8,965.63 4,557.96 - 3,163.80 5,964,511.81 640,062.75 15.00 - 2,754.51 - 80.77 10 12,500.00 90.18 114.31 8,965.45 4,529.07 - 3,111.29 5,964,483.93 640,115.80 15.00 - 2,704.71 -90.00 12,600.00 90.16 99.31 8,965.15 4,500.23 - 3,015.84 5,964,456.91 640,211.78 15.00 - 2,612.14 -90.03 12,700.00 90.14 84.31 8,964.88 4,497.07 - 2,916.17 5,964,455.66 640,311.48 15.00 - 2,513.13 -90.07 12,800.00 90.11 69.31 8,964.67 4,519.82 - 2,819.09 5,964,480.25 640,408.10 15.00 - 2,414.43 -90.11 12,840.00 90.09 63.31 8,964.60 4,535.88 - 2,782.47 5,964,497.00 640,444.40 15.00 - 2,376.56 -90.15 11 12,900.00 90.09 72.31 8,964.51 4,558.51 - 2,726.97 5,964,520.69 640,499.46 15.00 - 2,319.30 90.00 13,000.00 90.08 87.31 8,964.36 4,576.14 - 2,628.83 5,964,540.19 640,597.24 15.00 - 2,219.99 90.01 13,040.00 90.08 93.31 8,964.30 4,575.92 - 2,588.85 5,964,540.73 640,637.21 15.00 - 2,180.18 90.04 12 13,100.00 90.00 84.31 8,964.26 4,577.16 - 2,528.92 5,964,543.12 640,697.10 15.00 - 2,120.37 -90.50 13,200.00 89.87 69.32 8,964.38 4,599.91 - 2,431.84 5,964,567.71 640,793.73 15.00 - 2,021.67 -90.51 13,300.00 89.75 54.32 8,964.72 4,647.01 - 2,343.95 5,964,616.47 640,880.70 15.00 - 1,930.01 -90.49 13,340.00 89.70 48.32 8,964.91 4,672.00 - 2,312.74 5,964,642.05 640,911.42 15.00 - 1,896.74 -90.44 13 13,400.00 89.86 57.31 8,965.14 4,708.22 - 2,264.98 5,964,679.17 640,958.47 15.00 - 1,846.02 89.00 13,500.00 90.13 72.31 8,965.14 4,750.66 - 2,174.75 5,964,723.32 641,047.87 15.00 - 1,752.43 88.97 13,590,00 90.37 85.81 8,964.75 4,767.70 - 2,086.59 5,964,742.04 641,135.68 15.00 - 1,663.12 88.96 14 13,600.00 90.35 84.31 8,964.68 4,768.56 - 2,076.63 5,964,743.09 641,145.63 15.00 - 1,653.12 -91.00 13,700.00 90.07 69.31 8,964.32 4,791.31 - 1,979.55 5,964,767.68 641,242.25 15.00 - 1,554.42 -91.01 13,800.00 89.79 54.31 8,964.43 4,838.41 - 1,891.66 5,964,816.45 641,329.22 15.00 - 1,462.76 -91.06 13,840.00 89.69 48.32 8,964.61 4,863.40 - 1,860.45 5,964,842.02 641,359.94 15.00 - 1,429.49 -91.05 15 13,900.00 89.69 57.32 8,964.94 4,899.62 - 1,812.69 5,964,879.15 641,406.99 15.00 - 1,378.77 90.00 14,000.00 89.71 72.32 8,965.47 4,942.05 - 1,722.46 5,964,923.29 641,496.40 15.00 - 1,285.18 89.95 9/8/2009 2:40:53PM Page 4 COMPASS 2003.16 Build 71 Ear a talliiEli BP Coil Tubing Report bp INTEQ Company: North America - ALASKA - BP Larcal C o-ordinate R Well H Projec = . Prudhoe Bay TVI�.Reference eference H 05A: 05 72.83ft (H -05A:) @ Site: .; PB H Pad MD Reference: 11-05A: @ 72.83ft (11-05A:) North R True Wellbore: "' . Plan 2, H -05B Surve y . Calculatio eference: n Methiod 1716 ry Design Plan 2 D atabas e : ' EMinimu DM .1 Cu Anc Prod ature - WH24P Planned Survey MD In c Azi; T�/DSS " Nl EIW' Northing Fasting. DLeg . ; Sec. TFace : (ft) ( °) ( °) (ft) ft . 14,100.00 89.76 87.32 8,965.93 4,959.68 - 1,624.32 5,964,942.79 641,594.18 15.00 1,185.87 89.87 TD at 14100.00 - 2.875" III 9/8/2009 2:40:53PM Page 5 COMPASS 2003.16 Build 71 F11%r BP Coil Tubing Report 0 bp 1NTEQ Company: No rth America - ALASKA - BP y; • '. ° . Local Co- ordinate Reference: Well F+05 Project: Prudhoe Bay NO Reference: H -05A: @ 72.83ft (H -05A:) Site: PB H Pad MD Reference: H -05A: @ 72.83ft (H -05A:) Well: H -05 North Reference: True Wellbore: Plan 2, H -05B Survey Calculation Method; Minimum Curvature Design: Plan 2 Database : EDM .16 - Anc Prod - WH24P Targets Target Name - hitlmiss target Dip Angle Dip Dir. ND +N /-S +El -W Northing Fasting Shape ° ( °) " ( 91 (ft) (ft) . ' (ft) (ft) - ..(ft) Latitude Longitude H -05B Target 2 0.00 0.00 9,037.83 4,509.05 - 2,792.39 5,964,470.00 640,435.00 70° 18' 38.059 N 148° 51' 43.173 W - plan misses target center by 20.06ft at 12820.13ft MD (9037.46 TVD, 4527.42 N, - 2800.45 E) - Point H -05B Fault 1 0.00 0.00 72.83 4,080.12 - 3,745.81 5,964,023.00 639,490.00 70° 18' 33.837 N 148° 52' 10.976 W - plan misses target center by 8979.94ft at 11933.04ft MD (9024.08 TVD, 4774.21 N, - 3565.30 E) - Polygon Point 1 72.83 4,080.12 - 3,745.81 5,964,023.00 639,490.00 Point 2 72.83 3,981.30 - 3,284.58 5,963,933.00 639,953.00 Point 3 72.83 4,081.08 - 2,537.48 5,964,047.00 640,698.00 Point4 72.83 4,224.86 - 2,104.63 5,964,199.00 641,128.00 Point 5 72.83 4,081.08 - 2,537.48 5,964,047.00 640,698.00 Point 6 72.83 3,981.30 - 3,284.58 5,963,933.00 639,953.00 H -05B Target 1 0.00 0.00 9,037.83 4,485.26 - 3,117.93 5,964,440.00 640,110.00 70° 18' 37.824 N 148° 51' 52.668 W - plan misses target center by 43.09ft at 12506.34ft MD (9038.26 TVD, 4526.51 N, - 3105.49 E) - Point H -05B Target 3 0.00 0.00 9,037.83 5,063.25 - 1,431.47 5,965,050.00 641,785.00 70° 18' 43.513 N 148° 51' 3.481 W - plan misses target center by 218.90ft at 14100.00ft MD (9038.76 TVD, 4959.68 N, - 1624.32 E) - Point H -05B Polygon 0.00 0.00 72.83 4,690.19 - 3,374.08 5,964,640.00 639,850.00 70° 18' 39.838 N 148° 52 0.142 W • - plan misses target center by 8951.75ft at 12100.00ft MD (9023.94 TVD, 4791.84 N, - 3407.00 E) - Polygon Point 1 72.83 4,690.19 - 3,374.08 5,964,640.00 639,850.00 Point 2 72.83 4,557.87 - 3,516.64 5,964,505.00 639,710.00 Point 3 72.83 4,366.12 - 3,165.21 5,964,320.00 640,065.00 Point 4 72.83 4,403.68 - 2,774.39 5,964,365.00 640,455.00 Point 5 72.83 4,876.07 - 1,320.00 5,964,865.00 641,900.00 Point 6 72.83 5,265.22 - 1,532.64 5,965,250.00 641,680.00 Point 7 72.83 4,619.13 - 2,795.29 5,964,580.00 640,430.00 Point 8 72.83 4,579.67 - 3,086.11 5,964,535.00 640,140.00 9/8/2009 2:40:53PM Page 6 COMPASS 2003.16 Build 71 vu •tifilAals BP Coil Tubing Report 0 bp • 1NTEQ Company: ; North Amer - ALASKA - BP Local Co- ordinate Reference: Well 1+05 Project: Prudhoe Bay TVD Reference: H -05A: @ 72.83ft (1-1-08A:) Site: PB H Pad MD Reference '; H -05A: @ 72.83ft (H -05A:) Well : . ' H -05 ' North Reference: Tr Weligore: Plan 2, H -05B Survey Calculation Method M Curvature Design; : Plan 2 Database: EDM . 16 Anc Prod - WH24P Casing'Points ' ' ` Measured ' Depth Depth _ Diameter Diameter . ` �.: (ft) ( N (in) (In) 10,854.19 8 ,547. 83 7 " 7.000 8.500 14,100.00 9,038.76 2.875" 2.875 4.125 Plan Annotations , Measured Vertical Local Coordinates Depth Depth +N/-S, +E/ - (ft) (ft) (ft) (ft) Comment 11,933.04 9,024.08 4,774.21 - 3,565.30 TIP 11,950.00 9,024.09 4,782.42 - 3,550.46 KOP 11,970.00 9,024.01 4,791.39 - 3,532.59 End of 9 Deg /100' DLS 12,170.00 9,025.66 4,747.52 - 3,353.75 End of 40 Deg /100' DLS 12,185.00 9,026.38 4,735.35 - 3,345.01 5 12,200.00 9,027.59 4,723.23 - 3,336.26 6 12,240.00 9,031.39 4,692.55 - 3,310.91 7 12,290.00 9,034.74 4,657.91 - 3,275.06 8 12,340.00 9,036.68 4,622.99 - 3,239.37 9 12,440.00 9,038.46 4,557.96 - 3,163.80 10 12,840.00 9,037.43 4,535.88 - 2,782.47 11 III 13,040.00 9,037.13 4,575.92 - 2,588.85 12 13,340.00 9,037.74 4,672.00 - 2,312.74 13 13,590.00 9,037.58 4,767.70 - 2,086.59 14 13,840.00 9,037.44 4,863.40 - 1,860.45 15 L 14,100 00 9,038.76 4,959.68 - 1,624.32 TD at 14100.00 I Checked By: Approved By: Date: 9/8/2009 2:40:53PM Page 7 COMPASS 2003.16 Build 71 Azlmutha m Tme NeM WELLBORE DETAILS: Plan 2 H -058 REFERENCE INFORMATION /.. Project: Prudhoe Bay M a gnetic NoM: 2247° IP4 • Site: PB H Pad Coordinate (N /E) Reference: Well H -05, True North BAKUR Magnetic Field Parent on MD: 11933.04 rs: H Well: H -05 Strength: 576642anT Vertical (TVD) Reference: Mean Sea Level Tie on M 0 bp Wellbore: Plan 2, H -056 P lan• Plan 2 (H -051 Plan 2, H -058) Dip An Plan: (VS) Reference: Not - (O.00N, 0.00E) Date: t ec roe Mg Measured Depth Reference: H-05A. 72.838 (H -05A) • • Calculation Method: Minimum Curvature 11VTE�Q G ,�i • 6400 WELL DETAILS: H -05 6200 Ground Level: 0.00 *W-S *E / -W Northing Easting Latittude Longitude Slot 0.00 0.00 5960015.36 643312.65 70° 17' 53.718 N 148° 50 21.725 W 6000 SECTION DETAILS ANNOTATIONS 5800 Sec MD Inc Azi ssTVD +N/ -S +E/ -W DLeg TFace VSec Target Annotation 5600 1 11933.04 90.49 59.16 8951.25 4774.21 - 3565.30 0.00 0.00 - 3135.63 TIP 2 11950.00 89.45 62.91 8951.26 4782.42 - 3550.46 22.95 105.50 - 3120.14 KOP 3 11970.00 91.01 63.81 8951.18 4791.39 - 3532.59 9.00 30.00 - 3101.55 End of 9 Deg/100' DLS G 5400 1.1 Target 3 4 12170.00 88.21 143.77 8952.83 4747.52 - 3353.75 40.00 92.00 - 2927.21 End of 40 Deg /100' DLS a - e. c1 of 5 Deg/I30' DL. I 5 12185.00 86.26 144.90 8953.55 4735.35 - 3345.01 15.00 150.00 - 2919.57 5 0 521 I a, .. .1 Deg, t twr n c Agidi 6 12200.00 84.54 143.45 8954.76 4723.23 - 3336.26 15.00 220.00 - 2911.91 6 o I 7 • N 7 12240.00 84.57 137.42 8958.56 4692.55 - 3310.91 15.00 270.00 - 2889.33 7 H - D5/ 5 - 05A 8 12290.00 87.77 130.62 8961.91 4657.91 - 3275.06 15.00 295.00 - 2856.63 8 `5000 _ 11 Plan 2, 16058 9 12340.00 87.79 138.13 8963.85 4622.99 - 3239.37 15.00 90.00 - 2824.12 9 " 4P S 1 -058 "arget 10 12440.00 90.18 123.31 8965.63 4557.96 - 3163.80 15.00 279.00 - 2754.51 10 .4 4800 � - - 11 12840.00 90.09 63.31 8964.60 4535.88 -2782.47 15.00 270.00 -2376.56 11 G TI�'\ - 058 Target 1 / "D at 14100.00 12 13040.00 90.08 93.31 8964.30 4575.92 - 2588.85 15.00 90.00 - 2180.18 12 4, I I ' � - " 13 13340.00 89.70 48.32 8964.91 4672.00 - 2312.74 15.00 269.50 - 1896.74 13 - 1/ / t I 14 14 13590.00 90.37 85.81 8964.75 4767.70 - 2086.59 15.00 89.00 - 1663.12 14 �' _ r I 15 13840.00 89.69 48.32 8964.61 4863.40 - 1860.45 15.00 269.00 -142949 15 Y 4400 ' 13 16 14100.00 89.76 87.32 8965.93 4959.68 - 1624.32 15.00 90.00 - 1185.87 TD at 14100.00 0 - 10 11 12 ( I 1105/I 4000 r_ v ` H -15B Fault 1 3800 3600 -3800 -3600 -3400 -3200 -3000 -2800 -2600 -2400 -2200 -2000 -1800 -1600 -1400 -1200 -1000 -800 -600 -400 -200 / West( -) /East( +) (200 ft/in) 8460 8550 I / Q 8640 O 8730 End of 9 Deg/10B DLS ,p 8820 7 ! • A. TIP KOP / ' /D t H- 05 /H•05A H -05B Target 2 H -05/ ran 2, H -058 • A 8910 r 7 H -058 Target 3 • }.,, • • 9000, ,/ 89 10 11 12 3 14 I5 IL) at 14100.00 • 9090 End 31 40 Deg/10C DLS a-OSB Target 1 N 9180 H- 15/H -05 9270 9360 Mean Sea '_e• el 9450.. .... .... . ... .... .. . ... . . -3961 -3870 -3780 -3690 -3600 -3510 -3420 -3330 -3240 -3150 -3060 -2970 -2880 -2790 -2700 -2610 -2520 -2430 -2340 -2250 -2160 -2070 -1980 -1890 -1800 -1710 -1620 -1530 -1440 -1350 -1260 -1170 -1080 -990 -900 -810 -720 -630 -540 -450 Vertical Section at 85.00° (90 ft/in) Project: Prudhoe Bay Magne4c North: 22.47° WELLBORE DETAILS: Plan 2, H-05B REFERENCE INFORMATION MN Site: PB H Pad Coordinate (NIE) Reference: Well H -05, Tee North Magnegc Field Parent Wellbore: H -05A BAKIR 0 bp Well: H -05 Strength. 57664.2sor Vertical (TVD) Reference: H -05A: @ 72.838 (H -05A:) S Up Angle 80 91° Tie on MD: 11933.04 Section �1WrfG • Wellbore: Plan 2, H -056 (VS) Sbt- (O.00N, O.00E) P led: Plan 2 (H -05/ Plan 2, H -058) Moml�BG tGM2W5 Measured Depth Reference: H -05A: @ 72.83ft (F1-05A:) Calculation Method: Minimum Curvature INTEQ 4\ I 5890 p -u 1 N lilk -2 1/N-2 5795 5700 5605 il l 5510 5415 3 -31 - 30 - „ 195 • I • OIA • 5320 I9 p41 5225 g9 1 5130 gs :0 g ,, 0 0 05/ . 1. 5035 g LO — H-0 ./H-0•A •440 0 4940 w '.560 crN 475, IM Iii \� lA ■■■ 4655 ■�.�,l _ ' ... .0. t 4560 L■ - �/_ . • . 4465 .. /. -1 / .■- 'M��._ • ..!, f i o 4371 \ � �.�. - U t '.',== —�-_, - . . / . • II J • � 1 4275 4180 . . , �■■_, - , ' 'II■■ 4085, 8 ��!`.` _ �_. - - n 3990 i Im -, ••• 3895 r , � ___ 1 I II 3811 •.411 ■�� \N■ 3705 3610 3515. H -05A: . 111 I iL ■EM may_ - — -4180 -4085 -3990 -3895 -3800 -3705 -3610 -3515 -3420 -3325 -3230 -3135 -3040 -2945 -2850 -2755 -2660 -2565 -2470 -2375 -2280 -2185 -2090 -1995 -1900 -1805 -1710 -1615 -1520 -1425 -1330 -1235 -1140 -1045 -950 -855 -760 -665 • West( - )/East( +) (95 ft/in) • Project: Prudhoe Bay ANTI - COLLISION SETTINGS COMPANY CETAILS Korn Amelr- ALASKA - W NORTH AMERICA EMI Site: PB H Pad ALASKA . to) �u Interpolation Method: MD, interval: 4000 BAAIRms Ir' W ell: H- OS Depth Range From: 11933.04 To 14100.00 c.Nwatim McO4 Mlnmum cu,.a� Results Limited By: Centre Distance: 1607.18 E,rw sr >,rm iscwsA maw:: Plan 2, H -058 Reference; Plan: Plan 2 (H-05/ Plan 2, H-05B) s, « arou. En �(� ,- Plan: Plan 2 (H -051 Plan 2, H -05B) w.m N M°4n4 w .° ewe 1NTEQ WELL DETAILS: H -05 Ground Level: 0.00 +NI -S +E/ -W Northing Eastin Latittude Lon Slat From Colour To MD 0.00 0.00 5W0015.36 613312.65 70° 17' 53.718 N 148° 50' 21.725 W SECTION DETAILS Sec MD Inc Azi ND °WS •E/ -W DLe9 TFace 17980 T 0 1 11933.04 9049 59.16 024.08 477421 2565.30 0.00 0.00 - 3135.63 2D2 _ 0 0 0 2 11950.0 8945 62.91 024.09 478242 -355046 22.95 105.50 - 3120.14 _ 3 11970 00 91.01 63.81 024.01 4791.39 - 3532.59 9.0 30.0 - 3101.55 � 5 12185 86 26 144 90 4735.35 3345 0 0 01 15 150. -2919.57 4 12170 00 88 21 143 77 9025 66 4747 52 -3353.75 40.00 92 00 -2927 21 184 _ -`,..'.."-'4 6 12200 81.54 143.45 27.59 4723 23 - 3336.26 15. 220. 2911.81 �� 1 // ` \ 0 0 00 0 00 0 0 0 7 12240.0 61.57 137.42 031.39 4692.55 - 3310.91 15.0 270.0 2889.33 0 0 168 _ ` 8 122 87.77 130.62 034.74 4657.91 3275 15.0 295.0 -2856.63 0 '` _ \ 9 12340. 8779 133.33 037.53 4522 99 -2289 37 15.0 90.00 - 2824.12 \ \ 10 12440.18 123.31 9038.46 4557 96 -316380 80 0 0 15. 279 -2751.51 0 0 9037 / / -- \ \ 11 12640. 0 0 0 08 83.31 43 4535.86 - 276247 15.0 2700 - 2376.56 / \ ` 12 13040.08 93.31 37.13 457592 - 258885 15.0 0.0 - 210.18 H- 05/H -05A 13 13340.0 88.70 4832 037.74 4872.0 - 2312.74 15.0 2690 - 1898.74 / / 152 \ \ 0 0 0 0 14 135..37 65.81 37.58 4767.70 - 2086.59 15 0 0 89. -ifi63. 12 0 76 0 - -_ _, 136 `\ ` y 288 15 13840. 89. 4832 37.44 49 0 0 53.40 - 1880.45 15. 269. - 1429.49 0 0 � W _ _ \ 16 14100 00 87.32 038.76 4959 68 - 7821.32 15.0 0.0 - 1185.87 % � 120 � o , • jj \ \ N 60 30 / - 104, \ . _ ' .. SURVEY PROGRAM � 12 1:5 ' -- 72 �� \\\\ Date: 2009 -09- 03700:00:00 Validated: Yes Version: �� . � � \\ ` Tool \,� \!\\\ Depth From Depth To Survey/Plan ��j --1. 56 `t� 108.70 7908.70 1 . Camera based gyro multishoCB465)RO -MS � \ \Y��.� \� 7982.00 11933.04 H -05A MWD (H -05A) MWD �- \\ 11933.04 14100.00 Plan 2 Plan 2, H-058 MWD l ) 111111"Ittlt 4 41 j � LEGEND 4, - , .A. Nom HaHAN-olAvt �� 212038 II 1.2. Po, , II 1 11111 I l l l 271 IIIIIIIII 16!/ ))))i))))„ll 90 �1 °w (11111111111011vill1711 i _� Illilllllllllll _ . u. 64 % e iiiiii Iiiiiii � ▪ a,1Aa,1 rir 141111.1-1.1.1-19.9 "1r 1410.1.1.190P02 X.IPPP2 VI 8Q 240 \\ \ 12 _ � po % w . .. \ \ \ ` � 128 VI w1.e1 , 1“(A.4.11.41 \ \ \ `e 144 - ft./- - - 160 ▪ 2., , w \` 176 21r \` 192 150 _ °11 , 1122.11-224 N-22.10 . 11-22 e2 1 w°..2 180 Travelling Cylinder Azimuth (TFO +AZI) [O] vs Centre to Centre Separation [16 ft/in] 1 1..°'VI • • Ira r BA KER HUGIES INTEQ North America - ALASKA - BP Prudhoe Bay PB H Pad H -05 Plan 2, H -05B Plan 2 Travelling Cylinder Report 08 September, 2009 � bp pit/ • BAIQ Travelling Cylinder Report 0 bP 1NTEQ Company North America - ALASKA - BP Local Co- ordinate Reference: Well H-05 Project: Prudhoe Bay TVD Reference: H -05A: @ 72.83ft (H -05A:) Reference Site: = '< PB H Pad MD Reference: H -05A: @ 72.83ft (H -05A:) Site Error: 0.00ft North Reference: True Reference Well: H -05 Survey Calculation Method:. Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wetlhore; Plan 2, H -05B Database: EDM .16 - Anc Prod - WH24P Reference Design: Plan 2 Offset TVD Reference: Offset Datum Reference Plan 2 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 11,933.04 to 14,100.00ft Scan Method: Tray. Cylinder North Results Limited by: Maximum center - center distance of 1,607.18ft Error Surface: Elliptical Conic Survey Tool Program Date 9/3/2009! From To (ft) (ft):. , Survey (Wellbore) ? Tool Name ° Description 108.70 7,908.70 1 : Camera based gyro multisho (H -05) CB- GYRO -MS Camera based gyro multishot 7,982.00 11,933.04 I-I-05A MWD (H -05A) MWD MWD - Standard 11,933.04 14,100.00 Plan 2 ( Plan 2, H -05B) MWD MWD - Standard Casing Points f . Measured Vertical Casing Note Depth Depth Diameter ` Diameter (ft) (R) Name fin) fm) 10,854.19 8,547.83 7" 7.000 8.500 14,100.00 9,038.76 2.875" 2.875 4.125 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 9/8/2009 4:52:45PM Page 2 of 19 COMPASS 2003.16 Build 71 I/.ti• • • Travelling Cylinder Report 0 bP 1NTEQ Company: North America - ALASKA - BP Local ordinate Reference: H-05 Project Prudhoe Bay TVD Reference • H -05A: @ 72.83ft (H -05A:) Reference Site: PB H Pad MD Reference: H -05A: @ 72.83ft (H -05A:) Site Error: 0.00ft North Reference: True Reference Well: H - 05 Survey Calculation Method: Minimum Curvature Well Error: " 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan 2, H -05B Database: EDM .16 - Anc Prod - WH24P Reference Design: Plan 2 offset TVD Reference: Offset Datum St�r"i mart' Reference Offset Centre to No-Go Allowa[lle Measured + Measured . Centre Distance De1via Warning Site.Name °.Depth Depth Distance• . (f fromPlan Offset Weld Weilbore . Design . : `.. (ft) (ff) (ft) (ft) . ,. PB H Pad H -01 - H -01 - H -01 Out of range H -01A - H -01A - H -01A Out of range H- 01APB1 - H- 01APB1 - H- 01APB1 Out of range H -02 - H -02 - H -02 Out of range H -02 - H -02A - H -02A Out of range H -02 - H -02A - H-02A wp17 Out of range H -02 - H- 02APB1 - H -02a wp15 Out of range H -02 - H- 02APB1 - H- 02APB1 Out of range H -02 - Plan H -02B - Plan #2 H -02B Out of range H -03 - H -03 - H -03 Out of range H -04 - H -04 - H -04 Out of range H -04 - H -04A - H -04A Out of range H -04 - H -04A - Plan #6 Out of range H -05 - H -05 - H -05 12,400.00 10,825.00 1,042.38 404.04 695.89 Pass - Major Risk H -05 - H -05A - H -05A 12,000.07 12,000.00 0.20 1.44 -1.09 FAIL - Major Risk H -06 - H -06 - H -06 Out of range H -07 - H -07 - H -07 Out of range H -07 - H -07A - H -07A Out of range H -07 - H -07A - Plan #109 Out of range H -08 - H -08 - H -08 Out of range H -17 - H -17 - H -17 Out of range H -17A - H -17A - H -17A Out of range H- 18- H- 18 -H -18 Out of range H -19 - H -19 - H -19 Out of range H -19 - H -19A - H -19A Out of range H -19 - H- 19APB1 - H- 19APB1 Out of range H -19 - H- 19APB2 - H- 19APB2 Out of range H -19 - H -19B - H -19B Out of range H -20 - H -20 - H -20 Out of range H -21 - H -21 - H -21 Out of range H -22 - H -22 - H -22 Out of range H -22A - H -22A - H -22A Out of range H -23 - H -23 - H -23 Out of range H -23A - H -23A - H -23A Out of range H- 23APB1 - H- 23APB1 - H- 23APB1 Out of range H -24 - H -24 - H -24 Out of range H -24 - H -24A - H -24A Out of range H -24 - H -24A - Plan #6 Out of range H -25 - H -25 - H -25 Out of range H -26 - H -26 - H -26 13,150.00 9,950.00 1,594.83 433.29 1,162.51 Pass - Major Risk H -27 - H -27 - H -27 Out of range H -27 - H -27A - H -27A Out of range H -28 - H -28 - H -28 Out of range H -29 - H -29 - H -29 Out of range H -29A - H -29A - H -29A Out of range H -30 - H -30 - H -30 12,150.00 11,225.00 597.61 739.85 - 121.93 FAIL - Major Risk H -33 - H -33 - H -33 Out of range H -35 - H -35 - H -35 Out of range H -36 - H -36 - H -36 Out of range H -36 - H -36A - H -36A Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 9/8/2009 4 :52 :45PM Page 3 of 19 COMPASS 2003.16 Build 71 IGar • e �s • Travelling Cylinder Report bp LNTEQ Company North America - ALASKA - BP ,, Local Co- ordinate Refe • Well H 05 Project , Prudhoe Bay TVD Reference:' H -05A: @ 72.83ft (H-08A1 Reference Site: PB H Pad MDRefe . ? H -05A: @ 72.83ft (H -05A:) Site Error: . 0.00ft North Reference: True Reference Well: ' H -05 Survey Calculation Method: f; Minimum Curvature Well Error :: O.00ft Output errors are at 1.00 sigma Reference Wellbore Plan 2, H-05B Database: EDM .16 - Anc Prod - WH24P Reference Design:, Plan 2 Offset TVD Reference: Offset Datum S ummary . ., . Reference Offset _ Centre to : N�Go .: . AUoWable Measured '' Measured ; Centre Distance .,Deviation W i Site Name : Depth Depth . . Distance- (fit) from Pan Offset Well- Welibore - Design , (ft) (ft) (ff) `.. ,ii,',...- PB N Pad N -21 - N -21 - N -21 11,970.00 11,435.00 1,230.54 362.47 868.45 Pass -Major Risk N -21A - N -21A - N -21A 11,933.04 11,075.00 1,453.78 315.70 1,144.22 Pass -Major Risk N -22 - N -22B - N -226 12,550.00 13,155.00 1,207.56 655.46 561.51 Pass Major Risk N -22 - N -22B - N -22B wp06 12,550.00 13,116.52 1,214.70 651.39 565.42 Pass - Major Risk PB Q Pad Q 01 - Q -01 - Q -01 14,050.00 9,000.00 1,490.72 649.25 876.32 Pass -Major Risk Q -01A - Q -01A - Q -01A 14,100.00 9,775.00 1,254.85 724.95 535.14 Pass -Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 9/8/2009 4:52:45PM Page 4 of 19 COMPASS 2003.16 Build 71 Alaska Department of Naturalisources Land Administration System. Page 1 op t .:1 4 Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources "- Alaska DNR Case Summary File Type: ADL File Number: 28284 Printable Case File Summary See Township, Range, Section and Acreage? New Search J O Yes 0J No LAS Menu 1 Case Abstract 1 Case Detail 1 Land Abstract File: ADL 28284 ''tar Search for Status Plat Updates As of 09/15/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/19/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA -NRB ASSIGNMENT APPROVED Meridian: U Township: O11N Range: 013E Section: 15 Section Acres: 640 Search Plats Meridian: U Township: 011N Range: 013E Section: 16 Section Acres: 640 Meridian: U Township: 011N Range: 013E Section: 21 Section Acres: 640 Meridian: U Township: O11N Range: 013E Section: 22 Section Acres: 640 Legal Description 05 -28 -1965 * * *SALE NOTICE LEGAL DESCRIPTION* * * C14 -95 T11N- R13E -UM 15,16,21,22 2560.00 End of Case Summary Last updated on 09/15/2009. http: / /dnr.alaska.gov /projects /las /Case ?FileType= ADL &FileNumber = 2828... 9/15/2009 • • Ramirez, Darlene V (DOA) From: Foerster, Catherine P (DOA) Sent: Sunday, September 20, 2009 1:35 PM To: Ramirez, Darlene V (DOA) Subject: Re: 209 -100 Approve Sent from my iPhone On Sep 18, 2009, at 10:32 AM, "Ramirez, Darlene V (DOA)" <darlene.ramirez @alaska.gov > wrote: > «S45C- 209091809070.pdf» > The message is ready to be sent with the following file or link > attachments: > S45C- 209091809070.pdf > Note: To protect against computer viruses, e-mail programs may > prevent sending or receiving certain types of file attachments. > Check your e-mail security settings to determine how attachments are > handled. > <S45C- 209091809070.pdf> 1 • . TRANSMITTAL LETTER CHECKLIST WELL NAME 7f / /OSX PTD# 02091000 Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: P,PL//,,!/D4' Zf ' POOL: .Z el/Oh /G - Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last 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(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) 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. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has 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 program. Rev: 1/11/2008 Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 1-1-05B Program DEV - -_ —_ Well bore seg ❑ PTD#: 2091000 Company BP EXPLORATION(ALASKA) INC Initial Class/Type DEV / PEND GeoArea 890 Unit 11650 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes 13 Unique well name and number Yes I4 Well located in a defined pool Yes 15 Well 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 wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Blanket Bond # 6194193. 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes ACS 9/15/2009 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA • 115 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre- produced injector: duration of pre - production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA 18 Conductor string provided NA Conductor set in H -05A Engineering 19 Surface casing protects all known USDWs NA Surface casing set in H -05A 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing cemented 21 CMT vol adequate to tie -in long string to surf csg NA Production casing set in H-05A 22 CMT will cover all known productive horizons Yes cemented solid liner to be set and perfed , 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig equipped with Steel pits. All waste to approved disposal wells. 1 25 If a re- drill, has a 10-403 for abandonment been approved Yes 309 -321 126 Adequatewelibore separation proposed Yes Proximity analysis performed. H -30 598' ctr-ctr 27 If diverter required, does it meet regulations NA Wellhead and BOP stack in place Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Maximum expected fm pressure 7.0 ppg EMW ... drilling with 8.6 ppg mud 29 BOPEs, do they meet regulation Yes GLS 9/17/2009 Y 9 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 2320 psi 3500 psi BOP test planned • 31 Choke manifold complies w/API RP-53 (May 84) Yes I32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S on H - pad. Rig equipped with alarms and sensors. 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Max level H2S on H Pad was 180ppm for well H -22A. Geology 136 Data presented on potential overpressure zones NA Appr Date 1 37 Seismic analysis of shallow gas zones NA condition b eae conon surve (if off - shore) NA ACS 9/15/2009 38 Seabed survey (�- 1 39 Contact name /phone for weekly progress reports [exploratory only] Yes Ron Phillips - 564- 5913. Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date • Well History File APPENDIX Information of detailed nature that is not • particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • • tapescan.txt * * ** REEL HEADER * * ** MWD 10/01/06 BHI 01 LIS Customer Format Tape * * ** TAPE HEADER * * ** MWD 09/10/18 2818465 01 3" CTK * ** LIS COMMENT RECORD * ** 1111 111111111111111 Remark File Version 1.000 1111111111111111111 Extract File: ldwg.las 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 11605.5000: Starting Depth STOP.FT 14039.5000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. - 999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: H -05B FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 70 deg 17' 53.718 "N 148 deg 50' 21.725 "W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 18 Oct 2009 API . API NUMBER: 500292010602 -Parameter Information Block #MNEM.UNIT Value Description SECT. 21 Section TOWN.N T11N Township RANG. R13E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF . DF Log Measured from FAPD.F 72.83 Feet Above Perm. Datum DMF . DF Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 72.83 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 . DIRECTIONAL Other Services Line 1 -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are subsea corrected. (4) All Formation Evaluation data is realtime data. Page 1 0641-1o0 • • tapescan.txt (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 Downhole 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 Primary Depth Control log from Schlumberger GR CNL 20 Oct 2009 per Roger Sels with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from H -05A through a milled window in a 4 1/2 inch liner. Top of window 11950 ft.MD (8951.3 ft.TVDSS) Bottom of window 11959 ft.MD (8951.4 ft.TVDSS) (9) Tied to H -05A at 11933 feet MD (8951.2 feet TVDSS). (10) The resistivity interval between 11959 ft. to 12170 ft. MD (8951.1 ft. to 8951.4 ft. TVDSS) was logged on run 5 9 1/2 hours after drilling. Data has been correlated to drilled Gamma Ray data and depth shifted -1.2 ft. (11) The interval from 14004 feet to 14044 feet MD (8952.7 ft. to 8953.3 ft. TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD -API units) ROP AVG -> Rate of Penetration, feet /hour RACLX -> Resistivity (AT)(LS)400kHz- Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz- Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz- Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHz- Compensated Borehole Corrected (OHMM) TVDSS -> True vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 11612.4, 11612.9, ! 0.538086 11625.5, 11624.4, ! - 1.07617 11632.5, 11629.8, ! - 2.69141 11634.6, 11633, ! - 1.61523 11647.2, 11645.2, ! - 1.97363 11652.1, 11650.7, ! - 1.43555 11660, 11659.3, ! - 0.717773 11666.1, 11665.6, ! - 0.538086 11672.6, 11671.5, ! - 1.07617 11677, 11674, ! - 3.0498 11680.6, 11676, ! - 4.66406 11681.7, 11677.4, ! - 4.30566 11689.4, 11684.9, ! - 4.48535 11693.2, 11689.6, ! - 3.58789 11702.4, 11699.6, ! - 2.87109 11705.7, 11704.2, ! - 1.43457 11717, 11712.7, ! - 4.30566 11722.2, 11718, ! - 4.12695 11726.5, 11722.3, ! - 4.12598 11731.7, 11727.5, ! - 4.12598 11734, 11729.5, ! - 4.48535 11738.4, 11733.9, ! - 4.48438 11749.2, 11745, ! - 4.12598 11769.1, 11768, ! - 1.07617 11773.5, 11771.2, ! - 2.33203 11779.8, 11777.7, ! - 2.15332 11835.7, 11830.8, ! - 4.84375 11837.6, 11833.9, ! - 3.76758 11921.9, 11918, ! - 3.94727 11956.7, 11959.1, ! 2.33203 11958.3, 11960.7, ! 2.33203 12006.4, 12009.8, ! 3.4082 12270.6, 12271.7, ! 1.07617 12354.9, 12354.9, ! 0 12453.4, 12455, ! 1.61523 12515.8, 12518.1, ! 2.33203 12639.2, 12637.4, ! - 1.79395 12657.4, 12655, ! - 2.33301 12658.3, 12656.1, ! - 2.15234 Page 2 • tapescan.txt 12661.5, 12660, ! - 1.43555 12755.6, 12751.8, ! - 3.76758 12773.7, 12771.2, ! - 2.51172 12899.2, 12896.6, ! - 2.51172 12920, 12915.8, ! - 4.12598 12965.4, 12966, ! 0.538086 12974.4, 12974.6, ! 0.178711 13008.3, 13006.5, ! - 1.79395 13015.1, 13013, ! - 2.15332 13023.6, 13020.7, ! - 2.87012 13056.9, 13051.8, ! - 5.02344 13063.1, 13058.1, ! - 5.02344 13100.4, 13098.4, ! - 1.97363 13102.6, 13100, ! - 2.51172 13143.1, 13138.8, ! - 4.30566 13158.2, 13153.3, ! - 4.84375 13172.5, 13169.1, ! - 3.40918 13181.3, 13176.1, ! - 5.20215 13238.3, 13236.2, ! - 2.15234 13277, 13267.3, ! - 9.6875 13458.2, 13458.4, ! 0.179688 13460.9, 13460.3, ! - 0.538086 13463.6, 13463.6, ! 0 13482.9, 13484.5, ! 1.61426 13500.4, 13498.2, ! - 2.15234 13502.9, 13501.4, ! - 1.43457 13507, 13506.3, ! - 0.716797 13513.1, 13511.3, ! - 1.79395 13514.4, 13512.9, ! - 1.43555 13515.8, 13514.9, ! - 0.896484 13518.7, 13517.8, ! - 0.897461 13520.1, 13519.4, ! - 0.717773 13523.3, 13523, ! - 0.358398 13526.2, 13526.4, ! 0.179688 13541.8, 13542.2, ! 0.358398 13562.3, 13561.9, ! - 0.359375 13565, 13563.9, ! - 1.07617 13568.4, 13567, ! - 1.43555 13618, 13615.8, ! - 2.15234 13626.1, 13623.9, ! - 2.15234 13631.4, 13628.9, ! - 2.51172 13657.5, 13656.5, ! - 1.07715 13668.8, 13667.2, ! - 1.61426 13670.6, 13668.5, ! - 2.15234 13674.6, 13672.8, ! - 1.79395 13676, 13675.1, ! - 0.897461 13685.9, 13685.2, ! - 0.717773 13742.8, 13738.1, ! - 4.66504 13744.6, 13740.3, ! - 4.30566 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 165 records... Minimum record length: 10 bytes Maximum record length: 132 bytes * * ** FILE HEADER * * ** MWD .001 1024 Page 3 • . tapescan.txt * ** INFORMATION TABLE: CONS * ** LIS COMMENT RECORD * ** 1111,11111111111111 Remark File Version 1.000 The data presented here is final and has been depth adjusted to a Primary Depth Control log provided by Schlumberger GR CNL dated 20 Oct 2009 per Roger Sels with BP Exploration (Alaska), Inc. * ** INFORMATION TABLE: CIFO * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 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 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 136 Tape File Start Depth = 11605.500000 Tape File End Depth = 14039.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet * * ** FILE TRAILER * * ** Tape subfile: 2 149 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** FILE HEADER * * ** MWD .002 1024 Page 4 i i tapescan.txt * ** INFORMATION TABLE: CONS * ** LIS COMMENT RECORD * ** 11,1111111 II I!I Remark File version 1.000 This file contains the raw - unedited field MWD data. * ** INFORMATION TABLE: CIFO * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 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 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 272 Tape File Start Depth = 11604.750000 Tape File End Depth = 14044.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet * * ** FILE TRAILER * * ** Tape Subfile: 3 285 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** TAPE TRAILER * * ** MWD 09/10/18 2818465 01 Page 5 tapescan.txt * * ** REEL TRAILER * * ** MWD 10/01/06 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape subfile 1 is type: LIS 0 Tape subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 11605.5000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 11606.0000 25.8000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 14039.5000 - 999.2500 13.9393 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File start Depth = 11605.500000 Tape File End Depth = 14039.500000 Tape File Level spacing = 0.500000 Tape File Depth units = feet 0 Tape subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 11604.7500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 11605.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 14044.0000 - 999.2500 14.7000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File Start Depth = 11604.750000 Tape File End Depth = 14044.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet 0 Tape subfile 4 is type: LIS Page 6