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Home My WebLink About203-1577. 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 Q-07B Ext Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 203-157 50-029-20352-02-00 12764 Conductor Surface Intermediate Liner Liner 9023 80 2689 10260 762 2014 12290 20" x 30" 13-3/8" 9-5/8" 7" 4-1/2" 9023 29 - 109 28 - 2717 26 - 10286 10138 - 10900 10750 - 12764 29 - 109 28 - 2675 26 - 7875 7763 - 8419 8276 - 9023 None 2670 4760 5410 7500 12290 5380 6870 7240 8430 10908 - 12675 4-1/2" 12.6# 13cr, L-80 25 - 10760 8426 - 9026 Structural 4-1/2" HES TNT Packer 10703, 8233 10454, 10703 8009, 8233 Torin Roschinger Operations Manager Brenden Swensen brenden.swensen@hilcorp.com 907-748-8581 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, 0028285 25 - 8286 N/A N/A 434 663 86203 4530 92 688 0 950 900 750 325-439 13b. Pools active after work:Prudhoe Oil 4-1/2" Baker S3 Packer 10454, 8009 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 No SSSV Installed By Grace Christianson at 8:42 am, Sep 18, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.09.18 05:23:48 - 08'00' Torin Roschinger (4662) RBDMS JSB 092525 J.Lau 11/6/25 ACTIVITYDATE SUMMARY 8/25/2025 ***WELL S/I ON ARRIVAL*** RAN 3.70" CENTRALIZER & 2-1/2" SAMPLE BAILER TO DEVIATION @ 11,650' SLM ***WELL LEFT S/I ON DEPARTURE*** 8/28/2025 LRS CTU 2, 1.75" x .156" HT-110. Job Scope: Pull patch, Set CIBP, Ext. Adperf MIRU. Standby for crosswind above 25mph, unable to raise mast. Begin weather ticket ***Job in Progress*** 8/29/2025 LRS CTU #2 1.75" CT 0.156"WT HT-110 Job Objective:Pull Patch, Set CIBP, Adperf Continue RU following weather standby, Conduct weekly BOP test, Function test BOP on the well. MU/RIH YJ 2-7/8" fishing bha w/ 4"G-Spear bha. Latch Upper 45 Flo-Guard PKR at 12055' CTMD. Jar 19x/20 cycles with no signs of movement. Release form fish, POOH. RIH w/ 2-7/8" fishing assembly w/ 3X WT bars, latch upper patch and jar free, PUH, jar through XN nipple w/ 2 jar licks, overpull through each X nipple, POOH. Recover upper 45 Flo-guard packer, left 1 packing element in hole, snaplatch is not flowcut. B/D fishing bha, stack down to change packoffs. MU YJ 2- 7/8" fishing bha w/ 4"G-spear ***Continue on 8-30-25 WSR*** 8/30/2025 LRS CTU #2 1.75"CT 0.156"WT HT-110 Job Objective: Pull Patch, Set CIBP, Adperf RIH w/ YJ 2-7/8" fishing bha w/ 4"G-spear, tag spacer pipe at 12074', overpull 12k and spacer pipe came free, POOH. Recovered upper spacer pipe 13.12' w/ all seals, snap latch is not flow cut, RIH w/ YJ 2-7/8" fishing bha w/ 4"G-spear. Latched at 12087 CTM, overpull 24K and break free. POOH. Recovered lower spacer pipe. Snaplatch not flowcut, all seals recovered. Add weight bars and RIH with 4" GS BHA. Latched lower packer at 12109 CTM. 7 jar licks and packer came free. Allow element to relax. Run past tag depth. POOH. Recovered lower packer. 1 element missing. Freeze protect well with 38 bbl of diesel. Pad operator notified of well status. RDMO to LRS shop for Northstar prep. ***Job Incomplete*** ****All 4 pieces of the BKR 45 Flo-Guard straddle patch recovered*** ***LIH: (2) packer elements*** 9/2/2025 CTU #8 1.75" CT 0145" WT Job Scope: Set CIBP, Ext Adperf Travel to location. MIRU CTU. MU YJOS MHA and PT to 350 psi low / 3500 psi high. ***Job in Progress*** Daily Report of Well Operations PBU Q-07B Daily Report of Well Operations PBU Q-07B 9/3/2025 CTU #8 1.75" CT 0.145" WT Job Scope: Set CIBP, Ext Adperf MU YJOS Venturi BHA (3.70" max OD). Open up well and it is still dead from kill performed on 8/29. RIH for dry drift / recovery of 2 45KB packer elements. Drift clean down to 12676, POOH. Load well with 175bbls safelube. L/D YJ venturi. M/U HES GR/CCL w/3.5" DJN. RIH. Log from PBTD to 10,200. Paint flag at 12,050'. POOH pumping SL down BS. Confirm CTC tag against brass. Bump test H2S/LEL alarms. L/D HES logging tools. M/U YJ 4-1/2" CIBP. RIH and correct mid-element plug depth to flag, 12,057'. Set and tag plug at 12,290'. PUH to 11,600' EOP measurement and paint flag. Came up to 9000' and performed good no-flow test. Started to pump across top and immediately got returns back. Minimal losses from well while POOH. Perform good no-flow test after tagging up at surface, pump across top and get returns immediately. L/D YJOS setting tool and M/U perforating MHA. **Job in progress** 9/4/2025 CTU #8 1.75" CT 0.145" WT Job Scope: Set CIBP, Ext Adperf PT MHA to 3500 psi. Stand by for crane to arrive from DS1. Well taking 2 BBLS per hour. Spot in crane and hold deployment PJSM, discuss standing orders in the event of a kick and perform drill. Check safety joint makes up to gun adapter. Begin deploying 2-7/8" Maxforce guns, 60 deg phase 6 SPF, max swell 3.047", EHD-.37". RIH to flag, correct to top shot. RIH and perforate intervals 11,685-11702', 11,710- 11,757', 11,767-11,782', 11,811-11,841', 11,867-11,880', 12,031-12,185'. Well on vac after perforating and get differentially stuck for about 30 seconds. POOH. PJSM for undeployment, review monthly safety topic (line of fire), hold kick drill. Undeploy perf guns, all shots fired. Fluid pack coil and test injectivity, well taking fluid 1 bpm @ 1000 psi WHP. Swap to CTBS and bullhead 170 bbls diesel. RDMO to PM1-08. ***Job Complete*** 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU Q-07B Ext Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 203-157 50-029-20352-02-00 341J ADL 0028284, 0028285 12764 Conductor Surface Intermediate Liner Liner 9023 80 2689 10260 762 2014 12676 20" x 30" 13-3/8" 9-5/8" 7" 4-1/2" 9026 29 - 109 28 - 2717 26 - 10286 10138 - 10900 10750 - 12764 2620 29 - 109 28 - 2675 26 - 7875 7763 - 8419 8276 - 9023 None 2670 4760 5410 7500 None 5380 6870 7240 8430 10908 - 12675 4-1/2" 12.6# 13cr, L-80 25 - 107608426 - 9026 Structural 4-1/2" HES TNT Packer 4-1/2" Baker S3 Packer 10454, 8009 10703, 8233 Date: Torin Roschinger Operations Manager Brenden Swensen brenden.swensen@hilcorp.com 907-748-8581 PRUDHOE BAY 8/7/2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 11:47 am, Jul 25, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.07.25 11:35:19 - 08'00' Torin Roschinger (4662) 325-439 JJL 7/30/25 DSR-8/13/25 Perforating gun not to exceed 500'. Reestablish pressure containment prior to perforating. Perform and document well control drill on each shift using attached standing orders and verify correct XO for safety joint. Ensure well is dead before breaking containment A.Dewhurst 29JUL25 10-404 *&: 8/14/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.14 10:05:21 -08'00' RBDMS JSB 081825 Page 1 of 12 Extended Add Perforation Well: Q-07B PTD: 203-157 Well Name:Q-07B API Number:50-029-20352-02 Current Status:Ivishak Producer PTD #203-157 Estimated Start Date:8/7/2025 Rig:Service Coil Tubing Reg.Approval Req’std?10-403, 10-404 Estimated Duration:2 days Regulatory Contact:Abbie Barker 907-564-4915 (O) First Call Engineer:Brenden Swensen 907-748-8581 (M) Second Call Engineer:Finn Oestgaard 907-350-8420 (M) Current Bottom Hole Pressure:3,200 psi @ 8,800’ TVD (7.0 ppge, based on offsets) Maximum Expected BHP:3,500 psi @ 8,800’ TVD (est.) 7.6ppg EMW Max. Anticipated Surface Pressure:2,620 psi Gas Column Gradient (0.1 psi/ft) Last SI WHP:1,000 psi (7/8/2025) H2S Level (Most Recent / Highest):18ppm 03/07/2025, 25ppm 10/14/2017 History Q-07B was originally completed in 1979. The A wellbore was sidetracked in 1998 and the B wellbore sidetracked in 2003. Q-07B struggled with production tubing integrity issues in 2018. Two patches were set in 2018 to restore integrity. However, tubing integrity failed again in October 2020. A RWO was performed to replace the tubing in 2021. There have been 3 perforation iterations over the life of the B wellbore along with a production straddle patch isolating perforations in 2015. The well is currently a marginal cycle producer. The production profile modification planned out in this program intends to improve competitiveness and restore the well to a full on-time producer. Objective Pull patch isolating perforations in liner. Set plug to isolate the deepest perforation interval. Perforate ~276’ of additional Z1B Ivishak. Page 2 of 12 Extended Add Perforation Well: Q-07B PTD: 203-157 Procedure (Page 1 of 3) Slickline 1. Drift to deviation with ±3.70” gage ring and sample bailer. a. 10/1/2022 Eline was last to rig up on this well. Able to make it to 12,676’ MD with tractor for caliper log. b. Ensure tubing has no restrictions prior to pulling of patch. c. Deviation expected at 11,617’ MD 70deg inclination. i. SL made it to 12,603’ SLM on 9/24/2022 prior to eline tractor. Coil Tubing 2. Pull Baker straddle patch from 12,049’ MD. a. Patch is a 4-run patch assembly. As-run diagram attached. b. Review job service reports on 6/16/2015 and 6/17/2025 for additional information. c.CONTINGENT:If patch does not come out of hole, contingent plan is to set a plug inside the patch to isolate lower perforations, perforate the patch and above the patch. Perf depths will be shortened / modified accordingly. i.Plug will be set at ± 12,100’ MD ii.Bottom most perf will terminate at ± 12,095’ MD iii.Patch perforations will be smaller gun size, 1.56” preferred as only need to perf pipe. 3. Perform GR/CCL logging run from PBTD to 10,200’ MD. Flag pipe. a. The liner is L80, however Read caliper dated 09/30/2022 suggests that liner is in good condition. No need to rerun caliper for plug set. b. Send tie in to OE and Geo. i. Brenden Swensen brenden.swensen@hilcorp.com ii. Jeff Nelson jeff.nelson@hilcorp.com 4. Set plug at ± 12,350’ MD. a. 165’ offset from bottom perf target. If offset needs to be reduced more than ± 50’, converse with OE about setting plug after perforating to ensure plug is not damaged from perforating. b. Tie in log does not have CCL. Adjust depth at WSL discretion to avoid setting in a collar. Coil Tubing – Extended Perforating Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x 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 perf 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. 5. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. Page 3 of 12 Extended Add Perforation Well: Q-07B PTD: 203-157 Procedure (Page 2 of 3) Coil Tubing – Extended Perforating 6. Bullhead 1.2x wellbore volume ~200 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. (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.) a. Wellbore volume to top perf = 166 bbls 7. At surface, prepare for deployment of TCP guns. 8. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 9.*Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review standing orders 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. 10. Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. 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. Perf Schedule Use 2-7/8” MaxForce guns or similar** Sand TOP MD BOT MD Total Order to Shoot Gross Interval Net Guns Weight of Gun (lbs) Z1B 11,685'11,702'17 1 500 276 ± 12.6 ppf * 276' guns + ± 9.7 ppf * 224' spacer = ± 5,651 lbs Z1B 11,710'11,757'47 Z1B 11,767'11,782'15 Z1B 11,811'11,841'30 Z1B 11867'11,880'13 Z1B 12,031'12,185'*154* * See the note above on contingency if patch is unable to be retrieved ** Patch perforations will be smaller gun size, 1.56” preferred as only need to perf pipe. All other perforations will remain larger gun size. 11. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. Page 4 of 12 Extended Add Perforation Well: Q-07B PTD: 203-157 Procedure (Page 3 of 3) Coil Tubing – Extended Perforating 12. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary before pulling to surface. 13. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 14. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 15. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 16. RDMO CTU. 17. Turn well over to Operations POP. Attachments x Current Wellbore Schematic x Proposed Wellbore Schematic x Tie in Log x BOPE Schematic x Standing Orders x Equipment Layout Diagram x Sundry Change Form Page 5 of 12 Extended Add Perforation Well: Q-07B PTD: 203-157 Page 6 of 12 Extended Add Perforation Well: Q-07B PTD: 203-157 Page 7 of 12 Extended Add Perforation Well: Q-07B PTD: 203-157 Tie In Log (Page 1 of 2) Page 8 of 12 Extended Add Perforation Well: Q-07B PTD: 203-157 Tie In Log (Page 2 of 2) Page 9 of 12 Extended Add Perforation Well: Q-07B PTD: 203-157 BOP Schematic Page 10 of 12 Extended Add Perforation Well: Q-07B PTD: 203-157 Page 11 of 12 Extended Add Perforation Well: Q-07B PTD: 203-157 Page 12 of 12 Extended Add Perforation Well: Q-07B PTD: 203-157 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 HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:203-157 6.50-029-20352-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 12764 12676 8274 10454, 10703 None None 8009, 8233 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 30" 29 - 109 29 - 109 Surface 2689 13-3/8" 28 - 2717 28 - 2675 5380 2670 Intermediate 10260 9-5/8" 26 - 10286 26 - 7875 6870 4760 Liner 762 7" 10138 - 10900 7763 - 8419 7240 5410 Perforation Depth: Measured depth: 10908 - 12675 feet True vertical depth:8426 - 9026 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 25 - 10760 25 - 8286 10454 8009Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES TNT Packer Liner 2014 4-1/2" 10750 - 12764 8276 - 9023 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 7281000113631 26415832 0 36398 638 679 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Brian Glasheen Brian.Glasheen@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.5277 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing 5 GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9023 Sundry Number or N/A if C.O. Exempt: 321-125 4-1/2" Baker S-3 Perm Packer 10703 8233 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Tubing Swap Operations shutdown Change Approved Program 5 N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028284 & 0028285 PBU Q-07B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:53 pm, Sep 23, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.09.23 13:33:38 -08'00' Stan Golis (880) MGR15OCT2021 SFD 9/28/2021RBDMS HEW 9/24/2021 DSR-9/23/21 ACTIVITY DATE SUMMARY 3/13/2021 T/I/O = SSV/170/0+. Temp = SI. OA FL (pre MIT). No AL. OA FL @ near surface. SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:30 3/15/2021 T/I/O = 470/180/0. Temp = SI. OA Integrity Test to 1200 psi PASSED (Pre Rig). No AL. OA FL @ near surface. Used 3.2 bbls amb Diesel to pressure OA to 1200 psi. OAP decreased 40 psi in 5 min. No visible leaks detected on the surface kit, in the cellar, or anywhere else. Bled OAP to 0 psi (1.6 bbls). Hung tags. Final WHPs = 470/170/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:45 3/19/2021 T/I/O = SSV/170/0. Temp = SI. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. No AL. PPPOT-T: Stung into test port (800 psi), bled to 0 psi. Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 250 psi in 15 min, lost 50 psi in second 15 min (PASS). PPPOT-IC: Stung into test port (200 psi), bled void to 0 psi. Did not function LDS. Unable to pressure test void above 1900 psi. Bled void back to 0 psi. RU to PKG port and re-energized Y seal. Pressured test void to 3500 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. SV, WV, SSV = C. MV = O. IA & OA = OTG. 17:30. 3/20/2021 ***WELL S/I ON ARRIVAL*** (RWO) PULLED 4-1/2" BAKER FLO-GUARD PATCH FROM 4,938' SLM. PULLED 4-1/2" BAKER FLO-GUARD PATCH FROM 6,745' SLM. (missing 1 element) RAN 4-1/2" BRUSH, 3.75" 3 PRONG WIRE GRAB, S/D ERRATICALLY FROM 6,663' SLM - 7,200' SLM. (no recovery) ***WSR CONTINUED ON 3/21/21*** 3/21/2021 ***WSR CONTINUED FROM 3/20/21*** (RWO) PULLED 2-7/8" XX-PLUG FROM NIP-REDUCER @ 10,747' MD. PULLED 4-1/2" NIP-REDUCER FROM 10,747' MD. RAN 4-1/2" BRUSH, 3.60" G-RING TO BRUSH XN-NIP @ 10,747' MD. LRS LOADS TBG w/ 180 bbls CRUDE. SET 4-1/2" PX-PLUG w/ FILL EXT IN XN-NIP @ 10,747' MD. LRS PERFORMS PASSING CMIT-TxIA TO 2971/3033 PSI. ***JOB COMPLETE, WELL LEFT S/I*** 4/16/2021 T/I/O = 660/680/0. Temp = SI. TBG & IA FL (E-Line request). No AL or flowline. Wellhouse removed. TBG & IA FL @ surface. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:00 4/23/2021 ***WELL S/I ON ARRIVAL, DSO NOTIFIED***(tubing punch) PUNCH TUBING 10595'-10600' USING 2", 0 PHASE, 4 SPF, HSC LOADED W/ TITAN CIR-2107-4T281 CHARGES. SEEN TBG/IA PRESSURE CHANGE. CCL TO TOP SHOT OFFSET: 8.3', CCL STOP DEPTH: 10586.7'. CORRELATED TO TUBING TALLY RECORD DATED 12-OCT-2003. ...CONT ON 24-APR-2021... Daily Report of Well Operations PBU Q-07B Daily Report of Well Operations PBU Q-07B 4/23/2021 T/I/O= 500/550/0. LRS unit 72 Assist E-Line (RWO EXPENSE). Pumped 40 bbls of crude into the TBG during step rate test while taking IA returns to Q-05 (online per Pad Operator). T/I/O=1550/1200/0 @ 5 bpm. Pumped 850 bbls of 1% KCl into the TBG with IA returns to Q-05 F/L (online). Pumped 152 bbls of diesel into the TBG with IA reutrns. U-Tube TxIA for 1 hour. Bled the TxIA to 800 psi. Final T/I/O= 800/800/20. Flushed hardline to Q-05 treecap with 3 bbls of diesel. 4/24/2021 ...JOB CONT FROM 23-APR-2021... DETONATE 160 GR/FT STRING SHOT FROM 10629'-10635' CCL TO BOTTOM STRING SHOT: 8.6'. CCL STOP DEPTH: 10626.4'. CUT TUBING AT 10635' W/ 3.625" CHEMICAL CUTTER. CCL TO CUTTER OFFSET: 11.9'. CCL STOP DEPTH: 10623.1'. CORRELATED TO TUBING TALLY RECORD DATED 12-OCT-2003. ***TURN WELL LEFT S/I AND TURN OVER TO DSO*** 4/25/2021 T/I/O= 0/0/0. LRS unit 72 (RWO EXPENSE) Attempt CMIT-TxIA to 1000 psi *FAILED* T/IA lost 127/127 psi during the first 15 minutes (third attempt). Pumped 55 bbls of 35* F diesel to achieve test pressure.Bled back 2.5 bbls to Final T/I/O= 60/40/0. 4/26/2021 T/I/O = SSV/Vac/0. Temp = SI. IA FL (WIE call in). No AL, wellhouse or flowline. IA FL @ 40' (1.9 bbls). SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:50 4/27/2021 T/I/O = Vac/Vac/Vac. Temp = SI. CMIT T x IA to 1000 psi -Failed- (Pre Rig). No AL, flowline or wellhouse. TBG FL @ near surface. IA FL @ near surface. Pumped 19 bbls of DSL down the IA @ .3 bpm. Could not catch pressure. The max pressure seen was TBG/IA (Vac/11 psi). Tag hung. FWPs = vac/4/vac. SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:00 5/4/2021 ***WELL S/I UPON ARRIVAIL*** (rwo expense) R/U HES 759 SLICKLINE UNIT ***CONT WSR ON 5/5/21*** 5/5/2021 T/I/O=vac/vac/vac SI AssistSL with LDL (RWO EXPENSE) Pumped 57 bbls DSL down IA. Ubable to maintain LLR > 0.25bpm. Pressured up to 2500psi. Ia lost 100psi 1st 15min, 100psi 2nd 15min. Leak off rate approx 0.9gpm. FWHP's = 2000/2000/vac 5/5/2021 ***CONT WSR FROM 5/4/21*** (rwo expense) RAN 3.48" DECENT, 3.70" LIB TO 10,727' SLM (inconclusive) RAN 3.63" CENT, 3.50" LIB TO 10,729' SLM (impression of prong) RAN RCH STP LDL AS PER PROGRAM LRS PUMP TOTAL OF 57 BBLS DIESEL RAN RCH ACOUSTIC LDL AS PER PROGRAM (leak found @ plug) ***CONT WSR ON 5/6/21*** 5/6/2021 (TFS Unit 1 Assist Slickline with MIT-TxIA) Standby on location, Slickline unable to set plug. No fluids pumped. Slickline in control of well upon T FS departure. Daily Report of Well Operations PBU Q-07B 5/6/2021 ***CONT WSR FROM 5/5/21*** PULLED EQ PRONG FROM XN-NIP @ 10,747' MD(pkg imbedded w/ metal and torn) PULLED PXN PLUG BODY FROM XN @ 10,747'MD PLUG SET ATTEMPT IN XN @ 10,747' MD BROACH / SWEDGE TBG CUT @ 10,619' SLM TO 10,623' SLM SET 4-1/2" PXN IN XN @ 10,747' MD(check set) ***CONT WSR ON 5/7/21*** 5/7/2021 T/I/O=0/0/0 CMIT TxIA PASSED to 2500 psi (RWO Prep) Pumped 27 bbls diesel down IA to 2750 psi. T/IA lost 43/45 1st 15 min & 21/22 psi 2nd 15 min (1st test) 2nd attempt (Per Slickline WSL Bumped pressure with 0.5 bbl. T/IA lost 14/17 psi & 11/12 psi. Bled back 6 bbls to FWHPs=900/900/0 5/7/2021 ***CONT WSR FROM 5-6-21*** SET PXN @ 10,734' SLM SLICKLINE PUMPED 40 BBLS DIESEL, LRS PUMP 27 BBLS DIESEL TO LOAD TUBING & IA 1ST PT STARTING PSI T=2743psi, IA=2763psi, 1ST 15 MIN. T=2700psi, IA=2718psi, 30 MIN T=2679psi, IA=2696psi 2ND PT STARTING PSI T=2745psi, IA=2763psi, 1ST 15 MIN. T=2731psi, IA=2746psi, 30 MIN T=2720psi, IA=2734ps (GOOD TEST) BLEED PSI ON TUBING & IA TO 100psi ***WELL LEFT SI*** 5/9/2021 Circ Out to tanks (RWO EXPENSE) Pumped 845 bbls 1% SKL and 172 bbls DSO down IA, Up Tbg taking returns to tanks. U-Tube DSL into Tbg for 1 hour. FP surface lines w/ 60/40 meth. Pad Op notified of well status per LRS depature. SV,WV=C SSV,MV=O IA,OA=OTG **Tags on MV and IA 8/15/2021 ***COST PLACEHOLDER*** repair shear valve, 3-bk-dglv's for completion 8/24/2021 T/I/O=SSV/0/0. Wellhead tech open SSV, verify 0 psi on tubing, set 4" CTS BPV w/ dry rod, verify 0 psi on THA void, N/D 4" prodution tree and 13-5/8" THA, remove DX seal from hanger, clean void and hanger neck, inspect seal areas and lift threads, function all tubing hanger LDS to minimum of 4-1/8" clear bowl OUT measurement and in again, torque LDS and gland nuts to 550 ft/lbs, install CTS plug in BPV, MU 4- 1/2" NSCT test sub 8-1/2 RH turns, test CTS plug to 3500 psi for 5 mins, good test, bleed psi, BO test sub, assist WS orient and set BOP's, WS N/U BOP's with shooting flange and tree cap bonnet. Torqued to specs. Installed Integral on I.A. Job complete. FWP's TWC/0/0 9/4/2021 Thunderbird Rig 1: MIRU, Perform BOPE Shell Test to 250 psi low and 3,500 psi high. Continued on 9/5/21 WSR... 9/5/2021 Pull CTS Plug, retreive CTSBPV. S/B for circulate. M/U LJ to TBG HGR (4 1/2" NSCT lift threads) BOLDS to out measurement of 4 1/8". Pull TBG HGR to rig floor. Wrap TBG HGR w/ absorb. Laydown TBG HGR and LJ. Install TBG HGR neck protector. Send TBG HGR to get re-pupped. 9/5/2021 Pull CTS plug and retreive 4" CTSBPV with dry rod 0 pressure under plug. Stand by for circulation. M/U landing joint to TBG HGR (4 1/2" NSCT TBG HGR lift threads). BOLDS to out measurement of 4 1/2". Pull TBG HGR to rig floor, (95K to offset TBG HGR). Wrap TBG HGR w/ absorb. Lay down TBG HGR and remove landing joint. Daily Report of Well Operations PBU Q-07B 9/5/2021 Thunderbird Rig 1: ... Continued from 9/4/21 WSR. Replace gas Sensor. Perform BOPE Test to 250 psi low and 3,000 psi high with 4-1/2" test joint. AOGCC Inspector Austin McLeod witnessed. One Fail /Pass on CHk manifold valve #5. Serviced and retested. Verify 0 pressure on IA. Vault pulled CTS plug and BPV. Rock 172 bbls diesel out of well and send to recycle. Pump 75 bbls Baraklean followed by 750 bbls 160* 1% KCL @ 4.3 bpm @ 300 psi. Verify no flow on Tbg or IA. MU landinf jt f/ FOSV. BOLDS. Pulled hanger free @ 116K (expected) Hanging weight 108k. Break and L/D Hanger. POH w/4-1/2" 12.6# L-80 completion while filling displacement every 15 joints. Continued on 9/6/21 WSR... 9/6/2021 Inspect TBG HGR, M/U to LJ (4 1/2" NSCT lift threads) M/U TBG HGR to string. Land TBG HGR @ RKB of 10.7' verify landed through IA. 9/6/2021 Thunderbird Rig 1: ... Continued from 9/5/21 WSR. Continue to POH w/ 4-1/2" 12.6# L-80 completion. R/U GBR. Lay out completion. RIH w/ 4-1/2" 12.6" 13CR completion with Unique Machine Overshot and HES TNT Packer. P/U Joint #254. Tag 7' in on Joint (10,621' TB#1 RKB). Sit down 20k-lbs. Unable to slide Overshot over Tubing stub. Attempted multiple times. R/U to reverse circulate. R/U to reverse circulate at 1 BPM at 100 psi and attempt multiple times to slide over stump. Sitting down at 10,621' with 20k-lbs. Reverse circulate at 2 BPM at 150 psi and attempt multiple times to slide over stump. Sitting down at 10,621' with 20k-lbs. Reverse circulate at 3 BPM at 200 psi and attempt to slide over stump. Slide over stump. See shear pins at 10.625'. Continue to RIH with 10k-lbs down and no-go at 10,635'. Did not see 2nd set of shear pins. Overshot clearly over Tubing stub. Pump presure climbed from 200 psi to 450 psi as the stub was swallowed. L/D Joint #254. Calculate that no space out pups are needed. M/U Hanger. Land Hanger. RILDS. P/U = 107k-lbs. S/O = 77k-lbs. Continued on 9/7/21 WSR 9/7/2021 Continued from 9/6/21. RILDS and torque to 550 ft lbs. Torque gland nuts. S/B for set packer/test tbg. Set 4" HTWC. S/B for rig move off. N/D BOP. Remove TBG HGR neck protector, clean void, inspect TBG HGR neck and lift threads. Install new DX seal, install new BX160. N/U THA. Fill void w/ test oil. Test void to 5M for 30 min. loss of 100 psi after the first 15 min. 0 loss after last 15 min. Good test. Rig down test equipment. Bleed off pressure. S/B for tree N/U and shell test. Retreive 4" HTWC w/ dry rod. 9/7/2021 Thunderbird Rig 1: Continued from 9/6/21 WSR... Reverse Circulate 175 bbls of 1% KCl with 1% Baracor and 0.1% oxygon while taking returns to theTiger Tank at 3 BPM and 625 psi. Reverse Circulate 378 bbls of 1% KCl while taking returns to the Pits at 3 BPM and 625 psi. Drop Ball and Rod. Pressure up on Tubing to 500 psi for 5 minutes. Pressure up on Tubing to 3,000 psi and set packer. MIT-T to 3,000 psi for 30 charted minutes. Bleed Tubing to 1,000 psi. MIT-IA to 2,750 psi for 30 charted minutes. Bleed Tubing to 0 psi and shear DCK. Set TWC.Pressure test TWC to 500 psi from below. No visible leaks. RDMO to D-35. *** JOB COMPLETE **** 9/8/2021 Post RIg Freeze Protect (RWO EXPENSE) Pumped 3 bbls 60/40 meth, 152 bbls 120* DSL and 3 bbls 60/40 meth down IA takine returns from Tbg to open top tank. U- tube freeze protect into Tbg from IA for 1 hour. Pad Op notified of well status per LRS departure. SV,WV,SSV,MV=C IA,OA=OTG Daily Report of Well Operations PBU Q-07B 9/8/2021 ***WELL S/I ON ARRIVAL*** (post rig) PULLED B&R FROM RHC-BODY @ 10,611' MD PULLED BK-DGLV FROM STA #4 @ 3,626' MD PULLED BEK-CIRC VALVE FROM STA #3 @ 7,416' MD ***CONT WSR ON 9/9/21*** 9/8/2021 T/I/O=TWC/0/0. RD BOP's RU 2-9/16's THA.Torqued to API spec. RU Cameron 4" tree. Torqued to API spec. PT to 5000psi. Passed. Wellhead guys Pulled 4" H TWC. Job Complete. Final WHP's 0/0/0. 9/9/2021 ***CONT WSR FROM 9/8/21*** (rwo expense) SET BK-LGLV IN STA #4 @ 3,610' MD SET BK-OGLV IN STA #3 @ 7407' MD PULLED 4 1/2" RHC @ 10611' MD PULLED 4 1/2" PXN PLUG FROM 10,745' SLM ***JOB COMPLETE*** STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Reviewed By: P. 1. Sup�� BOPE Test Report for: PRUDHOE BAY UNIT Q -07B - Comm Contractor/Rig No.: Hilcorp Thunderbird 1 " PTD#: 2031570 - DATE: 9/5/2021 - Inspector Austin McLeod - Insp Source Operator: Hilcorp North Slope, LLC Operator Rep: Scarpella/Frazier Rig Rep: Flores/Noel Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopSAM210905190611 321-125 - Rams: Annular: Valves: MASP: Type Test: INIT 250/3000' 250/3000 - 250/3000 2345 Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: Upper Kelly 0 P/F Lower Kelly Visual Alarm Time/Pressure P/F Location Gen.: - P_-. Trip Tank P -_P System Pressure 3000 - P Housekeeping: P Pit Level Indicators P P Pressure After Closure _1500 P PTD On Location _P Flow Indicator P P _' 200 PSI Attained _ 18 P Standing Order Posted _P_ Meth Gas Detector P P Full Pressure Attained 112 P _ Well Sign _P_ - H2S Gas Detector _ P -P Blind Switch Covers: All stations - P DO. Rig P _ MS Mise NA NA Nitgn. Bottles (avg): 6 2166 P Hazard Sec. P ACC Misc 0 NA Misc NA FLOOR SAFTY VALVES: BOP STACK: Quantity P/F Upper Kelly 0 NA - Lower Kelly _ 0 _ NA_ Ball Type 1 - P Inside BOP - _ -1 , _P' FSV Misc 0 NA BOP STACK: Quantity Size P/F Stripper 0 NA Annular Preventer 1 "13-5/8 P- #1 Rams 1 "2-7/8x5-1/2 - P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 -3-1/8 P HCR Valves 1 '3-1/8 P Kill Line Valves 3 '3-1/8 P Check Valve 0 NA BOP Misc 0 NA Number of Failures: 1 Test Results Remarks: 4-1/2 joint. CMV #5 greased/cycled for a pass. CHOKE MANIFOLD: Quantity P/F No. Valves 11 FP Manual Chokes I P Hydraulic Chokes _ 1 P CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves 0 NA Test Time 7.5 Z—( Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:203-157 6.API Number:50-029-20352-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028284 & 028285 Property Designation (Lease Number):10. 8. PBU Q-07B 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well 5 Operations shutdown Tubing Swap Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 12764 Effective Depth MD: L-80 11. 5/1/2021 Commission Representative: 15. Suspended Contact Name: Brian Glasheen Contact Email: Brian.Glasheen@hilcorp.com Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9023 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 10703, 8232 No SSSV Installed Date: Liner 2014 4-1/2" 10750 - 12764 8276 - 9023 8430 7500 Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 28 - 2717 28 - 2675 14. Estimated Date for Commencing Operations: BOP Sketch 29 - 109 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S-3 Perm Packer 10908 - 12675 8426 - 9026 4-1/2" 12.6#25 - 10760 Production 10747 8273 10747 None 29 - 109 13-3/8" 9-5/8" Contact Phone:907.564.5277 Date: 4760 80 20" x 30"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2689 5380 Intermediate 10260 26 - 10286 26 - 7875 762 7"10138 - 10900 7763 - 8419 7240 5410 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2345 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 12:14 pm, Mar 11, 2021 321-125 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.03.11 11:49:29 -09'00' Stan Golis (880) DSR-3/11/21DLB 03/11/2021 X 10-404 BOPE test to 3000 psi. Annular to 3000 psi. MGR12MAR21 Yes Required? Comm 3/12/21 dta 3/12/2021 RBDMS HEW 3/15/2021 Tubing Swap Well: Q-07B PTD: 203-157 API: 50-029-20352-02-00 Well Name:Q-07B API Number:50-029-20352-02-00 Current Status:SI for TBG Leak Rig: Estimated Start Date:May Estimated Duration:4days Reg.Approval Req’d?Yes Date Reg. Approval Rec’vd:TBD Regulatory Contact:Abbie Barker Permit to Drill Number:203-157 First Call Engineer:Brian Glasheen 9075451144 (M) Second Call Engineer:Brodie Dave Wages 7133809836 (M) AFE Number:TBD Current Bottom Hole Pressure:3225 psi @ 8800’ TVD SBHP Survey 08/17/2013 Maximum Expected BHP:3225 psi @ 8800’ TVD Max. Anticipated Surface Pressure:2345psi Gas Column Gradient (0.1 psi/ft) Equivalent Brine Weight:7.3 ppg (7.0 +.3 SF) Min ID:2.313” @ 10747’ 4.5”x2-7/8” Nip Reducer Brief Well Summary Q-07B was sidetracked in 2003. Well came in very strong with 1900 bopd 4.5% WC and a GOR of 877 scf/bbl. Last well test 12/20 was 631 bopd, 15 % WC and a GOR of 57k scf/bbl. Q-07B struggled with WI issue in 2018 when it first failed a TIFL. Two patches were set in 2018 to restore integrity. Integrity was short lived after a TIFL failed in October 2020. After a CMIT proved PC integrity, a LDL was run and noted a leak below the current patch at 4955 MD. A RWO will be executed to retore tubing integrity. Scope of Work: The primary objective of the RWO is to restore integrity to the tubing. Pre Rig Prep Work: 1) MIT-OA to 1200 psi. PPPOT-T to 5000 psi. PPPOT-IC to 3500 psi. Function all LDS Slickline- 2) Pull Patch at 4955’MD 3) Pull Patch at 6761’MD 4) Pull TTP at 10747’ MD. Reset Plug with 4.5” PX with Extended fill. 5) CMIT-TXIA 2750 psi Eline- 6) Cut tubing at ~10630-10694’MD 7) CMIT-TXIA 1000 psi Proposed RWO Procedure: 1. MIRU. 2. Set TWC OR CTS 3. ND tree.Test BOPE to 250psi Low/ 3000psi High, annular to 250psi Low/ 3000psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8” and 4-1/2’’ test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Perform test per rig procedure Tubing Swap Well: Q-07B PTD: 203-157 API: 50-029-20352-02-00 4. Pull TWC or CTS 5. Pull 4.5” tubing. 6. Run 4.5’’ tubing with stacker packer completion 7. Perform MIT-T to 2750psi and MIT-IA to 2750psi. 8. Set TWC OR CTS. 9. ND BOPE 10. NU tree and adapter flange. 11. Test both tree and tubing hanger void to 500psi low/5,000psi high. 12. Pull TWC OR CTS. RD crane. Post rig Work 1. Spot Slickline unit and RU. 2. Pressure test lubricator to 300psi low and 2,800psi high. 3. Pull Ball and rod 4. Pull RHC profile 5. Pull TTP at 10747’ 6. Set GLV per GL Engr. 7. RDMO POP well with GL. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. BOP Drawing 4. RWO Sundry Revision Change Form Drop ball and rod, set packer. 30 minute charted test. Tubing Swap Well: Q-07B PTD: 203-157 API: 50-029-20352-02-00 Current Wellbore Schematic: Tubing Swap Well: Q-07B PTD: 203-157 API: 50-029-20352-02-00 Proposed Wellbore Schematic: Tubing Swap Well: Q-07B PTD: 203-157 API: 50-029-20352-02-00 BOP Sketch: Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: March 11, 2021Subject: Changes to Approved Sundry Procedure for Well Q-07BSundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations Shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: Set Patches - Pull wFo Plug 0 2. Operator Name. BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 1 Stratigraphic ❑ Exploratory ❑ Service ❑ 5. Permit to Drill Number. 203-157 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 1 6. API Number: 50-029-20352-02-00 7. Property Designation (Lease Number): ADL 028284 5 028285 = 8. Well Name and Number: PBU Q -07B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. FieldtPools: PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 12764 feet Plugs measured None feet true vertical 9023 feet Junk measured None feet Effective Depth: measured 12676 feet Packer measured 10703 feet true vertical 9026 feet Packer true vertical 8232 feet Casing: Length: Size: MD: TVD: Burst Collapse. Structural Conductor 80 20" x 30" 29-109 29-109 Surface 2689 13-3/8" 28-2717 28-2675 5380 2670 Intermediate 10260 9-5/8" 26-10286 26-7875 6870 4760 Liner 762 7" 10138 -10900 7764-8419 7240 5410 Liner 2013 4-1/2" 10751 - 12764 8277-9023 8430 7500 Perforation Depth: Measured depth: 10908 - 12675 feet True vertical depth: 8426-9026 feet Tubing (size, grace, measured and true vertical depth) 4-1/2" 12.6# L-80 25-10760 25-8285 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 10703 8232 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: 214 887 32 750 649 Subsequent to operation: 620 33435 110 1000 711 14. Attachments (.quires per 20 nac 25,070 25,071. a 25.2s1) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 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 and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Wellman, Julie Contact Name: Wellman, Julie Authorized Title: Production Engineer Contact Email: Julie.Wellmanabp.com Authorized! Signature W11----- Date: Contact Phone: +19075644657 Form 10-<O4 ftevisetl 04/2017 �t �l��j' Submit Original Only RBDMMEC 2 1 2018 ***WELL S/I ON ARRIVAL*** (profile modification) RIGUP DRIFT (3.70" OD 38.6') SD PXN @ 10747' MD 10/11/2018 ***CONT. TO 10/12/18 WSR*•• ***CONT. FROM 10/11/18 WSR**• (profile modification) PULLED P -PRONG FROM 10,730' SLM PULLED 4-1/2" PXN PLUG FROM XN-NIP @ 10,747' MD EQUALIZED WFD WRP @ 11,053' SLM PULLED WFD WRP FROM 11,053' SLM (lost 3/4 of middle element) SET 4-1/2" XN x 2-7/8" X NIPPLE REDUCER DAL = 38" @ 10747' MD 10/12/2018 *'*CONT. TO 10/13/18 WSR*** ***CONT. FROM 10/12/18 WSR'•* (profile modification) RAN 4-1/2" CHECK SET @ 10747' MD SET 2-7/6" XX PLUG IN NIPPLE REDUCER @ 10,747' MD PERFORM PASSING CMIT-TxIA (see data 10/13/2018 **'WELL /I ON DEPARTURE, DSO NOTIFIED*•• *"WELL SHUT-IN ON ARRIVAL*** (SLB E -LINE CONVEYED PDS LDL) INITIAL T/I/O = 275/275/0 PSI. MIRU. RIH W/ PDS LDL STRING. DAL = 29', OAW = 235 LBS, MAX OD = 1.69". LOG BASELINE PASS DOWN AT 100 FPM FROM 100' TO 10734'. LOG MAIN PASS UP AT 30 FPM FROM 10734' TO SURFACE. MAKING STOPS AT ANY ANOMOLIES. ONLY LEAK SIGNATURE FOUND @ 6785'. 11/29/2018 ***JOB CONTINUED ON 30-NOV-2018*** ***JOB CONTINUED FROM 29-NOV-2018"* (SLB E -LINE CONVEYED LDL AND PATCH SETTING) RUN 2: RIH W/ 4-1/2" X 30' ELEMENT TO ELEMENT BKR PATCH. SET PATCH TOP Mme@ 6763' ME AND BTM ME @ 6793'. TOP OF PATCH @ 6761' MD. MIN ID= 2.45". STANDBY DUE TO SHUTDOWN FOR EARTHQUAKE IN TOWN 11/30/2018 "*JOB CONTINUED ON 1 -DEC -2018'*• *'*JOB CONTINUED FROM 30-NOV-2018•'* (SLB CONVEYED LDLAND PATCH SETTING) RUN 2: RIH W/ 4-1/2" X 32' ELEMENT TO ELEMENT BKR PATCH. SET 4-1/2" BKR PATCH ME @ 4956'. PATCHED INTERVAL = 4956' - 4988'. TOP OF PATCH 4955'. MIN ID 2.45". REFERENCED PDS LDL (11/30/18) TO SET BOTH PATCHES. FINAL T/I/O = 0/400/0 PSI. 12/1/2018 ***JOB COMPLETE, WELL LEFT SHUT-IN ON DEPARTURE*** T/I/O = 58/435NAC. Temp = SI. MIT -T "PASSED to 2636 psi** (post patch set). Max applied = 2700 psi, target = 2600 psi. T FL @ surface. Pumped 2.3 bbls of diesel to increase TP from 58 psi to 2708 psi. TP lost 50 psi in 1 st 15 min, TP lost 22 psi in 2nd 15 min for a 30 min total of 72 psi. Bled TP from 2636 psi to 130 psi in 15 min, 2.5 bbls. Tags hung. Final WHPs = 130/801VAC. 12/3/2018 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 12:00 **'WELL SHUT IN ON ARRIVAL**' (Profile Mod) EQUALIZE 2-7/8" XX -PLUG @ 10,740' SLM/10,747' MD. 12/3/2018 ****CONT JOB ON 12-4-18'•** **'CONT JOB FROM 12-3-18*** PULL 2-7/8" XX- PLUG FROM 10,740' SLM/10,747' MD. ATTEMP TO SET 4-1/2" WHIDDON CATCHER (UNABLE TO GET PASSED 4941' SLM) RUN KJ, 2' 1-7/8" STEM, 3.80" GAUGE RING TO 4941' SLM (UNABLE TO PASS) SET 4-1/2" WHIDDON CATCHER ON PATCH @ 4941' SLM. PULL RK-DGLV FROM STA#4 (3610' MD) SET RK-DGLV IN ST#4 @ 3,610' MD PULL EMPTY 4-1/2" WHIDDON CATCHER @ 4,936' SLM 12/4/2016 ***WELL LEFT SHUT IN, PAD -OP NOTIFIED-** Tom= 4-1/16"CAMERON WELLHEAD= WLVOY ACTIWTOR= BAKER OKE. H.E/ = 69.5' REF ELEV = 68.56' BF. R = 41.03' KOP= 1850' Max Angle = 95" @ 12056' Datum MD= 11386' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, D = 12.347" 2717' 14-1/2' BKR PATCH. 1)=2.45'(12101/18) 1 16761• - 6791-1 Minimum ID = 2.313" @ 10747' 4-112" X 2-7/8" NIPPLE REDUCER TOPOFWHPSTOCK 10286- 19-5/8' CSG, 47#, L-80, 8.681'10286' Q-0 SAFETY NOTES: W ELL ANGLE> 70° @ 11617'. 2190' 4 -1/2 -HES X NP, D=3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3610 3387 46 M lru M SO RK 24 12104/18 3 7407 5805 52 MMGM DMY RK 0 08123/18 2 9548 7300 37 KfAG-M DMY RK 0 11/14/03 1 10613 8150 25 KBG2 DMY BK 0 11/14/03 MLLOUT WINDOW (Q -07B): 10286'- 10302' 14-1/2' HES X NP, ID = 3.813' I 17"X 4-1/2' BAKER S-3 PKR, D = 3.875' 1 4-1/2' HES X NP. D = 3.813' (10/12/18) 7" LNR, 26#, L-80_0383 bpf, D = 6.276'10900' BKR 45 FLO-GLIA RD STRADDLE PATCH (0&17/15) PBTD (NCLUDES REFANEi BLOCK) — 12676' 4-1/2' LNR, 12.6#, L-80, .0152 bpf, D =T958- 12764' DATE REV BY COMvSJfS FE FORATION SIM%4ARY REV BY CORMENTS RTF LOG: SPEiRY SUJ MWD GR ON 10/09/03 10/15/18 NHJMD FULLED VvMSET NP RED & RUG ANGLEAT TOP PERF: 18` @ 10908' RWO Note: Refer to Production DB for historical perf data SIZE SPF NFE2VAL Opn/Sgz SHOT SOZ 2-7/8" 6 10908 - 10936 O 11129/17 2-7/8" 4 11890 - 11970 O 10/13/03 2-7/8" 6 12060 - 12090 C 02/13/13 2-7/8" 4 12390 - 12675 O 10/13/03 BKR 45 FLO-GLIA RD STRADDLE PATCH (0&17/15) PBTD (NCLUDES REFANEi BLOCK) — 12676' 4-1/2' LNR, 12.6#, L-80, .0152 bpf, D =T958- 12764' DATE REV BY COMvSJfS DATE REV BY CORMENTS 03113179 ORIGINAL COMPLETION 10/15/18 NHJMD FULLED VvMSET NP RED & RUG 07/05/94 RWO 12/19/18 BTNJMD SET TVVO BKR PATCHES 03/02198 SIDETRACK [Q -07A) 12/19/18 MTWJMD PULLE)XXFLUG(12/04/18) 1011403 CJSITLP SIDETRACK(Q-07B) 12/19/18 MIWJMD CLV C/O (12/04/18) 08/27/18 EPTVJMD GLV C/O (08/23118) 08/28/18 E D/jmD SEr XXN RUG (08/22/18) PRUDHOE BAY UNIT WE -L: Q -07B PE MT No: 2031570 AR No: 50-029-20352-02 i, R13E T11 PL 355 FNL, 516 FEL BP Exploration (Alaska) STATE OF ALASKA iLASKA OIL AND GAS CONSERVATION COMM!, N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations Q Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate ❑ Alter Casing 0 Change ApprovedpJ?grrarrri, E Plug for Redrill ElPerforate New Pool CIRepair Well 0 Re-enter Susp Well 0 Other:Meg rgit Pel4s"74 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 203-157 3 Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20352-02-00 7 Property Designation(Lease Number): ADL 0028285 8. Well Name and Number: PBU C1-07B 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: RECO7► ED Total Depth. measured 12764 feet Plugs measured feet true vertical 9023 feet Junk measured feet I U L 2 2 201'1 Effective Depth. measured 12676 feet Packer measured 10703 feet true vertical 9026 feet Packer true vertical 8232 39 feet A 0(30 C Casing: Length: Size• MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 29-109 29-109 Surface 2689 13-3/8"72#L-80 28-2717 28-2675 4930 2670 Intermediate 10260 9-5/8"47#L-80 26-10286 26-7875 6870 4760 Production Liner 2014 4-1/2"12.6#L-80 10751 -12764 8277-9023 8430 7500 Liner 762 7"26#L-80 10138-10900 7764-8419 7240 5410 Perforation Depth: Measured depth: 11890 11970 feet 12390-12675 feet True vertical depth: 9028-9028 feet 9026-9026 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#L-80 25-10760 25-8285 Packers and SSSV(type,measured and 7"LTP/5"ZXP LTP 10150/10758 7772 5/8283.74 true vertical depth) No SSSV Installed 12.Stimulation or cement squeeze summary: Intervals treated(measured) CANNED ?t (I 4' S 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. 561 32389 129 500 1135 Subsequent to operation: 559 42298 119 500 1146 14.Attachments'(required per 20 AAC 25 070 25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory 0 Development Q Service 0 Stratigraphic 0 1 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 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 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature ,/ \ Phone +1 907 564 4424 Date 7/21/15 Form 10-404 Revised 5/2015 V/ G 1/Z6 1 1`• ./' �/J 9 5JUL RBDMS3 2 4 2015 in O , O E0 N -O Y O 0 (v 0 Q O �_ O coQ -p a °- Lo N co O D Q Q V N ,- ~ ° : . O (n N �1 (6 0) 0 C V Q (n (� _C J >� O O O _p .L J a) ° L N M F- _ M 3 ° Q O _ • _ En V O . " O > CD D c E N M u- M O N N co * >' a) I() O N �� (n o -0 N U C a l`_'J (6 O O > O O < ma O w D ° > O E c o- -c CD O J I- Fs C Y (0) c d L W Co J CO Q 0 O (0 3 0p 0 E W O Q N Q= M 2 O co ; cL c 0 C _ o w g ca o o c a as 3 ° O 0 D O c i6 m as <CL C b a. m N o 0 o Q 0 ca a0 ma) Q o c�i 0 a O °) ' c� 0 CD >. to i- ca F- a ;La o I- eN O cO 0 @Q O ) NM >,� 3m m . 0) X a ~ O co U It O -TD 0a s E L_ 0) _ ��y ° �_ _ ° t° Q § N U) - 't (1) \,7CO m J U) O CE W. Q- H LL Q-C _ (0 M ° a O 0 = * O �� a �' Q c O N U - W i m J Q 2 z " - m N J (0 p a) p Y r- Z Q) O a < m t t ~ U Z Q - CC w m _ a) 0 coo - � a) Q} Q � o cc * Low a o� m a -.--• `p vc) ,-N o a s � ( � H * vwi (� UT- m Qom * m m Ea. o ° Z U U >+_C 7 t.() U O O 0 N a < < I '- < ° - o 3- Q o ° 0 1 a� ci O C° 0m w -c = m (o 2 w E ro = a '• N0 -o Ya v 0) a) ca 2rti c > jFH 0Ua �M CC oOao - -a Q= m ooa ,- _ � , N 0 i- Z Z - °> c0 ° _ _om ca O c p C -p _ a) Q E -, -a -p Q J u� � cnDSi0 a) � u) o O cam O : N- - u°)) N a) ca E ulO JU00 CJ O La c O (0 Tc ° M _ M O J > W' a' > o J _> 0 . .= > o fl- p cB Q '= > a O U J D � � a > � ° _ oUDOW M = E a) c(1,) c.) 02 6 = i a -9, U) o * * * a' O * H (a O * I- _0 0 M 0 : ° * H ca Lo * (2 o O N ii cr : : 0 -o 0020_ = : 00aOaa m ca « UOcc Q� .� v 0 - LoZ Lu I- < Lo La LU Lc) LU 0 >- O O 0 ON N N N N LC) NT CV CV N IC) O m M N V H CD O O O U Q TREE= 4-1/16'CAMERON S _Y NOTES:WELL ANGLE>70°@ 11617'. WELLHEAD= Rot EV OY ACTUATOR= BAKER Q_0 7 B NTWL KB.ELEV= 69.5' BF.ELEV= KOP= 1850' 2190' H4-1/2"HES X NP,D=3.813' Max Angie= 95'@ 12056' - — Datum MD= 11386' 0 Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80,D=12.347" H 2717' -11 GAS LFT MANDRELS Minimum ID =3.725" 10747' ST MD TVD DEV -TYPE VLV LATCH PORT DATE 4 3610 3387 46 MMMG-M DONE RK 16 10/20/03 HES XN NIPPLE L 3 7407 5805 52 MMG-M S/O RK 20 10/20/03 2 9548 7300 37 MMG-M (WY RK 0 11/14/03 1 10613 8150 25 KBG2 DMY BK 0 11/14/03 L L TOP OF 7'LNR --I 10138' ---s' MLLOUT WNJOW(Q 07B): 10286'-10302' 9-5/8"CSG,47#.L-80,8.681" — 10286' 10682' —{HIES X NP,D=3.813' TOP OF WHPSTOCK — 10286' 10703' —I 7'BAKER S-3 PKR,D=3.875' &tk* .1• 10726' H FES X NP,D=3.813' 10747' H HES XN NP,D=3.725" r., 10750' HBKR ZXP LM2 TOP PKR .0 Ni 10760' H4-1/2'WLEG,D=3.958' --(ELM)TT NOT LOGGED 4-1/2"TBG, 12.6#,L-80,.0152 bpf,D=3.958" -I 10760' 1- (7"LNR,26#,L-80,.0383 bpf,D=6.276' H 10900' ` ii {i BKR 45 FLO-GUARD STRADDLE H 12049'- 12105' `. PERFORATION SUMMARY ir PATCH(06/17/15) REF LOG: SPERRY SUN MWD GR ON 10/09/03 ANGLE AT TOP PERF: 93'@ 11890' Am`, Note:Refer to Production DB for historical pert data FBTD(NCLUDES RETANER BLOCK) 1— 12676' sks Alva`• SCE SPF INTERVAL OpNSgz SHOT SQZ 4-1/2'LNR, 12.6#,L-80, .0152 bpf,ID=3.958" —I 12764' 2-7/8" 4 11890- 11970 0 10/13/03 2-7/8' 6 12060- 12090 C 02/13/13 2-7/8" 4 12390- 12675 O 10/13/03 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/23/79 ORIGINAL COMPLETION 03/19/10 SV CONS _ WELL 0-076 07/05/94 MVO 02/19/13 CLF/JM? ADt F(02/13/13) PERMT Na: 2031570 03/02198 SIDETRACK(Q-07A) 07/15/15 ALMJND SET FLOGUARD PKR(6/17/15) AR No: 50-029-20352-02 10/14/03 CJS/TLP SIDETRACK(Q-07B) SEC16,R13E,T11N, 355 FTL,516 FEL 10/20/03 Mi+TLP GLV CIO 03/19/10 JLW/SV CSG CORRECTION BP Exploration(Alaska) Image "oject Well History File c!er 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. d 03 " (57 Well History File Identifier D Two-sided 11111111I11" 111111 Production Scanning Stage 1 Page Count from Scanned File: It; J .(count does include7r sheet) Page Count Matches Number in Scann;ng Preparation: V YES ~ Date: 1.:).; ß os- Organizing (done) RESCAN DIGITAL DATA D Color Items: D Greyscale Items: D Diskettes, No. D Other, NolType: D Poor Quality Originals: D Other: NOTES: BY: ~ Date I a- 12/05 Project Proofing Date Jd-' 1.3 / t) 5" x 30 = ,(Pi( + Date: I ~ 13/ fJ5" BY: ~ Scanning Preparation ~ BY: c~ BY: Stage 1 , If NO in stage 1, page(s) discrepancies were found: BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: WlP 11111111111111" III Mr (aD mP D Rescan Needed 111111111111111111I OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: /5/ /5/ = TOTAL PAGES (Count does not include cover sheet) /5/ 11111111I1111111111 /5/ NO V11P YES NO /5/ 1III1III11III111111 11111111I11111 1111/ /5/ Quality Checked IIIIIIII1IIII1IIII1 10/6/2005 Well History File Cover Page. doc 2.2.532. • O 10 0 0) 0 0 0 0 0 0 0 0 C/ 0000000 U • (l 'i∎ o CO ?u'a cr UI * r P P O rya F T G a 0 d C2 v) ,- Y I) >`i �� 1 k Ou to ar ( � � v -0M 73 -Cu M LJ e�7 a a 5kyd • KJ 1 M M M M M \�. 7 /rte ,.� w i L 6 L f6 P4 0 H .1i - P O a1) CO p i� CU > c al C!1 t_i 1 P O N O P P P CNd x Cl > < co CO r i co o O 1 i � c0 t* '` LL 0 Ill 1J1 t- U a W W LL 0 = •` 0 Y 0 Ce a • }, f- } U- -§ i _ _ CL y o 2 Or/50 (n -.1 _1 -1 m O Z Z Z f- cV W ce W re U U U N Q a m an a-1 Lf1 y+ co to X CD 5 .... ii •..., l- Ili ? 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Z W ,X ;X "X ,X ;X ;X ,X ,X X X iii Q I Q c it- O E . ca co J t '� N in Tr w r) (I) (+) e- CO o 0) r' e- Y (y V ®C,co 0 A e- N, M CIO Y V !° O M N •e- OA C., e ^ O en j a- O CO h p CO ID CO Z p a- O O N a- 0 p a- = _ ;I p o 0 0 p 0 0 O ∎;p O O p O 0 0 p 0 o O o O o O O p o w „ p O O0p oOOWO >•0 CID o H 0 _ o O 0 0 O i x i U V X '� U o M 2 X _ -2 X X X m -, M 2 Q CC > > m m M - n M a m U U U U U U U Q U CO U U CO CO CO U U m c O O f� M m Lr' N ;>„ Op rn r6 7.3 cn N r co a7 � C �-1 C Q 6• 7 v Q Q1 al m Q n CO CO Ill J c °° p `� M J m m o v 'E C E w ;_ mo u < O 'O ' ' 7 in CV ' h p O ' OA a- N O i) w N rro m ro = z o m w -' Z:O Z o o C� 'o a °r° '", J °a-° C a o w 0 v v m o t -. - p .. [ N In 0 w t ✓ ° V cc N u l co a oo c gig r'n o ern § N Q x a m rn Q 4_ k............. RECEIVED STATE OF ALASKA KA OIL AND GAS CONSERVATION COMMISSION MAR 0 7 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon Li Repair Well L1 Plug Perforations Li Perforate U Other[J 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: Na me: BP Exploration (Alaska), Inc Development Q Exploratory ❑ -� 203 -157 -0 3. Address: P.O. Box 196612 Stratigraphicfl Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20352 -02 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028285 n PBU Q -07B 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 12764 feet Plugs measured None feet true vertical 9023.22 feet Junk measured None feet Effective Depth measured 12676 feet Packer measured See Attachment feet true vertical 9025.87 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" x 30" 30 - 110 30 - 110 0 0 Surface 2688 13 -3/8" 72# L -80 29 - 2717 29 - 2675.14 4930 2670 Intermediate None None None None None None Production 10258 9 -5/8" 47# L -80 28 - 10286 28 - 7875.15 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11890 - 11970 feet 12060 - 12090 feet 12390 - 12675 feet True Vertical depth 9027.52 - 9027.79 feet 9025.74 - 9023.36 feet 9025.63 - 9025.9 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 27 - 10759 27 - 8284.63 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): APR (� Treatment descriptions including volumes used and final pressure: S C A WED A®1- R 19 ? 3 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 720 43621 178 0 710 Subsequent to operation: 697 22345 286 0 688 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 [J WDSPLL) GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summerl . /1 � BP.com Printed Name Nita Summerhays / Title Petrotechnical Data Technician e i zy Si. . - . '' �. f /�� ` j _` 4, , Phone 564 -4035 Date 3/5/2013 RBDMS MAR 0 $10'3 21 t11) V Ll ��} i` e' Form 10 -404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028285 ACTIVITYDATE 1 SUMMARY V - 01 on'nue. rom /1 - - - Job Objective: PPROF and MCNL with CIBP and Adperf At surface after PPROF. Data OK. Make up MCNL logging BHA. Shut in well and begin pumping 1% KCL down backside to fluid pack while RIH. RIH to flag at 12634' ctm. Log up with MCNL at 60 fpm to 10700'. RIH to flag and log up second pass at 60 fpm up to 10700'. RIH. Place 60 bbl Borax behind pipe. Log up from flag to 10700' at 60 fpm. Place 115 bbl Borax out perfs and log up for second MCNL pass. Flag coil at 12000'. POH. Lay out guns. Good data. M/U CTC Pull test. M/U 2.8B" drift BHA. PT lube. Freeze protect flowline with Little Red, 290 bbl crude. Make up dummy gun BHA and RIH to tag bottom at 12668'. POOH swapping wellbore over to diesel. 2/12/2013 ....Continued on WSR 2- 13 -13... meth spear followed by 290 bbls 120* crude, and a 5 bbl meth tail through choke skid. wing valve closed flagged & tagged CTU in control of all valves PAD OP notified at 2/12/2013 departure. C rU #3 - 1.75" Coil ** *Continued from WSR 2- 12 -13" ** Job Objective: Drift and AdPerf At surface after 3" drift with dummy guns. Well Turned over to diesel. PT disconnect and make up perforating BHA with 30' of 2 7/8" PJO guns loaded with 6 spf. RIH. Correct depth to flag. Launch 1/2" AL ball. Perforated Interfval: 12060 - 12090'. POH with diesel in tubing and no pump to swab in well. Well still dead with BHA at surface. Close swab and SSV. PJSM. Lay out fired pert guns. All shots fired. Stack down lubricator and injector. N/D BOPE. N/U tree cap. PT tree cap. Tubing is freeze protected with diesel. RDMO CTU 3. Move to shop for maintenance. Well left shut in. SIWHP = 0 psi. Well will need back flowed or poor boy gas lift to get flowing. 2/13/2013 «< Job Complete »> FLUIDS PUMPED BBLS 96 60/40 METH 427 1% KCL 280 BORAX 212 DIESEL 580 CRUDE 12 METH 1607 TOTAL Casing / Tubing Attachment ADL0028285 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" x 30" 30 - 110 30 - 110 LINER 762 7" 26# L -80 10138 - 10900 7763.47 - 8418.5 7240 5410 LINER 2014 4 -1/2" 12.6# L -80 10750 - 12764 8276.17 - 9023.22 8430 7500 PRODUCTION 10258 9 -5/8" 47# L -80 28 - 10286 28 - 7875.15 6870 4760 SURFACE 2688 13 -3/8" 72# L -80 29 - 2717 29 - 2675.14 4930 2670 TUBING 10732 4 -1/2" 12.6# L -80 27 - 10759 27 - 8284.63 8430 7500 • • • Packers and SSV's Attachment ADL0028285 SW Name Type MD TVD Depscription Q -07B PACKER 10703 8163.7 7" Baker S -3 Packer Q -07B PACKER 10750 8207.61 4 -1/2" Baker ZXP Packer • TTiEE= 41/16" GAME320N • SA Y NOTES: WELL ANGLE> 70° @ 11617'. WaLHEAD= tubEVOY ACTUATOR= BAKER Q -0 7 B ENfTWL KB. BEV = 69.5 BF- ELEV = I KOP= 1850' Max Angle = 95° �2 12056' 2190' I—{4 -112" HES X NP, D = 3.813" Datum MD = 11386 Datum TVD = 8800' SS 113 -318" CSG, 72#, L-80, D = 12.347" H 2717' 1- GAS LFT MANDRELS Minimum ID = 3.72 / 10747° ST MD TVD DEV TYPE VLV LATCH FORT DATE 4 3610 3387 46 1.14/11.43-M DOPE RK 16 10/20/03 HES XN NIPPLE L 3 7407 5805 52 MMG-M S/O RK 20 10/20/03 2 9548 7300 37 KING-M DMY RK 0 11/14/03 1 10613 8150 25 KBG2 _ DMY BK 0 11/14/03 I. L NLLOUT WIDOW (Q -07B): 10286' - 10302' [TOP OF 7" Lt�12 H 10138' � � ,_. 19 -518' CSG, 47 #, L -80, 8.681" H 10286' 10682' I—i X NP, D = 3.813" I ITOP OF WA-IPSTOCK H 10286' I 10703' H r BAKER S-3 PKR, D = 3.875" I 10726' 1-1' X NP, D = 3.813° I hillhh. 10747' H FES XN NP, D = 3.725" I ; 4, I 10750' HBKRZXPLNR TOP PKR I ii i. I 10760' H4 -1/2° WLEG, D= 3.958" I H ELID TT NOT LOGGED I I4 -12" TBG, 12.6#, L -80, .0152 bpi, D = 3.958" H 10760' 7' LNR, 26#, L -80, .0383 bpf, D = 6.276" I— 10900• PERFORATION SUMMARY REF LOG: SPERRY SUN MAD GR ON 10/09/03 ANGLE AT TOP PE32F: 93° © 11890' Note: Refer to Production DB for historical pert data I PBTD (INCLUDES RETAIN BLOCK) —I 12676' 4 �i� ► SIZE SFF MERVAL Opn/Sgz SHOT SQZ ",'„' 2 -7 .- J __1990 - 1 _ 0 10/13/03 4 -1/2" LNR, 12.64, L -80, .0152 bpf, D= 3.958" —I 12764' I am. 2 -78" 6 12060 - 12090 0 02/13/13 '2 -918 T5 DATE REV BY COMIE•ITS DATE REV BY COIVIVIENTS FREJDNOEBAY UNIT 03/23/79 ORIGINAL COMPLETION 03/19/10 SV CORRECTIONS WELL: Q-07B 07/05/94 RWO 02/19/13 CJF /JPID ADPBRF (02/13/13) PERMIT IT No: 2031570 03/02/98 SIDETRACK (4-07A) AFE No: 50 -029- 20352 -02 10/14/03 CJS/TLP SIDETRACK (4-07B) SEC16, R13E, T1IN, 355 FNL, 516 FE L 10/20/03 MHMTLP GLV CIO 03/19/10 ,I_W /SV CSG CORRECTION BP Exploration (Alaska) OPERABLE: Producer Q -07B (PTD #20315704ubing Integrity Restored • Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelIIntegrityCoordinator @bp.com] Sent: Wednesday, October 19, 2011 4:18 PM ' Biel iliz S t u To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, OPS Well Pad RJQ; Phillips, Patti J Cc: Walker, Greg (D &C); LeBaron, Michael J; AK, D &C Well Integrity Coordinator Subject: OPERABLE: Producer Q -07B (PTD #2031570) Tubing Integrity Restored All, Producer Q -07B (PTD #2031570) passed a TIFL on 10/17/2011 after bringing the well online proving tubing integrity has been restored. The well has been reclassified as Operable. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Saturday, October 15, 2011 9:36 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr Cc: Walker, Greg (D &C); Arend, Jon (NORTHERN SOLUTIONS LLC); Olson, Andrew Subject: UNDER EVALUATION: Producer Q -07B (PTD #2031570) Sustained IA Pressure Above MOASP All, Producer Q -07B (PTD #2031570) was found to have sustained casing pressure on the IA above MOASP. The wellhead pressures were tubing /IA/OA = 2160/2030/20 on 10/13/2011. A cold TIFL was performed on the same day and failed. The well is reclassified as Under Evaluation and may be placed on production while diagnostics are conducted. The plan forward is: 1. Donwhole Diagnostics: Re -TIFL after well is put on production aT 2. Slickline: Change out orifice GLV if TIFL fails = 667Ors,` 3. Downhole Diagnostics: TIFL post GLV change out A TIO plot and wellbore schematic are attached for reference: n0 o� Please call if you have any questions. Thank you, 11/2/2011 OPERABLE: Producer Q -07B (PTD #2031571jubing Integrity Restored • Page 2 of 2 Mehreen Vazir (Alternate. Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 11/2/2011 PBU Q -07B PTD # 2031570 10/15/2011 TIO Pressures Plot WeH: Q -07 4.000 3,000 • —�►— Tbp — IA 2,000 w.-. -u --A— OA ODA ODDA On 1,000 • 07/16/11 07/23/11 07/30/11 08/06/11 0943111 08/20/11 08/27/11 09/03111 09/10/11 09/17/11 09/24/11 10/01/11 10/08/11 10/15/11 TREE = 4-1/16" CAMERON WELLHEAD = McEVOY SAFETY NOTES: ACTUATOR= BAKER CO7B KB. ELEV = 70.6' . . BF. ELEV = KOP = 1850' Max Angle = 95 @ 12119' 1 2190' H4-112" HES X NIP, ID = 3.813" 1 Datum MD= 11386' Datum TVD = 8800' SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 113-3/8" CSG, 72#, L-80, ID = 12.347" H 2717' I— 4 3610 3387 46 MMMG-M DOME RK 16 10/20/03 3 7407 5805 52 MMG-M S/0 RK 20 10/20/03 Minimum ID = 3.725" @ 10747' 2 9548 7301 37 MMG-M DMY RK 0 11/14/03 HES XN NIPPLE lin 1 10613 8150 25 KBG2 DMY BK 0 11/14/03 IP • IP 1 I X 1 MILLOUT WINDOW (Q 10286' - 10302' 'TOP OF 7" LNR 1— 10138' 10682' H HES X NIP, ID = 3.813" 19-5/8" CSG, 47#, L-80, 8.681" H 10286' 1 ( 'TOP OF WHIPSTOCK H 10286' 1---- 10703' H7" BAKER S-3 PKR, ID = 3.875" \./ 10726' H HES X NIP, ID = 3.813" I AA544)- rs; + , 10747' 1—I HES XN NIP, ID = 3.725" 667o 1 4* 1 10750' H BKR ZXP LNR TOP PKR I 10760' H4-1/2" WLEG, ID = 3.958'' 1 H ELMD TT NOT LOGGED 1 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I—I 10760' 17" LNR, 26#, L-80, .0383 bpf, ID = 6.276" hj 10900' NII4 PERFORATION SUMMARY REF LOG: SPERRY SUN MWD GR ON 10/09/03 ANGLE AT TOP PERF: 93 @ 11890' Note: Refer to Production DB for historical perf data 44., Akio", SIZE SPF INTERVAL Opn/Sqz DATE .1141e," 2-7/8" 4 11890 - 11970 0 10/13/03 1 PBTD (INCLUDES RETAINER BLOCK) 1-1 12676' limo 2-7/8" 4 12390 - 12675 0 10/13/03 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" H 12764' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/23/79 ORIGINAL COMPLETION 03/19/10 SV CORRECTIONS WELL: Q-07B 07/05/94 RWO PERMIT No: 2031570 03/02/98 SIDETRACK (Q API No: 50 10/14/03 CJS/TLP SIDETRACK (Q SEC16, R13E, T11N, 355 FNL, 516 FEL 10/20/03 MH/TLP GLV C/O 03/19/10 JLW/SV CSG CORRECTION BP Exploration (Alaska) ~ - s BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 March 31, 2010 ~,d ~- t ~~ Mr. Tom Maunder nservation Commission Alaska Oil and Gas Co 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Pad Q Dear Mr. Maunder, by ~, APR ~ '~ 2111( •~~~,~~~ ~~~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad Q 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, Anna Dube, at 659-5102. Sincerely, tj ?.,~.'.»s~'.~ 1~ ~ ,L{' ~ ~ a E~ ~ lb i ~ Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date: 03/31 /10 C Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al Q-01A 1971260 50029203010100 0.1 NA 0.1 NA 1.70 3/10/2010 Q-02A 1971470 50029203330100 0.2 NA 0.2 NA 1.70 3/10/2010 Q-03A 1972540 50029203220100 0.1 NA 0.1 NA 1.70 3/10/2010 Q-04B 2091010 50029203400200 1 NA 1 NA 3.40 3/10/2010 Q-O58 2071560 50029203440200 0.5 NA 0.5 NA 3.40 3/9/2010 Q-O6A 1980900 50029203460100 0.2 NA 0.2 NA 1.70 3/9/2010 Q-078 203'1570 50029203520200 0.7 NA 0.7 NA 3.40 3/9!2010 • • .~., s ~¢~- -w. ~:~ b~' „,; '- -_ ~: MICROFILMED 03/01 /2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFichelC~rPgs_InsertslMicrofilm Marker.doc e e WELL LOG TRANSMITTAL (JO?;-/57 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 r3Lt>Ú?~ RE: MWD Formation Evaluation Logs Q-07B, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 Q-07B: LAS Data & Digital Log hnages: 50-029-20352-02 1 CD Rom ~ ~ IJ ~J\ \J ~~~r DATA SUBMITTAL COMPLIANCE REPORT 11/8/2005 Permit to Drill 2031570 Well Name/No. PRUDHOE BAY UNIT Q-07B Operator BP EXPLORATION (ALASKA) INC ~t~0-0~9-2~~ J MD 12764"- TVD 9023"" Completion Date 10/13/2003" Completion Status 1-01L Current Status 1-01L UIC N - REQUIRED INFORMATION Mud Log No Samples No Yes 2~ ..~~-_."" DATA INFORMATION Types Electric or Other Logs Run: DIR, GR, RES, DEN, NEU Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No Interval OH I Start Stop CH Received Comments . ~ p Directional Survey 0 12463 Induction/Resistivity ~ IwrtinnLRf''';''t¡.,ljty l.' ~ 1I.c""\f~~1t _ ~ 12463 Neutron npt ~OlItron 6 0 12463 Density npt DoncHy ~D 12463 Rate of Penetration npt nstc of f"\cnctretion Name Interval Start Stop 10199 12764 10/27/2003 3-5 10279 12713 3/18/2004 GR, EWR4, CNP, SLD, Rap 3-5 10279 12713 3/18/2004 GR, EWR4, CNP, SLD, ROP 3-5 10279 12713 3/18/2004 GR, EWR4, CNP, SLD, ROP 3S 1027::1 12713 3/1 O/200~ cn, CWn4, Ct~r, SLD, Rap 3-5 10279 12713 3/18/2004 GR, EWR4, CNP, SLD, ROP 36 1CX270 12713 3/1 8/2004 GR, ~WR4, cþ¡;>, SL¡;)·, . Rap 3-5 10279 12713 3/18/2004 GR, EWR4, CNP, SLD, ROP :x; 10279 1271:) :)11 0/2004 on, CWI14, CNP, ~LD, ROP Sample Set Sent Received Number Comments ~-,_._-~--- Well Cores/Samples Information: Permit to Drill 2031570 MD 12764 TVD 9023 ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ...,. 7 N ~ Analysis Received? ~ Comments: - Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 11/8/2005 Well Name/No. PRUDHOE BAY UNIT Q-07B Operator BP EXPLORATION (ALASKA) INC Completion Date 10/13/2003 Completion Status 1-01L Current Status 1-01L Daily History Received? ð/N Q/N Formation Tops ~ Date: API No. 50-029-20352-02-00 UIC N )J~~r . . . . 803 -151 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska March 11, 2004 RE: MWD Formation Evaluation Logs Q-07B, AK-MW-2678820 1 LDWG formatted Disc with verification listing. q) I API#: 50-029-20352-02 ) ()' L l:r;..3 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Sign~a(L~~O ~/'Y" RECEIVED '. '1 0 "1'\1'\ A . \ U t..:Uvi4 J,.í,aska Oil & Gas Cons. Commission ,~nchorage RBDMS p~ MAR ~~wnnl; · STATE OF ALASKA ._ ALASKA: . AND GAS CONSERVATION COMI'./WION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 CASING, LINER AND CEMENTING RECORD SETtINGÐEPTH lOP BOTTOM Surface 110' 28' 2717' 33' 10286' 10138' 10900' 10750' 12764' o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 355' SNL, 516' WEL, SEC. 16, T11N, R13E, UM Top of Productive Horizon: 1804' SNL, 91' EWL, SEC. 14, T11N, R13E, UM Total Depth: 2860' SNL, 308' EWL, SEC. 14, T11N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 643940 y- 5965725 Zone- ASP4 TPI: x- 649857 y- 5964392 Zone- ASP4 Total Depth: x- 650096 y- 5963341 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: DIR, GR, RES, DEN, NEU 22. 30" x 20" Insulated Conductor 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 26# L-80 4-1/2" 12.6# L-80 23. Perforations open to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state' none"): 2-7/8" Gun Diameter, 4 spf MD TVD MD TVD 11890' - 11970' 9028' - 9028' 12390' - 12675' 9026' - 9026' One Other 5. Date Comp., Susp., or Aband. 10/13/2003 6. Date Spudded 10/1/2003 7. Date T.D. Reached 10/7/2003 8. Elevation in feet (indicate KB, OF, etc.) KBE = 68.56' 9. Plug Back Depth (MD+ TVD) 12676 + 9026 Ft 10. Total Depth (MD+TVD) 12764 + 9023 Ft 11. Depth where SSSV set (Nipple) 2190' MD 19. Water depth, if offshore N/A MSL 1b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-157 13. API Number 50- 029-20352-02-00 14. Well Number PBU Q-07B 15. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 16. Lease Designation and Serial No. ADL 028285 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PULLED 36" 17-1/2" 12-114" 8-1/2" 6-1/8" RECORD 577 cu ft Permafrost II 4520 cu ft Arcticset II 1566 cu ft Class 'G', 688 cu ft AS I 202 cu ft Class 'G' 257 cu ft Class 'G' T.uElINGRECGRD DEPTH SET (MD) 10759' PACKER SET (MD) 10703' 24. SIZE 4-1/2", 12.6#, L-80 25. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 157 Bbls of Diesel 26. Date First Production: November 15, 2003 Date of Test Hours Tested PRODUCTION FOR None Yet TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED ...... Press. 24-HoUR RATE""" 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oll-Bsl GAs-McF WATER-Bsl OIL-Bsl None rcõ:<~ 7;;"~f·Îi·:ç~rl ! "~re J" t h,Wk., I v~:n ~ GAs-McF WATER-BsL RBDMS ÖfL NOV 2:¡ iOœ . Revised 2/2003 oq'G'N/~L CONTINUED ON REVERSE SIDE ~ V CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (CORR) 28. GEOLOGIC MARKERS. 29. .RMATlON TESTS NAME MD rvD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10905' 8423' None Shublik 10940' 8456' Sadlerochit 11018' 8530' Top CGL Base CGL 11210' 8710' 11267' 8764' 25N 11361 ' 884 7' 21P 11520' 8962' Zone 1B 114N 11650' 9015' 14P 11684' 9021' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble /fÓ ~ {i ~ Title Technical Assistant Date II J 19/Q ~ PBU Q-07B 203-157 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Phil Smith, 564-4897 Permit NO.1 Approval No. 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. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ORIGINAL ITEM 29: List all test information. If none, state "None". 10-407 Revised 2/2003 of 1 1 Page BP EXPLORATION Leak-Off Test Summary Q-07 Q-078 .. . EMW 12.50 (ppg) 10.00 (ppg) Surface Pressure Leak Off Pressure (BHP) 490 (psi 5.113 (psi) 658 (psi 4.375 (psi) AMW 11.30 (ppg) 8.50 (ppg) Test Depth (TMD) Test Depth (TVD) 10,286.0 (ft) 7.875.0 (ft) 0,900.0 (ft) 8,418.0 (ft) Test Type Legal Name: Common Name Test Date 9/30/2003 FIT 10/5/2003 FIT þ 4 012012003 8:54:00 AM Printed: ! I ! , / ~ - ..... BP EXPLORATION Operations Summary Report Page 1 of 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Q-07 Q-07B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 9/27/2003 Rig Release: 10/14/2003 Rig Number: 2 Spud Date: 2/10/1979 End: 10/14/2003 Date From ÄTo Hours Task Code NPT Phase:" Description:of Operations 9/26/2003 20:30 - 00:00 3.50 MOB P PRE Move camp, shop, and pit I pump module from F-06A location along spine road to Q-pad access at J-pad entrance. Stage on Q-pad. RD / MO of F-06A with rig sub structure. 9/27/2003 00:00 - 02:00 2.00 MOB P PRE Move rig sub structure from F-06A to F-pad access road. 02:00 - 03:00 1.00 MOB P PRE Trouble shoot surging problem with moving system. Replace speed control joystick in driver's cab. 03:00 - 04:00 1.00 MOB P PRE Move sub base from F-pad access road, along spine road to Q-pad access road. 04:00 - 05:00 1.00 MOB P PRE Replace a-ring and flange adapter on #2 jack / steer pump. 05:00 - 06:00 1.00 MOB P PRE Move along Q-pad access road to Q-pad. 06:00 - 08:00 2.00 RIGU P PRE Raise and pin derrick, raise and pin cattle chute. 08:00 - 15:00 7.00 RIGU P PRE Lay mats, spread herculite, spot and level sub base over Q-07. Spot pits / pump module, camp, shop, and cuttings tank. Hook up lines, bridle down, berm all areas, and clean up rig and surrounding area. Rig accepted at 12:00. A 3 hour adjustment was made due to delay; waiting for site preparation. 15:00 - 15:30 0.50 RIGU P PRE Pre spud Safety and Environmental meeting. 15:30 -16:00 0.50 WHSUR P DECOMP Install secondary annulus valve. 16:00 - 17:00 1.00 WHSUR P DECOMP Pull BPV with DSM and lubricator. 17:00 - 18:00 1.00 WHSUR P DECOMP RlU circulating lines. 18:00 - 19:30 1.50 WHSUR P DECOMP Circulate out freeze protection by pumping down annulus at 5 bpm and 530 psi, then down tubing at 5 bpm and 300 psi to recover -152 bbls diesel. 19:30 - 20:00 0.50 WHSUR P DECOMP Cameron dry rod in TWC. Test from below to 1,000 psi. 20:00 - 21 :30 1.50 WHSUR P DECOMP NID tree and adapter flange. 21 :30 - 00:00 2.50 BOPSURP DECOMP N/U BOPE. RlU test equipment. 9/28/2003 00:00 - 03:30 3.50 BOPSURP DECOMP Test BOPE, and all related valves, to 250 psi low and 3,500 psi high. Witness of test waived by Lou Grimaldi of the AOGCC. 03:30 - 04:30 1.00 WHSUR P DECOMP RlU DSM ; pull TWC with lubricator. 04:30 - 07:00 2.50 WHSUR P DECOMP PIU Baker spear w/ grapple. Decided to spear due to damaged hanger threads. RIH and attempt to spear. Could not successfully pass through body of hanger. UD spear. M/U TDS XO on landing joint. BOLDS. Pull hanger to floor with 145K up weight. 07:00 - 07:30 0.50 WHSUR P DECOMP Break out and UD tubing hanger. 07:30 - 08:30 1.00 PULL P DECOMP RlU casing equipment. 08:30 - 11 :30 3.00 PULL P DECOMP POOH with 41/2",12.6#, L-80, TDS tubing to SSSV. Recovered 53 SS control line bands. 11 :30 - 12:00 0.50 PULL P DECOMP RID Camco control line spooling unit. 12:00 - 18:00 6.00 PULL P DECOMP UD 41/2" tubing from 8,120'. 18:00 - 19:00 19:00-21:30 1.00 PULL P 2.50 BOPSURP Recovered a total of 257 joints of 41/2",12.6#, L-80, TDS tubing, 1 - SSSV, 5 - GLM, 1- 'X' landing nipple, and 31.92' cut off joint. Very clean tubing cut. DECOMP RID tubing handling equipment. Clear rig floor. DECOMP RlU test joint. Test BOPE with 4" test equipment. Redress test plug. Test plug wouldn't seat properly. C/O test plug. Test upper and lower pipe and Hydril to 250 psi low and3,500 psi high. RID test equipment. Printed, 1012012003 8,54,13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ...,. - , Page 2 of 14 BP EXPLORATION Operations Summary Report Q-07 Q-07B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES 'Code! NPT . Phase Date . From - To Hours Task . ___0.- 9/28/2003 21 :30 - 22:00 0.50 CLEAN 22:00 - 00:00 2.00 CLEAN 9/29/2003 00:00 - 00:30 0.50 CLEAN 00:30 - 07:00 6.50 CLEAN 07:00 - 08:30 08:30 - 10:00 10:00 - 11 :00 11 :00 - 12:00 12:00 - 16:00 16:00 -17:00 17:00 - 21 :00 9/30/2003 21 :00 - 00:00 00:00 - 01 :30 P P P P DECOMP DECOMP DECOMP DECOMP 1.50 CLEAN P DECOMP 1.50 CLEAN P 1.00 CLEAN P 1.00 CLEAN P 4.00 CLEAN P 1.00 CLEAN P 4.00 STWHIP P DECOMP DECOMP DECOMP DECOMP DECOMP WEXIT 3.00 STWHIP P 1.50 STWHIP P WEXIT WEXIT 01 :30 - 04:30 3.00 STWHIP N DFAL WEXIT 04:30 - 05:30 1.00 STWHIP N DFAL WEXIT 05:30 - 07:00 1.50 STWHIP N DFAL WEXIT 07:00 - 11 :00 4.00 STWHIP N DFAL WEXIT 11 :00 - 15:00 4.00 STWHIP N DFAL WEXIT 15:00 - 16:00 1.00 STWHIP P WEXIT 16:00 - 16:30 0.50 STWHIP P WEXIT 16:30 - 22:30 6.00 STWHIP P WEXIT 22:30 - 23:30 23:30 - 00:00 1.00 STWHIP P WEXIT 0.50 STWHIP P WEXIT Start: 9/27/2003 Rig Release: 10/14/2003 Rig Number: 2 Spud Date: 2/10/1979 End: 10/14/2003 Description of Operations - . ... . .. . . -..-..--.---..--. - ..--.......-.. .... -. .. Install wear bushing. PJSM. P/U milling BHA to 850'. P/U and RIH with BHA to 1,035'. P/U drill pipe 1 X 1. RIH with mills assembly from 1,035' to 10.370'. Tag tubing stump at 10,370' (DPM). Verify tag with 15K down weight. Fill pipe every 3,000'. Displace well to 11.3 ppg milling fluid at 12 bpm and 2,700 psi. P/U weight 220K, S/O weight 135K, Rot weight 170K. Torque off btm 8,000. Cut and slip 105' drilling line. Service top drive. CBU at 12 bpm and 2,950 psi. Pressure test casing to 3,500 psi for 30 minutes. Record test. Pump dry job. POOH from 10,370' to 1,034' (SLM). C/O handling equipment. POOH with BHA from 1,034'. M/U BHA to 1,137'. Orient MWD. Upload and surface test MWD. M/U 59' of 4 1/2" tubing stinger on bottom of whip stock. RIH with drill pipe from 1,137' to 7,022'. Fill pipe every 3,000'. Sperry Sun MWD Tool Quit Pulsing During Pipe Filling Operation While Breaking Circulation - Make Several Attempts To Regain Detection (No Good) - POH From 7,022' To 6,648' And Pump 10 BBL Water Pill Through Tool At 225 SPM, 550 gpm, And 2,830 Psi. Attempt To Regain Detection With No Success - Pump Dry Job - Blow Down Top Drive POH With BHA NO.2 From 6,648' To 1,137' POH Working BHA NO.2 From 1,137' To 172' Surface Test MWD Tool (No Signal) - Down Load MWD - POH With BHA Make Up Whipstock And Milling Assembly BHA NO.3 - Change Out Pulser, OM, And RLL Tools - Orient MWD Tool And Initialize - Surface Test At 12 BPM With 1,730 Psi. (Test Good) - Make Up BHA And RIH To 1,141' RIH With BHA NO.3 From 1,141' To 7,022' - Check MWD Tool Every 2,500' On Trip In The Hole RIH With BHA NO.3 From 7,022' To 10,295' Orient 9 5/8" Whipstock At 87 Degrees Right Of High Side - Tag Up At 10,370' And Set Bottom Trip Anchor With 20,000 Ibs. Shear Whipstock Lug With 30,000 Ibs. Mill 9 5/8" Casing Window From 10,286' Top Of Window To 10,302' Bottom Of Window - WOB Rotating 2,000# To 5,000# While Milling Window And 8,000# To 12,000# While Milling Formation, RPM 65 To 95, Rotary Torque 10,000 ft / Ibs To 16,000 ft / Ibs, Pump Rate 449 gpm, SPP 2,800 psi, String Weight Up 195,000#, String Weight Down 140,000#, String Weight Rotating 170,000# - Drill Formation From 10,302' To 10,315' To Get Upper String Mill Out Of Window - Recovered 90 Ibs. Of Metal Work String Mills In And Out Of Window While Circulating Sweep Around At 13 BPM With 3800 Psi. Hold Pre-Job Safety Meeting - Preform FIT To 12.50 PPG EMW Closed Top Pipe Rams And Performed FIT. Strokes Pmp'd Pressure Printed: 10120/2003 8:54:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ,... - Page 3 of 14 BP EXPLORATION Operations Summary Report Q-07 Q-07B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 9/27/2003 Rig Release: 10/14/2003 Rig Number: 2 Spud Date: 2/10/1979 End: 10/14/2003 9/30/2003 23:30 - 00:00 Date ; From - To Hours· Task : Code· NPT : Phase , Description of Operations . ___m _ _ ._., ,on... ..... _. 0.50 STWHIP P WEXIT 10/1/2003 00:00 - 00:30 0.50 STWHIP P WEXIT 00:30 - 04:00 3.50 STWHIP P WEXIT 04:00 - 05:30 1.50 STWHIP P WEXIT 05:30 - 06:30 1.00 STWHIP P WEXIT 06:30 - 09:00 2.50 DRILL P LNR1 09:00 - 13:00 4.00 DRILL P LNR1 13:00 - 13:30 0.50 DRILL P LNR1 13:30 - 00:00 10.50 DRILL P LNR1 2 4 6 8 10 12 14 16 18 20 50 psi 110 psi 140 psi 200 psi 240 psi 290 psi 330 psi 390 psi 440 psi 490 psi Held Test F/ 10 minutes w/ 20 Psi. Pressure Loss. MW 11.3 ppg, Top Of Window TVD 7,875' Pressure 490 psi = 12.50 PPG. EMW. Bleed Pressure To 0 Psi. - Open Top Pipe Rams Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive POH With BHA NO.3 From 10,315' To 1,141' Stand Back BHA NO.3 From 1,141' To 82' - Lay Down UBHO Sub, Bumper Sub, And String Mills - *NOTE* Upper String Mill At 8 1/2" 0.0. - Clear Rig Floor Remove Wear Bushing - Pick Up Johnny Wacker And Flush Out BOP Stack - Lay Down Flushing Tool - Recovered Additional 5 Ibs. Metal From BOP Stack And Under Shakers - Install Wear Bushing Make Up BHA NO.4 - Pick Up Sperry Sun Motor, Adjust Bend On Motor To 1.22 Degrees, Make Up 8 1/2" HTC PDC Bit, Pick Up MWD/LWD Tools - Orient And Initialize MWD/LWD Tools - Make Up UBHO Sub, Pick Up Flex Drill Collars - Surface Test Sperry Sun Equipment - RIH With BHA No.4 To 1,187' Pick Up 30 Joints Of 4" Drill Pipe And RIH With BHA No.4 From 1,187' To 2,121' - RIH From 2,121' To 10,230' Filling Drill String Every 3,000 Feet Establish Circulation Orient And Slide Thru Whipstock Window At 10,286' With No Problems - Ream Under Gauge Hole From 10,307' To 10,315' Drilled 8 1/2" Directional Hole By Rotating And Sliding From 10,315' to 10,641' WOB Rotating 5,000# - 10,000#, WOB Sliding 5,000# To 10,000#, RPM 65 To 95, Motor RPM 174, Torque Off Bottom 9,000 ft / Ibs - On Bottom 14,000 ft / Ibs, Pump Rate 529 gpm, SPP Off Bottom 3,800 psi, On Bottom 4,050 psi. String Weight Up 250,000#, String Weight Down 140,000#, String Weight Rotating 175,000# - ART = .39 Hrs. - AST = 6.11 Hrs. *NOTE* Hole Attempted To Pack Off At 10,547' Circulate Pump Sweeps And Clean Up Same With Out Any Further Related Problem 10302-10333 Kingak E Predominantly Shale ROP averaging 30-50'/hr while sliding to increase distance from parent wellbore. Good character tie by GR with PDC log in parent well. MWD logs appear on depth. Printed: 1012012003 8:54:13 AM ~ . Page 4 of 14 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Q-07 Q-07B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES , Date : From - To : Hours Task Code: NPT Phase . .--.-- 10/1/2003 13:30 - 00:00 10.50 DRILL P LNR1 10/2/2003 00:00 - 09:30 9.50 DRILL P LNR1 09:30 - 11 :00 1.50 DRILL P LNR1 11 :00 - 11 :30 0.50 DRILL P LNR1 11 :30 - 12:00 0.50 DRILL P LNR1 12:00 - 13:00 1.00 DRILL P LNR1 13:00 - 13:30 0.50 DRILL P LNR1 13:30 - 15:00 1.50 DRILL P LNR1 15:00 - 15:30 0.50 DRILL P LNR1 Start: 9/27/2003 Rig Release: 10/14/2003 Rig Number: 2 Spud Date: 2/10/1979 End: 10/14/2003 Description of Operations _ ......--..-..-- ..--.-...-,-.. ----.--.. 10333-10575 Kingak 0 Predominantly thin silts and shale. ROP averaging 40-60'/hr while sliding. Commence rotating in lower part of unit, up to 100'/hr. ROP dropped dramatically in lowermost 0 interval. Well evidently encountering sticky shales causing problems with balled bit or packing off around stabilizers. Pumped sweeps to clean well, alleviated problem. 10575-10600 Kingak C Predominantly clean shales. ROP averaging 40-60'/hr. Drilled 8 1/2" Directional Hole By Rotating And Sliding From 10,641' to 10,900' WOB Rotating 5,000# - 10,000#, WOB Sliding 5,000# To 10,000#, RPM 82, Motor RPM 164, Torque Off Bottom 14,500 ft / Ibs - On Bottom 16,500 ft / Ibs, Pump Rate 495 gpm, SPP Off Bottom 3,800 psi, On Bottom 4,050 psi. String Weight Up 250,000#, String Weight Down 155,000#, String Weight Rotating 180,000# - ART = .86 Hrs. - AST = 4.63 Hrs. Lithologies encountered: 10600-10727 Kingak C Predominantly clean shales. GR averaging 130 API. Interval drilled well averaging 40-60'/hr while sliding to drop angle and azimuth control per wellplan. 10727-10810 Kingak B Predominantly shale with minor thin sands. Shales are dark gray and splintery, with an increasingly ratty character on GR. ROP averaging 30-50'/hr while sliding. 10810-10895 Kingak A Shale with increasing thin siltstone beds. Shales are dark gray, splintery and firm. Siltstones are light gray, firm, and locally pyritic. Rap averaging 40'/hr while sliding, 60-70'/hr while rotating. Notable increase in ROP below 10890 tied to siltstone above SGR. 10895-10900 TSGR Predominantly siltstone, minor sand. Siltstone is light gray, firm, with common pyrite. Sand is poorly represented in sample, but appears fine grained, well sorted, rarely glauconitic and consolidated. Circulate Hi-Vis Sweep At 12 BPM With 3,890 Psi. While Rotating And Reciprocating Drill String - Monitor Well Bore (Static) POH (Wet) With Directional Drilling BHA No.4 From 10,900' To 10,247' With No Hole Problems - Monitor Well Bore (Static) - Clean And Wash Off Rig Floor Service Top Drive, Traveling Blocks, And Crown Sheaves Slip And Cut 1 1/4" Drilling Line RIH With Directional Drilling BHA No.4 From 10,247' To 10,817' With No Hole Problems - As Precaution Wash From 10,817' To 10,900' - No Fill On Bottom Circulate Sweep Around At 12.0 BPM With 3,900 Psi. While Rotating And Reciprocating Drill String Monitor Well Bore (Static) - Spot Liner Running Pill - Pump Dry Printed: 10/20/2003 8:54: 13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ! From - To .. --... . 10/2/2003 15:00 - 15:30 15:30 - 16:30 16:30 - 20:30 20:30 - 00:00 ..... .. BP EXPLORATION Operations Summary Report Q-07 Q-07B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Hours Task Code: NPT Phase 0.50 DRILL P 1.00 DRILL P LNR1 LNR1 4.00 DRILL P LNR1 3.50 DRILL P LNR1 10/3/2003 00:00 - 01 :00 1.00 DRILL P LNR1 01 :00 - 02:00 1.00 BOPSUR P LNR1 02:00 - 02:30 0.50 BOPSURP LNR1 02:30 - 03:00 0.50 BOPSURP LNR1 03:00 - 03:30 0.50 CASE P LNR1 03:30 - 04:45 1.25 CASE P LNR1 04:45 - 05:15 0.50 CASE P LNR1 05:15 - 05:30 0.25 CASE P LNR1 05:30 - 10:30 5.00 CASE P LNR1 10:30 - 11 :00 0.50 CASE P LNR1 11:00 -11:30 0.50 CASE P LNR1 11 :30 - 12:30 12:30 - 15:00 1.00 CASE P LNR1 2.50 CEMT P LNR1 Page 5 of 14 Start: 9/27/2003 Rig Release: 10/14/2003 Rig Number: 2 Spud Date: 2/10/1979 End: 10/14/2003 Description of Operations . ..-.--........----.-- - . .-...-.... ..- ... Job Drop Sperry Sun ESS Tool - Work Drill String And Allow Time To Fall And Seat In UBHO Sub - POH From 10,900' To 10,247' With No Problems - Take Surveys At 10,841' And 10,716' During Trip To Window POH With BHA NO.4 From 10,247' To 1,192' - Change Out Handling Equipment POH Laying Down Directional BHA NO.4 From 1,192' - Lay Down Cross Over Sub, (23) Joints 5" HWDP, Daily Drilling Jars, (9) Steel Drill Collars, (3) Flex Drill Collars - Down Load Sperry Sun MWD/LWD Tools - Retrieve Sperry Sun ESS - Flush Out BHA With Fresh Water - Lay Down UBHO Sub, Hang Off Collars, MWD/LWD Tools, Float Sub, And String Stabilizer Drain Mud Motor And Remove HTC 81/2" Bit - Lay Down Sperry Mud Motor Clear Rig Floor Monitor Well Bore (Static) - Change Out Variable Pipe Rams In Top BOP Gate To 7" Pull Wear Bushing And Install Test Plug - Rig Up Testing Equipment - Test 7" Rams At 250 Psi. Low And 3,500 Psi. High (Good Test) Rig Down Testing Equipment - Pull Test Plug - Install Wear Bushing And Energize Lock Down Studs Rig Up Power Tongs - Casing Tools And Equipment Pick Up And RIH With Shoe Track - Baker Lock Connections To Insert Landing Collar Joint NO.3 - Verify Floats Holding - RIH With 18 Joints Of 7" BTC-M 26 lb. L-80 Casing To 737' - Make Up To Mark Torqued To 8,200 ftIlbs. Change Out Handling Equipment To 5" DP Elevators - M I U Baker HMC Liner Hanger, ZXP Packer, Liner Tie Back Sleeve, And Running Tool - Change Out Handling Equipment P / U Cross Over, (1) 4" Drill Pipe Pup Joint, RIH w/ 1 Stand 4" Drill Pipe From Mast Circulate 7" Liner Volume At 220 GPM With 170 Psi. - Recorded Liner Weight At 20,000# RIH With 18 Joints Of 7" BTC-M 26 lb. L-80 Liner On 4" Drill Pipe From 882' To 10,222' - Fill 4" Drill Pipe Every 10 Stands Circulate Drill Pipe And 7" Liner Volume At 252 GPM With 1,000 Psi. RIH With 7" BTC-M 26 lb. L-80 Liner On 4" Drill Pipe From 10,222' To 10,877' With No Problems - Pick Up Baker Cement Head - Install Manifold And Circulating Lines - Establish Circulation At 2 BPM With 620 Psi And Full Returns - Wash To Bottom At 10,900' Stage Up Pumping Rates From 2 BPM With 620 Psi. To 7.0 BPM With 1,570 Psi. - Condition Mud With No Pipe Movement And Full Returns Held PJSM With All Personal Regarding Cementing Operation - Shut Down And Turn Over To Dowell - Pump 5 BBLS Water- Test Surface Lines And Equipment To 4,500 Psi. (Test Good) - Clear Lines With Mud Push Prior To Going Down Hole - Pump 30 BBLS 12.3 PPG Mud Push, Followed With 41.8 BBLS (202 Sacks) 15.8 PPG Class "G" Tail Cement At 4.8 BPM - Wash Printed: 10120/2003 8:54:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ·,Dat~ ,... .. Page 6 of 14 BP EXPLORATION Operations Summary Report Q-07 Q-07B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 9/27/2003 Rig Release: 10/14/2003 Rig Number: 2 Spud Date: 2/10/1979 End: 10/14/2003 , . Description of Operations 10/3/2003 12:30 - 15:00 From -To Hpurs Task Code NPT'Phase LNR1 Up Lines To Floor - Drop Dart And Displace With 11.3 PPG LSND Mud At 6.4 BPM With 970 Psi. - Slow Rate And Latch Liner Wiper Plug With 101.5 BBLS Pumped Away - Increase Rate To 6.4 BPM Continue To Displace - Slow Rate To 4.2 BPM With Final Circulating Pressure At 1,030 Psi. - Bump Plug With A Total Of 123.3 BBLS Pumped Increase Pressure To 2,500 Psi. To Set Baker Liner Hanger - Bleed Off Pressure And Check Floats (Floats Held) - Cement In Place At 13:38 Hours - Rotate 15 Turns To The Right And Release From Liner - Pressure Up Down Drill Pipe To 1,000 Psi. - Pick Up To Release Pack Off From Seals And Expose Running Tool Dogs As Pressure Decreases Ramp Up Pumps To Maximum Rate At 11.7 BPM With 3,571 Psi. And Circulate Cement Up Hole 30 BBLS - Reduce Pump Rate To 6.4 BPM With 1,379 Psi. Slack Off String With 70,000 Ibs. To Set Baker ZXP Packer Rotate And Repeat Process Several Times (No Clear Surface Indication That Packer Set) - Increase Pump Rate At 11.3 BPM With 3,263 Psi.And Continue To Circulate Out Trace Of Cement Estimated At 3 BBLS. To Surface - Top Of Liner At 10,137', Insert Landing Collar At 10,814', Float Collar At 10,856', Float Shoe At 10,898' Circulate And Condition Mud Due To High PH Levels - Break Down Cement Circulating Lines And Lay Down Baker Cementing Head - Clean Under Shakers - Pump Dry Job Blow Down Top Drive POH With Baker 7" Liner Running Tool From 10,137' - Inspect Running Tool Brass Pins Were Not Sheared Indicating That The ZXP Packer Did "Not" Set - Lay Down Running Tool And Clear Rig Floor Attempt To Test 9 5/8" Casing, 7" Liner Top Packer, And 7" Casing (Test No Good) 15:00 -16:30 16:30 - 20:00 20:00 - 20:30 20:30 - 22:00 22:00 - 23:00 23:00 - 23:30 2.50 CEMT P 1.50 CEMT P 3.50 CASE P 0.50 CASE N DFAL LNR1 1.50 CASE P 1.00 CASE P 0.50 CASE N DFAL LNR1 LNR1 LNR1 Strokes Pmp'd 27 54 81 108 117 126 135 144 153 Pressure 750 psi 1250 psi 1790 psi 2250 psi 2390 psi 2530 psi 2670 psi 2750 psi 2850 psi LNR1 Shut Down Pumps Held Test F/2 minutes w/ 350 Psi. Pressure Loss - Bleed Pressure To 0 Psi. Change Out 7" Pipe Rams In Top BOP Gate To 31/2" By 6" Variables Pull Wear Bushing And Install Test Plug - Rig Up Testing Equipment - Test 3 1/2" X 6" Variables To 250 Psi. Low And 3,500 Psi. High (Good Test) - Rig Down Testing Equipment And Pull Test Plug - Install Wear Bushing And Energize Lock Down Studs Re-Test 95/8" Casing, 7" Liner Top Packer, And 7" Casing LNR1 Printed: 10/20/2003 8:54: 13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 10/3/2003 10/4/2003 10/5/2003 / I ~ ... Page 7 of 14 BP EXPLORATION Operations Summary Report Q-07 Q-07B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES . From - To Hours Task; Code' NPT Phase 23:00 - 23:30 23:30 - 00:00 00:00 - 01 :30 01 :30 - 03:00 03:00 - 05:00 05:00 - 05:30 05:30 - 06:30 06:30 - 07:00 07:00 - 10:00 10:00-11:30 11 :30 - 18:00 18:00 - 21 :00 21 :00 - 00:00 00:00 - 01 :30 01 :30 - 04:00 "NOTE" Blind Shear Rams Failed On Initial Test -Junk Iron Found In Ram Cavity Of 13 5/8 5M BOP (Packer Slip Segement, And Partial Bow Spring Centrilizer) Change Out Shear Ram Blocks For Conventional Set Of Blind Rams And Re-Tested (OK) PROD1 Make Up BHA NO.6 - Pick Up Sperry Sun Motor, Make Up 6 1/8" Smith XR20 Insert Bit, Pick Up MWD/LWD Tools - Orient And Initialize MWD/LWD Tools - Pick Up (1) Flex Drill Collar- Surface Test Sperry Sun Equipment - Hold PJSM And Install Nuke Sources Lower Below Rig Floor - Pick Up (2) Flex Drill Collars, Daily Mechanical Jars, Circulating Sub, (5) 3 1/2" HWDP, And Cross Over Sub To 387' PROD1 RIH With Directional Drilling BHA NO.6 From 387' To 7,199' PROD1 RIH With Directional Drilling BHA NO.6 From 7,199' Tag Insert Landing Collar At 10,814' PROD1 Drill Landing Collar And Wiper Plugs - Drill Cement To Float Collar At 10,856' - Drill Cement To Float Shoe At 10,898'- WOB Rotating 5,000# - 12,000#, RPM 50, Motor RPM 69, Torque Off Bottom 10,000 ft / Ibs - On Bottom 12,000 ft / Ibs, Pump Rate 230 gpm, SPP Off Bottom 2,100 psi, On Bottom 2,260 psi. String Weight Up 220,000#, String Weight Down 112,000#, String Weight Rotating 150,000# 0.50 CASE N DFAL LNR1 0.50 CASE N DFAL LNR1 1.50 CASE N DFAL LNR1 1.50 CASE P LNR1 2.00 CASE N DFAL LNR1 0.50 CASE N DFAL LNR1 1.00 CASE P LNR1 0.50 CASE N DFAL LNR1 3.00 CASE N DFAL LNR1 1.50 CASE N DFAL LNR1 6.50 BOPSURP PROD1 3.00 DRILL P 3.00 DRILL P 1.50 DRILL P 2.50 DRILL P Start: 9/27/2003 Rig Release: 10/14/2003 Rig Number: 2 Spud Date: 2/10/1979 End: 10/14/2003 Description of Operations __ ..__.__... .__n_..._____..__ With Same Results (Test No Good) Pick Up BHA NO.5 And RIH - Pick Up Baker Rotating Dog Assembly, (9) 61/2" Drill Collars, (12) 5" HWDP, Cross Over Sub Pick Up BHA NO.5 And RIH To 653' - Pick Up Baker Rotating Dog Assembly, (9) 61/2" Drill Collars, (12) 5" HWDP, Cross Over Sub Pick Up 78 Joints Of 4" HT -40 Drill Pipe And RIH With BHA NO.5 From 653' To 3,077' RIH With BHA NO.5 From 3,077' To 10,137' Weight Set ZXP Packer - Pressure Up Down Annulus To 1,000 Psi. To Assist In Setting Process - Unsting Seal Assembly And POH From 10,137' To 10,082' Test 9 5/8" Casing, 7" Liner Top Packer, And 7" Casing At 3,500 Psi. Record On Circle Chart For 30 Minutes (Test Good) Pump Dry Job - Blow Down Top Drive POH With BHA NO.5 From 10,082' To 653' Lay Down BHA NO.5 From 653' - Lay Down Cross Over Sub, (12) 5" HWDP, (9) 6 1/2" Steel Drill Collars, Baker Rotating Dog Sub And Seal Assembly - Clear Rig Floor Remove Wear Bushing - Install Test Plug - Rig Up Testing Equipment - Test BOP And Related Equipment - Witness Of BOP Test Waived By AOGCC Inspector John Crisp - Test Annular, Upper And Lower Pipe Rams, Blind Rams, Manual And HeR Valves On Choke And Kill Lines, Choke Manifold, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 3,500 Psi. High - Perform Accumulator Test - Rig Down Testing Equipment - Pull Test Plug - Install Wear Bushing And Energize LOS - Blow Down Choke Manifold And Kill Lines - Clear Rig Floor Printed: 1012012003 8:54:13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ..... .. BP EXPLORATION Operations Summary Report Page 8 of 14 Q-07 Q-07B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 9/27/2003 Rig Release: 10/14/2003 Rig Number: 2 Spud Date: 2/10/1979 End: 10/14/2003 .,./ Date FrÓh1- To Hours' Task Code NPT Phase .. . ..... .. ... . . .... .... Description 'of Operations 10/5/2003 04:00 - 06:30 06:30 - 07:00 07:00 - 07:30 07:30 - 00:00 10/6/2003 00:00 - 00:30 00:30 - 01 :00 01:00 - 02:15 02:15 - 05:30 05:30 - 07:30 07:30 - 09:30 2.50 DRILL P PROD1 Rotate And Reciprocate Drill String While Displacing 11.3 PPG LSND Mud In Well Bore To 8.5 PPG Flo-Pro Mud System At 250 GPM With 2,350 Psi. - Clean Out Possom Belly And Under Shakers PROD1 Drill Float Shoe And 61/8" Hole From 10,898' To 10,920' - Pull Into Casing PROD1 Hold Pre-Job Safety Meeting - Preform FIT To 10.0 PPG EMW 0.50 DRILL P 0.50 DRILL P Closed Top Pipe Rams And Performed FIT. Strokes Pmp'd Pressure 4 180 psi 8 280 psi 12 330 psi 16 470 psi 20 550 psi 24 630 psi 26 670 psi 16.50 DRILL P Held Test F/ 10 minutes w/ 30 Psi. Pressure Loss. MW 8.50 ppg, 7" Casing Shoe TVD 8,418' Pressure 658 psi = 10.0 PPG. EMW. Bleed Pressure To 0 Psi. - Open Top Pipe Rams PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 10,920' to 11,558' WOB Rotating 20,000# - 25,000#, WOB Sliding 15,000# To 20,000#, RPM 60 To 85, Motor RPM 82, Torque Off Bottom 5,000 ft / Ibs - On Bottom 7,000 ft / Ibs, Pump Rate 272 gpm, SPP Off Bottom 1,810 psi, On Bottom 1,990 psi. String Weight Up 200,000#, String Weight Down 140,000#, String Weight Rotating 170,000# - ART = 4.7 hrs.- AST = 8.20 hrs. PROD1 Due To Target Change Unable To Get Required Build Rates To Hit Target With Current Motor Settings - Prepare To POH - Circulate Hi-Vis Sweep In Open Hole Section At 6.5 BPM With 1,810 Psi. While Rotating And Reciprocating Drill String PROD1 Monitor Well Bore (Static) - POH With Directional BHA NO.6 From 11,558' To 10,842' With No Problems PROD1 Drop Dart And Open Circulation Sub - Circulate Bottoms Up At 11.3 BPM With 1,200 Psi. - Remove Blower Hose - Monitor Well Bore (Static) - Pump Dry Job And Blow Down Surface Equipment PROD1 POH With Directional BHA NO.6 From 10,842' To 387' PROD1 Handle BHA NO.6 - Stand Back BHA - Held PJSM For Sperry Sun Radioactive Sources - Pulled BHA To Rig Floor And Removed Sources - Down Load Sperry Sun MWDILWD Tools- Remove Smith 6 1/8" XR20 Bit And Increase Bend On Mud Motor To 1.83 Degrees PROD1 Make Up BHA NO.7 - Make Up 61/8" Smith XR20 Insert Bit, Pick Up OM And Hang Off Collar MWD Tools - Orient And Initialize MWD/LWD Tools - Surface Test Sperry Sun Equipment - Hold PJSM And Install Nuke Sources Lower Below Rig Floor - RIH With (3) Flex Drill Collars, Daily Mechanical Jars, Baker Circulating Sub, (5) 3 1/2" HWDP, And Cross Over Sub To 387' 0.50 DRILL P 0.50 DRILL P 1.25 DRILL P 3.25 DRILL P 2.00 DRILL P 2.00 DRILL P Printed: 10/2012003 8:54:13 AM - . Page 9 of 14 BP EXPLORATION Operations Summary Report RIH With Directional Drilling BHA NO.7 From 387' To 10,842' While Filling Drill String Every 3,000 Feet Slip And Cut 105 Feet Of 1 1/4" Drilling Line - Adjust Draworks Mechanical Breaks Service Top Drive, Traveling Blocks, And Crown Sheaves RIH With Directional BHA NO.7 From 10,842' To 11,495' With No Problems - Take Benchmark MWD Survey At 11,212' - As Precaution Wash To Bottom From 11,495' To 11,558' Drilled 6 1/8" Directional Hole By Rotating And Sliding From 11,558' To 11,746' WOB Rotating 20,000# - 25,000#, WOB Sliding 20,000# To 25,000#, RPM 20, Motor RPM 82, Torque Off Bottom 5,000 ft Ilbs - On Bottom 8,000 ft / Ibs, Pump Rate 275 gpm, SPP Off Bottom 1,840 psi, On Bottom 1,950 psi. String Weight Up 200,000#, String Weight Down 145,000#, String Weight Rotating 170,000# - ART = .16 Hrs. - AST = 5.70 Hrs. PROD1 Drilled 61/8" Directional Hole By Rotating And Sliding From 11,873' To 12,764' WOB Rotating 20,000# - 25,000#, WOB Sliding 20,000# To 25,000#, RPM 20 To 75, Motor RPM 82, Torque Off Bottom 7,000 ft Ilbs - On Bottom 9,000 ft / Ibs, Pump Rate 275 gpm, SPP Off Bottom 2,020 psi, On Bottom 2,190 psi. String Weight Up 195,000#, String Weight Down 135,000#, String Weight Rotating 165,000# - ART = 9.91 Hrs. - AST = 6.85 Hrs. Circulate Sweep Around At 6.5 BPM With 2,100 Psi. While Rotating And Reciprocating Drill String Monitor Well Bore (Static) - POH With Directional BHA No.7 From 12,764' To 10,842' With No Problems Service Top Drive, Traveling Blocks, And Crown Sheaves RIH With Directional BHA NO.7 From 10,842' To 12,712' With No Problems - As Precaution Wash To Bottom From 12,712' To 12,764' - No Fill Circulate Sweep Around At 6.5 BPM With 2,100 Psi. While Rotating And Reciprocating Drill String - Monitor Well Bore (Static) - Spot Liner Running Pill Monitor Well Bore (Static) - POH With Directional BHA No.7 Laying Down 51 Joints Of 4" Drill Pipe From 12,764' To 11,157' With No Problems - Drop Rabbit With Slick Line Tail - POH From 11,157' To 10,842' PROD1 Drop Dart And Open Circulation Sub - Circulate Bottoms Up At 12.5 BPM With 1,450 Psi. - Remove Blower Hose - Monitor Well Bore (Static) - Pump Dry Job And Blow Down Surface Equipment PROD1 POH With Directional BHA NO.6 From 10,842' To 387' PROD1 POH Laying Down Directional BHA NO.7 From 387' - Lay Down Cross Over Sub, (5) Joints 3 1/2" HWDP, Circulating Sub, Daily Drilling Jars, (2) Flex Drill Collars - Held PJSM For Sperry Sun Radioactive Sources - Pulled BHA To Rig Floor And Removed Sources - Down Load Sperry Sun MWDILWD Tools- Flush Out BHA With Fresh Water - Lay Down Flex Drill Collar, Hang Off Collars, MWDILWD Tools, Remove Smith 61/8" XR20 Bit And Lay Down Sperry Sun Motor - Clear Rig Floor COMP Rig Up Power Tongs - Casing Tools And. Equipment Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Q-07 Q-07B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From - To ! Hours i Task ; Code! NPT ' Phase ! .n j 10/6/2003 09:30 - 13:30 4.00 DRILL P PROD1 13:30 - 14:30 1.00 DRILL P PROD1 14:30 - 15:00 0.50 DRILL P PROD1 15:00 -15:30 0.50 DRILL P PROD1 15:30 - 00:00 8.50 DRILL P PROD1 10/7/2003 00:00 - 22:00 22.00 DRILL P 22:00 - 00:00 2.00 DRILL P PROD1 10/8/2003 00:00 - 01 :00 1.00 DRILL P PROD1 01 :00 - 01 :45 0.75 DRILL P PROD1 01 :45 - 02:30 0.75 DRILL P PROD1 02:30 - 04:45 2.25 DRILL P PROD1 04:45 - 06:30 1.75 DRILL P PROD1 06:30 - 08:00 1.50 DRILL P 08:00 - 11 :00 11 :00 - 14:30 3.00 DRILL P 3.50 DRILL P 14:30 - 15:00 0.50 CASE P Start: 9/27/2003 Rig Release: 10/14/2003 Rig Number: 2 Spud Date: 2/10/1979 End: 10/14/2003 Description of Operations Printed: 1012012003 8:54: 13 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ..... .. Page 10 of 14 BP EXPLORATION Operations Summary Report Q-07 Q-07B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 9/27/2003 Rig Release: 10/14/2003 Rig Number: 2 Spud Date: 2/10/1979 End: 10/14/2003 10/8/2003 15:00 - 17:45 Date ...... From -To Hours Task Code NPT Phase . . .. . . Description of.Operations 2.75 CASE P COMP 17:45 - 18:15 0.50 CASE P CaMP 18:15 - 21 :45 3.50 CASE P CaMP 21 :45 - 22:00 0.25 CASE P CaMP 22:00 - 23:00 1.00 CASE P COMP 23:00 - 00:00 1.00 CASE P COMP 10/9/2003 00:00 - 01 :45 1.75 CASE P COMP 01 :45 - 05:00 3.25 CEMT P COMP Pick Up And RIH With Shoe Track - Baker Lock Connections To Landing Collar Joint NO.3 - Verify Floats Holding - RIH With 48 Joints Of 4 1/2" IBT-M 12.6 lb. L-80 Casing To 1,983'- Make Up To Mark Torqued To 3,900 ft/lbs. - Change Out Handling Equipment To 4" DP Elevators - M / U Baker FormLock Liner Hanger Packer, And Hydraulic Setting Tool - P / U Cross Over, (1) 4" Drill Pipe Pup Joint, RIH w/ 1 Stand 4" Drill Pipe From Mast To 2,088' Circulate 4 1/2" Liner Volume At 258 GPM With 170 Psi. - Recorded Liner Weight At 27,000# RIH With 48 Joints Of 4 1/2" IBT-M 12.6 lb. L-80 Liner On 4" Drill Pipe From 2,088' To 10,864' - Fill 4" Drill Pipe Every 10 Stands Circulate Drill Pipe And 4 1/2" Liner Volume At 224 GPM With 650 Psi. RIH With 4 1/2" IBT-M 12.6 lb. L-80 Liner On 4" Drill Pipe From 10,864' To 12,740' With No Problems - Pick Up Baker Cement Head - Install Manifold And Circulating Lines - Establish Circulation At 1 BPM With 417 Psi And Full Returns - Wash To Bottom At 12,764' Reciprocate 4 1/2" Liner And Form Lock Liner Hanger Packer - Stage Up Rate To 6 BPM Reciprocate 4 1/2" Liner And Form Lock Liner Hanger Packer- Stage Up Rate To 6 BPM - Held PJSM With All Personal Regarding Cementing Operation - Batch Mix Cement Shut Down And Turn Over To Dowell - Pump 5 BBLS Water- Test Surface Lines And Equipment To 4,500 Psi. (Test Good) - Pump 15 BBLS CW-100 - 25 BBLS 9.5 PPG Mud Push, Followed With 53 BBLS (252 Sacks) 15.8 PPG Class "G" Tail Cement At 5.0 BPM - Wash Up Lines To Floor - Drop Dart And Displace With 60.4 BBLS Perf Pill And 78.2 BBLS 8.5 PPG Flo-Pro Mud At 6.1 BPM - Slow Rate And Latch Liner Wiper Plug With 108.4 BBLS Pumped Away - Increase Rate To 5.0 BPM Continue To Displace - Slow Rate To 2.4 BPM With Final Circulating Pressure At 1,284 Psi. - Bump Plug With A Total Of 138.6 BBLS Pumped Increase Pressure To 4,000 Psi. To Set Baker Form Lock Liner Hanger Packer - Slack Off To 100K Bleed Off Pressure At 420 Psi. Liner Slid Down Hole Weight Indicator Went To 120K Continue To Bleed Off Pressure And Check Floats (Floats Held) - Cement In Place At 03:15 Hours- Pick Up On Liner To 275K Liner Slid Up Hole - Slack Off And Place Liner 1 Foot Off Bottom - Pressure Up Down Casing To 4,500 Psi. - Slack Off To 100KAnd Bleed Off Pressure - Pick Up On Liner To 290K Liner Slid Up Hole - Reposition Liner And Pressure Up To 4,950 Psi. - Slack Off On Liner To 1 OOK - Bleed Off Pressure - Rotate 25 Turns To The Right And Release From Liner - Pressure Up Down Drill Pipe To 1,000 Psi. - Pick Up To Release Hydraulic Swedge From Liner, No Good Liner Appears To Be Coming Up Hole Have Same Up Weights And Still Holding Pressure From Seals - Increase Pressure To 1,250 Psi. To Help Hydraulic Swedge From Liner As The Pressure Decreased Pumps Ramped Up To Maximum Rate At 12.5 BPM With 2,400 Psi. - Circulate Bottoms Up Printed: 10120/2003 8:54:13 AM ./ - -- ~ BP EXPLORATION Page 11 of 14 Operations Summary Report Legal Well Name: Q-07 Common Well Name: Q-07B Spud Date: 2/10/1979 Event Name: REENTER+COMPLETE Start: 9/27/2003 End: 10/14/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/14/2003 Rig Name: NABORS 2ES Rig Number: 2 Date : From - To Hours, Task . Code: NPT Phase Description of Operations -----..-........ . 10/9/2003 01 :45 - 05:00 3.25 CEMT P COMP Estimated 10 BBLS. Cement To Surface - Top Of Liner At 10,765', Landing Collar At 12,676', Float Collar At 12,719', Float Shoe At 12,762' *NOTE* Time Spent Attempting To Set And Release From Liner With Tools In Cement With Out Any Circulating At From 03:15 Hours To 04:09 Hours 05:00 - 06:30 1.50 CASE P COMP Circulate And Displace Well To Seawater While Reciprocating Liner Running Tool At 12.5 BPM With 2,400 Psi. 06:30 - 07:00 0.50 CASE P COMP Break Down Cement Circulating Lines And Lay Down Baker Cementing Head 07:00 - 10:00 3.00 CASE P COMP POH With Baker 41/2" Liner Hydraulic Setting Tool From 10,765' 1 0:00 - 12:00 2.00 CASE P COMP Upon Inspection Of Baker Setting Tool Gauge Dog And Retainer Fell Out - Lay Down Setting Tool And Slick Stick - Drain BOP Stack And Look For Missing Parts - Clear Rig Floor 12:00 - 14:30 2.50 CASE P COMP Service Can-Rig Top Drive - Oil In Top Drive Bull Gear Appeared Discolored (Milky) Change Oil In Top Drive 14:30 - 15:00 0.50 CASE N DFAL COMP Attempt To Pressure Test 9 5/8" X 7" X 4 1/2" Liner (NO Good) Pressured Up To 2,000 Psi. 8.8 BBLS Pressure Was Bleeding Off Downhole - Shut Down Testing Operation And Bleed Off To 0 Psi. At Surface 15:00 - 15:30 0.50 CASE N DFAL COMP Rig Up Power Tongs - Handling Tools And Equipment For 2 7/8" Drill Pipe 15:30 - 18:30 3.00 CASE N DFAL CaMP Pick Up BHA No.8 - Baker Flat Bottom Mill, Cross Overs, And 66 Joints Of 27/8" PAC Drill Pipe To 2,065' 18:30 - 19:00 0.50 CASE N DFAL COMP Rig Down Handling Tools And Equipment For 2 7/8" Drill Pipe 19:00 - 21:15 2.25 CASE N DFAL COMP RIH With BHA NO.8 On 4" Drill Pipe From 2,065' To 10,148' 21:15-22:00 0.75 CASE N DFAL COMP Record Up And Down Weights At 7" Liner Top (10,137') - Establish Circulation 7.5 BPM With 2,810 Psi. - Wash Liner Top Area To 10,180' - Shut Down Pumps And Pull Above Liner - Work Into Liner Top And RIH To 41/2" Liner Top (10,765') Repeat Previous Process - Spot Perf Pill In Clean Out String To Mill 22:00 - 00:00 2.00 CASE N DFAL COMP RIH With BHA NO.8 Thru 41/2" Liner From 10,765' To 12,676' Top Of Landing Collar With Liner On Bottom - Work And Wash Thru Problem Areas In LinerTag Up With 6,000 Ibs. On Bridges At 10,749' -11,166' -11,444' 10/10/2003 00:00 - 02:30 2.50 CASE N DFAL COMP Circulate Hi-Vis Sweep At 7.4 BPM With 3,150 Psi. - Trace Of Cement Back On Bottoms Up - Spot Perf Pill In 4 1/2" Liner 02:30 - 03:45 1.25 CASE N DFAL COMP POH With BHA NO.8 Thru 4 1/2" And 7" Liners From 12,676' To 10,093' With No Problems 03:45 - 04:45 1.00 CASE P CaMP Slip And Cut 97 Feet Of 1 1/4" Drilling Line 04:45 - 07:30 2.75 CASE N DFAL COMP POH With BHA NO.8 From 10,093' To 2,065' 07:30 - 08:00 0.50 CASE N DFAL COMP Attempt To Pressure Test 95/8" X 7" X 4 1/2" Liner (NO Good) Pressured Up To 1,600 Psi. - Pressure Was Bleeding Off Downhole Stabilized At 1,150 Psi. - Shut Down Testing Operation And Bleed Off To 0 Psi. At Surface 08:00 - 08:30 0.50 CASE N DFAL COMP Rig Up Power Tongs - Handling Tools And Equipment For 2 7/8" Drill Pipe 08:30 - 09:30 1.00 CASE N DFAL COMP Lay Down BHA No.8 - Lay Down 66 Joints Of 2 7/8" PAC Drill Pipe, Cross Overs, And Baker Flat Bottom Mill From 2,065' 09:30 - 10:30 1.00 CASE N DFAL COMP Rig Down Handling Tools And Equipment For 2 7/8" Drill Pipe - Printed: 10/20/2003 8:54:13 AM . . Page 12 of 14 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Q-07 Q-07B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From .,.To :Hours Task Code NPT Phase 10/10/2003 09:30 - 10:30 1.00 CASE N DFAL CaMP 10:30 - 14:30 4.00 CASE N DFAL COMP 14:30 - 15:00 0.50 CASE N DFAL COMP 15:00 - 19:00 4.00 CASE N DFAL COMP 19:00 - 22:30 3.50 CASE N DFAL COMP 22:30 - 23:30 1.00 CASE N DFAL COMP 23:30 - 00:00 0.50 CASE P COMP 10/11/2003 00:00 - 00:30 0.50 CASE P COMP 00:30 - 04:30 4.00 CASE N DFAL COMP 04:30 - 05:00 0.50 BOPSURP COMP 05:00 - 07:30 2.50 BOPSURP COMP 07:30 - 08:00 0.50 BOPSUR P CaMP 08:00 - 08:30 0.50 PERF P COMP 08:30 - 09:00 0.50 PERF P COMP 09:00 - 11 :00 2.00 PERF P COMP 11 :00 - 11 :30 0.50 PERF P COMP Start: 9/27/2003 Rig Release: 10/14/2003 Rig Number: 2 Spud Date: 2/10/1979 End: 10/14/2003 Description;:Qf Operations .. . . . . . Clear Rig Floor RIH With Baker 5.15 0.0. Polishing Mill To Top Of Baker Form Lock Liner Hanger Packer At 10,765' Polish The Form Lock Liner Hanger Packer Tie Back From 10,765' To 10,773' Pump Dry Job - Blow Down Top Drive - POH With Polishing Mill From 10,773' - Make Service Breaks On Milling Assembly And Lay Down Same - Clear Rig Floor Pick Up Baker Tie Back Seal Assembly, ZXP Liner Top Packer, Hydraulic Setting And Running Tool - Install Cross Over And RIH To 10,765' Pick Up Single Of 4" Drill Pipe And Connect Top Drive - Up Weight At 180,000 Ibs. Down Weight At 140,000 Ibs. - Sting Seal Assembly Into Baker Form Lock Liner Hanger Packer At 10,765' And Slack Off To "No Go" - Pressure Up Down Drill String To 1,000 Psi. To Verify That Seals Covered - Bleed Pressure To 0 Psi. And Unsting Seals - Break Single And Drop Ball - Make Up Joint And Pump Ball To Seat - Shut Down Pumps And Open Bleeder - Slack Off Seal Assembly To "No Go" - Pressure Up Drill String To 3,000 Psi. Hold For 5 Minutes - Bleed Pressure To 0 Psi. Pick Up On String To 205,000 To Verify That ZXP Packer Set, Slack Off To 110,000 Ibs. - Pressure Up Down Drill String To 3,500 Psi. Hold For 5 Minutes And Bleed To 0 Psi - Place String At Netural Weight And Rotate 20 Turns To The Right - Pick Up On String Verify That Running Tool Is Released - Lay Down Single Of 4" Drill Pipe Pressure Test 95/8" X 7" X 41/2" Liner At 3,500 Psi. Pressure Test 9 5/8" X 7" X 41/2" Liner At 3,500 Psi. - Record On Circle Chart For 30 Minutes (Test Good) POH With Baker Running Tool From 10,755' - Service Baker Running Tool And Lay Down - Clear Rig Floor Remove Wear Bushing - Install Test Plug - Rig Up Testing Equipment Hold Pre-Job Safety Meeting - Test BOP And Related Equipment - Witness Of BOP Test Waived By AOGCC Inspector Chuck Sheave - Test Annular, Upper And Lower Pipe Rams, Blind Rams, Manual And HeR Valves On Choke And Kill Lines, Choke Manifold, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 3,500 Psi. High - Perform Accumulator Test - Rig Down Testing Equipment Pull Test Plug - Install Wear Bushing And Energize LOS - Blow Down Choke Manifold And Kill Lines - Clear Rig Floor Hold Pre-Job Safety Meeting Regarding Peforation Gun Handling Operation Rig Up Handling Tools And Equipment For Schlumberger Power Jet 27/8" Perforating Guns Pick Up 816' Of 2 7/8" Power Jet Guns - 365' Charges Loaded With 4 SPF At 60 Degree Phase - Make Up Firing Head And Cross Overs Rig Up Power Tongs - Change Handling Tools And Equipment For 27/8" Drill Pipe Printed: 1 0/20/2003 8:54: 13 AM ...... .. Page 13 of 14 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Q-07 Q-07B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From - To Hours Ta~k Code NPT Phase 10/11/2003 11 :30 - 13:00 1.50 PERF P COMP 13:00 - 13:30 0.50 PERF P COMP 13:30 - 18:00 4.50 PERF P COMP 18:00 - 18:30 0.50 PERF P CaMP 18:30 - 18:45 0.25 PERF P CaMP 18:45 - 21:00 2.25 PERF P CaMP 21 :00 - 22:00 1.00 PERF N RREP COMP 22:00 - 22:30 0.50 PERF P COMP 22:30 - 00:00 1.50 PERF P COMP 10/12/2003 00:00 - 01 :30 1.50 PERF P CaMP 01 :30 - 02:30 1.00 PERF P COMP 02:30 - 03:30 1.00 PERF P COMP 03:30 - 04:00 0.50 PERF P COMP 04:00 - 05:00 1.00 PERF P COMP 05:00 - 07:30 2.50 PERF P COMP 07:30 - 08:30 1.00 PERF P COMP 08:30 - 10:00 1.50 PERF P COMP 10:00 - 10:30 0.50 BOPSUR P COMP 10:30 - 11 :00 0.50 RUNCOI\rP COMP 11 :00 - 19:45 8.75 RUNCOI\rP COMP 19:45 - 20:45 1.00 RUNCOI\rP COMP 20:45 - 21 :00 0.25 RUNCOI\rP COMP 21 :00 - 00:00 3.00 RUNCOI\rP COMP 10/13/2003 00:00 - 01 :15 1.25 RUNCOI\rP COMP 01:15-02:45 1.50 RUNCOI\rP CaMP Start: 9/27/2003 Rig Release: 10/14/2003 Rig Number: 2 Spud Date: 2/10/1979 End: 10/14/2003 ... . ... .. . ... . .. Description oJ Operations Pick Up 38 Joints Of 2 7/8" PAC Drill Pipe To 1,987' Rig Down Power Tongs - Change Handling Tools And Equipment For 4" Drill Pipe RIH With 2 7/8" Power Jet Guns On 4" HT -40 Drill Pipe From 1,987' To 12,676' (Top Of Landing Collar) - Place Perf Guns On Depth w/ Bottom Shot At 12,675', Top Shot At 11,890', Spaced Out Throughout The Interval w/ 365' Of Loaded Guns At 4 SPF, 60 Degree Phasing- Close Annular - Pressure Up To 2,500 Psi. And Fire Perf Guns - Bleed Pressure To 0 Psi. - Open Annular - Surface Indication Guns Fired POH With Schlumberger Perf Guns Above Top Shot At 11,890' - From 12,675' To 11,860' Monitor Well Bore Static Loss Rate At 1 BPH - Pump Dry Job - Blow Down Top Drive POH Laying Down 4" Drill Pipe From 11,860' To 8,705' Repair Rig - Valve Body On Varco Iron Ruffneck Washed Out - Replace Valve Body Service Top Drive, Traveling Blocks, And Crown Sheaves POH Laying Down 4" Drill Pipe From 8,705' To 5,997' POH Laying Down 4" Drill Pipe From 5,997' To 3,200' Slip And Cut Drill Line POH Laying Down 4" Drill Pipe From 3,200' To 1,983' Rig Up 2 7/8" Handling Tools, Power Tongs And Equipment Lay Down 2 7/8" Pac Drill Pipe From 1,983' To 816' POH From Laying Down Schlumberger 2 7/8" Power Jet Perforation Guns From 816' - All Shots Were Fired Wash Off And Clear Rig Floor Make Up Mule Shoe And RIH With 4" Drill Pipe From Mast To 1,310' - POH Laying Down 4" Drill Pipe Rig Up And Pull Wear Bushing Rig Up 4 1/2" Tubing Handling Tools, Power Tongs And Equipment Hold Pre-Job Safety Meeting Regarding Tubing Running Operation - Run 4 1/2" Completion Per Detail- Pick Up Tail Pipe Assembly Baker Lock Connections Below Baker S -3 Packer - Torque To 3,900 ftllbs. - RIH With 256 Joints Of 41/2" L-80 12.6 lb. IBT-M Tubing To 10,761' Tagged Bottom Of 4 1/2" Liner Tie Back Sleeve Space Out 41/2" Completion String - Lay Down 3 Joints Of 4 1/2" Tubing - Pick Up 3 Space Out Pup Joints - Pick Up Joint NO.254 - Make Up Tubing Hanger With Pup And Landing Joint With Cross Overs - Up Weight At 147,000 Ibs. Down Weight At 105,000 Ibs. Block Weight At 28,000 Ibs. - Wire Line Entry Guide At 10,759' (2 Feet Off Bottom Of Tie Back Sleeve) Land Cameron Tubing Hanger - Run In Lock Down Studs Reverse Circulate Sea Water And Corrossion Inhibitor At 3 BPM With 160 Psi. Reverse Circulate Sea Water And Corrossion Inhibitor At 3 BPM With 160 Psi. Drop Ball And Rod - Pressure Up On The Tubing To 3500 Psi To Set Baker "S"-3 Packer At 10,702' - Hold The Pressure For 30 Minutes On Chart Recorder For Tubing Test - Bleed The Pressure To 1500 Psi. - Pressure Annulus To 3500 Psi For 30 Printed: 10/20/2003 8:54:13 AM .... .. Page 14 of 14 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Q-07 Q-07B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES ¡ Date . From - To Hours Task ¡Code NPT Phase 10/13/2003 01:15 - 02:45 1.50 RUNCOrvP COMP 02:45 - 03:00 0.25 WHSUR P COMP 03:00 - 03:30 0.50 WHSUR P COMP 03:30 - 12:00 8.50 BOPSURP COMP 12:00 - 14:30 2.50 WHSUR P COMP 14:30 - 15:00 0.50 WHSUR P COMP 15:00 - 16:00 1.00 WHSUR P COMP 16:00 - 16:30 0.50 WHSUR P COMP 16:30 - 17:45 1.25 WHSUR P COMP 17:45 - 18:45 1.00 WHSUR P COMP 18:45 - 19:00 0.25 WHSUR P COMP 19:00 - 19:30 0.50 WHSUR P COMP 19:30 - 20:30 1.00 WHSUR P CaMP Start: 9/27/2003 Rig Release: 10/14/2003 Rig Number: 2 Spud Date: 2/10/1979 End: 10/14/2003 Description of Operations - .... ....--.--.--.....-..---....--- .--. .....---------.---. -..- Mininutes For Packer Test On The Chart Recorder - Bleed Off The Tubing Pressure To Shear The OCR Valve Set At 2500 Psi. Install Two Way Check Valve - Test From Below To 1,000 Psi. (Good Test) Blow Down Surface Lines And Equipment Nipple Down BOP And Related Equipment - Remove Ram Blocks From All Gates And Break Stack Apart For Inspection - Remove From Cellar Area Clean Off Tubing Hanger Nipple Up Tubing Head Adaptor And Production Tree - Test Adaptor Flange Void To 5,000 Psi. (Test Good) Test Production Tree And Record On Circle Chart To 5,000 Psi. For 15 Minutes (Test Good) Rig Up DSM Lubricator And Pull Two Way Check Valve - Rig Down Lubricator And Clear Rig Floor Rig Up Circulating Lines And Equipment Test Little Red Services Surface Lines And Equipment At 1,000 Psi. (Test Good) - Pump 157 Barrels Of Diesel At 2.5 BPM With 450 Psi. U-Tube Diesel From Annulus To Tubing Suck Back Diesel In U-Tube Lines - Drain And Rig Down Same Pick Up T-Bar And Install Back Pressure Valve - Install Tree Cap And Test Back Pressure Valve From Below At 1,000 Psi. For 5 Minutes Remove Secondary Annulus Valve And Install Flange - Install Tree And Annulus Gauges - Secure Well - Clean Up Cellar Area "NOTE" - Rig Released From Well Work On Q-07B At 20:30 Hours On 10-13-2003 Printed: 10/2012003 8:54:13 AM e AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . Re: Distribution of Survey Data for Well Q-078 Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,199.06' MD 10,286.00' MD 12,764.00 I MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~~ ~"''\ \-~ 903- JSt- 16-0ct-03 Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_WOA Q Pad Q-07B Job No. AKMW2678820, Surveyed: 7 October, 2003 Survey Report 13 October, 2003 Your Ref: API 500292035202 Surface Coordinates: 5965725.00 N, 643940.00 E (70018'49.7480" N, 148050' 00.2484" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 965725.00 N, 143940.00 E (Grid) Surface Coordinates relative to Structure Reference: 2369.30 N, 1545.25 E (True) Kelly Bushing: 68.56ft above Mean Sea Level Elevation relative to Project V Reference: 68.56ft Elevation relative to Structure Reference: 68.56ft SPE!'í'í"Y-SU:f1 c !=tIt... t... I, N G . S e R. v 1 c: e s A Halliburton Company DEFINITIVE . . Survey Ref: svy4111 Sperry-Sun Drilling Services Survey Report for PBU_WOA Q Pad - Q-07B Your Ref: API 500292035202 Job No. AKMW2678820, Surveyed: 7 October, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 10199.06 40.880 108.810 7741.13 7809.69 846.10 S 5525.19 E 5964984.97 N 649480.40 E 2691 .64 Tie On Point MWD Magnetic 10286.00 41.420 109.500 7806.59 7875.15 864.87 S 5579.23 E 5964967.24 N 649534.79 E 0.812 2727.83 Window Point 10313.23 40.110 111 .480 7827.22 7895.78 871.09 S 5595.89 E 5964961.34 N 649551.56 E 6.759 2739.39 10344.67 38.370 113.140 7851.57 7920.13 878.64 S 5614.28 E 5964954.15 N 649570.10 E 6.464 2752.79 . 10372.78 36.720 116.330 7873.86 7942.42 885.80 S 5629.84 E 5964947.29 N 649585.79 E 9.069 2764.86 10406.89 34.820 119.520 7901.53 7970.09 895.12 S 5647.46 E 5964938.31 N 649603.58 E 7.803 2779.66 10436.17 32.950 122.530 7925.84 7994.40 903.52 5 5661.45 E 5964930.18 N 649617.73 E 8.580 2792.35 10465.73 30.820 125.870 7950.94 8019.50 912.28 S 5674.37 E 5964921.66 N 649630.81 E 9.354 2805.02 10499.87 28.750 130.130 7980.57 8049.13 922.70 S 5687.73 E 5964911.50 N 649644.38 E 8.668 2819.39 10530.85 27.690 130.040 8007.87 8076.43 932.13 S 5698.94 E 5964902.29 N 649655.76 E 3.424 2832.10 10558.90 27.270 128.430 8032.76 8101.32 940.32 S 5708.96 E 5964894.29 N 649665.94 E 3.042 2843.23 10590.27 26.030 129.550 8060.79 8129.35 949.17 S 5719.90 E 5964885.65 N 649677.05 E 4.265 2855.30 10621.20 25.080 131.260 8088.70 8157.26 957.82 S 5730.06 E 5964877.21 N 649687.37 E 3.888 2866.91 10653.63 23.940 133.740 8118.20 8186.76 966.90 S 5739.98 E 5964868.32 N 649697.46 E 4.734 2878.84 10684.20 22.590 137.850 8146.29 8214.85 975.54 S 5748.41 E 5964859.84 N 649706.05 E 6.904 2889.85 10714.91 21.190 140.740 8174.79 8243.35 984.21 S 5755.88 E 5964851.31 N 649713.69 E 5.751 2900.56 10746.37 20.270 142.700 8204.21 8272.77 992.95 S 5762.78 E 5964842.71 N 649720.75 E 3.662 2911.14 10778.84 19.420 147.120 8234.75 8303.31 1001.96 S 5769.12E 5964833.82 N 649727.27 E 5.309 2921.77 10810.57 18.400 151.430 8264.77 8333.33 1010.79 S 5774.38 E 5964825.09 N 649732.69 E 5.449 2931.87 10835.29 17.730 154.250 8288.27 8356.83 1017.60 S 5777.88 E 5964818.35 N 649736.32 E 4.456 2939.48 10869.38 17.440 157.750 8320.77 8389.33 1027.01 S 5782.07 E 5964809.02 N 649740.69 E 3.216 2949.75 . 10961.43 19.240 166.510 8408.16 8476.72 1054.53 S 5790.83 E 5964781.68 N 649749.98 E 3.571 2978.61 11055.58 20.520 172.080 8496.70 8565.26 1085.96 S 5796.72 E 5964750.36 N 649756.48 E 2.427 3010.15 11149.06 20.200 172.490 8584.34 8652.90 1118.19 S 5801.09 E 5964718.22 N 649761.46 E 0.375 3041.92 11242.83 19.530 170.940 8672.53 8741.09 1149.72S 5805.68 E 5964686.79 N 649766.65 E 0.909 3073.11 11276.46 22.870 166.650 8703.89 8772.45 1161.635 5808.07 E 5964674.92 N 649769.27 E 10.945 3085.12 11306.89 27.260 164.520 8731.44 8800.00 1174.11 S 5811.30 E 5964662.51 N 649772.74 E 14.726 3097.94 11335.54 28.760 164.300 8756.74 8825.30 1187.07 S 5814.91 E 5964649.62 N 649776.60 E 5.248 3111.36 11366.35 31.920 164.110 8783.32 8851.88 1202.045 5819.15 E 5964634.73 N 649781.12 E 10.261 3126.87 11398.02 36.810 163.430 8809.46 8878.02 1219.20 S 5824.15 E 5964617.68 N 649786.45 E 15.488 3144.70 13 October, 2003 - 13:20 Page 2 of 4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA Q Pad - Q-07B Your Ref: API 500292035202 Job No. AKMW2678820, Surveyed: 7 October, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 11428.48 41.340 162.860 8833.10 8901.66 1237.57 S 5829.72 E 5964599.42 N 649792.37 E 14.919 3163.87 11462.04 46.710 162.880 8857.22 8925.78 1259.85 S 5836.59 E 5964577.27 N 649799.67 E 16.001 3187.15 11493.28 51 .430 163.670 8877.68 8946.24 1282.45 8 5843.37 E 5964554.81 N 649806.88 E 15.229 3210.71 11523.23 55.630 163.190 8895.48 8964.04 1305.52 S 5850.24 E 5964531.86 N 649814.19 E 14.082 3234.74 11556.47 61.570 164.080 8912.79 8981.35 1332.74 S 5858.23 E 5964504.81 N 649822.70 E 18.015 3263.04 . 11586.49 67.260 163.700 8925.75 8994.31 1358.74 S 5865.74 E 5964478.96 N 649830.71 E 18.988 3290.04 11617.34 70.580 164.390 8936.84 9005.40 1386.41 S 5873.65 E 5964451.44 N 649839.15 E 10.962 3318.75 11651.77 77.180 165.710 8946.40 9014.96 1418.35 S 5882.17 E 5964419.67 N 649848.28 E 19.519 3351.67 11678.86 81.820 167.730 8951.33 9019.89 1444.27 S 5888.28 E 5964393.88 N 649854.89 E 18.630 3378.11 11711.58 86.290 169.350 8954.72 9023.28 1476.15 S 5894.75 E 5964362.12 N 649861.96 E 14.521 3410.28 11742.60 89.440 167.580 8955.88 9024.44 1506.52 S 5900.94 E 5964331.88 N 649868.74 E 11.646 3440.93 11774.01 88.580 162.220 8956.42 9024.98 1536.83 S 5909.12 E 5964301.73 N 649877.50 E 17.280 3472.20 11804.95 85.930 162.390 8957.90 9026.46 1566.27 S 5918.51 E 5964272.48 N 649887.45 E 8.583 3503.08 11837.48 87.280 162.710 8959.83 9028.39 1597.25 S 5928.25 E 5964241.69 N 649897.78 E 4.265 3535.52 11870.10 92.590 163.380 8959.87 9028.43 1628.44 8 5937.76 E 5964210.69 N 649907.89 E 16.407 3568.08 11897.83 92.650 163.140 8958.60 9027.16 1654.97 S 5945.74 E 5964184.32 N 649916.37 E 0.891 3595.73 11931.20 89.200 166.800 8958.06 9026.62 1687.18 S 5954.39 E 5964152.28 N 649925.64 E 15.G70 3628.96 11962.85 87.650 167.610 8958.93 9027.49 1718.038 5961.40 E 5964121.56 N 649933.23 E 5.525 3660.34 11991.82 87.220 167.530 8960.23 9028.79 1746.298 5967.62 E 5964093.43 N 649940.00 E 1.510 3689.02 12026.05 94.260 172.210 8959.78 9028.34 1779.96 S 5973.64 E 5964059.89 N 649946.66 E 24.691 3722.70 12056.46 94.510 172.520 8957.46 9026.02 1810.01 S 5977.67 E 5964029.92 N 649951.27 E 1.307 3752.31 12084.47 94.570 171.810 8955.24 9023.80 1837.67 S 5981.48 E 5964002.33 N 649955.60 E 2.536 3779.60 . 12119.37 94.760 171.690 8952.40 9020.96 1872.09 S 5986.47 E 5963968.01 N 649961.25 E 0.643 3813.64 12150.29 91.540 171.150 8950.71 9019.27 1902.62 8 5991.07 E 5963937.58 N 649966.44 E 10.559 3843.89 12178.76 88.150 170.650 8950.78 9019.34 1930.73 S 5995.57 E 5963909.56 N 649971.48 E 12.036 3871.84 12272.66 88.400 170.160 8953.61 9022.17 2023.27 S 6011.22 E 5963817.34 N 649988.90 E 0.586 3964.13 12366.12 88.210 169.610 8956.37 9024.93 2115.24 S 6027.63 E 5963725.70 N 650007.07 E 0.622 4056.14 12459.32 89.200 168.160 8958.48 9027.04 2206.66 S 6045.59 E 5963634.64 N 650026.78 E 1.883 4148.17 12552.82 89.750 167.530 8959.34 9027.90 2298.06 S 6065.27 E 5963543.63 N 650048.21 E 0.894 4240.77 12646.77 91.670 169.100 8958.17 9026.73 2390.05 S 6084.30 E 5963452.03 N 650069.00 E 2.640 4333.70 12698.13 91.730 168.290 8956.65 9025.21 2440.39 S 6094.36 E 5963401.89 N 650080.02 E 1.581 4384.44 12764.00 91.730 168.290 8954.66 9023.22 2504.86 S 6107.72 E 5963337.69 N 650094.62 E 0.000 4449.58 Projected Survey 13 October, 2003 - 13:20 Page 3 of 4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA Q Pad - Q-07B Your Ref: API 500292035202 Job No. AKMW2678820, Surveyed: 7 October, 2003 BPXA North Slope Alaska All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 159.920° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12764.00ft., The Bottom Hole Displacement is 6601,41ft., in the Direction of 112.299° (True). . Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10199.06 10286.00 12764.00 7809.69 7875.15 9023.22 846.1 0 S 864.87 S 2504.86 S 5525.19 E 5579.23 E 6107.72 E Tie On Point Window Point Projected Survey Survey tool program for Q-07B From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) . 0.00 10199.06 0.00 7809.69 10199.06 12764.00 7809.69 BP High Accuracy Gyro (Q-07) 9023.22 MWD Magnetic (Q-07B) 13 October, 2003 - 13:20 Page 4 of 4 DrillQuest 3.03.02.005 · . mJ} !Æ~ !Æ ~ ~ ~!Æ II FRANK H. MURKOWSKJ. GOVERNOR .AI,ASIiA OILAlQ) GAS CONSERVATION COMMISSION / I 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit Q-07B BP Exploration (Alaska), Inc. Permit No: 203-157 Surface Location: 355' SNL, 516' WEL, Sec. 16, TllN, R13E, UM Bottomhole Location: 2832' SNL, 373' EWL, Sec. 14, T11N, R13E, UM Dear Mr. Isaacson, Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ;f-. ~;f..- ~ ~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this---1.!- day of September, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ¡¡JlJ,f- 'it ¡ð/¿OO3 _ STATE OF ALASKA . ALASKA OPAND GAS CONSERVATION COM I SION PERMIT TO DRILL 20 MC 25.005 11 b. Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 5. Bond: 181 Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 12757' TVD 9026' 7. Property Designation: ADL 028285 o Drill II Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 355' SNL, 516' WEL, SEC. 16, T11N, R13E, UM Top of Productive Horizon: 1867' SNL, 133' EWL, SEC. 14, T11N, R13E, UM Total Depth: 2832' SNL, 373' EWL, SEC. 14, T11N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x-643940 Y-5965725 Zone-ASP4 16. Deviated Wells: Kickoff Depth 18. Casil'lgProgråm Size CasinQ 7" Hole 8-1/2" 6-1/8" 10300 ft Maximum Hole Angle SpeCifications Grade CouplinQ L-80 BTC-M L-80 IBT-M 4-1/2" WeiQht 26# 12.6# II Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number:/ PBU Q-07B 12. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool 8. Land Use Permit: 13. Approximate Spud Datei' 09/25/03 14. Distance to Nearest Property: 18,480' (Approx.) 9. Acres in Property: 2560 91 10. KB Elevation Plan KBE 15. Distance to Nearest Well Within Pool (Height above GL): = 70.6' feet H-28 is 668' away at 11700' MD 17. Anticipated pressure (see 20 AAC 25.035) / Max. Downhole Pressure: 3440 psig. Max. Surface Pressure: 260Ó psig SettirlgDepth QuåntityofCèl11ent Top Bottom (c.f. or sacks) MD TVD MD TVD (includinQ staQe data) 10150' 7773' 10888' 8400' 208 cu ft Class 'G' ./ 10738' 8258' 12757' 9026' 300 cu ft Class 'G' / LenQth 738' 2019' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): lEffective Depth MD (ft): JEnective D epth TVD 13047' 9010' None 12975' 9007' ': ..0·'. '. CementVoI.ume .. . ..... Structural Conductor 137' 20" x 30" 577 cu ft Permafrost II 137' 137' Surface 2717' 13-3/8" 4520 cu ft Arcticset II 2717' 2675' Intermediate 10925' 9-5/8" 1566 cu ft Class 'G', 688 cu ft Arcticset I 10925' 8323' Production Liner 984' 7" 528 cu ft Class 'G' 10379' - 11363' 7945' - 8600' Liner 2560' 2-7/8" 109 cu ft Class 'G' 10487' - 13047' 8023' - 9010' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name f\ïllsaacsí>n Title Senior Drilling Engineer .lL... \., C Phone 564-5521 Date ~ !4j 6~ Commission Use Only I Permit A~2°V ~I Date: ~ '/1 '?[) Mud Log qui ed Directional Survey Required Perforation Depth MD (ft): 12203' - 12974' 20. Attachments 181 Filing Fee 0 BOP Sketch o Property Plat 0 Diverter Sketch Permit To Drill I API Number: Number: 20, ~ -' /. .ç 7 50- 029-20352-02-00 Conditions of Approval: Samples Required Hydrogen Sulfide Measures Other: T ~.... t-ßo P E: +0 ŠS'DD P ,; . Approved By: L...L #~~ Form 10-401 Revi::d ;/2~01 perfOration Depth TVD (ft): 9013' - 9007' 181 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 181 Drilling Fluid Program 18120 AAC 25.050 Requirements Date: Contact Phil Smith, 564-4897 Prepared By NameJNumber: Terrie Hubble, 564-4628 DYes ~No [gYes D No I See cover letter for other requirements DYes ~No )2š Yes D No BY ORDER OF ;9~/.I~ o R1\J\W1\ l:HE COMMISSION Date s~2'iD~e e _ I Well Name: I Q-078 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: Estimated Target Location: Ivishak Zone 1 B/2A Bottom Hole Location: x = 643,939.9 Y = 5,965,725.8 355' FNL 516' FEL Sec. 16, T11 N, R13E Umiat X = 649,900.0 Y = 5,964,330 TVDss 8955' 1867' FNL 133' FWL Sec. 14, T11N, R13E Umiat X = 650,160.0 Y = 5,963,370.0 TVDss 8955' 2832' FNL 373' FWL Sec. 14, T11 N, R13E Umiat I AFE Number: 1 PBD4P2134 1 I Estimated Start Date: 1 09/25/03 / I I MD: 112,757' I I TVD: 19,026' 1 I GL: 142.1' I KB: 128.5' 1 I KBE: 170.6' 1 / I 1 1 I I Rig: I Nabors 2ES I Operating days to complete: 117 I Well Design (conventional, slim hole, etc.): 1 Two String Horizontal Sidetrack I Objective: 1 Ivishak Zone 1 B/2A Formation Markers Formation Tops (wp04) MD KINGAK TJF KOP 10,300 7886 -7816 TJD -7845 ~C ~M7 TJB -8185 TJA -8263 SAG RIVER 10,888 8401 -8330 SHUBLIK 10,922 8433 -8362 EILEEN NA TSAD / TZ4B 11,003 8509 -8438 TCGL / TZ3 11,203 8699 -8628 BCGL / TZ2C 11,257 8750 -8679 25N 11,350 8834 -8763 21 P 11,519 8955 -8884 PGOC 11,532 8962 -8891 TZ1 B 11,623 9002 -8931 MHO/HOT -8960 TDF / TZ1 A -8970 BelowTVDSS BSAD BelowTVDSS TD Criteria: Well needs at least 500' of perfable sand in the toe of the well with 150' standoff from faults. TVD TVDss Comments ABOVE KICKOFF ABOVE KICKOFF 3140 psi @ 8800 Q-07B Permit to Drill Page 1 _420 in the 8-1/2" intermediate section (at KOP) -910 in the 6-1/8" horizontal section H-28 passes BP's anti-collision policy when minor risk based at 1/200. H-28 fails against Q-07B while in the production interval. The center to center distance is -668' at planned depth of 11,700'. ,/ MW D Standard e Directional - Sperry wp04 KOP: 110,300' MD Maximum Hole Angle: Close Approach Wells: Survey Program: e CasinglTubing Program Hole Size CsgITbg WtlFt G~de co/, Length Top Btm O.D. MDITVD MDITVD 8-1/2" 7" 26# L-80 BTC-M 738' 10,150'/7,773' 10,888'/8,400' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 2019' 10,738/8,258' 12,757'/9,026' Tubing 4-1/2" 12.6# L-80 IBT-M 10,710' GL 10,738'/8,258' Mud Program Section Millinr Mud Properties: LSND Density (ppg) Viscosity I PV 10.7 50-65 11-13 Intermediate Mud Properties: LSND Den sit.y~..... (p ) I Viscosity I PV ,,10.7 45 - 55 12-15 I Lô Production Mud Properties: FloPro Density (ppg) I Viscosity I PV 8.4 - 8.5 45-55 4 - 7 Logging Program 8-1/2" Intermediate: Sample Catchers - None Drilling: Dir/GR/Res- Real time Open Hole: None Cased Hole: None 1 Whip Stock Window 9-5/8", 47# 1 YP I TauO I HTHP FL I PH 25-30 5-9 <12 8.5 - 9.0 1 8-1/2" hole section YP I TauO 20-25 3-7 1 I HTHP FL I PH <12 8.5 - 9.0 YP MBT 20 - 28 < 3 pH I API FI I 8.5 - 9.0 N/C 6-1/8" Production: Drilling: Open Hole: Cased Hole: Sample Catchers - over entire interval, samples described Dir/GR - Real time; Den/Neu - recorded mode for GOC None None Q-07B Permit to Drill Page 2 It e Cement Program I Casing Size 1 7" 26#, L-80 Intermediate Liner Basis: Lead: None Tail: Based on 80' shoe track, 588' of 7" X 8-1/2" open hole with 40% excess, 150' 7" X 9-5/8" lap, and 200' of 9-5/8" X 4" DP excess. Tail TOC: 10,150' MD (Top of Liner) I Total Cement Volume: 1 Tail 137 bbls, 208 ft3, 179 sacks Class G @ 15.8 ppg, 1.16 ft3/sack I Casing Size 14.5" 12.6#, L-80 Production Liner Basis: Lead: None Tail: Based on 80' shoe track, 1869' of 4-1/2" X 6-1/8" open hole with 40% excess, 150' 4-1/2" X 7" Liner Lap, and 200' of 7" X 4" DP excess. Tail TOC: 10,738' MD (Top of Liner) I Total Cement Volume: I Tail 153 bbls, 300 ft3, 259 sacks Class G @ 15.8 ppg, 1.16 ft3/sack Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing Test Integrity Test - 8-1/2" hole Production Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casingn" Liner Test Integrity Test - 6-1/8" hole Planned completion fluids 3440 psi @ 8400' TVDss (7.9 ppg EMW) 2600 psi (.10 psi/ft gas gradient to surface) / Infinite with a 11.0 ppg FIT / Rams test to 3,500 psi/250 psi. ./ Annular test to 2,500 psi/250 psi 3500 psi surface pressure 11.0 ppg FIT after drilling 20' from middle of window 3140 psi @ 8800' TVDss (6.9 ppg EMW) 2260 psi (.10 psi/ft gas gradient to surf~e) Infinite with a 10.0 ppg FIT / Rams test to 3,500 psi/250 psi. Annular test to 2,500 psi/250 psi 3500 psi surface pressure 12.0 ppg FIT after drilling 20' from middle of window 8.4 ppg Seawater /7.2 ppg Diesel Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Q-07B Permit to Drill Page 3 e e Sidetrack and Complete Procedure Summary Pre-Riq Work: / 1. P&A existing perforations with 16 bbls cement from PBTD to -10,400' MD 2. Drift 4-1/2" tubing and tag top of cement. 3. Chemical cut the 4-1/2",12.6#, L-80 tubing at -10,320' MD. 4. Fluid pack T X IA with seawater and freeze protect same. 5. Function all lock-down screws. Repair or replace as needed. 6. Remove the well house. If necessary, level the pad. Please provide total well preparation cost on the handover form. Riq Operations: 1. MIRU N2es. 2. Pull BPV. Circulate out freeze protection and giSplace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. .pull TWC. 4. Pull 4-1/2" tubing from above pre-rig cut. 5. MU 9 5/8" milling assembly and RIH to top of cut tubing stub. Swap well over to 10.7 ppg milling/drilling fluid. 6. RIH with 9-5/8" Baker bottom trip whipstock assembly. Orient whipstock and set on tubing stub 7. Mill window in 9-5/8", 47# casing at 10,300' MD. Drill 20' past middle of window. Perform FIT to 11.5 /~ ppg EMW. POOH 8. MU 8-1/2" drilling assembly with Dir/GR/Res and RIH. Kick off and drill the 8-1/2" intermediate interval to top Sag River at an estimated depth of 10,888' MD. 9. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing to 10,150' / MD. Displace cement with mud. POOH. 10. MU 6-1/8" BHA with Dir/GR/Res/Den/Neu and RIH. /~ 11. Drill the shoe tract and 20' new formation. Swap the well over to 8.4 ppg Drill-In fluid and perform FIT to 10.0 ppg. 12. Drill the 6-1/8" production interval building at 14°/100' to horizontal, targeting Z1B/2A Ivishak. Drill/ ahead to an estimated TD of 12,757' MD. 13. Run and cement a 4-1/2" solid liner throughout the 6-1/8" wellbore and back into the 7" liner. / 14. Displace well to clean seawater. /. 15. RIH with DPC perf guns. Perf intervals to be determined from LWD logs. 16. POOH. LD DP and perf guns. 17. Run 4-1/2",12.6#, L-80 completion tying into the 4-1/2" liner top. / 18. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 19. Set and test TWC. 20. ND BOPE. NU and test the tree to 5000 psi. 21. Freeze protect the well to -2200' and secure the well. 22. RDMO Post-Riq Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. Q-07B Drilling Program Q-07B Permit to Drill Page 4 e e Job 1: MIRU Hazards and Contingencies ~ Q-07 is the first well on the seven-well, single-row pad. No wells will require well house removal or shut-in for the rig move onto Q-07. The l"0sest neighboring well is Q-06 at -110'. ~ Q-Pad is not designated as an H2S site. However, Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: #1 Closest SHL #2 Closest SHL #1 Closest BHL #2 Closest BHL Well Name Q-05A Q-06A J-15B G-19A H2S Reading No Data No Data 15 ppm 10 ppm Date 3/5/2002 9/16/2000 No H2S data is available for Q pad ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Job 2: De-complete Well Hazards and Contingencies ~ Q-07A is currently Shut-in. Pre-Rig operations will include P&Aing the perforations in the 2-7/8" liner with cement. After the cement work and tubing cut, the wellbore will be fluid packed, pressure tested and freeze protected. ~ The tubing is severely corroded with several confirmed holes in the area of 3900'-4200'. A PDS caliper log in August of 2002 reported 77 joints with 20-40% loss, 92 joints with 40-85% loss. ~ Note and record required PU weight to pull tubing at cut point. ~ NORM test all retrieved well head and completion equipment. ~ Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP Job 4: Window Mill Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP Job 5: Drill 8-1/2" Intermediate Hole Q-07B Permit to Drill Page 5 e e Hazards and Contingencies ~ The intermediate section will kick off in the Kingak shale package and TD at the top of Sag River. Since 0-07B will be at -400 inclination or less, maintain mud weight at minimum 10.7 ppg to interval TD. Follow all shale drilling practices to minimize potential problems. ~ There are no fault crossings in the intermediate section. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. ~ KICK TOLERANCE: In the worst-case scenario of 8.8 ppg pore pressure at the Sag River depth, a fracture gradient of 12.0 ppg at the 9-5/8" casing window, and 9.8 ppg mud in the hole, the kick tolerance is Infinite. Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" Job 6: Install 7" Intermediate Liner Hazards and Contingencies ~ Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies ~ The 0-07B target lies in an area of moderate fault density as mapped from the Midfield 3-D seismic survey. The well plan is expected to cross one mapped fault in Zone 1 B. The fault strikes NW-SE and has -10 ft. throw down to the NE. This fault is not considered high risk for lost circulation because of the small amount of throw and lack of evidence for recent activation and offset. During the build section through Zone 2 the well plan comes within 90 ft. of a medium sized fault, but doesn't intersect. Both 0-07 and 0-07 A came within 45 ft. of the mapped fault and did not experience any losses. This fault is considered low risk for lost circulation because of the increase in standoff and lack of any historical losses. ~ Be prepared with LCM products as per LCM decision tree and try to cross fault on first BHA.. All drilling BHAs should include a circulation sub to help place LCM if required. ~ H-28 has been 1/200 minor risk based to pass BP's anti-collision policy. It has a center to center distance of 668' at the closest point. 0-07B Permit to Drill Page 6 e e ~ KICK TOLERANCE: In the worst-case scenario of 8.3 ppg pore pressure in the Ivishak, a fracture gradient of 9.5 ppg at the 7" casing window, and 8.5 ppg mud in the hole, the kick tolerance is Infinite. Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP Job 9: Install 4-1/2" Solid Production Liner Hazards and Contingencies ~ Differential sticking is a concern. The 8.5 ppg mud will be -750psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Reduce losses as much as feasible prior to cement job and pump excess cement as per loss rate. Evaluate alternative cement options based upon conditions. Hydraulic set packer may be required if losses exist prior to running liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 4-1/2" liner will need to be run to extend -150' back up into the 7" intermediate liner. ~ Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. Reference RPs .:. "Production Liner/Casing and Cementing Guidelines" .:. Schlumberger Cement Program Job 10: DPC Perforate Production Casinq Hazards and Contingencies ~ Observe Halliburton's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. Reference RPs .:. Follow Halliburton perforating practices and recommendations. .:. "DPC Perforating" RP Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Q-07B Permit to Drill Page 7 e e ~O'~'M~!»i'!; Job 13: ND/NUlRelease RiQ Hazards and Contingencies ~ No wells will require well house removal or shut-in for the rig move onto Q-078. The closest neighboring well is spaced as follows: 15-07 at -120'. Care should be taken while moving onto the well. Spotters will be used at all times. Reference RP .:. "Freeze Protecting an Inner Annulus" RP Q-078 Permit to Drill Page 8 TREE :, WELLHEAD = "m.'______.................. ,~. ACTUA TOR = KB. ELEV = ",.."u",.,....___________."..____...,_____. BF. ELEV = KOP= """....,"""".,.~'w..." fW3~m~gle = . Datum MD = Datum TVD = CAMERON 4-1/16" -5000 psi BAKER 69.47' 42.1' 1850' ,,----...............,.,,'". 95 @ 12633' 11721 ' 8800'SS e Q-07 A SAlaNOTES: 700@ 11917' AND 90° @ 12046'. SL ~D GLMs OFF DEPTH; NO VERlRCATION FROM E-LINE JEWELRY LOGS (SEE 6//29/02 WSR). - - . I 2202' - 4-1/2" OTIS SSSV LAND NIP, ID = 3.813" --i 2296' - 9-5/8" FOC I = I 2416' H 9-5/8" DV PKR . GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 5 3095 3020 30 MERLA DMY RA 0 06/29/02 4 5917 5053 49 MERLA DMY RA 0 06/29/02 L 3 8622 6825 43 MERLA DMY RA 0 06/29/02 2 10060 7946 36 MERLA DMY RA 0 06/29/02 1 10207 8057 39 MERLA DMY RA 0 06/29/02 13-3/8" CSG, 72#, L-80, ID = 12.347" - 2717' µ Minimum ID = 2.441" @ 10487' TOP OF 2-7/8" LNR :8: 10227' H 4-1/2" OTIS X NIP, ID = 3.813" I :8: 10341' - 9-5/8" X 4-1/2" TIW HBBP PKR, ID = 4.0" 10365' H 4-1/2" OTIS X NIP, ID = 3.813" I I 10444' - 7" LNR/HGR TIEBACK I 10468' H 4-1/2" OTIS XN NIP, ID = 3.80" I 10481' - 4-1/2" TBG TAIL WLEG I 10534' - ELMDTT LOG NOT AVAILABLE I ~ I 11154' H TOP OF CEMENT (04/21/03) I I 7" SIDETRACK WINDOW @ 11363' I TOP OF 7" LNR - 10444' .. I TOP OF 2-7/8" LNR H 10487' I 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" - 10481' 9-5/8" CSG, 47#, L-80, ID = 8.681" - 10925' r-- TOP OF WHIPSTOCK - 11354' I TOP OF CEMENT - 11521' I PBTD H 12975' ~ORATlONSUMMARY REF LOG: SÆRRY SUN GR/MWD ON 02/28/98 ANGLE AT TOP ÆRF: 89 @ 12203' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OPN/SQZ DA TE 1-11/16" 4 12203 - 12427 0 03/01/98 1-11/16" 4 12520 - 12570 0 03/01/98 1-11/16" 6 12630 - 12655 0 OS/27/02 1-11/16" 6 12664 - 12689 0 OS/27/02 1-11/16" 6 12698 - 12723 0 OS/27/02 1-11/16" 4 12773 - 12824 0 03/01/98 1-11/16" 4 12874 - 12974 0 03/01/98 12-7/8" LNR, 6.16#, L-80, l-i 13047' I 0.0058 bpf, 10 = 2.441" 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" - 12247' DATE 03/23/79 07/05/94 03/02/98 03/14/01 02/12/02 OS/27/02 REV BY SIS-lsl RNlTP JA M/tlh COMMENTS ORIGINAL COMPLETION RWO SIDETRACK COMPLETION CONVERTED TO CANVAS CORRECTIONS ADD ~S DATE REV BY COMMENTS 06/29/02 MH/KAK GLV C/O & SAFETY NOTE 04/21/03 PvVE/TLH TOP OF CMT LNR PRUDHOE BA Y UNIT WELL: Q-07A PERMIT No: 1980030 API No: 50-029-20352-01 SEC 16, T11N, R13E, 355' SNL & 516 WEL BP Exploration (Alaska) TREE!: CAMERON WELLHEAD = 4-1/16" -5000 psi "Ä"CfOÄTOR = ~.M 'W"' BÄf<ER: ~ "'m~,m~~m~m KB. ELEV = 69.47' BF. ELEV = U "U-42.1' KOP = 1850' Max Angle = 95@12633' ~mu.w~m..mmw,·", ,~ DatumMD= 11721' Datum TVD = ·8800' 55 &1-07 A Pre-Rig e 13-3/8" CSG, 72#, L-80, ID = 12.347" H 2717' µ Minimum ID = 2.441" @ 10487' TOP OF 2-7/8" LNR Tubing cut at -10,320' MD - Top of Cement P&A plug at -10,400' MD I TOP OF 7" LNR H 10444' I TOP OF 2-7/8" LNR H 10487' I 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" H 10481' 9-5/8" CSG, 47#, L-80, ID = 8.681" H TOP OF WHIPSTOCK H 11354' I TOP OF CEMENT H 11521' ÆRFORA TION SUMMARY REF LOG: SÆRRY SUN GR/MWD ON 02/28/98 ANGLE AT TOP ÆRF: 89 @ 12203' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL OPN/SQZ DA TE 1-11/16" 4 12203 - 12427 0 03/01/98 1-11/16" 4 12520 - 12570 0 03/01/98 1-11/16" 6 12630 - 12655 0 OS/27/02 1-11/16" 6 12664 - 12689 0 OS/27/02 1-11/16" 6 12698 - 12723 0 OS/27/02 1-11/16" 4 12773 - 12824 0 03/01/98 1-11/16" 4 12874 - 12974 0 03/01/98 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" H 12247' DATE 03/23/79 07/05/94 03/02/98 03/14/01 02/12/02 OS/27/02 REV BY SIS-lsl RNlTP JA M/tlh COMMENTS ORIGINAL COMA..ETION RWO SIDETRACK COMA..ETION CONVERTED TO CANVAS CORRECTIONS ADD ÆRFS DATE 06/29/02 04/21/03 07/25/03 REV BY COMMENTS MHlKAK GLV C/O & SAFETY NOTE F¥JElTLH TOP OF CMT LNR WSI Proposed pre-rig work for RST PRUDHOE BAY UNrr WELL: Q-07 A PERMrr No: 1980030 API No: 50-029-20352-01 SEC 16, T11N, R13E. 355' SNL & 516 WEL . I 2202' H 4-1/2" OTIS SSSV LAND NIP, ID = 3.813" --J 2296' H 9-5/8" FOC I = I 2416' H 9-5/8" DV PKR I . GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 5 3095 3020 30 MERLA DMY RA 0 06/29/02 4 5917 5053 49 MERLA DMY RA 0 06/29/02 L 3 8622 6825 43 MERLA DMY RA 0 06/29/02 2 10060 7946 36 MERLA DMY RA 0 06/29/02 1 10207 8057 39 MERLA DMY RA 0 06/29/02 - - -:::,...::>----- :::: ~ :8:~ I 10227' H 4-1/2" OTIS X NIP, ID=3.813" I 10341' H 9-5/8" X 4-1/2" TIW HBBP PKR, ID = 4.0" 10365' H 4-1/2" OTIS X NIP, ID = 3.813" I 10444' H 7" LNR/HGR TIEBACK I 10468' H 4-1/2" OTIS XN NIP, 10 = 3.80" I 10481' H 4-1/2" TBG TAIL WLEG I 10534' H ELMD TT LOG NOT A V AILABLE I ~ -I 11154' H TOP OF CEMENT (04/21/03) I I 7" SIDETRACK WINDOW @ 11363' I PBTD H 12975' 12-7/8" LNR, 6.16#, L-80, l-f 13047' I 0.0058 bpf, ID = 2.441" BP Exploration (Alaska) 2717' ~ / 10,150' 10,300' 10,320' 10,341' 10 925'~ , 12,247' Date 07-25-03 Q-07e Proposed Com.tion _ ~3-3/B"' 72#, L-BO -I: 14-1/2" 'X' nipple at 2200' MD I TREE = 4-1''6" CAMERON WELLHEAD = McEvoy -5000 psi ~m'....... , ~~.~.........m...~. ~ ACTUA TOR = BAKER KB. ELEV = 70.6' ~~~<._ ~'mmm<o~~ ~ . m......m~< BF. ELEV = 42.1' KOP = 1850' ~.~þ'n~le = ~_._.~__.._..._~5 @ .1.?6~~ Datum MD= 11721' "~....,,,.,.....,.u,,' " Datum lVD = 8800' SS l GLM Design: #4 - ??17' TVD - 4-1/2" X 1-1/2" #3 - ???1' TVD - 4-1/2" X 1-1/2" #2 - 1717' TVD - 4-1/2" X 1-1/2" #1 - 1 jt above packer - 4-1/2" X 1" 14-1/2", 12.6#, L-80, IBT-M Tubing 1 -I: 9-5/8" X 7" HMC Liner Hanger with ZXP Liner Top Packer and C2 Running Tool Tubing Tail: -10' Pup Joint -X Nipple (3.813") -10' Pup Joint -Packer -20' Pup Joint -X Nipple (3.813") -20' Pup Joint -XN Nipple (3.725") -10' Pup Joint -WLEG 7" X 4-1/2" 5-3 Permanent Packer @ 10,680' I 7" X 4-1/2" HMC Liner Hanger with ZXP Liner Top Packer and C2 Running Tool @ 10,740' 17',26#, L-80, BTC-M @ 10,888' I / ~ 9-5/8",47#, L-80 .... ...... 14-1/2", 12.6#, L-80, IBT-M Production Liner @ 12,757'1 ~ 7", 29#, L-80 2-7/8",6.16#, L-80 @ 13,047' Rev By Comments WSI Proposed Completion Design - wp03 PRUDHOE BAY UNIT WELL: Q-07B API NO: 50-029-20352-02 Permit NO: GPB Rotary Drilling SURVEY PROGRAM Plan: Q-07B wp04 (Q-07/Plan Q-07B) Depth Fm Depth To Survey/Plan Tool Created Dy: Ken Allen Date: 7/301200 00 12756.67 Planned: Q-07B wp04 V6 MWD Checked: Date Reviewed: Date WELL DETAILS Name +N/-" +E/-W Nortlung Easting Latitude Longitude Slot Q-072370.27 1543.44 5965725.00 643940.00 70018'49.748N 148°S0'00.248W 01 TARGET DETAIL~ Name TYD tN/oS t-El-W Nortlúng Easting Shape Q-07B TSag 8413.60 -1045.23 5786.64 5964790.97 649745.17 Cin:1e (Radius: 100) Q-07BT2 9025.60 -1945.12 5979.27 5963895.00 649955.00 Point Q-07B 1"3 9025.60 -2474.00 6174.19 5963370.00 650160.00 Point Q-07BTO 9025.60 -1509.12 5932.62 5964330.00 649900.00 Point Q-G7BPoly2 9030.60 -1868.22 5880.72 5963970.00 649855.00 Polygon SECTION DETAILS See MD Ine Azi TVD +N/-S +EI-W DLeg TFaee VSee Targe, ] 10300.00 41.51 109.60 7886.15 -867.51 5586.83 0.00 0.00 0.00 2 10320.00 41.78 113.19 7901.09 -872.36 5599.20 2.00 85.00 8.80 3 10833.]5 18,69 166.06 8348.] 8 -1023.75 5781.31 6.50 ]52.32 213.53 4 1 ]254.32 ]8.69 ]66.06 8747.15 -1154.72 58]3.83 0.00 0.00 347.69 5 11750.20 88.00 160.00 9025.60 -1509.12 5932.62 4.00 -6.47 721.3 3 Q-07B TO . 6 11940.42 90.66 178.84 9027.84 -1695.23 5967.38 0.00 82.13 908.07 7 12076.29 90.66 178.84 9026.26 -]831.07 5970.] 3 0.00 0.00 1036.59 8 12]90.79 90.00 172.00 9025.60 -1945.12 5979.27 6.00 -95.52 ] ]46.85 Q-07B T2 9 12457.27 90.00 156.0] 9025.60 -2200.46 6052.46 6.00 -90.00 14] 1.79 10 12756.67 90.00 156.01 9025.60 -2474.00 6174.19 0.00 0.00 17]0.49 Q-07B T3 REFERENCE INFORMA nON Co-ordil1ate (N/E) Reference: Wen Centre: Q-07, True North Vertical (TVD) Reference: 70.60 70.60 Section (VS) Reference: User Defined (-867.51N,5586.83E) Measured Depth Reference: 70.60 70.60 Calculation Method: Minimum Curvature COMPANY DETAILS BP Amoco Minimum Curvature ISCWSA Trav Cylinder North Elliptical + Casing Ru1es8ased CASING DETAILS Calculation Method: Enor System: Scan Method: Error Surface: Waminj!; Method: FORMATION TOP DETAILS Formation TSag Shub TSAD 1 TZ4B TCGL 1 TZ3 BCGLI TZ2C 25N 2]P PGOC TZ]B MDPath 10888.49 10922.27 11002.50 11203.07 11256.91 11350.22 ] 1519.27 11531.98 11622.86 TVDPath 8400.60 8432.60 8508.60 8698.60 8749.60 8833.60 8954.60 8961.60 900 I. 60 No. I 2 3 4 5 6 7 8 9 Size 7.000 4.500 Name 7' 4 MD 0888.49 2756.66 TVD 8400.60 9025.60 No. 12' All TVD depths are ssTVD plus 70.60'jor RKBE. e '/. ~Ift ,~ ø§'~~ IffP I -I ~ I I ~ I ,¡¡P ,I Il Q-07 (Q-07 6800 I> hT -_..~¡ I'll:. ¡ I ".~" . . _X.'?" ',,0<;'. 117".~=. t~I._:.'¡>~ . 'j":'~; -1-~'. \11>.I:jo..; ! ~-;: I· ",,'. I.',,.·C, .'t· \1!>. 'J" (l)-'-I7.~I·1 (()-Oll! ~ ?r__- -.....-. le\l',! 'f.'I -_~.~'d PII . j ! , ..m.\."'........__ ¡. :-'1::l1)1i! ¡ \' , '!\~ \11). \11>. !C , , ! - I. :¡ \1 ............ ..\ . ~~ ¡.:. ll'··1· 6400 W est( - )/East( +) [400ft/in] II Ii ;'"!.,. \< / \ , -~mT:- I) 1'7 I " " - , 6000 i ~I ',I.); ·,1 '\ .) f ., -.......-.....y--- 5600 -800 5200 1200 600 -2000 -2400 Æ ¢: o o :!. +' ~ ~ t '" COMPANY DETAILS REFERENCE INFORMA nON SURVEY PROGRAM Plan: Q-07B wp04 (Q-07/Plan Q-07B) SP Amoco Co-ordinate (NIB) Referencc: Well Centre: Q-07, True North Depth Fm Depth To Survey/Plan Tool Created By: Ken Allen Date: 7/30/2003 Vertical (TVD) Reference: 70.60 70.60 Calculation Method: Minimum Curvature Section (VS) Reference: User Defined (-867.5 IN,5586.83E) 10300.00 12756.67 Planood: Q-07B wp04 V6 MWD Checked: Date Error System: ISCWSA Measured Depth Reference: 70.60 70.60 Scan Method: Trav L'ylinder North Calculation Method: Minimum Curvature Reviewed: Date Error Surface: Elliptical+Casing Wamin~ Method: Rules Based 7800- FORMATION TOP DETAILS WELL DETAILS N=, +N/-S +EI-W Northing Basting Latitude umgitude Slot No. TVDPath MDPath Formation Q-07 2370.27 1543.44 5965725.00 643940.00 70018'49.748N 148°50'00.248W 07 1 8400.60 10888.49 TSag TARGET DETAILS 2 8432.60 10922.27 Shub 3 8508.60 11002.50 TSAD 1 TZ4B N,~ TVD +N/-S +EI-W Northing Basting Shape 4 8698.60 11203.07 TCGL 1 TZ3 Q-07BTSag 8413.60 -1045.23 5786.64 5964790.97 649745.17 Polygon 5 8749.60 11256.91 BCGL /TZ2C Q-07B T2 9025.60 -1945.12 5979.27 5963895.00 649955.00 Point 6 8833.60 1 I 350.22 25N Q-07BT3 9025.60 -2474.00 6174.19 5963370.00 650160.00 Point Q-07B TO 9025.60 -]509.12 5932.62 5964330.00 649900.00 Point 7 8954.60 11519.27 21P Q-07B Poly2 9030.60 -1868.22 5880.72 5963970.00 649855.00 Polygon 8000 8 8961.60 11531.98 PGOC 9 900 I. 60 I 1622.86 TZIB SECTION DETAILS CASING DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target No. TVD MD Name Size 1 10300.00 41.51 109.60 7886.15 -867.51 5586.83 0.00 0.00 5508.66 2 10320.00 41.78 113.19 7901.09 -872.36 5599.20 12.00 85.00 5521.95 I 8400,60 10888.49 7" 7.000 3 10833.15 18.69 166.06 8348.18 -1023.75 5781.31 6.50 152.32 5747.30 2 9025.60 12756.66 41/2" 4.500 4 11254.32 18.69 166.06 8747.15 -1154.72 5813.83 0.00 0.00 5826.20 5 11750.20 88.00 160.00 9025.60 -1509.12 5932.62 14.00 -6.47 6068.29 Q-07B TO e 6 11940.42 90.66 178.84 9027.84 -1695.23 5967.38 10.00 82.13 6169.78 8200 7 12076.29 90.66 178.84 9026.26 -1831.07 5970.13 0.00 0.00 6222.86 8 12190.79 90.00 172.00 9025.60 -1945.12 5979.27 6.00 -95.52 6273.77 Q-07B T2 9 12457.27 90.00 156.01 9025.60 -2200.46 6052.46 6.00 -90.00 6436.68 10 12756.67 90.00 156.01 9025.60 -2474.00 6174.19 0.00 0.00 6651.41 Q-07B T3 ]" 8400 ¢:: o o S!. ,s '" Ö ~ '€ " > 2 ¡.. 8600 8800 .)1/0';- i" LQ 1A. '\ o 200 All TVD depths are ssTVD plus 70.60'!or RKBE. : ,II.: ) I I.' .:: - :'-. \1 ) ',I .' .:;;~.. 1\ ") 400 I I I I I I I I I I 800 1000 Vertical Section at 159.920 [200ft/in] 600 I I I .I I I ~ I , ~ .. '-, '., , '" , "" ~+ Total Depth: 12756.67' MD, 9025.6' TVD ., , \ " '\)-"-11 wp04 ~~ ,,,' " \. 1.2' I I ' 1800 e e BP KW A Planning Report ----'..--.---.-..-. .. -_·_"-'-~-'ì I i I i I I Date: 7/30/2003 Time: 10:35:17 Co-ordinate(NE) Reference: Well: Q-07, True North Vertical (TVD) Reference: 70.6070.6 Section (VS) Reference: User (-867.51N,5586.83E, 159.92Azi) Survey Calculation Method: Minimum Curvature Db: Oracle BP Amoco PrudhOEd3ay PB Q Þad Q-07 Plan Q-07B . Company: Field: Site: Well: Wellpath: Page: , ------.--.-. Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Alaska, Zone 4 Well Centre bggm2003 Map Zone: Coordinate System: Geomagnetic Model: Site: PB Q Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5963326.07 ft 642441.90 ft Latitude: 70 18 Longitude: 148 50 North Reference: Grid Convergence: 26.438 N 45.275 W True 1.09 deg Well: Q-07 Slot Name: 07 Q-07 Well Position: +N/-S 2370.27 ft Northing: 5965725.00 ft Latitude: 70 18 49.748 N +E/-W 1543.44 ft Easting : 643940.00 ft Longitude: 148 50 0.248 W Position Uncertainty: 0.00 ft Wellpath: Plan Q-07B Q-07 10300.00 ft Mean Sea Level 25.61 deg 80.84 deg Direction deg 159.92 Drilled From: Tie-on Depth: 70.60 ft Above System Datum: Declination: Mag Dip Angle: +E/-W ft 5586.83 Current Datnm: Magnetic Data: Field Strength: Vertical Section: 70.60 5/22/2003 57556 nT Depth From (TVD) ft 33.60 Height +N/-S ft -867.51 Plan: Q-07B wp04 7/28/2003 6 From: Definitive Path Date Composed: Version: Tied-to: Principal: Yes Casing Points ........................-....-..........-........................................---..........-.....---..- :\'lD TVD Diameter Hole Size Name ft ft in in 10888.49 8400.60 7.000 8.500 7" 12756.66 9025.60 4.500 6.125 4 1/2" Formations MD TVD Formations ft ft --...-... --.-...-..... 10888.49 8400.60 TSag 10922.27 8432.60 Shub 11002.50 8508.60 TSAD I TZ4B 11203.07 8698.60 TCGL I TZ3 11256.91 8749.60 BCGL I TZ2C 11350.22 8833.60 25N 11519.27 8954.60 21P 11531.98 8961.60 PGOC 11622.86 9001.60 TZ1B Targets ....--..-----. .--....-..-.-.-. . .--- .........-.-----.-..---...-.-- ....................................- -.....--.-.., Lithology Dip Angle Dip Direction deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 deg ....--.---.--- -- 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ................. ..........-.- -.-.-.......-.-.......- ...............--..--..------..----.-..-.......-..... Map Map <--- Latitude ---> <--- Longitude ---> TVD +N/-S +~/-W Northing Easting Deg Min Sec Deg Min Sec ft ft ft ft ft ...-....-.-.....-..-..-. w___ 8413.60 -1045.23 5786.64 5964790.97 649745.17 70 18 39.446 N 148 47 11.461 W 9025.60 -1945.12 5979.27 5963895.00 649955.00 70 18 30.594 N 148 47 5.863 W 9025.60 -2474.00 6174.19 5963370.00 650160.00 70 18 25.391 N 148 47 0.191 W Name Description Dip. Dir. ---.......-. Q-07B TSag -Circle (Radius: 100) Q-07B T2 Q-07B T3 Company: Field: ; Site: ..'Well: ,..\Vellpath: Targets Name 0-07B TO 0-07B Poly2 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 BP Amoco Prudhoe Bay PB Q Pad 0-07 Plan Q-07B Plan Section Information M) ft 10300.00 10320.00 10833.15 11254.32 11750.20 11940.42 12076.29 12190.79 12457.27 12756.67 Survey :\11) ft 10300.00 10320.00 10350.00 10400.00 10450.00 10500.00 10550.00 10600.00 10650.00 10700.00 10750.00 10800.00 10833.15 10888.49 10900.00 10902.21 10922.27 11000.00 11002.50 11100.00 11200.00 11203.07 11254.32 11256.91 11275.00 11300.00 11325.00 Inel deg 41.51 41.78 18.69 18.69 88.00 90.66 90.66 90.00 90.00 90.00 Inel deg 41.51 41.78 40.06 37.24 34.48 31.80 29.23 26.79 24.52 22.48 20.73 19.35 18.69 18.69 18.69 18.69 18.69 18.69 18.69 18.69 18.69 18.69 18.69 19.05 21.57 25.05 28.54 Description Dip. I>ir. Azim deg 109.60 113.19 166.06 166.06 160.00 178.84 178.84 172.00 156.01 156.01 Azim deg 109.60 113.19 114.60 117.18 120.12 123.49 127.40 131.97 137.36 143.71 151.16 159.76 166.06 166.06 166.06 166.06 166.06 166.06 166.06 166.06 166.06 166.06 166.06 165.93 165.17 164.36 163.73 e --......-.....-..-- TVD ft 9025.60 9030.60 9030.60 9030.60 9030.60 9030.60 9030.60 9030.60 9030.60 TVD ft 7886.15 7901.09 8348.18 8747.15 9025.60 9027.84 9026.26 9025.60 9025.60 9025.60 TVD ft 7886.15 7901.09 7923.76 7962.81 8003.33 8045.20 8088.27 8132.42 8177.50 8223.36 8269.85 8316.83 8348.18 8400.60 8411.50 8413.60 8432.60 8506.23 8508.60 8600.96 8695.69 8698.60 8747.15 8749.60 8766.56 BP KW A Planning Report +N/-S ft -1509.12 -1868.22 -2577.26 -2365.93 -2117.41 -1516.99 -1393.07 -1868.22 -2289.91 +N/-S ft -867.51 -872.36 -1023.75 -1154.72 -1509.12 -1695.23 -1831.07 -1945.12 -2200.46 -2474.00 Sys TVD ft 7815.55 7830.49 7853.16 7892.21 7932.73 7974.60 8017.67 8061.82 8106.90 8152.76 8199.25 8246.23 8277 .58 8330.00 8340.90 8343.00 8362.00 8435.63 8438.00 8530.36 8625.09 8628.00 8676.55 8679.00 8695.96 e ..------.--.-.-".-,. .-........-. .....-.. ..'---' -...- Date: 7/30/2003 ;' Time:¡10:35:17 .'Co-ordinate(NE) Referencè: Wåll:Q-07, True North Vertical (TVD) Reference: 70.60 70.6 . Section (VS) Reference: User (-867.51 N,5586.83E, 159.92Azi) Survey Calculation Method: Minimum Curvature Db: Oracle +E/-W ft 5932.62 5880.72 6082.18 6276.28 6096.00 6082.51 5879.83 5880.72 5702.59 .. _____.......___n_ +E/-W ft 5586.83 5599.20 5781.31 5813.83 5932.62 5967.38 5970.13 5979.27 6052.46 6174.19 ...._-- Map Map :-.lorthing Easting ft· ft 5964330.00 649900.00 5963970.00 649855.00 5963265.00 650070.00 5963480.00 650260.00 5963725.00 650075.00 5964325.00 650050.00 5964445.00 649845.00 5963970.00 649855.00 5963545.00 649685.00 <--- Latitude ---> Deg Min Sec 70 18 34.883 N 701831.352N 70 18 24.377 N 70 18 26.454 N 70 18 28.899 N 70 18 34.804 N 70 18 36.025 N 70 1831.352 N 70 18 27.206 N -~_.~-------- DLS Build Turn deg/100ft deg/100f! deg/100ft .......................................-... MapN' ft 5964964.81 5964960.20 5964952.59 5964939.52 5964926.01 5964912.08 5964897.79 5964883.19 5964868.32 5964853.23 5964837.97 5964822.58 5964812.33 5964795.21 5964791.65 5964790.97 5964784.76 5964760.71 5964759.94 5964729.77 5964698.83 5964697.88 5964682.03 5964681.22 5964675.17 8789.52 8718.92 5964665.68 8811.83 8741.23 5964654.91 n__ .. 0.00 12.00 6.50 0.00 14.00 10.00 0.00 6.00 6.00 0.00 ........ 0.00 1.33 -4.50 0.00 13.98 1.40 0.00 -0.58 0.00 0.00 MapE f! 649542.01 649554.47 649572.58 649600.93 649626.90 649650.40 649671.37 649689.73 649705.42 649718.40 649728.62 649736.05 649739.43 649744.03 649744.99 649745.17 649746.84 649753.30 649753.51 649761.62 649769.93 649770.19 649774.45 649774.67 649776.35 649779.14 649782.44 0.00 17.95 10.30 0.00 -1.22 9.90 0.00 -5.97 -6.00 0.00 VS f! 0.00 8.80 22.44 44.87 66.86 88.34 109.24 129.49 149.03 167.79 185.72 202.75 213.53 231.15 234.82 235.53 241.92 266.68 267.47 298.53 330.39 331.37 347.69 348.52 354.77 364.63 375.86 1'1<'0 deg 0.00 85.00 152.32 0.00 -6.47 82.13 0.00 -95.52 -90.00 0.00 DLS deg/100f! 0.00 12.00 /6.50 6.50 6.50 6.50 6.50 6.50 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 14.00 14.00 Target 0-07B TO Q-07B T2 Q-07B T3 no deg 0.00 85.00 152.32 151.26 149.24 6.50 6.50 6.50 6.50 6.50 146.86 144.03 140.66 136.62 131.77 Page: 2 125.94 119.01 110.93 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 353.53 353.65 <--- Longitude --> Deg Min Sec 148 47 7.213 W 148 47 8.735 W 148 47 2.876 W 148 4657.211 W 148 47 2.462 W 148 47 2.842 W 148 47 8.750 W 148 47 8.735 W 148 47 13.940 W -~~-- Too MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD TSag MWD 0-07B TSag Shub MWD TSAD I TZ4B MWD MWD TCGL I TZ3 MWD BCGL I TZ2C MWD 14.00 354.37 MWD 14.00 355.11 MWD e BP e KW A Planning Report Cornlall~ : BP Amoco Dale: 7/30/2003 Time: 10:35:17 1)1'~C: .1 "il'lIl: Prudhoe Bay Co-ordinatl~(:\ E) I{efl~rencc: Well: Q-07. True North Site: PB Q Pad \'l'rlical (Tn» Ih'fen'lIl:l~: 70.6070.6 Well: Q-07 Sl'l~tioll (\'S) Ih'ferelll'l:: User (-867.51N,5586.83E, 159.92Azi) Wl'lIlnllh: Plan Q-07B SIII"\'e~' C;llclllatioll .\h'lhod: Minimum Curvature )h: Oracle SlIrvey , 1\1D IlIeI Azim TVD Sys TVD MapN MapE VS DLS TFO Too L_!t___._ deg deg ft ft ft ft ft deg/100ft deg' ._w...·w..·_ .....-.....-.... ... ......-...-.---.--...-- 11350.00 32.03 163.24 8833.41 8762.81 5964642.90 649786.26 388.45 14.00 355.67 MWD 11350.22 32.03 163.24 8833.60 8763.00 5964642.79 649786.30 388.56 0.00 0.00 25N 11375.00 35.52 162.83 8854.19 8783.59 5964629.69 649790.57 402.32 14.12 356.10 MWD 11400.00 39.02 162.48 8874.08 8803.48 5964615.33 649795.36 417 .44 14.00 356.44 MWD 11425.00 42.51 162.19 8893.01 8822.41 5964599.88 649800.61 433.75 14.00 356.71 MWD 11450.00 46.01 161.93 8910.92 8840.32 5964583.39 649806.31 451.18 14.00 356.94 MWD 11475.00 49.50 161.69 8927.72 8857.12 5964565.93 649812.42 469.68 14.00 357.12 MWD 11500.00 53.00 161.49 8943.37 8872.77 5964547.56 649818.93 489.16 14.00 357.28 MWD 11519.27 55.69 161.34 8954.60 8884.00 5964532.81 649824.20 504.81 14.00 357.41 21P 11525.00 56.50 161.30 8957.79 8887.19 5964528.34 649825.81 509.57 14.00 357.50 MWD 11531.98 57.47 161.25 8961.60 8891.00 5964522.83 649827.80 515.42 14.00 357.52 PGOC 11550.00 59.99 161.12 8970.95 8900.35 5964508.36 649833.04 530.82 14.00 357.55 MWD 11575.00 63.49 160.96 8982.79 8912.19 5964487.68 649840.59 552.83 14.00 357.61 MWD 11600.00 66.99 160.81 8993.25 8922.65 5964466.38 649848.44 575.52 14.00 357.69 MWD 11622.86 70.18 160.67 9001.60 8931.00 5964446.43 649855.84 596.80 14.00 357.75 TZ1B 11625.00 70.48 160.66 9002.32 8931.72 5964444.54 649856.54 598.81 14.00 357.80 MWD 11650.00 73.98 160.52 9009.95 8939.35 5964422.25 649864.88 622.62 14.00 357.81 MWD 11675.00 77 .48 160.39 9016.11 8945.51 5964399.58 649873.42 646.84 14.00 357.85 MWD 11700.00 80.98 160.26 9020.78 8950.18 5964376.62 649882.13 671.40 14.00 357.88 MWD 11725.00 84.47 160.13 9023.95 8953.35 5964353.46 649890.98 696.19 14.00 357.91 MWD 11750.20 88.00 160.00 9025.60 8955.00 5964330.00 649900.00 721.33 14.00 357.92 Q-07B TO 11800.00 88.69 164.93 9027.04 8956.44 5964282.85 649915.90 771.05 10.00 82.13 MWD 11850.00 89.39 169.89 9027.88 8957.28 5964234.29 649927.72 820.60 10.00 81.99 MWD 11900.00 90.09 174.84 9028.11 8957.51 5964184.89 649935.32 869.41 10.00 81.91 MWD 11940.42 90.66 178.84 9027.84 8957.24 5964144.60 649938.32 908.07 10.00 81.89 MWD 12000.00 90.66 178.84 9027.15 8956.55 5964085.07 649940.67 964.42 0.00 0.00 MWD 12076.29 90.66 178.84 9026.26 8955.66 5964008.85 649943.68 1036.59 0.00 0.00 MWD 12100.00 90.53 177.42 9026.02 8955.42 5963985.18 649944.91 1059.11 6.00 264.48 MWD 12150.00 90.24 174.44 9025.68 8955.08 5963935.39 649949.41 1107.16 6.00 264.47 MWD 12190.79 90.00 172.00 9025.60 8955.00 5963895.00 649955.00 1146.85 6.00 264.45 Q-07B T2 12200.00 90.00 171.45 9025.60 8955.00 5963885.91 649956.50 1155.87 6.00 270.00 MWD 12250.00 90.00 168.45 9025.60 8955.00 5963836.86 649966.17 1205.10 6.00 270.00 MWD 12300.00 90.00 165.45 9025.60 8955.00 5963788.39 649978.39 1254.72 6.00 270.00 MWD 12350.00 90.00 162.45 9025.60 8955.00 5963740.62 649993.14 1304.59 6.00 270.00 MWD 12400.00 90.00 159.45 9025.60 8955.00 5963693.69 650010.36 1354.57 6.00 270.00 MWD 12450.00 90.00 156.45 9025.60 8955.00 5963647.72 650030.01 1404.54 6.00 270.00 MWD 12457.27 90.00 156.01 9025.60 8955.00 5963641.13 650033.07 1411.79 6.00 270.00 MWD 12500.00 90.00 156.01 9025.60 8955.00 5963602.43 650051.19 1454.42 0.00 0.00 MWD 12600.00 90.00 156.01 9025.60 8955.00 5963511.87 650093.58 1554.19 0.00 0.00 MWD 12700.00 90.00 156.01 9025.60 8955.00 5963421.31 650135.98 1653.96 0.00 0.00 MWD 12756.67 90.00 156.01 9025.60 8955.00 5963370.00 650160.00 1710.49 0.00 0.00 Q-07B T3 WELL DETAILS ANTI-COLLISION SETTINGS COMPANY DETAILS SURVEY PROGRAM Name +Ni-S +E/-W Northing Easting Latitude Longitude Slot Interpolation MethodMD Interval: 25.00 Depth Range From: 10300.00 To: 12756.67 Maximum Range: 1472.31 Reference: Plan: Q·078 wp04 BP Amoco Depth Fm Depth To Survey/Plan 10300.00 12156.61 Planned: Q"{}1B wp04 V6 Tool Q..{}1 231017 1543.44 5965125.00 643940.00 10"18'49.748N 148"50'û0148W 01 Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav Cylinder North Error Surface: Elliptical + Casing Warning Method: Rules Based MWO -128 -120 o WELLPATH DETAILS From Colour ToMD PlanQ-01B 0 300 PanmtWcllpatll: Q-01 300 600 TieonMD: 10300.00 600 900 Rig: Ref. Datum: 70.60 70.6Oft 900 1200 V.scction Origin Origin Starting 1200 1500 AnoJ' +N/-S +E/-W From TVD 1500 2000 111.84" 0.00 0.00 33.60 2000 2500 2500 3000 3000 3500 3500 4000 LEGEND 4000 4500 H-28 (H-28), Minor 1/200 H-36 (H-36), Major Risk 4500 5000 .20(J-20),MajorRisk 5000 6000 -20(-20A),MajorRisk """""" -20 (1-20B), Major Risk 6000 8000 - Q..Q5A (Q-05A), Major Risk - Q-01APBI (Q-07APB1), NOERRORS 8000 9000 - Q-07APB2 (Q-01APB2), NOERRORS 9000 10000 - Q-01A(Q-07A),NOERRORS - - Q-07 (Q-01), NOERRORS 10000 12000 - PlanQ"{}7B === Q"{}1B wp04 2000 15000 -100 " -80 --60 -40 -20 -0 -20 -40 --60 e -80 -100 SECTION DETAILS S~ MO Inc Azi lVO +N/-S +E/-W Ole, TFace VS~ Target I 10300.00 41.51 109.60 1886.15 -867.51 5586.83 0.00 0.00 5508.66 2 10320.00 41.18 113.]9 7901.09 -872.36 5599.20 12.00 85.00 5521.95 3 10833.15 18.69 166.06 8348.18 -\023,75 5181.31 6.50 ]52.32 5741.30 4 11254.32 18.69 166.06 8147.15 -1l54.72 5813.83 0.00 0.00 582610 5 1175010 88.00 160.00 9025.60 -1509.12 5932.62 ]4.00 -6.41 6068.29 Q-01B TO 6 11940.42 90.66 118.84 9027.84 -1695.23 5967.38 10.00 82.13 6169.78 1 ]2076.29 90.66 118.84 9026.26 -1831.07 5970.13 0.00 0.00 6222.86 8 12190.79 90.00 172.00 9025.60 -1945.12 5979.27 6.00 -95.52 6273.77 Q-07BT2 9 12457.27 90.00 156.Q1 9025.60 -2200.46 6052.46 6.00 -90.00 6436.68 10 12156.67 90.00 156.Q1 9025.60 -2474.00 6114.19 0.00 0.00 6651.41 Q-07BT3 -120 -128 e BP Anticollision Report e Company: Field: Reference Site: Referenëc Well: Referenee Wellpath: BP Amoco Prudhoe Bay PB 0 Pad Q-07 Plan 0-07B Date: 7/30/2003 Time: 09.:00:17 Pa¡:e: 1 Co-ordinate(I'Œ) Referenee: Well: Q-07, True North Vertical (TVD) Reference: 70.6070.6 .. Db: Oracle . . - GLOBAL SCAN APPLIED: All wellPatbs within 200'+ 100/1000 of reference - There ar~8fells in thlS'~al Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 10300.00 to 12756.67 ft Scan Method: Trav Cylinder North Maximum Radius: 1472.31 ft Error Surfaee: Ellipse + Casing Survey Program for Definitive Wellpath Date: 5/22/2003 Validated: No Planned From To Survey ft ft 101.10 10300.00 10300.00 12756.67 Version: Tooleode 4 Tool Name 1: Sperry-Sun BOSS gyro multi (1 01.1 0-12£mS$)qYRO Planned: Q-07B wp04 V6 MWD Sperry-Sun BOSS gyro multishot MWD - Standard Casing Points -.----".... MD TVD l>iameter Hole Size Name ft ft in in _u ..--.-.--..-- 10888.49 8400.60 7.000 8.500 7" 12756.66 9025.60 4.500 6.125 41/2" Summary "A_·__n_ -..... <-------------------- Off.~et Wellpath > Referenee Offset Ctr-Ctr No-Go Allowable Site Well Well path \11) MD Distance Area Deviation Warning ft ft ft ft ft __._____n ..------- ......-.---..-------.. PB H Pad H-28 H-28 V1 11700.00 12327.22 668.11 0.00 668.11 Pass: Minor 1/200 PB H Pad H-36 H-36 V1 Out of range PB J Pad J-20 J-20 V1 11275.00 12334.22 1119.24 364.55 754.69 Pass: Major Risk PB J Pad J-20 J-20A V2 11142.84 12375.00 1272.89 372.43 900.46 Pass: Major Risk PB J Pad J-20 J-20B V2 10817.54 11700.00 1356.32 332.06 1024.25 Pass: Major Risk PB Q Pad Q-05A 0-05A V1 11170.22 11400.00 1433.14 275.23 1157.91 Pass: Major Risk PB 0 Pad Q-07APB1 Q-07APB1 V1 10301.10 10300.00 0.00 No Reference Casings PB Q Pad Q-07 APB2 Q-07 APB2 V1 10301.10 10300.00 0.00 0.00 0.00 Pass: NOERRORS PB Q Pad Q-07A Q-07A V4 10301.10 10300.00 0.00 0.00 0.00 Pass: NOERRORS PB Q Pad Q-07 Q-07 V4 10301.10 10300.00 0.00 No Reference Casings Site: PB H Pad Well: H-28 Rule Assigned: Minor 1/200 Wellpath: H-28 V1 Inter-Site Error: 0.00 ft "' .. .............................-..- .................-...-....-.-...-- Reference Offset Semi-Major Axis Ctr-Ctr :'Iio-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HS>istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 12190.79 9025.60 11325.00 8531.28 32.84 184.44 242.03 70.03 7.000 1462.03 0.00 1462.03 Pass 12176.22 9025.61 11350.00 8547.29 32.41 190.12 243.26 70.39 7.000 1440.19 0.00 1440.19 Pass 12172.82 9025.62 11375.00 8563.28 32.31 191.96 243.84 70.76 7.000 1418.53 0.00 1418.53 Pass 12169.37 9025.62 11400.00 8579.24 32.21 193.83 244.43 71.15 7.000 1396.95 0.00 1396.95 Pass 12165.85 9025.63 11425.00 8595.14 32.11 195.74 245.03 71.54 7.000 1375.44 0.00 1375.44 Pass 12162.27 9025.64 11450.00 8610.97 32.00 197.69 245.65 71.94 7.000 1353.99 0.00 1353.99 Pass 12150.00 9025.68 11475.00 8626.70 31.64 202.66 246.79 72.36 7.000 1332.67 0.00 1332.67 Pass 12150.00 9025.68 11500.00 8642.36 31.64 203.38 247.21 72.78 7.000 1311.31 0.00 1311.31 Pass 12150.00 9025.68 11525.00 8657.93 31.64 204.14 247.64 73.21 7.000 1290.05 0.00 1290.05 Pass 12150.00 9025.68 11550.00 8673.40 31.64 204.90 248.08 73.64 7.000 1268.90 0.00 1268.90 Pass 12150.00 9025.68 11575.00 8688.78 31.64 205.66 248.53 74.09 7.000 1247.86 0.00 1247.86 Pass 12150.00 9025.68 11600.00 8704.07 31.64 206.42 248.99 74.55 7.000 1226.95 0.00 1226.95 Pass 12134.97 9025.76 11625.00 8719.27 31.27 212.52 250.36 75.03 7.000 1205.96 0.00 1205.96 Pass 12130.71 9025.78 11650.00 8734.42 31.16 214.84 251.11 75.52 7.000 1185.20 0.00 1185.19 Pass 12126.36 9025.81 11675.00 8749.50 31.05 217.20 251.87 76.02 7.000 1164.54 0.00 1164.54 Pass 12121.91 9025.84 11700.00 8764.52 30.94 219.61 252.65 76.54 7.000 1144.00 0.00 1144.00 Pass 12117.36 9025.87 11725.00 8779.50 30.83 222.07 253.46 77.07 7.000 1123.60 0.00 1123.60 Pass 12100.00 9026.02 11750.00 8794.47 30.40 229.08 255.05 77.63 7.000 1103.50 0.00 1103.50 Pass 12100.00 9026.02 11775.00 8809.43 30.40 229.97 255.63 78.20 7.000 1083.30 0.00 1083.30 Pass 12100.00 9026.02 11800.00 8824.38 30.40 230.86 256.22 78.80 7.000 1063.31 0.00 1063.31 Pass 12100.00 9026.02 11825.00 8839.32 30.40 231.76 256.83 79.41 7.000 1043.54 0.00 1043.54 Pass P055123 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS 7/14/2003 INV# PR071003M PERMIT TO DRILL FEE e Qû1Q; THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHOIìAGi:, AK9951ß-6612 PAY: e TO THE ORDER OF: NATIONAL CITY BANK Ashland, Ohio 1110 5 5 ~ 2 j liD I: 0... ~ 2 0 ~ a ~ 5 I: o. 2 7 a ~ b III DATE I I 7/14/2003 CHECK NO. 055123 VENDOR DISCOUNT NET H 56-389 412 No. P 05512~ CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT *******$100 .0_~*~*:~J NOTVALlD AFTF,R 1::>0 nAYS ~~':';'::i ~: ~>:.::: ;:.::::: :~S::::::~:::· ;::..~ j}:~.:~:).~~:; ~~:;:/::·~:i;··~:· ~ . .. ~;~ .." ......,..-'...... ...... I ~' 1'\,(~rt{J¡:.;~~i;¡;~;i~/è'j e e TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (H API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing weD ~ Permit No, API No. Production sbould continue to be reported as a function· of tbe original API number. stated above. HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot bole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). paOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/1 0/02 C\jody\templates Tbe permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to tbe spacing . exception tbat may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals tbrough target zones. WELL PERMIT CHECKLIST Company BP EXE'LORATION (ALASKA) INC Well Name: PRUDHOE BAY UNIT Q-07B Program DEV Well bore seg D PTD#: 2031570 Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Initial ClasslType DEV I 1-01L GeoArea 890 Unit 11650 On/Off Shore ~ Annular Disposal D Administration 1 P~rmitfee attached_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 leas~_number _appropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _U.nique weltn_a[11~_aod ollmb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ 4 WeHJQcat~d in_a_d_efjnedpool_ _ _ _ _ _ _ _ _ _ .. _ _ y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 5 WellJQcat~d properdistaoce_ from driJling unit boundary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 WellJQcat~d proper _distance_ from other weHs_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7 _S_ufficientacrea9.e_ayailable indrillio9. unjt _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 8 Jf.d~viated, js weJlbQre platiocJuded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ 9 _Operator onlY' affected party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 10 _Oper_ator bas_appropriate_ Qond inJorce _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ y~s _ _ . . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ 11 P~rmit cao be isslled wjthQut conservation order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 12 P~rmitcall be iSSlled WmJQut administrative_approvaJ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ RPC 9/10/2003 13 Can permit be approved before 15-day wait Yes 14 WellJQcat~d within area and_strata authorized by.llljectioo Ord~r # (puIlOD in_cO(Tl[11ellts) (For_ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 .AJI w~l)s_within JI4_rTJite_area_of reyi~w jd~olified (For servjc_e .w.ell Qnly). _ _ . . . . _ _ _ _ _ _ _ . .NA _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ . 16 Pre-produçecl injector; duratiQn_of pre-production I~ss_ than 3 months_ (For service well onJy) _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 17 .AÇMP_FïodingofCon_si~teoçyh_as bee_nJssued_forthis project _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Engineering Appr Date WGA 9/10/2003 Geology Appr RPC Date 9/10/2003 Geologic Commissioner: e 18 _C.olldu_ctor stringprQvided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 19 _S_urface_casing_protec.ts all_known USDWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 20 _CMTv_oladeQlIateto circ_utate_o_ncond_uctor& su_rf_csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 21 _CMTv_otadeQuatetotie-inJQng_stringtosurf~g_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 22 _CMTwill coyera!lkoo.w.nWo_ductiye bQrilon_s_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 23 _C_asillg desiglls actequa_te for C,T, B_&_perrTJafrost _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 24 Mequate.tan_kageor reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ y~s _ _ _ _ _ _ _ ~ab.ors_2_ES, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 25 Jf.a.re-drill~ has_a_ t0403 for abandonme.nt be~1l approved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 26 _Mequatewe!lbore separatJo_n_proposed _ _ _ _ _ _ . . _ _ _ _ _ _ _ . . . _ _ _ _ _ _ _ . . _ _ _ _ _ _ y~s . _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ . . _ . _ _ _ _ _ _ . . _ _ _ _ _ _ . _ . . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ 27 JfdJv~rter required, does jt me~t reguJatioos_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ Sidetrack. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 28 DriUiog fluid_program sGhemalic&equipJistadequat~_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ y~s _ _ _ _ _ _ _ Max MW_tO]_ppg._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 29 _BPPEs,_do_they meetreguJation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 30 BPPEpressra.!illg appropriate; _testto(pu_t psig in_comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ y~s _ _ Test to 3500_ psLMSF' 26_00 psi._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 31Choke_rTJanifold cQmpJies w/API RF'-53 (May 64) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 32 Work wi]1 occ_ur withoutoperatjon _shlltdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 33 Js presence_ of H2S gas_ prOQable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 34 Mecba_nicalcondJlion of wells within ,t\OR yerifiect (for_s_erviœ w~H onJy) _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ e - - - - -- - - - - - - - - - - ~ 35 P~(Il]it Gall be isslled wlo_ hydrogen_ s_ulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 36 _D_ata_preseotect on_ pote_ntial oveJpressurezone$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 37 _S~i~(Tlic_analysjs_ Qf $baJlow gas_zolles_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 38 _S~abedcondjtioo survey (if off-shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 39 _ Conta_ct oam_elphoneJor_weelsly progresueports [exploratoryonlYl _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Date: Engineering Commissioner: Public ~ Commissioner ~7~ Date ~ ¥'ijb3 e e 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 infonnation, 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. Sperry-Sun Dr"'ng Services LIS sca~ility . &03 ~- 15 7- $Revision: 3 $ LisLib $Revision: 4 $ Wed Mar 10 14:39:45 2004 I ~ 'í~) Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/03/10 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.................... .04/03/10 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA Q-07B 500292035202 BP Exploration (Alaska) I Inc. Sperry-Sun Drilling Services 10-MAR-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 MW0002678820 T. GALVIN R. BORDES / MWD RUN 4 MW0002678820 T. GALVIN R. BORDES / MWD RUN 5 MW0002678820 T. GALVIN R. BORDES / # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 16 11N BE 355 516 MSL 0) .00 68.56 42.10 RECEIVED # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.500 6.125 CASING SIZE (IN) 9.625 7.000 DRILLERS DEPTH (FT) 10138.0 10900.0 ~.., lì 1 0 r.nu!l~ r"J.!·,· I) /' 11'1 + (: H \ -- I,..,.V 'T ß'Ja\lSk~ Oil & Gas Cons. Commission Þ.ndwrage # RODMS RD MAR :-1 () ïpm. REMARKS: 1. ALL DEPTH~E BIT DEPTHS UNLESS OTHERWISE~ED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 2 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK, THE TOP OF WHICH WAS AT 10286'MD/7875'TVD AND THE BOTTOM WAS AT 10302'MD/7887'TVD. NO PROGRESS WAS MADE ON MWD RUN 1. 4. MWD RUNS 3 - 5 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUNS 4 & 5 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN) STABILIZED LITHO-DENSITY (SLD); AND AT-BIT INCLINATION (ABI). 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE BLOCK-SHIFTED l' DOWNHOLE, PER E-MAIL FROM K. COONEY (SIS/BP) DATED 2 MARCH 2004. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 6. MWD RUNS 3 - 5 REPRESENT WELL Q-07B WITH API#: 50-029-20352-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12764'MD/9023'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.4 - 8.5 PPG MUD SALINITY: 3300 - 3600 PPM CHLORIDES FORMATION WATER SALINITY: 10994 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ . . File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/10 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE RPX RPS RPM RPD FET GR ROP NPHI FCNT NCNT DRHO RHOB PEF $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 10271.5 10271. 5 10271.5 10271. 5 10273.0 10279.0 10316.5 10871.0 10871.0 10871.0 10901.0 10901.0 10901.5 STOP DEPTH 12721.0 12721.0 12721.0 12721.0 12721.0 12713.5 12765.0 12677.0 12677.0 12677.0 12692.0 12692.0 12692.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------- BASELINE DEPTH 10279.0 12765.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: GR 10278.0 12764.0 BIT RUN NO 3 4 5 MERGED MAIN PASS. $ MERGE TOP 10270.5 10900.0 11557.5 MERGE BASE 10900.0 11557.5 12764.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 GR MWD API tp 1 68 8 3 . RPX MWD OHMM 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10271.5 12765 11518.3 4988 10271.5 12765 ROP MWD FT/H 0 364.88 72.7948 4898 10316.5 12765 GR MWD API 13.59 544.58 62.1347 4870 10279 12713 .5 RPX MWD OHMM 0.4 1869.07 15.1294 4900 10271.5 12721 RPS MWD OHMM 0.53 1793.12 16.729 4900 10271.5 12721 RPM MWD OHMM 0.39 1975.79 22.2574 4900 10271.5 12721 RPD MWD OHMM 0.23 2000 53.0844 4900 10271.5 12721 FET MWD HOUR 0.34 71. 58 3.20256 4897 10273 12721 NPHI MWD PU-S 4.8 56.91 21.3168 3613 10871 12677 FCNT MWD CNTS 115 3652.6 735.87 3613 10871 12677 NCNT MWD CNTS 14475.1 51861.9 29305.8 3613 10871 12677 RHOB MWD G/CM 2.03 2.995 2.35524 3583 10901 12692 DRHO MWD G/CM -0.162 0.639 0.0647541 3583 10901 12692 PEF MWD BARN 0.91 9.84 2.31859 3582 10901.5 12692 First Reading For Entire File......... .10271.5 Last Reading For Entire File....... ... .12765 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/10 Maximum Physical Record. .65535 File Type.............. ..LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/10 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY 2 header data for each bit run in separate files. 3 .5000 VENDOR TOOL CODE RPX RPS RPM RPD FET GR ROP $ START .H 10270.5 10270.5 10270.5 10270.5 10272.0 10278.0 10315.5 STOP DEPTH 10855.5 10855.5 10855.5 10855.5 10855.5 10862.5 10900.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . . 02-0CT-03 Insite 66.37 Memory 10900.0 10315.0 10900.0 18.4 41.4 TOOL NUMBER 124724 127479 8.500 10138.0 LSND 11.30 53.0 9.1 2600 3.8 .950 .450 .900 1.100 68.0 151.0 68.0 68.0 Datum Specification Bloc4llLb-type...0 . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 Rap MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10270.5 10900 10585.3 1260 10270.5 10900 Rap MWD030 FT/H 0 192.88 53.9988 1170 10315.5 10900 GR MWD030 API 58.38 147.95 1l0.488 1170 10278 10862.5 RPX MWD030 OHMM 0.4 1869.07 5.53936 1171 10270.5 10855.5 RPS MWD030 OHMM 0.53 1793.12 7.41114 1171 10270.5 10855.5 RPM MWD030 OHMM 0.39 1608.98 6.14773 1171 10270.5 10855.5 RPD MWD030 OHMM 0.23 2000 32.159 117l 10270.5 10855.5 FET MWD030 HOUR 0.75 22.44 3.08459 1168 10272 10855.5 First Reading For Entire File......... .10270.5 Last Reading For Entire File.......... .10900 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/10 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name........... ..STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/10 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM RPD FET RPS RPX GR 3 header data for each bit run in separate files. 4 .5000 START DEPTH 10856.0 10856.0 10856.0 10856.0 10856.0 10863.0 STOP DEPTH 11513.0 11513.0 11513.0 11513.0 11513.0 11506.5 NPHI FCNT NCNT RHOB DRHO PEF ROP $ 10870.. 10870.0 10870.0 10900.0 10900.0 10900.5 10900.5 11471.0 11471.0 11471. 0 11485.0 11485.0 11485.0 11557.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.......... .......... .60 .1IN Max frames per record.... ........ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 . 05-0CT-03 Insite 66.37 Memory 11558.0 10900.0 11558.0 17.4 51.4 TOOL NUMBER 160796 115170 100983 148574 6.125 10900.0 FLO-PRO 8.50 46.0 9.5 3100 6.8 1.910 .910 1. 900 2.100 70.0 155.1 70.0 70.0 Depth Units. . . . . . . . . . . . . e· . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 DRHO MWD040 G/CM 4 1 68 44 12 RHOB MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10856 11557.5 11206.8 1404 10856 11557.5 ROP MWD040 FT/H 0 364.88 64.8576 1315 10900.5 11557.5 GR MWD040 API 13.59 544.58 54.0607 1288 10863 11506.5 RPX MWD040 OHMM 0.7 261.37 31.7169 1315 10856 11513 RPS MWD040 OHMM 0.79 294.27 35.2689 1315 10856 11513 RPM MWD040 OHMM 0.84 1975.79 55.9668 1315 10856 11513 RPD MWD040 OHMM 0.82 2000 145.709 1315 10856 11513 FET MWD040 HOUR 0.37 71. 58 6.00944 1315 10856 11513 NPHI MWD040 PU-S 4.8 56.91 18.654 1203 10870 11471 FCNT MWD040 CNTS 115 3652.6 979.138 1203 10870 11471 NCNT MWD040 CNTS 14475.1 51861.9 30750.6 1203 10870 11471 DRHO MWD040 G/CM -0.162 0.418 0.0538787 1171 10900 11485 RHOB MWD040 G/CM 2.03 2.995 2.30865 1171 10900 11485 PEF MWD040 BARN 0.91 9.84 2.24866 1170 10900.5 11485 First Reading For Entire File....... ...10856 Last Reading For Entire File.......... .11557.5 File Trailer Service name............ .STSLIB.003 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation... ... .04/03/10 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/03/10 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 · header data for 5 .5000 each bit run in separate ftltS. RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI PEF RHOB DRHO GR RPX RPS RPM RPD FET Rap $ START DEPTH 11471.5 11471.5 11471.5 11485.5 11485.5 11485.5 11507.0 11513.5 11513.5 11513.5 11513.5 11513.5 11558.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ STOP DEPTH 12676.0 12676.0 12676.0 12691.0 12691.0 12691.0 12712.5 12720.0 12720.0 12720.0 12720.0 12720.0 12764.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 07-0CT-03 Insite 66.37 Memory 12764.0 11558.0 12764.0 55.6 94.8 TOOL NUMBER 160796 115170 100983 148574 6.125 10900.0 FLO-PRO 8.50 45.0 9.9 3150 6.8 1.910 .900 1.900 2.100 70.0 156.6 70.0 70.0 REMARKS: . . # $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing................... ..60 .1IN Max frames per record............ . Undefined Absent value.................... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 NPHI MWD050 PU-S 4 1 68 32 9 FCNT MWD050 CNTS 4 1 68 36 10 NCNT MWD050 CNTS 4 1 68 40 11 RHOB MWD050 G/CM 4 1 68 44 12 DRHO MWD050 G/CM 4 1 68 48 13 PEF MWD050 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11471.5 12764 12117.8 2586 11471.5 12764 Rap MWD050 FT/H 0.23 286.63 86.2341 2413 11558 12764 GR MWD050 API 15.29 152.89 42.991 2412 11507 12712.5 RPX MWD050 OHMM 3.97 19.66 10.7455 2414 11513.5 12720 RPS MWD050 OHMM 4.14 19.74 11.1495 2414 11513.5 12720 RPM MWD050 OHMM 4.47 21.17 11.7093 2414 11513.5 12720 RPD MWD050 OHMM 5.15 22.46 12.779 2414 11513.5 12720 FET MWD050 HOUR 0.34 17.41 1.73062 2414 11513.5 12720 NPHI MWD050 PU-S 15.79 29.42 22.646 2410 11471.5 12676 FCNT MWD050 CNTS 373.1 1049.6 614.437 2410 11471.5 12676 NCNT MWD050 CNTS 22257.4 36510.8 28584.5 2410 11471.5 12676 RHOB MWD050 G/CM 2.132 2.955 2.37786 2412 11485.5 12691 DRHO MWD050 G/CM -0.075 0.639 0.070034 2412 11485.5 12691 PEF MWD050 BARN 1. 28 5.05 2.35251 2412 11485.5 12691 First Reading For Entire File......... .11471.5 Last Reading For Entire File.......... .12764 File Trailer Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/03/10 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF . Tape Trailer Service name............ .LISTPE Date.................... .04/03/10 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/03/10 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. Writing Library. . Scientific Technical Services Scientific Technical Services