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205-019
7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 02-26C Mill CIBP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-019 50-029-20774-03-00 13006 Conductor Surface Intermediate Liner Liner 9023 80 2627 9241 7360 2903 12493 20" 13-3/8" 9-5/8" 7" 4-1/2" x 3-3/16" 9020 29 - 109 28 - 2655 27 - 9268 3051 - 10411 10103 - 10657 29 - 109 28 - 2655 27 - 7455 3049 - 8416 8149 - 8623 12970 (2) 470 2670 4760 5410 13890 12493 1490 5380 6870 7240 13450 11400 - 12950 4-1/2" 12.6# L-80 9895 - 10229 9003 - 9016 Structural 4-1/2" HES TNT, 9790, 7879 9790 7879 Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (907) 564-4672 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 0028309 , 0028308 7970 - 8257 365 466 38786 35534 28 81 0 0 878 911 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Anne Prysunka at 11:36 am, Dec 06, 2022 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2022.12.05 15:37:48 -09'00' RBDMS JSB 120822 DSR-12/6/22WCB 11-26-2024 ACTIVITYDATE SUMMARY 11/26/2022 CTU#9 1.75" Coil 0.145 Wall Job Scope: Mill 2-7/8" CIBP / Push to PBTD Road CTU 9. MIRU, M/U baker milling BHA w/2.35 3 blade junk mill. Load well with 95bbls KCL w/safelube and cap with 20bbls 60/40. RIH and dry tag at 12,064. Pick up and reconfirm tag. Perform fluff and stuff above top perf then RBIH to 12,300 and chase above top perf with multiple small overpulls. Work pipe up and down gaining depth up hole each time. Get above top perf and pulling clean. RBIH and set down with increase in motor work. Pull up into vertical section at 10,900 then RBIH and dry drift down. Tag multiple spots, work thru. Dry tag CIBP @ 12,461' CTM 12,500' Mech. Mill thru CIBP and push down to PBTD @ 12,934' CTM 12,973' Mech. FP CT & POOH. ***Continue on WSR 11/27/22*** 11/27/2022 ***Continue from WSR 11/26/22*** CTU#9 1.75" Coil 0.145 Wall Job Scope: Mill 2-7/8" CIBP @ 12,493'/ Push to PBTD 12,970' POOH. BD BOT milling BHA. RDMO CTU 9 ***Job Complete*** Daily Report of Well Operations PBU 02-26C g yg @ Mill thru CIBP and push down to PBTD @ 12,934' CTM 12,973' Mech CIBP fish is correctly shown on the WBS below. -WCB 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 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 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 02-26C Extended Perforating Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-019 50-029-20774-03-00 13006 Conductor Surface Intermediate Liner Liner 9023 80 2627 9241 7360 2903 12493 20" 13-3/8" 9-5/8" 7" 4-1/2" x 3-3/16" x 2-7/8" 9020 29 - 109 28 - 2655 27 - 9268 3051 - 10411 10103 - 13006 29 - 109 28 - 2655 27 - 7455 3049 - 8416 8149 - 9023 12970 470 2670 4760 5410 13890 12493 1490 5380 6870 7240 13450 11400 - 12950 4-1/2" 12.6# L-80 9895 - 10231 9003 - 9016 Structural 4-1/2" HES TNT, 4-1/2" Baker S-3 9786 , 10177 9786 , 10177 7876 , 8213 Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com (907) 564-4672 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 13.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 0028309 , 0028308 No SSSV 7970 - 8260 7876 , 8213 212 536 13991 34684 36 101 0 0 832 897 321-287 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: By Samantha Carlisle at 10:15 am, Nov 22, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.11.22 07:43:57 -09'00' Bo York DSR-11/22/21 9041 SFD 11/29/2021 SFD 11/29/2021 MGR29DEC2021 RBDMS HEW 11/24/2021 ACTIVITYDATE SUMMARY 11/4/2021 CTU#9 1.75" CT .145 WT Job Objective; Log/ Extended Addperf Continue RIH w/ Logging Tools. Tag high at 12065' down / 12054' up (12,083' corrected). Log from compression at 50 FPM from 12065' - 10400'. Flag pipe at 11420' and continue POOH. Bullhead 200 BBL's of 1% KCL down the backside. Pump pipe displacement while pooh. Recieve good data (+16' Correction). Log correlated to PDS Memory Coil Flag dated 08-MAR-2015. Pumped 1% KCL across the top taking ~ 0.6 bpm losses. Deploy 420' of 2" guns (255' loaded with Maxforce, 6 SPF, 60 degree phase charges). Perforate 11,400' - 11,525', 11,580' - 11,620', and 11,720' - 11,810'. POOH and lay down 420' of HES MaxForce guns. Bullhead 100 bbls diesel (5700 TVD). Notify Pad Op of well status. Start Rigging down. ***Continued on 11/05/21*** 11/5/2021 CTU#9 1.75" CT .145 WT Job Objective; Log/ Extended Addperf Rig down CTU. ***Job Complete. Daily Report of Well Operations PBU 02-26C yg( . Perforate 11,400' - 11,525', 11,580' - 11,620', andg 11,720' - 11,810'. Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:205-019 6.API Number:50-029-20774-03-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028309 Property Designation (Lease Number):10. 341H 8. PBU 02-26C 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 Operations shutdown Op Shutdown GAS GSTOR WAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5Stratigraphic Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 13006 Effective Depth MD: L-80 11. 6/18/2021 Commission Representative: 15. Suspended Contact Name: David Bjork Contact Email: David.Bjork@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 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 55Perforate Perforate New Pool 9786 , 10177 / 7876 , 8213 No SSSV Installed Date: Liner 2903 4-1/2" x 3-3/16" x 2-7/8" 10103 - 13006 8149 - 9023 13450 13890 Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 28 - 2655 28 - 2655 14. Estimated Date for Commencing Operations: BOP Sketch 29 - 109 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" HES TNT , 4-1/2" Baker S-3 11870 - 12950 9002 - 9016 4-1/2" 12.6# L-80 9895 - 10231 Liner 12493 9020 12493 129770 29 - 109 470 13-3/8" 9-5/8" Contact Phone:(907) 564-672 Date: 6-10-2021 4760 80 149020"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2627 5380 Intermediate 9241 27 - 9268 27 - 7455 7360 7" 3051 - 10411 3049 - 8416 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 2405 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. CTU Extended Perforations By Samantha Carlisle at 9:42 am, Jun 11, 2021 321-287 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.06.11 07:20:19 -08'00' Bo York 10-404 DSR-6/11/21SFD 6/14/2021 , ADL 028308 MGR16JUN21 SFD 6/14/2021 dts 6/16/2021 JLC 6/17/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.17 10:26:45 -08'00' RBDMS HEW 6/17/2021 Add Perf Procedure 02-26C PTD: 2050190 Well Name: 02-26C Add Perf API Number: 50-029-20774-03 Current Status: Flowing Rig: CTU Estimated Start Date: 06/18/2021 Estimated Duration: 2 days Regulatory Contact: Carrie Janowski Permit to Drill Number: 2050190 First Call Engineer: David Bjork (907) 440-0331 (c) Second Call Engineer: AFE Number: IOR 34 Current Bottom Hole Pressure: 3,285 psi @ 8,800’ TVD 7.2 PPGE | SBHPS taken as analog from offset 02-14. Max. Anticipated Surface Pressure: 2,405psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP: 900 psi (Taken on 08/12/2020 wireless) Min ID: 2.37” ID – 2-7/8” liner @ 11,370’MD Max Angle: 99 Deg @ 12,695’ Reference Log: PDS GR-CCL Log Dated 08-Mar-2015 Brief Well Summary: 02-26C is a CST completed in Z2A in March 2005. Additional perfs were added in 2014 and 2015. 02-26C is a decent well but has a low rate. Objective: The objective of this procedure is to shoot additional Z2A perforations from 11,400-11,525 and 11,580-11,620 and 11,720- 11,810. These perfs were identified as a future opportunity during the initial completion to get more footage open in Z1A and increase production. This will add rate and provide more uniform drawdown along the lateral. Sundry Procedure (Approval Required to Proceed): Note: The well will be killed and monitored before making up the initial perfs guns. 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. Coil Tubing 1. MIRU Coiled Tubing Unit and spot ancillary equipment. 2. Bullhead 167 bbls of KWF, 8.4 ppg 1% KCl or 8.5 ppg down the tubing to the formation. (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 = 167 bbls b. 4-1/2” Tubing – 10,103’ X .0152bpf = 154 bbls c. 3-1/2” Liner - 49’ X .0087bpf = 0.4 bbls d. 3-1/4” Liner - 1218’ x .0079 = 9.6 bbls e. 2-7/8” Liner – 500’ X .0058bpf = 3 bbls 3. MU and RIH with logging tools and drift BHA to resemble 2” dmy gun. Run past 11900’ctmd and log OOH. 4. POOH and confirm good data. 5. Freeze protect tubing as needed. * Add Perf Procedure 02-26C PTD: 2050190 6. At surface, prepare for deployment of TCP guns. 7. 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 continuous hole fill taking returns to tank until lubricator connection is reestablished. 8. Pickup safety joint and TIW valve and space out before MU guns. Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. 9. Break lubricator connection at QTS and begin makeup of TCP guns and blanks per schedule below. 02-26C Addperf Schedule *HES 2” guns were used to estimate for this job. If unavailable, use another vendor as needed. 10. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. POOH. a. Note any tubing pressure change in WSR. 11. POOH. Stop at surface to reconfirm well dead and hole full. 12. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 13. RDMO CTU. 14. RTP or FP well. Attachments: 1. Current Wellbore Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Schematic 4. Equipment Layout Diagram 5. Standing Orders for Open Hole Well Control during Perf Gun Deployment 6. Mini Log 7. Tie In Log/Perf Sheet Perf Interval Perf Interval Perf Interval Perf Length Gun Length Weight of Gun (lbs) 11,400-11,525’ 11,580-11,620’ 11,720-11,810’ 255’ 410’ 2,296lbs (5.6ppf) Standing orders flow chart included with this sundry request. MU lubricator *See note above regarding kill methods if pressure observed at surface after perforating. Add Perf Procedure 02-26C PTD: 2050190 Current Wellbore Schematic Add Perf Procedure 02-26C PTD: 2050190 Proposed Schematic Add Perf Procedure 02-26C PTD: 2050190 Coiled Tubing BOPs Add Perf Procedure 02-26C PTD: 2050190 Equipment Layout Diagram Add Perf Procedure 02-26C PTD: 2050190 Standing Orders for Open Hole Well Control during Perf Gun Deployment Add Perf Procedure 02-26C PTD: 2050190 02-26C Mini Log PE Notes Producer Possible 2A and 2C thin lenses Possible AddperfsEnd of Life Add Perf Procedure 02-26C PTD: 2050190 02-26C Tie-In Log Add Perf Procedure 02-26C PTD: 2050190 Add Perf Procedure 02-26C PTD: 2050190 Add Perf Procedure 02-26C PTD: 2050190 Add Perf Procedure 02-26C PTD: 2050190 Add Perf Procedure 02-26C PTD: 2050190 • • Gyrodata Incorporated 205019 gyro/data23000 Northwest Lake Dr. • Houston, Texas 77095 T: (281) 213-6300 • F: (281)213-6301 CIE Precision Wellbore Placement n6 ..; 1 2 SEP 02 2V.3 AOGOO DATA LOGGED it !2015 K BENDER SCANNED JUN 0 8 ZQ1S, SURVEY REPORT BP Exploration Drill Site: 2 #02-26C Wellhead Prudhoe Bay, North Slope Borough, AK AK0415GCM121 2 April 2015 RIGHT PLACE FIRST TIME www.gyrodata.com Gyrodata Incorporated • • 23000 Northwest Lake Dr.y ,gyrolrodata In 4 Houston,Texas 77095 Precision Wellbore Placement T: (281) 213-6300 • F: (281) 213-6301 August 31, 2015 State of Alaska - AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: Drill Site: 02, Well # 02-26C Prudhoe Bay, Alaska Enclosed, please find one (1) copies, and one (1) disk of the completed survey for the above referenced well. 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O W T , r T _, . _0 0 o vo 0 a W 1e v) o cQ r L T T T 1 *.i 1O in •.r row L 1 O O ist : - (.9 Q m D �kii2t - o Q 1 J L 1 - J . .me y--_� _O i ed •o U to C N O r.N t ,- T + 00 1 O o f V c0 Z cn 4 Q N no 0 ID L •L _ c Q- 0 ado -0 CO J 00 I`, O Li) Cr M N ,-i o uDzIDA]S DJ1JOa Survey QC - RGS-CT Specification Sheet gym/data SURVEY QUALITY CONTROL- SPECIFICATION DATA PRE-JOB CALIBRATION VERIFICATION CHECK(ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 69 271.02 76.44 0.00001889 -14.12 68 271.02 82.81 0.00002047 -13.06 67 225.18 57.03 0.00001426 -13.03 66 225.18 59.34 0.00001484 -17.76 65 44.39 54.98 0.00001376 -9.58 64 44.39 59.82 0.00001497 -10.13 63 0.88 343.35 0.00008688 -6.51 62 0.88 347.24 0.00008787 -6.77 61 330.66 382.65 0.00009626 -2.99 60 330.66 383.10 0.00009637 -5.91 59 299.98 233.58 0.00005805 -1.91 58 299.98 236.42 0.00005876 -2.54 57 270.23 78.34 0.00001936 -4.61 56 270.23 85.37 0.00002110 -1.94 55 238.51 39.97 0.00000994 -7.24 54 238.51 47.11 0.00001172 -6.02 53 209.46 168.47 0.00004240 -6.72 52 209.46 172.80 0.00004349 -6.89 51 180.18 330.49 0.00008363 -10.54 50 180.18 331.89 0.00008398 -11.59 49 148.25 360.27 0.00009054 -10.19 48 148.25 363.77 0.00009142 -8.85 47 118.69 206.08 0.00005120 -9.87 46 118.69 207.65 0.00005159 -8.98 45 89.47 63.69 0.00001574 -9.56 44 89.47 67.93 0.00001679 -9.52 43 59.49 38.95 0.00000969 -8.67 42 59.49 42.28 0.00001052 -8.60 41 29.69 179.08 0.00004506 -8.46 40 29.69 182.56 0.00004594 -10.40 39 0.59 358.58 0.00009074 -8.60 38 0.59 364.26 0.00009218 -13.54 37 269.81 114.96 0.00002842 -11.80 36 269.81 115.62 0.00002858 -13.95 35 225.10 106.44 0.00002663 -12.58 34 225.09 114.36 0.00002861 -16.40 33 44.63 100.45 0.00002513 -10.73 32 44.63 104.32 0.00002610 -10.84 31 0.16 351.11 0.00008885 -2.65 30 0.16 355.46 0.00008995 -4.29 29 330.78 402.79 0.00010133 -0.74 28 330.78 406.76 0.00010233 -1.89 27 299.86 299.22 0.00007438 -2.48 26 299.86 302.66 0.00007523 -2.70 25 271.74 149.16 0.00003687 -4.18 24 271.74 156.13 0.00003859 -6.71 23 240.62 97.80 0.00002432 -8.42 22 240.62 99.50 0.00002474 -9.87 21 209.51 184.49 0.00004643 -12.77 20 209.51 183.57 0.00004620 -14.95 19 180.12 312.88 0.00007917 -15.96 18 180.13 315.41 0.00007981 -19.31 17 149.36 347.59 0.00008739 -2.64 16 149.36 349.37 0.00008784 -7.85 15 119.04 230.74 0.00005733 -9.77 14 119.04 231.99 0.00005764 -10.39 13 88.99 79.71 0.00001970 -12.33 12 88.99 85.94 0.00002124 -11.55 11 60.55 43.94 0.00001093 -11.13 10 60.55 50.98 0.00001267 -12.13 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 1 of 6 AK0415GCM121 t Survey QC - RGS-CT Specification Sheet gyro/data 9 29.85 154.01 0.00003875 -8.21 8 29.85 155.99 0.00003925 -8.51 7 0.05 311.72 0.00007887 -8.71 6 0.05 308.82 0.00007814 -5.33 MBO = -0.34 Gravity Error = 197.35 Scale Factor Uncertainty = 0.00004953 Rate Error = -8.86 POST-JOB CALIBRATION VERIFICATION CHECK (ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 14588 269.68 84.67 0.00002093 -5.97 14587 269.68 96.03 0.00002374 -7.45 14586 225.91 108.48 0.00002713 -8.56 14585 225.91 111.20 0.00002781 -11.29 14584 45.27 87.93 0.00002199 -8.63 14583 45.26 94.61 0.00002366 -10.04 14582 0.25 422.45 0.00010692 -8.21 14581 0.25 427.58 0.00010821 -8.95 14580 331.11 457.99 0.00011524 -7.42 14579 331.11 463.07 0.00011652 -6.63 14578 300.11 276.14 0.00006864 -6.46 14577 300.11 278.37 0.00006920 -6.64 14576 271.80 92.50 0.00002286 -5.96 14575 271.80 101.08 0.00002498 -5.95 14574 240.40 58.81 0.00001462 -11.00 14573 240.40 58.35 0.00001451 -10.63 14572 209.97 217.40 0.00005471 -13.01 14571 209.97 221.11 0.00005564 -13.12 14570 181.83 403.78 0.00010219 -11.28 14569 181.83 409.39 0.00010361 -12.04 14568 149.56 406.09 0.00010212 -9.80 14567 149.56 411.93 0.00010359 -9.84 14566 119.53 209.56 0.00005207 -8.40 14565 119.53 210.99 0.00005243 -8.90 14564 91.11 35.73 0.00000883 -9.54 14563 91.11 39.87 0.00000985 -9.31 14562 59.18 23.98 0.00000597 -12.22 14561 59.18 30.56 0.00000760 -10.54 14560 29.00 224.71 0.00005656 -12.23 14559 29.00 229.30 0.00005772 -11.52 14558 359.90 443.62 0.00011228 -5.95 14557 359.90 446.35 0.00011297 -4.64 14556 269.49 99.04 0.00002448 -4.82 14555 269.48 106.69 0.00002637 -3.53 14554 225.41 120.93 0.00003025 -7.71 14553 225.41 127.29 0.00003184 -7.99 14552 45.59 100.06 0.00002502 -8.16 14551 45.59 103.74 0.00002594 -8.68 14550 0.75 443.37 0.00011222 -10.16 14549 0.75 450.39 0.00011399 -9.36 14548 330.87 476.78 0.00011997 -6.35 14547 330.86 479.44 0.00012063 -6.20 14546 301.37 301.94 0.00007509 -7.00 14545 301.38 307.03 0.00007636 -5.27 14544 271.59 113.31 0.00002801 -7.84 14543 271.59 119.99 0.00002966 -9.16 14542 240.59 77.82 0.00001935 -4.48 14541 240.59 83.83 0.00002084 -5.62 14540 209.48 249.24 0.00006273 -5.13 14539 209.48 250.73 0.00006311 -5.82 14538 179.74 427.64 0.00010823 -3.43 14537 179.74 431.01 0.00010908 -3.14 14536 149.56 427.48 0.00010750 2.16 SURV-Q167(OPS SUR-MA-003) 19`h Nov 03/Rev 15 Page 2 of 6 AK0415GCM121 Survey QC - RGS-CT Specification Sheet gYro/data 14535 149.56 434.38 0.00010924 0.48 14534 120.46 242.59 0.00006031 -5.02 14533 120.46 247.65 0.00006157 -3.37 14532 91.06 73.08 0.00001806 -7.93 14531 91.06 87.21 0.00002156 -7.46 14530 61.15 74.39 0.00001849 -8,38 14529 61.15 81.85 0.00002035 -7.85 14528 28.14 258.03 0.00006497 -12.66 14527 28.14 265.67 0.00006690 -12.31 14526 0.22 435.71 0.00011027 -8.96 14525 0.22 435.01 0.00011010 -9.86 MBO = -0.13 Gravity Error = 236.20 Scale Factor Uncertainty= 0.00005934 Rate Error= -7.86 INITIALISATION Gyro Compass Reading /Station Raw Inclination Raw Azimuth Abs (ERMeas-ERTheo) 103 10.01 280.92 0.0861 104 10.01 280.50 0.0893 105 10.01 280.51 0.0679 106 10.01 280.54 0.0681 Average 10.01 280.62 0.0779 Tolerance on Average* N r•. � . . � �� ;� �, 0.0813 Standard Deviation 0.00 0.20 0.0114 Tolerance on St. Dev.** 0.10 0.20 0.0365 Advanced Initialisation Azimuth Advanced Initialisation Standard Deviation Tolerance =TBA * Tolerance on Average of earth horizontal rate difference is given by (1/Cosl)*J[(CosA*SinI*0.1)2+0.0821 °/hr ** Tolerance on Standard Deviation of earth horizontal rate difference tolerance is given by (1/Cosl)*4[(cosA*SinI*0.1)2+(0.082/(n-1))] °/hr DRIFT TUNES Drift Tune Ending Ending Ending Ending Residual Gx Bias Residual Gy Bias Number Time Depth Inclination Azimuth Start End Start End 1 385.98 3150.68 15.38 254.78 0.001 -0.002 -0.000 -0.000 2 756.34 4000.68 35.01 255.36 0.000 -0.001 -0.001 -0.000 3 1111.49 5999.98 47.98 261.27 -0.009 0.008 -0.002 0.001 4 1155.48 8000.11 50.39 262.34 -0.009 0.008 -0.003 0.002 5 1174.46 9499.94 31.98 291.71 -0.005 0.003 -0.001 -0.000 6 880.11 10130.12 31.03 311.05 -0.003 0.002 -0.000 0.002 7 873.34 9500.09 31.72 291.79 0.005 -0.004 -0.002 -0.000 8 1640.06 8000.02 50.42 262.31 0.006 -0.005 -0.002 -0.001 9 1096.64 7000.00 51.10 263.72 0.007 -0.006 0.001 -0.002 10 1091.67 6000.09 48.09 261.36 0.006 -0.005 0.000 -0.002 11 1153.17 4979.95 44.69 256.79 0.007 -0.007 -0.001 -0.002 12 1139.39 3999.97 35.14 255.47 0.006 -0.005 -0.000 -0.004 13 971.20 3149.46 15.38 254.48 0.009 -0.003 -0.002 -0.002 14 454.55 3000.28 10.11 279.23 0.002 -0.002 -0.001 0.001 Average 0.002 -0.001 -0.001 -0.001 Standard Deviation 0.006 0.005 0.001 0.002 SURV-Q167(OPS SUR-MA-003) 19t Nov 03/Rev 15 Page 3 of 6 AK0415GCM121 Survey QC - RGS-CT Specification Sheet gyr%lata Tolerance for both the Average and the Standard Deviation 0.033°/hr 0.033°/hr 0.033°/hr 0.033°/hr INCLINATION AND AZIMUTH INRUN AND OUTRUN COMPARISON Depth Corrected Inclination Corrected Azimuth Inrun * I Outrun * f Difference Inrun * I Outrun * I Difference 100.00 0.21 0.13 0.08 140.74 82.79 57.95 200.00 0.15 0.26 -0.12 169.38 165.58 3.80 300.00 0.21 0.25 -0.04 162.14 173.11 -10.97 400.00 0.28 0.24 0.04 193.74 180.57 13.17 500.00 0.22 0.27 -0.04 193.57 185.00 8.57 600.00 0.23 0.30 -0.07 188.21 189.42 -1.20 700.00 0.32 0.26 0.06 212.24 191.05 21.19 800.00 0.28 0.22 0.06 184.29 192.67 -8.38 900.00 0.25 0.26 -0.01 138.96 163.32 -24.36 1000.00 0.39 0.30 0.09 130.32 133.79 -3.47 1100.00 0.49 0.39 0.10 119.82 127.07 -7.25 1200.00 0.52 0.48 0.04 109.38 120.51 -11.13 1300.00 0.52 0.46 0.06 107.82 114.63 -6.81 1400.00 0.39 0.45 -0.06 116.08 108.75 7.34 1500.00 0.18 0.28 -0.11 90.29 40.49 49.80 1600.00 0.01 0.12 -0.11 24.35 331.57 52.78 1700.00 0.25 0.17 0.08 323.54 329.21 -5.67 1800.00 0.16 0.22 -0.06 305.64 327.67 -22.04 1900.00 0.19 0.29 -0.10 329.41 263.94 65.48 2000.00 0.27 0.35 -0.08 209.37 199.35 10.02 2100.00 0.37 0.38 -0.01 202.11 222.78 -20.68 2200.00 0.45 0.40 0.05 251.99 247.58 4.41 2300.00 0.45 0.57 -0.12 234.02 228.16 5.87 2400.00 0.81 0.74 0.07 206.17 207.98 -1.81 2500.00 0.77 0.75 0.03 182.69 194.73 -12.03 2600.00 0.86 0.76 0.10 179.91 181.60 -1.69 2700.00 0.66 0.69 -0.03 175.01 176.13 -1.12 2800.00 0.82 0.93 -0.11 239.61 240.37 -0.76 2900.00 6.53 6.83 -0.30 283.81 282.53 1.29 3000.00 10.01 10.00 0.01 280.76 279.34 1.42 3100.00 13.55 13.63 -0.08 262.46 262.33 0.12 3200.00 16.29 16.27 0.01 253.45 253.44 0.01 3300.00 18.21 18.20 0.01 252.55 252.61 -0.06 3400.00 19.65 19.60 0.05 253.04 253.13 -0.08 3500.00 21.68 21.64 0.03 254.07 254.11 -0.03 3600.00 24.56 24.53 0.03 254.48 254.55 -0.06 3700.00 26.88 26.88 0.01 255.08 255.15 -0.07 3800.00 29.51 29.49 0.02 255.35 255.41 -0.06 3900.00 32.19 32.18 0.01 255.48 255.54 -0.06 4000.00 34.99 34.99 0.00 255.35 255.44 -0.09 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 4 of 6 AK0415GCM121 Survey QC - RGS-CT Specification Sheet gyro/data 4100.00 37.31 37.29 0.03 256.11 256.19 -0.08 4200.00 40.10 40.08 0.02 256.98 257.05 -0.07 4300.00 43.47 43.43 0.03 256.73 256.80 -0.07 4400.00 44.87 44.84 0.03 256.61 256.68 -0.07 4500.00 44.70 44.64 0.06 256.61 256.67 -0.05 4600.00 44.94 44.88 0.06 256.66 256.72 -0.06 4700.00 45.06 45.01 0.05 256.64 256.68 -0.04 4800.00 45.06 45.03 0.03 256.58 256.61 -0.04 4900.00 45.21 45.18 0.04 256.62 256.65 -0.03 5000.00 44.56 44.52 0.04 256.93 256.96 -0.03 5100.00 44.85 44.81 0.05 257.04 257.06 -0.03 5200.00 45.34 45.28 0.06 257.53 257.54 -0.02 5300.00 45.24 45.18 0.05 257.36 257.37 -0.02 5400.00 45.52 45.47 0.06 257.54 257.55 -0.01 5500.00 46.35 46.28 0.07 258.35 258.36 -0.01 5600.00 47.40 47.33 0.07 259.55 259.56 -0.01 5700.00 47.56 47.50 0.06 260.32 260.34 -0.02 5800.00 47.65 47.59 0.06 260.44 260.47 -0.03 5900.00 47.64 47.60 0.03 261.04 261.08 -0.04 6000.00 48.04 47.96 0.08 261.29 261.32 -0.04 6100.00 49.11 49.04 0.07 261.33 261.35 -0.02 6200.00 49.13 49.09 0.04 261.22 261.23 -0.01 6300.00 49.12 49.05 0.07 261.39 261.39 0.01 6400.00 50.09 50.04 0.05 262.31 262.27 0.04 6500.00 50.72 50.63 0.09 263.14 263.11 0.03 6600.00 50.86 50.79 0.07 263.33 263.30 0.04 6700.00 51.03 50.98 0.05 263.40 263.35 0.05 6800.00 51.29 51.22 0.06 263.62 263.57 0.05 6900.00 51.06 51.06 0.01 263.77 263.70 0.07 7000.00 51.08 51.00 0.08 263.77 263.70 0.07 7100.00 51.16 51.14 0.02 263.58 263.52 0.06 7200.00 51.30 51.23 0.07 263.36 263.29 0.07 7300.00 51.37 51.33 0.04 263.21 263.12 0.08 7400.00 51.26 51.21 0.06 263.20 263.13 0.07 7500.00 51.04 51.00 0.04 263.11 263.03 0.08 7600.00 50.78 50.74 0.03 262.94 262.87 0.07 7700.00 50.65 50.55 0.10 262.84 262.75 0.09 7800.00 50.60 50.54 0.06 262.65 262.58 0.07 7900.00 50.54 50.48 0.06 262.50 262.44 0.06 8000.00 50.44 50.37 0.07 262.36 262.29 0.07 8100.00 50.15 50.13 0.02 262.47 262.36 0.11 8200.00 50.02 49.93 0.09 262.22 262.14 0.08 8300.00 49.34 49.28 0.06 262.32 262.23 0.09 8400.00 48.86 48.80 0.05 262.18 262.07 0.10 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 5 of 6 AK0415GCM121 Survey QC - RGS-CT Specification Sheet gyr/dab A i _ _l 8500.00 48.33 48.25 0.08 262.48 262.38 0.10 8600.00 47.95 47.92 0.03 262.17 262.07 0.10 8700.00 47.60 47.53 0.07 261.99 261.92 0.07 8800.00 47.42 47.38 0.04 261.59 261.51 0.08 8900.00 46.89 46.82 0.07 261.36 261.26 0.11 9000.00 46.69 46.62 0.07 261.19 261.09 0.10 9100.00 46.42 46.41 0.01 260.89 260.76 0.12 9200.00 45.96 45.90 0.06 261.14 260.99 0.15 9300.00 44.84 44.82 0.02 264.99 264.66 0.33 9400.00 40.81 40.95 -0.14 277.16 276.57 0.58 9500.00 31.92 32.03 -0.11 291.73 291.41 0.31 9600.00 31.79 31.73 0.06 298.69 298.32 0.37 9700.00 29.84 29.79 0.05 301.32 301.17 0.15 9800.00 31.80 31.87 -0.07 304.22 304.07 0.15 9900.00 30.68 30.62 0.05 304.15 304.08 0.06 10000.00 29.39 29.24 0.15 305.96 305.76 0.20 10100.00 31.26 31.18 0.08 310.14 309.96 0.18 Average 0.0244t f 0.0474 Standard Deviation 0.0663 ` ' ' �_ 0.1153 Tolerance for both the Average and the Standard Casing 0.30 , � n q Casing 0.50 Deviation Drillpipe 0.30 ,..: t., ? Drillpipe 0.750 *.Inclination and Azimuth interpolated to same depths as shown. SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 6 of 6 AK0415GCM121 Survey QC - RGS-CT Analysis Sheet gy cIa 1 SURVEY QUALITY CONTROL- DATA ANALYSIS REFERENCE SYSTEMS Grid System I Grid Correction 10.00 Azimuth reference: Grid/True North TRUE NORTH Vertical reference: RKB/MSL/Other If other give details TIE ON DATA Depth 0.00 Inclination 0.00 Azimuth 0.00 TVD 0.00 Northings 0.00 Eastings 0.00 Latitude 70.2012 Az. Ref: Grid Corrected Y/N? Description Grid/True CALIBRATION Tool Number 1523 Calibration Date 03 Dec 2013 OPERATING TEMPERATURE Calibration range From 49.64 To 119.93 Gyro operating range From 0.00 To 85.80 Spec'- Within calibration range FIELD ROLL TEST (Only valid on fixed structures. When not possible input roll test data performed after return to base) Cal value Pre job offset Post job Abs dif.cal.post Abs dif.pre.post Spec' offset Accel Scale 0.000056 0.000050 0.000059 0.000059 0.000010 Cal/Post-0.00015 Mass Unbalance 6.45 -0.34 _ -0.13 0.13 0.21 Pre/Post- 0.4°/hr INITIALISATION Depth (Approx) 3000.41 No of stns 4 Spec'- Min No. - 6 Azimuth Mean 280.62 Std deviation 0.20 Spec'-Azi SD 0.2° Inclination Mean 10.01 Std deviation 0.00 Spec'-Inc SD 0.1° Earth Horizontal Rate Mean (Abs(meas-theor)) 0.08 Std deviation 0.01 Spec'-See Q167 DRIFT TUNE Residual x gyro bias Mean -0.001 Std dev' 0.005 Spec's - Mean and SD - 0.333°/hr Residual y gyro bias Mean -0.001 Std dev' 0.002 Spec's - Mean and SD- 0.333°/hr TOOLFACE RATE Maximum toolface rate 54.46 I Spec'-400°/sec IN/OUT COMPARISON (AZI' N/A IF INC' <15°) Inclination Difference Mean 0.02 Std dev' 0.07 Spec's - Casing 0.3°/Drill pipe 0.3° Azimuth Difference Mean 0.05 Std dev' 0.12 Spec's -Casing 0.5°/Drill pipe 0.75° Lateral Divergence/1000 0.39 Spec- 5.0/1000 Vertical Divergence/1000 0.36 Spec'- 2.0/1000 DEPTH CONTROL Wireline Company I Line type Encoder SF Max Depth (TD) CCL Corrected Zero Depth (Rig up) Rezero Depth Given pup joint depth Measured PJ Strech cor. At TD divided by TD/1000 Spec'- 1.5/1000 Dif. Between rigup and rezero depths divided by TD/1000 Spec'- 2.0/1000 Dif. Between given and meas depth divided by meas/1000 Spec'-2.0/1000 SURV-Q165(OPS SUR-MA-010)22nd Jan 2004/Revision 20 Page 1 of 1 AK0415GCM121 1 Survey QC - RGS-CT Acceptance Sheet gyro/data FIELD AND SURVEY INFORMATION Operator BPXA Field/Platform WELLHEAD Well Number PRUDHOE BAY 02-26C Survey section From 0.00 ft. to 10138.10 ft. Date 02 Apr 2015 Gyrodata Job No AK0415GCM121 Gyrodata Surveyors Henry Drew Job Objective High Accuracy Gyro Survey SURVEY PERFORMANCE In Spec' QC Parameter Yes/No/NA Possible Actions Contact Duty Engineer to discuss options: Operational temperature within No 1. Recalibrate tool to higher temperature specification 2. Resurvey with backup tool 3. Resurvey'Hot'section at higher speed Roll test data within specification Contact Duty Engineer to discuss options: Only valid on land/fixed installations Yes 1. Recalibrate tool and reprocess survey 2. Resurvey with backup tool Continuous initialisation within Take new initialisation, after three failures: specification No 1. Contact Duty Engineer or, 2. Resurvey with back up tool. Contact Duty Engineer to discuss options: Toolface rate within specification Yes Resurvey section from previous bias check Investigate and comment if effects are negligible Contact Duty Engineer to discuss options: Drift tunes within specification Yes 1. Reprocess with different software settings 2. Resurvey with backup tool Inrun/Outrun comparison within Contact Duty Engineer to discuss options. specification Resurvey is usually not required if either inrun or outrun meet all other QC parameters Depth control within specification Contact Duty Engineer to discuss options. Action taken: Note: Provided satisfactory action has been taken, parameters out with specification will not necessarily fail a survey. SURVEY ACCEPTED Gyrodata Representative Client's Representative SURV-Q166(OPS SUR-MA-003)13"Nov 03/Revision 12 Page 1 of 1 AK0415GCM121 STATE OF ALASKA RECEIVED A. ,KA OIL AND GAS CONSERVATION COME, ION REPORT OF SUNDRY WELL OPERATIONS APR 0 1 2015 1 Operations Abandon H Repair Well H Plug Perforations U Perforate U Other*XEteree4__ Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension Change Approved Program ❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2 Operator 4 Well Class Before Work 5.Permit to Drill Number Name. BP Exploration(Alaska),Inc DevelopmertR Exploratory ❑ 205-019-0 3 Address. P.O Box 196612 Stratigraphic Service ❑ 6.API Number. Anchorage,AK 99519-6612 50-029-20774-03-00 7.Property Designation(Lease Number). 8.Well Name and Number ADL0028309 PBU 02-26C 9 Logs(List logs and submit electronic and printed data per 20AAC25 071)' 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 13006 feet Plugs measured 12493 feet true vertical 9041.42 feet Junk measured None feet Effective Depth measured 12493 feet Packer measured See Attachment feet true vertical 9038.56 feet true vertical See Attachment feet Casing Size MD TVD Burst Colla C 9 Lengthse P Structural None None None None None None Conductor 80 20"91 5#H-40 28 54-108 54 28 54-108.54 1490 470 Surface 2627 41 13-3/8"72#L-80 27 89-2655 3 27 89-2655 23 4930 2670 Intermediate 9241 3 9-5/8"47#L-80 26.7-9268 26 7-7469.91 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment ' Perforation depth Measured depth See Attachment feet SCANNED True Vertical depth See Attachment feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured). Treatment descriptions including volumes used and final pressure 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 230 24752 20 0 956 Subsequent to operation 350 10541 26 0 860 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run Exploratory❑ Development❑✓ Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil Q Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt: N/A Contact Nita Summerhays Email Nita.Summerha s• b•.com Printed Name Nita Summerhays / /� Title Petrotechnical Data Engineer .../-a"Signatu / - ' Phone 564-4035 Date 4/1/2015 ' V 4/10 / i5---- RBDMS AA APR - 7 2015 Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028309 ACTIVITYDATE S M Y CTU#3 1.75" CT(CTV=31.2) Objective-Set CIBP,Ad Perf 150' MIRU, MU PDS GR/CCL logging string with 2.3" nozzle, L&K well with 259 bbls of Slick 1% KCL w/Safelube and 39 bbls 60/40 FP. RIH w/logging string. Log from 12600'- 12450'. Paint white/black flag. Log from 12450'-9600'. Pulled heavy intermittently from 12000'- 10470'. POH. 3/7/2015 In Progress _ CTU #3 1.75" CT(CTV=31.2) Objective-Set CIBP,Ad Perf 150' POH w/PDS GR/CCL logging string. Download data. +2' correction. Run WFT 1.69"Venturi, hoover from 11,000'- 12,500' recover small amount of metal shavings. MU WFD 2-7/8"CIBP, RIH to flag and correct to top of plug- 12,541'. RIH to set depth and launch ball, good indication of set; top of CIBP at 12,485'. Due to depth discrepancies between electronic and mechanical counters, decide to re-log to confirm top of CIBP depth prior to perforating. RIH w/PDS GR/CCL logging string and 2.3"JSN. 3/8/2015 ***In Progress*** CTU#3 1.75"CT(CTV=31.2) Objective-Set CIBP,Ad Perf 150' RIH w/PDS GR/CCL logging string and 2.3"JSN. Tag CIBP at 12461'. Log up at 50 fpm. Paint yellow flag at 12000.5'. Log up at 50 fpm to 9600'. POH. PDS downloads data. +24.5' correction. Corrected top of CIBP 12,493.02' ELMD. MU Gun#1 RIH to CIBP and correct bottom to shot at 12,492.3', PUH and perforate interval 12,035- 12,065' . MU Gun#2 RIH to CIBP and 3/9/2015 correct bottom to shot at 12,492.3', PUH and perforate interval 12,005-12035..In Progress _ CTU#3 1.75" CT(CTV=30.7 ) Objective-Set CIBP Add Perf 150' MU gun#3 RIH stab in lubricator and low& high PT. Good test. RIH to tag CIBP. Correct the depth 12492.31 and PUH to 11960. Launch the ball. Guns fired after 27.4 bbls away. Perforated 11930-11960 interval. POOH laydown gun run#3 and MU gun run#4. RIH with Gun#4, tag CIBP and correct depth to 12,492.31', PUH and perforate interval 11,900-11930'. POOH laydown gun run#4 and MU gun run#5, RIH to tag CIBP. Correct the depth 12492.31 and PUH to 11900. Launch the ball. Guns fired after 28.1 bbls away. Perforated 11870-11900 interval. POOH to surface. Broke out lubricator and laid down guns. 3/10/2015 ***Job continued on 3/11/15 WSR*** CTU#3 1.75"CT(CTV=30.4) Objective-Set CIBP Add Perf 150' Laid down guns. Did pipe management. Cut 125'of pipe. Made up tree cap and PT. Perform 7 day BOP test on back deck with no failures. RDMO 3/11/2015 ****Job Complete**** FLUIDS PUMPED BBLS 487 60/40 METH 342 1% SLICK KCL W/SAFELUBE 107 SEAWATER W/SL 936 TOTAL a) 0 M CO CO CA Y- c- CO C f. 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N M CO (0 ao CO CO M W O) CO v- N O) O O) M J CC H �O W W D � VUC� UC7 cdpf � f � � CCCCLLZZZZ V Z W W W W W W W m m c-70 Q H Z Z Z Z Z Z D D D D j J U Z J J J J J W H H H H a`) L - a) U L N Co - c d U a) O a Q Cn N 0 a . F- E � 0 (.) - -c a) >d tl) U N d = a- ct. co a> d2ZmN - o- NNit 45 Wcco U) Y I m m m m N N N r r � V O O N CO 1"-- 41 0 � CO CO Q > CO V N O MO co CO N N co I— N- CO CO co CD O CO J < CD U) t LO N L • CO O O O O V Cr) O O C 11 CC CC CC CC CC • W W W W W O_YYYYY >'00000 Q Q Q Q Q CL O d Q O a) E 0 0 0 0 U co CO CO CO CO CO Z N N N N N N N N • 0 CD CD CD CD U) TREE= . 4-1/16"avv WELLHEAD= FINC-SM 02-26C S, t NOTES: WELL ANGLE- ACTUATOR= BAKERC 70"@ 11411' MAX DOGLEG:28"@„594• OKB.ELEV= 64' I BF H-EV 302 /I 2123' -I4-1/2"FES X NP,D=3.813" KOP= _ .. 2995' 20"CONDUCTOR H 112' - M3x Angle= 99 @ 12695' 91#,H-40, Datsun MD= 10903' D=19.124" 3055' -9.63"X 7"ZXPN LTP w/FLEXLOC HGR,D=6.15" n batteTV D= - 8800'SS GAS LFT MANDRELS 13-3/8"CSG,72#,L-80 BUTT,D=12.347" -{ 2661' ST MD TVD DEV TYPE VLV LATCH PORT DATE TOP OF r SCAB LNR -{ $056' = 3 3520 3494 23 KBG2 DOME BK 16 01/31/14 2 7036 6001 51 KBG2 SO BK 20 01/31/14 7"SCAB LINK 26#,L-80 VAM TOP, -i 9111' 1 © 1 9643 7770 31 KBG2 DMY BK 0 01/22/14 .0383 bpf,D=6.276" + • 9-5/8'WWSTOCK(XX/XX/XX) H 9268' 9106" BKR TEBACK SLEEVE D=7.500" 9113' --I9-5/8"X 7"BKR ZXP PKR,D=6.313" 9-5/8"CSG,47#,L-80,D=8.681" 1 10455' } ✓ 9118' 7'TEBK ASSY w/CRC PORTS V. ABOVE LWR SEAL D=6.17' 3Minimum ID = 2.377" @ 11370' \*.,,,,,.:,, � 911x' -j95/8"x7"BKR E ncHGR,D=6.313" 3-3/16"X 2-7/8" XO LSL SUB 9-5/8"CSG MILLOUT WINDOW(02-26B)9268'-9286' ' 9760' 14-1/2"FES X NP,D=3.813" z X 9790' H 7'X 4-1/2"FES TNT PKR,D=3.856' 4-1/2"TBG,12.6#,13CR-86 YAM TOP, -1 9895' 1' ' 9825' H4-1 2"FES X NP,D=3.813' .0152 bpf,ID=3.958" 4-1/2"TBG STUB(RIG 01/20/14) -{ 9899' 1 9910` -I 7"X 4-1/2"UNC OVERSHOT 10103'_-13-1/2'BOT DEPLOY SLV,D=3.00j 10122` 13-1/2"HOMO X NI',D=2.813" 4-1/2"TBG,12.6#,L-80 BT-M, 1 10229' r 10152' 13-1/2"X 3-3/16"XO,D=2.786" .0152 bpf,D=3.958" 7"LNR,26#,L-80,.0383 bpf,D=6.276" H 10413' Z 10175' -dr'X 4-1/2"BKR S-3 PKR,D=3.875" 4-1/2"NECHAMCAL WHIPSTOCK(03/08/05) 1 10657' ' 111 10206' 14-1/2"FES XN NP,MILLED TO 3.80"(03/10/05) w/RA PIP TAG fa 10666' / \ 10225' -17"X 4-1/2"BKR TBACK SLV,D=5.250" 4-1/2"LHR,12.6#,L-80 BTC-M, 1 -10657' 10229' H4-1/2"VVLEG,D=3.958" BEHIND .0152 bpf,D=3.958" 10232' -7"X 4-1/2"BKR ZXP PKR,D=4.375" CT LNR PEFFORATION SUMVARY 10239' -j 7"X 41/2"BKR MAC FiGR D=4.375" REF LOG:MCNUCCUGR ON 03/20/05ERF ANGLE AT TOP P : 87" ! 12207' K K I 10600' EST TOP OF CEMHYT 4 Note:Refer to Roduction DB for historical perf data i MILLOUT WINDOW(02-26C)10657'-10665' SIZE SPF INTB VAL Opn/Sqz SHOT SQZ 2" 6 11870-11960 0 03/10/15 �V 2" 6 12005-12065 0 03/09/15 11370' -I3-3/16"X 2-7/8"XO,D=2.377" 2" 6 12207-12237 0 10/11/14 012493'ELMD 12-7/8"WFD C8P(03/09/15) 2" 6 12257-12287 0 10/11/14 2" 6 12307-12367 0 10/10/14 12970'CTM -FISH-CBP 2" 6 12390-12405 0 12/23/14 3-3/16"LNR,6.2#,L-80 TC11, 11370' 014(12(21/ UFUSH 2" 6 12405-12435 0 12/23/14 DH(12/21/14) 2" 6 12650-12850 0 03/20/05 .0076 bpf,D=2.80" FWD --I 12973' �:' 2" 6 12890-12950 0 03/20/05 2-7/8'LNR,6.16#, L-80 SR,.0058 bpf,D=2.441' 1 13006' DATE REV BY OOIVIVENTS DATE REV BY COMMENTS PRLDHOE BAY UNIT' 08/02/82 IMTIAL COMPLETION 04/17/14 TAQ/JMI]RLL JCtSANDANRP(4/13-16/14) WELL: 02-26C 06/28/97 CTD SIDETRACK (02-26A) 05/13/14 PJC SFIY NOTE DOGLEG ADDED PERMIT Nix'2050190 09/13/00 N7ES SIDETRACK (02-268) 10/13/14 SROM PJC SET CBA'ADPERF(10/10-11/14) AR Pb: 50-029-20774-03 03/21/05 NORDIC 1 CTD SIDETRACK (02-28C) 01/06/15 AMJMD MLL CBPADPEiFS(12/21-23/14) SEC 35,T11 N,R14E,1563'FNL&7'FEL 01/23/14 D-14 RVVO 03/12/15 ALMPJC SET CBP/ADFERF(03/09-03/10/15) 02/07/14 PJC IFot/CONDUCTOR UPDATEBP Exploration(Alaska) STATE OF ALASKA RECEIVED • Al ;A OIL AND GAS CONSERVATION COMM JN REPORT OF SUNDRY WELL OPERATIONS JAN 1 4 2015 Il 1 Operations Abandon El Repair Well ❑ Plug Perforations ❑ Perforatel=1 Other ❑ Performedb.ri V V' Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waiver El Time Extension❑ Change Approved Program❑ Operat Shutdown❑ Stimulate-Other El Re-enter Suspended W❑ 2 Operator 4 Well Class Before Work. 5 Permit to Drill Number BP Exploration(Alaska),Inc Name Development 0 Exploratory 205-019-0 3 Address P O Box 196612 Stratigraphic ❑ Service❑ 6.API Number Anchorage,AK 99519-6612 50-029-20774-03-00 7 Property Designation(Lease Number) 8 Well Name and Number: ADL0028309 PBU 02-26C 9 Logs(List logs and submit electronic and printed data per 20AAC25 071). 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary- Total Depth measured 13006 feet Plugs measured 12515 feet true vertical 9041 42 feet Junk measured None feet Effective Depth measured 12970 feet Packer measured See Attachment feet true vertical 9036 83 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91 5#H-40 28 54-108 54 28 54-108 54 1490 470 Surface 2627 41 13-3/8"72#L-80 27 89-2655 3 27 89-2655.23 4930 2670 Intermediate 9241 3 9-5/8"47#L-80 26 7-9268 26 7-7469 91 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12207-12237 feet 12257-12287 feet 12307-12337 feet 12337-12367 feet 12390-12405 feet 12405-12435 feet 12650-12850 feet 12890-12950 feet True Vertical depth 9031.38-9032 31 feet 9032.35-9032.7 feet 9032 88-9033 56 feet 9033.56-9034.15 feet 9034 37-9034 46 feet 9034.46-9034 67 feet 9042.26-9030 17 feet 9029 96-9034 44 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) SCANNED L Treatment descriptions including volumes used and final pressure J f, ,v 0IL- 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 3603 0 1100 197 Subsequent to operation: 599 17042 51 740 947 14 Attachments. 15 Well Class after work Copies of Logs and Surveys Run Exploratory Cl Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work. Oil 0 Gas El WDSPL El GSTOR El 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 0 Exempt LN/A Contact Garry Catron Email Garry.CatronaBP.Com Printed Name Garry Catron Title PDC PE Signature Affer C Phone 564-4424 Date1/13/2015 VTI- 1/7?//5- RBDMSS JAN 1 6 2015 Form 10-404 Revised 10/2012 Submit Onginal Only L - a) U Y L (O (0 ) 0_ • 0_ U O Q- U a H Eo 0 a) co 0 LL Z L L CB Cr) NNw (o co L L Y = 00 ry� m Y I . "_,(0 N N N CDE RS Q 0 tf) cON N> in - CO c0 00 (/' O H O M CO N N co co CO CO N O Cl) Q C as cisLo L to co O to M o � ON O O co O co V Co a a, wwwww C.YYYYY >+000UU Q Q Q Q Q QQQOO a) E00000 IC (0 CO CO (0 CO Z N N N N • N N N CN >j O O O O O U) CD • 0• 000o � 000 `—° N- v v O 00 c�O Lf) O O O LO cY) N 00 N- U y o o 0 0 0 Loo 0 0 C) N- V V co M N C') m CO 00 M CA co O co r CA N M CO O) (A N CO LO V CO t N M LC) CA N M 00 O <- c- LO O N Cn CO CO co O N V' V' LO CA I,- V M N O (0 O CO O) N 00 00 O 00 O N 00 H CA O) 0) M C) f- co r- M O N O) O O 00 O Lr co O r- ON co'cr N N O CO <-- N N O N N CA M N- co a) co CA f- CD N O CA CO V LC) f- Lf) O Ln O co O O V M CO co O O N 0 0 0 co N O L ✓ a O M N M O M M LC) CS) ti LO O O Ln N t` co in 6) CO N N O M N N co N M 0 0 0 ca) C la O J D Ln O o 0 0 0 Co o o 0 00 00 00 0D co U co Q> 00 co J It J M J J J r N CO CO N CO • NN N O 00 N U 6) ' ' N ,- N 0\O cov NZNI O (` M CV M V N V L +-, CO 00 CA O r- 0O V CO O 0) ' Ac'M N O CO O co N O M N M O co cc) M 0) C•1 ) O — 0) M J W R' ~ • H 0 U W U 0 CL CC CC CC CC f LLZ Z Z W W W W W W W m �p Q F Z Z Z Z Z Z J D J U Z J J J J J J U) F- F- • • a) � -o x o) as ccu c a) X N - a) c .,..7c cu -c m E C 2 N a) a) ca > c c o o g I m •4- p ,- `- Y N L N tY U -' 2 a 2 3 a) E u) ai rn .§ > U c\i c" c 0)m o >> * p C c N s- U) C > � i 0 3a'� ami 3 0 � 0 E4 'n o _ .o o , Uia 0 c — o U m I O U p O N H v � ON ol3Dy * .) 0)11 * � � 31 D N c a * w • c Q c ,- O O N O - .Q O) O 0)_ _ +-' U) '� E I a c a IC) c';1 •••-•• Q0 < .E a) � NN4= (cp c0 Q N Or o j (0 N O U 0)Q O N N C C a -p N C O * _ c0 N O� (6 N r E c6 c •- OU c7 -0 O * 0 a aoi O c a • IX aci a) > m rx cs x m N o o mm ,= 'mt c3 -aryu) > a EI O_ � CU CV OHO ,_ b U - 0 a) � � -0 j c13 _c o)* >> 0m 0ON -ca) Eco -0 o- r o c °>> E = U '3 � o v E ui J O M o � 0 � 03 .>'" � Qc2O >, 7oo � � No •cO N O N Qa QCD a O > N N a - m- O N N c It _C2 o , 0 O C c E o o _o c c E u) CO c a C a) vim- O o a) -0 Q ca .- - U N C '.-+ L - -p C aS a +-' a) 0 a 0 C O U) a) E O U) c -0 N a) O �' 00 O (6 si = Y i Q U s' >, O • m U U a) Q a) (A > U o = o Z N o a) * O I .0 m E C U * * N ea 'C a Op c * -±-- -c � @ Z m O OpUy Q-0dv°)i .oQa) � 5a) oEaci0 _c0a) vmQ -p a) To M -a O ui L -Cr) CZ > N m C -o oz5 O • al 'a Dm 0 CO Q @ . �0 = c = mQ E Y p.� Q Cc) - NZ Q iz N N d u) ~ c E Y E - d cn I u) c a c) 0 � a 4 0 m -\ - - E m E rnm o12 ° € o- 0 m . J c 0 U E o 0 0 U co a ° a * U co ` in V C O t 0 = YO) 0to4- U `- U) _ -C 0 _cI = N co chL0 (N _ •. 0 QO. N -1 �- E c '2-a Y rn2 _c •-,. 02032A ---N 2 '= m `- N U /5 a c c a) +-' a) , O a) N > F-- rn O Qj u) c) C 3 •• N a 1 '>' 715 ca c oC � >'� > � U C = a F>' ONC[) C)I > z - U _ E L a' 0 0 'O O � 3 p o C N Q u) I 7 x) O C a) O O N X a .:.Q.,(1) r 0 3 � cn0 � c N cu N � .0 C — N CU 0 C• ° -c °p E 0 0 0 a) a) = a) N O a) E I cu O E o H u) o a oa H 0 Oo 0 o O H o z o rnD H c6 ami U E rn a) a) a) c o .` 0 u O N •_) i m 0 U) 0 ' a) 0 Z Y o -a Q U) O-N C c O E - co O •L ti o Q o_2 o 0 � cam - c3 = ° cc\i .m� a m m O ti =' ,.,� .- . -p -0 a) a) .- to E � _a m� O - N- ib = a) Q) p L 13 > �f O L U) a N - N Q ."-§ -p a) N � N � 0 . c � 3 m -2 a°)i Z 73 aoi c� c� 3 N ``) ,`- - c3 ami 3 .3 0 d Q o * c\i E CO m Q -' cu o f =-4 3 0 m .( a`_) E * -.- .c u) N * 3 a) U D D .0cqu) � E >, D -1-. Qc N .0 D10o Cm - `- DI 0 _0 UCS CO -1c�i o 2 .�U � CZ c�a 0 °) UdH mc(v _occvUixcn � tU Qv v v G C) o 0 C) N N N N N M N N N N F., N N N N U Q TREE= 41/16"CIW WELIIfAD FMGSM 02-26C SA NOTES: WELL MAX DOGLEG:28°@ 115A9I44'E ' "PREVIOUS 11' ACTUATOR= BAKER C NTIAL KB.ELEV 64' I 1 WELLBORES NOT SHOWN'"" BF ELEV 30.2' KOP= 2995' 20"CONDUCTOR -110 - 2123' H4-1/2"FES X NP,D=3.813" Max Angle= 99°@ 12695' 91#,H•40, Datum MD= 10903' 3055' H9.63"X 7"ZXPN LNR TOP PKR D=19.124" Datum TVD= 8800'SS &FLEX-LOCK HGR,D=6.15 13-3/8'CSG,72#,L-80,D=12.347" H 256V GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE TOP OF 7"SCAB LNR -{ 3066' ;� 3 3520 3494 23 KBG2 DOME BK 16 01/31/14 Minimum ID = 2.377" @ 11370' ��' 2 lois soot 51 KBG2 so BK zo 01/31/14I 1 9643 7770 31 KBG2 DMY BK 0 01122/14 13-3/16"x 2-7/8" XO LSL SUB A - 7"SCAB LNR 26#,L-80 VAM TOP!BTC-M, - 9111' A9106' -{BKR TEBACK SLEEVE,D=7.500" .0383 bpf,D=6276" .: 9113' -19-5/8"X 7"BKR ZXP PKR,D=6.313" 9-5/8"WHIPSTOCK(XX/XX/XX) --I 9268' 9118' 7'TEBK ASSY w/CPC PORTS 9-5/8"CSG,47#,L-80,D=8.681" H 10455' ABOVE LWR SEAL D=6.17" 9118' -19-5/8"X 7"BKR I-NC HGR,D=6.313" \ 4 9-5/8"CSG MILLOUT WINDOW(02-26B)9268'-9286' I 11.----- 9760' -{4-1/2"HES X NP,D=3.813" Z 4-1/2"TBG,12.6#,13CR-85 VAM TOP, H 9895' 9790' --17"X 4-1/2"HES TNT NKR,D=3.856" .0152 bpf,D=3.958" \, iri 9826' H4-1/2"HES X NP,D=3.813" 4-1/2"TBG STUB(RIG 01/20/14) H 9899' -( ) 8910 J 7"X 4-112"UNIQUE OVERSHOT I 10103' H3-1I2"BOT DEPLOY SLV,D=3.00" 1 10122' -3-1/2"H0VACO X NP,D=2.813" ,-- I 10152' 1-13-112"X 3-3/16"XO,D=2.786" 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" H 10229' Z X......---` 10175' -17"X 4-1/2"BKR S-3 PKR,D=3.875" I ,� 10206' --)4-1/2"HES XN NP,MLLED TO 3.80"(03/10/05) 7"LNR 26#,L-80,.0383 bpf,D=6.276" H 10413' / ‘ 10225' ,-{7"X 412"BKR TRACK SLV,D=5.250" 41/2"MEiCHAMCAL WHIPSTOCK(03/08/05) -{ 10657' 10229' H412"WLEG,D=3.958" BEHIND w/RA PIP TAG O 10666' 10232' H7"X 41/2"BKR ZXP PKR,D=4.375" CT LNR 4-1/2"LNR,12.6#,L-80,.0152 bpf,D=3.958" H -10657' , 10239' H 7"X 4-12"BKR MAC HCS D=4.375' PERFORATION SUM/ARY 10600' HEST TOP OF CEMENT REF LOG:MCNJCCUGR ON 03/20/05 ANGLE AT TOP FE RE: 87"@ 12207' MILLOUT WINDOW(02-26C)10657'-10665' Note:Refer to Roduction DB for historical pert data . , SIZEINTERVAL SPF BRVAL Opn/Saz SHOT SC?Z :::� ) 11370' H 3-3/16"X 2-7/8"XO,D=2.377" 2" 6 12207-12237 0 10/11/14 2" 6 12257-12287 0 10/11/1412970'CTM -FISH:CEP 2" 6 12307-12367 0 10/10/14 , 441114, 4144, MLL/PUSH OH 2" 6 12390-12405 0 12/23/14444*❖:•: .�.,.•. (12/21/14) 2" 6 12405-12435 0 12/23/14 2" 6 12650 12850 0 03/20/05 3-3/16"LNR,6.2#,L-80 TC11, 11370' V 2" 6 12890-12950 0 03/20/05 .0076 bpf,D=2.80" PBTO 12973' 2-7/8"LNR,6.16#, L-80 STL,.0058 bpf,D=2.441" - 13006' DATE REV BY COMMENTS _ DATE REV BY COMMENTS FRIDHOE BAY UNT 08/02/82 INTIAL COMPLETION 04/17/14 TAQ/JMD RLL JGSAMYWt '(4/13-16/14) WELL: 02-26C 06/28/97 CTD SIDETRACK (02-26A) 05/13/14 PJC SFTY NOTE DOGLEG ADDED PERMIT No:"2050190 09/13/00 MES SIDETRACK (02-26B) 10/13/14 SHY PJC SET CEP/ADI (10/10- 11/14) AR No: 50-029-20774-03 03/21/05NDRDIC ICTD SIDETRACK (02-26C) 01/06/15 AANJMD KILL CBP/ADFERFS(12/21-23/14) SEDC 35,T11N,R14E,1563'FM_&7'FEL 01/23/14 D-14 RWO 02/07/14 PJC 'TREE/CONDUCTOR IRIATE BP Exploration(Alaska) . . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~O 5- 0 J ~ Well History File Identifier Organizing (done) o Two-sided ""1111111" 11111I o Rescan Needed III 11111111 II 1I1II1 RES CAN '~color Items: ~GreYSCale Items: \ p~ DIGITAL DATA ~iskettes, No. ~ o Other, Norrype: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: Date Lf/~3/D7 o Other:: mf Is~11111111II11 "III rn f BY: ~ 151 Project Proofing BY: ~ Date: + J q = TOTAL PAGES 71 ~t does not include cover sheet) 151 If Scanning Preparation BY: Production Scanning Stage 1 Page Count from Scanned File: ~ 0 (Count does include ~ sheet) Page Count Matches Number in Scanning Preparation: V YES BY: ~ Date: 4- / d-3/ tJ 7 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES III 111111111111111I NO Iw mp NO BY: Maria Date: Isl 11111111111111/111I Scanning is complete at this point unless rescanning is required. ReScanned 11I111111111111111I BY: Maria Date: Isl Comments about this file: Quality Checked 1111/1111111111111I 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA 1020360632 ,- ASKA OIL AND GAS CONSERVATION COMMioSION 11M11111111 11111111 REPORT OF SUNDRY WELL OPERATIONS + 1 Operations Abandon U Repair Well U Plug Perforations U Perforate141 v I��rrr1)t Other Li Pull Plug Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑, k-TirAe Ektension❑ Change Approved Program (J Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended WOO 2.Operator 4 Well Class Before Work: 5.Permit to Drill Number. Name: BP Exploration(Alaska),Inc Development Exploratory ❑ 205-019-0 3.Address: P O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-20774-03-00 7.Property Designation(Lease Number): 8 Well Name and Number. ADL0028309361S34 PBU 02-26C 9 Logs(List logs and submit electronic and printed data per 20AAC25 071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary: Total Depth measured 13006 feet Plugs measured None feet true vertical 9041 42 feet Junk measured None feet Effective Depth measured 12973 feet Packer measured See Attachment feet true vertical 9037.2 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 79 20"94#H-40 28-107 28-107 1530 520 Surface 2629 13-3/8"72#1-80 27-2656 27-2655.93 4930 2670 Intermediate None None None None None None Production9242 9-5/8"47#L-80 26-9268 26-7469.91 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12650-12850 feet 12890-12950 feet True Vertical depth 9042 26-9030 17 feet 9029.96-9034.44 feet SCANNED Jl/l U 62014 Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: RBDM . 2 2 2014 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 525 25251 42 0 1021 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15 Well Class after work: Copies of Logs and Surveys Run Explorator)Q Development❑✓ Service❑ Stratigraphic ❑ j Daily Report of Well Operations X 16 Well Status after work: Oil U Gas Li WDSPLU GSTOR ❑ WINJ ❑ WAG 0 GINJ 0 SUSP 0 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 0 Exempt: N/A Contact Garry Catron Email Garry.Catron a(�.BP.Com Printed Name Garry Catron Title PDC PE Signature OC4A.47 ( Phone 564-4424 Date 4/24/2014 /7-4-J7-- 5/Z4// 4- mss''/2 7/17 Form 10-404 Revised 10/2012 Submit Original Only i � Y N U co Y d U O ~ E O` r. •c U cow a �a2I- ci) o aX. 0_ N N 1L-c) ) N = m m Y Y _ _ C m CO N N N ti n 4 4 4 E L C) g0d 0) u op 04 O Lo cv rcog co Q Q CU H in iAelLN � OonOOD is" M CD aMO) a)) 0a r CU a cc cc CC CC CC to ill LU IJJ )▪UUUUU QQQQQ an. aaa m E00000 Z N N N N 3 0 0 0 0 0 w ,, TREE= 4-1/16"CIW --.___- _. 1 WELLFFAD= FMC-5M 02-26 PREVIOUS WE LBORES NOT SHOWN * T03' '"' " ACTUATOR= BAKER C INITIAL KB,ELEV 64' I BF E:1.EV 30.2' Z KOP- 2995' 20"CONDUCTOR --�10 { + 2123' H4-112"HES X NP,D=3.813" I Max Angle= 99°©12695' 91#,1+40, ' r Datum MD= 10903' 3055' 9.63'X 7"ZXPN LNR TOP PKR ID=19.124" Datum TVD= 8800'SS &FLEX-LOCK HGR,D=6.15 GAS LIFT MANDRELS 13-3/8"CSG,72#,L-80.ID=12.347" -4 2561' ST MD TVD DEV TYPE VLV LATCH PORT DATE TOP OF 7"SCAB ll]-[ 3065' I !1 3 3520 3494 23 KBG2 DOME BK 16 01/31/14 Minimum ID = 2.377" @ 11370' I I' 2 7036 6001 51 KBG2 SO BK 20 01/31/14 3-3/16"x 2-718"XO LSL SUB Y 1 9643 `7770 31 KBG2 DMY 8K 0 01/22114 17"SCAB LNR,26#,L-80 VAM TOP/BTC-M, 9111' , ' � 9106' -16KR TEBACK SLEEVE,D=7.500" .0383 bpf,D=6.276" 9113' -19.5/8"X 7"BKR ZXP PKR,D=6.313" 1 19-5/8"WHIPSTOCK(XX/XX/XX) H 9268• 8118' 117"TEBK ASSY w/CIRC PORTS 9-5/8"CSG,47#,L-80,D=8.68-1-Thi 10455 ABOVE LWR SEAL ID=6.17" 9118' -9-5/8'X 7"BKR HMC HGR,D=6313" 9-5/8"CSG MILLOUT WINDOW(02-2613)9268'-9286' I 11-_--1- 9760' I I4-1/2"FES X NP,D=3.813"1 z 4-1/2'TBG,12.8#,13CR-85 VAM TOR -4 9895 \, 9790'-1-17"X 4-112"HEs TNT PKR,D=3-856' I .0152 bpi,D=3.958" `1 8825' I-+4-1!2"HES X NP,D=3.813' I 14-1/2'TBG STUB(RIG 01/20/14) - 9899' I ( ) 991-137-1-17"X 4-1f2"UNIQUE OVERSHOT 10103' -13-1/2"BOT DER OY SLV,D=3.00" 1 �� 10122' -13-1/2"HOWOO X NP,D=2.813" I • 10152' H3-1/2"X 3-3/16"XO,D=2-786" Z I 10175' 1-7"X 4-1/2"BKR S-3 FKR,D=3.875'1 I al 10206' 1--14-1/2"FES XN NP,MLLED TO 3.80"(03/10/05) 4-1/2"TBG, 12.6#,L-80,.0152 bpf,D=3.958" I-I 10229' / \ 10226' (' X 4-1/2"BKR TBACK SLV,D=5-250" 1 10229' -4-1/2"WLEG,D=3.958" BEHIND 7"LNR,26#,L-80,.0383 bpf,D=6.276" 1-!__10413' 10232' -17"X 4-1/2"BKR ZXP PKR D=4.375" CT LNR I4-i/2'MECHAMCAL WHPSTOCK(03/08/05) 1-{ 10657' 66r 10239' -7"X 4-1/2"BKR HMC HGR,D=4.375" wIRA PIP TAG a10886' 11 4-1l2'COP(03/06/05) - 10770' ! 1 10600° EST TOP OF CEMENT PERFORATION SUARY MILLOUT WINDOW(02-28C)10657'-10665' REF LOG:MCNJCCUGR ON 03/20/05 MIA N •4%4„ ANGLE AT TOP FU : 95"@12650' ;4 ANGLE 11370" H - /16"X 2-7/8"X0,13=2.377" Note:Refer to Production DB for historical pert data SIZE SPF MHNAL Opn/Sqz SHOT SOZ I 2" 6 12650-12850 C 03/20105 7" • LNR ` 12973' --(MD 6 12890-12950 C 03/2W05 ••••i i p• .Q Oc 0 - • o• ° > .a) a) (...,-/ 0 0 a) 3H. a-0 W Q U o N o U W N 02 0 2 v• T_ as ° a. 3 c � in z J C) (n CC 00 c • o N -� N 0 m W O Cl) N r ON O \ E 'O O c CC J U) w in cti -i 0 0 < < 0 2 J U N p as co o .t O 2 ❑ co D -O . c E J "- ° a t F' U) < t c -c c ca Y a) N as c� o OF- o 0 .E Upm _c ca c ~ 0 - WO in W W Z * c cvi '- CC CO ° 0 2 ° Y a) 3 E co Z a) Q � > W CS:; J > - *Li.I U c o a� E 0 c Ns x N OUz 0OU w0 � 0in U c 0 d0 c m E c w O cc O W 0 F- '�. ° 'N ° E GG co _ cn ip = � Y u) cc H CC _JQ Q cn Y 2 al 05 o 0) u) c� 3 N o U _J in Z > a) N i C I n 2 - Cl ai Qco Y O °�a. 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O C U a) O n , C L L O Q L0 U -'— ° o 3 Lip > • a� o a -° m :C .c a) _ 3 O a . co ,ew@j o - � .c —o • Q3 E c o � �O roi � � -o c E o CL Y OU .Q r CO _ 71- c .3 T--- -- 3 " U-0 cn o 0• ; U a��i E c o m U CC r a� T U ro c N u3 -°a 0) 0 U a� cu .o U . RI �n Y U o 0, a) t j .� a a.@) -- > `� • 3 o c �-- a) .- 0 ° a) ic CI U a� c o E ro 3 a •Q'r U cD a) c°) a- 3 N -0 3 ns M U o 0 N CC -r. ° in is C ' cA .N ro = w 0 .1- in 12 a- Ca a O oo 0 U 2 ro os � E Q 0) o c3 0 (CS a) -O (Lf r a Y cA -6 o 0- a Q. c 3 0 N. E ) (n as ro o o (n -° a ° T o Q c = cC E m U o a s c c- a ( c a� . c o a 00 a) o m m 3 3 coo a� D E ctl a oLI- m e DE -6 ° —- o f 3 0 , 0 a _( = ,- c) .(1'»s- _ -) U � .� o co) � � U (..IJ UU > � oT Q� .. .E (s- Q :° � 000 © c = O : v Id- o c) 0 N N N .1t (n CO • SITATE ALASEA SEAN PARNELL, GOVERNOR ALASKA. OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 David Reem Engineering Team Leader q BP Exploration (Alaska), Inc. C�� P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02 -26C Sundry Number: 311 -257 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this of October, 2011. Encl. 1 00 ,?A'` TA F ALASKA - � ' • S TE O • „_,,,,/ . rlo' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ® Repair Well - ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate IS Pull Tubing- ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing - ® Other 7" scab liner 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development - ❑ Exploratory 205 -019 - 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 029 - 20774 - 03 - 00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 02 -26C - Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028308 & 028309 • Prudhoe Bay Field / Prudhoe Bay Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13006 - 9041 12973 - 9037- 10038' None Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 79' 79' 1490 470 Surface 2661' 13 -3/8" 2661' 2661' 4930 2670 Intermediate 9268' 9 -5/8" 9268' 7470' 6870 4760 Production Liner 1306' 7" 9105' - 10411' 7356' - 8434' 7240 5410 Liner 432' 4 -1/2" 10225' - 10657' 8272' - 8642' 8430 7500 Liner 2903' 3-1/2" x 3- 3/16 "x 2 -7/8" 10103' - 13006' 8167' - 9041' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12650' - 12950' (below plug) 9042' - 9034' (below plug) 4 - 1/2 ", 12.6# L - 80 10227' Packers and SSSV Type: 7" x 4 - 1/2" BKR S - Packer Packers and SSSV 10175' MD / 8229' ND MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory - ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: September 30, 2011 - ® Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Bjork, 564 -5683 Printed Name vid Reem Title Engineering Team Leader Prepared By Name/Number: Signature (. 41 Phone 564-5743 Date g) t 7-12,01; Elizabeth Barker, 564 -5674 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number W .,, 7 ❑ Plug Integrity VI BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance K 3 Soo ,s1 L3oP T:si- Other. Z SVC. P S L /`t rips 4.4.6-t -c 771; 1 (A"'`: Subsequent Form Required: `o_ 1/ D y if t Approved By: p APPROVED BY ¢ "~l ► ^^° r " r A 1 C OM MISSIONER P THE COMMISSION Date t I Form 10-403 Revised 11/201u u ` 4 MS 2 4 Submit In Duplicate &If .N dia240 • • b p G Pj eateraftrawffiyy 02 -26c Expense Rig Workover Scope of Work: Pull old 4 -W L -80 tubing, run and cement 7" scab liner. Change the 9- casing packoff. Re- complete with new 4 -W 13Cr -80 tubing and TNT packer at -9,800' MD. MASP: 2,370-psi Well Type: Producer Estimated Start Date: Sept 30, 2011 Production Engineer: James Russell Intervention Engineer: David Bjork Pre -Riq Work Request: W 1 Check all lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT -T & IC. F 2 CMIT -T x IA to 1,000 psi for 30 minutes. MIT - OA 1,000 psi for 30 minutes. Record LLR if necessary S 3 Bail 10' of sluggits on top of the WRP and set a junk catcher c joo3f' ,. E 4 Power Jet cut 4 -W L -80 tubing at -10,010' MD, -10' down on the second full joint above junk catcher (Reference tubing tally dated 09/11/00). F 5 CMIT -T x IA to 1,000 -psi for 10 minutes post cut. Circulate well with clean seawater and freeze protect to 2,000'. W 6 Set a 5 - / ISA BPV in the tubing hanger. - 1a,# $ P✓ (,• /h' Proposed Procedure: 1. MIRU Doyon 16. ND tree. NU and test BOPE with three preventers configured top down (annular, blind shears, mud cross and 3 - x 6" VBR's. Test the VBR's and annular to 3,500 -psi. Circulate out freeze protection fluid and circulate well to kill weight fluid through the cut. 2. Pull 4-W L -80 tubing from tubing from -10,010' MD. 3. Scrape the 9 casing and polish the 7" liner top. 4. RIH with test seals and a RTTS packer. Test the 7" liner and liner top. Test the 9 casing from 3,050' to surface. 5. Run a 7" RBP in the liner and cover with 20ft of sand. 6. Fully cement 7" L -80 BTC scab liner from -9,100' to 3,050'. (Note the 3 -1/2" x 6" VBR's will not be changed to 7" fixed as there will be two mechanical barriers to the reservoir while running the liner) [) w (ZP c 1003€ 7. Change the 9- / casing pack -off. GA L) R 1 Zoe atetto R 8. Retrieve 7" RBP. L'► Drat .4./ (`'"" 9. Pressure test the wellbore to 3,500 psi for 30 charted minutes. 10. Dress the tubing stub and scrape the 7" liner. 11. Retrieve the junk catcher. Retrieve the 4 - WRP. 12. Run 4 -W 12.6# 13Cr -85 VamTop tubing with HES TNT packer and overshot, set the packer at -9,800' MD. 13. Displace the IA to packer fluid and set the packer. 14. Test tubing and IA to 3,500 psi. Freeze protect to 2,200' MD. 15. Set BPV. ND BOPE. NU and test tree. RDMO. TREE= '4-1/16" FMC 5M is 1/fIRLHEAD= FMC 5M SAFETY•TES: WELL ANGLE> 70° @ 11703'. ACTUATOR = AXLESON O ** *ORIGINAL WELLBORE NOT SHOWN BELOW KB. ELEV = 58.7' WHIPSTOCK. 02 - 26A P &A'D W/ CMT * ** BF. ELEV = 30.2' KOP= 2995' Max Angle = 99 @ 12695' , 2219' I-14 -1 /2" HES X NIP, ID = 3.813" Datum MD = 10903' Datum TVD = 8800' SS GAS LIFT MANDRELS 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2661' ST MD TVD DEV TYPE VLV LATCH PORT DATE Ir 1 3708 3665 27 MMG DMY RK 0 03/05/06 2 7170 6085 51 MMG DMY RK 0 03/05/06 3 9574 7711 31 MMG DMY RK 0 09/19/00 Minimum ID = 2.377" @ 11370' -I 9105' I-IBKR TEBACKSLEEVE, ID= 7.500" I 3- 3/16 "x 2 -7/8" XO LSL SUB L I LI 9113' I -19- 5 /8 " X7 " BKR ZXP PKR, ID= 6.313" I 9118' H9-5/8" X 7" BKR HMC HGR , ID = 6.313" / 9 -5/8" CSG MILLOUT WINDOW (02 -26B) 9268' - 9286' I --I 10038' H4 -1/2" WRP (09/25/10) I ✓ 9 -5/8" CSG, 47 #, L -80, ID = 8.681" I-I 10455' 10103' -- I3 -1/2" BOT DEPLOY SLV, ID= 3.00" I I 10122' 1 HOWCO X NIP, ID = 2.813" I 10152' H3-1/2" X 3 -3/16" X0, ID = 2.786" I I 10175' 1-1r X 4 -1/2" BKR S -3 PKR, ID = 3.875" I 10206' I 4 -1/2" HES XN NIP, ID = 3.800" I 1 (MILLED 03/10/05) I 10225' 1-1r X 4-1/2" BKR TBACK SLV, ID = 5.250" I BEHI ND 1 4-1 /2" TBG, 12.6#, L -80, .0152 bpf, ID = 3.958" H 10229' I-4 J 10229' H4-1/2" 1MLEG, ID = 3.958" ( PIPE ll 10232' Hr X 4-1/2" BKR ZXP PKR, ID = 4.375" I 10239' 1-1r X 4-1/2" BKR HMC HGR, ID = 4.375" I 17" LNR, 26 #, L -80, .0383 bpf, ID= 6.276" I-i 10413' I- • 10600' 1-1 EST TOP OF CEMENT I K 7 !MECHANICAL WHIPSTOCK (03/08/05) I-1 10657' 4 a I MILLOUT WINDOW (02- 26C) 10657' - 10665' K IRA PIP TAG I-I 10666' CIBP (03/06/05) --I 10770' •' � **' I 11370' H LSL SUB 3- 3/16" X 2 -7/8" XO, ID = 2.377" I PERFORATION SUMMARY REF LOG: MCNUCCUGR ON 03/20/05 ANGLE AT TOP PERF: 95 @ 12650' Note: Refer to Production DB for historical pert data ` SIZE SPF INTERVAL Opn/Sqz DATE 12973' -I PBTD I 2" 6 12650 -12850 C 03/20/05 '•'•-∎ 44%* 2" 6 12890 -12950 C 03/20/05 _ **��� *�� 2 -7/8" LNR, 6.16#, L-80, STL, 13006' ��� 14-1/2" LNR, 12.6#, L -80, .0152 bpf, ID = 3.958" 1-1 12707' I .0058 bpf, ID = 2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/02/82 ORIGINAL COMPLETION 1 1 02/04/09 MGM/SV PULL KB PATCHES (01/24/09) WELL: 02 -26C 06/28/97 CTD SIDETRACK (02 -26A) 02/15/09 KDC/SV SET WRP (02/10/09) PERMIT No: 205 -019 09/13/00 RIG SIDETRACK (02 -26B) 02/26/09 PJC PULL PX/ SET 1NRD (02/10/09) API No: 50- 029 - 20774 -03 03/21/05 NORDIC 1 CTD SIDETRACK (02 -26C) ; 09/26/10 JKC/PJC PULL/ RESET WRP (09/24- 25/10) SEC 35, T11 N, R14E 3716' NSL & 6' WEL 09/21/08 JRA /SV SET KB PATCH EXT (09/17/08) 12/09/08 SEW /SV SET KB PATCH EXT (12/06/08) ! BP Exploration (Alaska) TREE , 4 - 1/16" FMC 5M SAFETYES: WELL ANGLE 70° 11703'. V17ELLHEAD = FMC 5M 02-26C ** *ORIGINAL W ELLBORE NOT SHOWN BELOW KB ELEV = = AXL 58 Proposed RWO WHIPSTOCK. 02 -26A P &A'D W/ CMT * ** BF. ELEV = 30.2' KOP = 2995' Max Angle = 99 © 12695' Datum MD = 10903' 1 2,000' H3.813" HES 'X' Nipple I Datum TVD = 8800' SS 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2661' 1 i I — I 3,050' 1 19 - 5 /8" x 7" Liner Top I 14 -1/2" 12.6# 13Cr -85 Tubing H 10,010' 1 Y IT LNR, 26#, L -80, .0383 bpf, ID = 6.276" I--I 9,105' I n I 91W I -j I ic01/1 9,853' I— {3.813" HES 'X' Nipple 1 9 , 8 84 ' H r x 4 - 1 /2" HES'TNT Packer 1 9,918' H3.813" HES'X' Nipple I — I 9,976' 1 13.725" HES 'X' Nipple I 19 -5/8" CSG, 47 #, L -80, ID = 8.681" H 10455' I lo 3-12' F HROI8V, D 3�' 9 -5/8" CSG MILLOUT WINDOW (02 -26B) 9268' - 9286' 10122' 3 - 1/2" HOWCO X NIP, ID = 2.813" I 10152' I-I 112" X 3-3/16" XO, ID = 2.786" I Minimum ID = 2.377" @ 11370' 3- 3116 "x 2 -7/8" XO LSL SUB /I 10175' HT X 4 -1/2" BKR S-3 PKR, ID = 3.875" I / BEHIND 10206' I — 4-1/2" HES XN NIP, ID = 3.800" BEHIND (MILLED 03/10/05) PIPE 1 4-1 /2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" I—I 10229' I — _ _ 71 42' Tc I 1 29 - �4- VZ �3 ' l 17" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" I-i 10413' 1 L I 10600' HEST TOP OF CEMENT 1 'MECHANICAL WHIPSTOCK (03/08/05) H 10657' io 4 i MILLOUT WINDOW (02 10657' - 10665' I RA PIP TAG H 10666' I CIBP (03/06/05) I—I 10770' liatiiiiz.. I 11370' I --ILSL SUB 3-3/16" X 2 -7/8" XO, ID = 2.377" I / PERFORATION SUMMARY REF LOG: MCNUCCUGR ON 03/20/05 ANGLE AT TOP PERF: 95 @ 12650' Note: Refer to Production DB for historical perf data 12973' PBTD 6 SIZE S INTERVAL Opn /Sqz DATE 2" 6 12650 50 - - 12850 C 03/20/05 ∎••j••�j 2" 6 12890 -12950 C 03/20/05 �•�•���� 2 -7/8" LNR, 6.16#, L -80, STL, 13006' -� v 14 -1/2" LNR, 12.6#, L -80, .0152 bpf, ID = 3.958" I—I 12707' 1 .0058 bpf, ID= 2.441" DATE REV BY COMMENTS 1 DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/02/82 ORIGINAL COMPLETION 02/04/09 MGM/SV PULL KB PATCHES (01/24/09) WELL: 02 - 26C 06/28/97 CTD SIDETRACK (02 -26A) 1 02/15/09 KDC/SV SET WRP (02/10/09) PERMIT No: 205 -019 09113/00 RIG SIDETRACK (02 -26B) I 02/26/09 PJC PULL PX/ SET WRD (02/10/09) API No: 50- 029 - 20774 -03 03121/05 NORDIC 1 CTD SIDETRACK (02 -26C) 1 09/26/10 JKC/PJC PULL/ RESET WRP (09/24- 25/10) SEC 35, T11 N, R14E 3716' NSL & 6' WEL 09/21/08 JRA /SV SET KB PATCH EXT (09/17/08) 12/09/08 SEW /SV SET KB PATCH EXT (12/06/08) ! BP Exploration (Alaska) Cb 11:'1 Page 1 of 1 `14(ASO Hubble, Terrie L From: Colombie, Jody J (DOA) [jody.colombie @alaska.gov] Sent: Wednesday, October 19, 2011 11:25 AM To: Schwartz, Guy L (DOA); Hubble, Terrie L �"� Cc: Bjork, David 1 i Subject: RE: 10-403 for PBU 02 -26C / PTD # 205 -019 Al e Oil & Gas Cons. Commission Commission +iF dress It to me, so I can give it the correct number and to assure no duplication." �� .� POR From: Schwartz, Guy L (DOA) Sent: Wednesday, October 19, 2011 11:22 AM To: Hubble, Terrie L Cc: Bjork, David; Colombie, Jody J (DOA) Subject: RE: 10 -403 for PBU 02 -26C / PTD # 205 -019 Terrie, Unfortunately we have misplaced this document... I apologize. Can you please send us another copy and we will expedite as best we can. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Hubble, Terrie L [mailto:Terrie.Hubble @bp.com] Sent: Tuesday, October 18, 2011 2:26 PM To: Schwartz, Guy L (DOA) Cc: Bjork, David Subject: 10 -403 for PBU 02 -26C / PTD # 205 -019 Hi Guy, Recently I was reviewing outstanding approvals (not yet received back from the AOGCC) and I identified this 10- 403 as one that has been at the AOGCC for quite some time and I worried that it has gotten misplaced. We are not in a particular hurry for it as the work has been pushed out a bit, but just to clean up my paperwork, I thought I should see about it. This 10-403 was sent over to the AOGCC on August 17th and work was planned to begin September 30th. Thanks for looking into this for us. Terrie 10/19/2011 • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August 22, 2011; E cip 4) Mr. Tom Maunder cc6 Alaska Oil and Gas Conservation Commission . t99 333 West 7 Avenue ~Y7ct Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS -02 c,®' 0 I 7 a,--' lr Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -02 Date: 07/21/2011 Vol. of Corrosion Initial top of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 02-01B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -06B 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -08B 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -136 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -228 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -306 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -32B 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -338 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -34B 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -35B 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02 -40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 • • MICROFILMED 03/01/2008 DO .NOT PLACE ,. x ; ANY NEW MATERIAL UNDER THIS PAGE F:~I,aserFichelCvrPgs_Inserts~Rtiticmfilm Ma~er.doc )l ~v~ ~ DATA SUBMITTAL COMPLIANCE REPORT 4/11/2007 Permit to Drill 2050190 Well Name/No. PRUDHOE BAY UNIT 02-26C Operator BP EXPLORATION (ALASKA) INC MD 13006 TVD 9041 Completion Date 3/21/2005 Completion Status 1-01L Current Status 1-01L ~.- --~----- REQUIRED INFORMATION Mud Log No Samples No Ì). ~ Pl~ r API No. 50-029-20774-03-00 UIC N Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD GR / EWR, MGR / CCL / CNL Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Electr Data Digital Dataset Type Med/Frmt Number Name r D Asc Directional Survey og Neutron i / f.-ÉD C Lis 13242 Neutron I .,rED D Lis 13327 I nd uction/Resistivity I ~D C Lis 13602 I nd u ction/Resistivity fOg Leak Log Log Run Scale Media No Interval OH/ Start Stop CH Received 10649 13006 Open 4/27/2005 9797 12882 Case 7/14/2005 9797 12883 Case 7/14/2005 10500 12958 Open 1 0/26/2005 10665 13006 Open 2/22/2006 75 10100 Case 8/10/2006 2 Blu 15 Blu ~- -.._~~-~- Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? Y7-r::¡- ~/N (J>/N Daily History Received? Formation Tops Analysis Received? ~ ------ ------~- ---<-------_._--~.__.._---~-~-- -_._._--._~------,_._-- ----~._--- ~."----~_.._.-._-~-_._----_._----_._-_._---_._----_._-,--_._--~-- Comments: e Comments ----- MCNL Memory GRlCCUCNL MCNL Memory GRlCCL/CNL GR EWR4 ROP ROP DGR EWR plus Graphics LDL, PRES, TEMP, CCL, GR, GRADIO, ILS, FBS 16- May-2006 __ _-------1 e "--~._-_.~----,._,._--- DATA SUBMITTAL COMPLIANCE REPORT 4/11/2007 Permit to Drill 2050190 Well Name/No. PRUDHOE BAY UNIT 02-26C Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20774-03-00 MD 13006 TVD 9041 -....-."- ~c:P"t;O" D." 3/21/2005 Completion Status 1-01L Current Status 1-01L UIC N Date: }¿ tLp~? ---~ Compliance Reviewed By: e e 02-26C (PTD# 2050190) Classified as problelell e All, Well 02-26C (PTD# 2050190) has been found to have sustained casing pressure on the IA. The TIO pressures were 2320/2340/360 on 04/08/07 when the well failed a TIFL. The plan forward for the well is as follows: 1. D: TIFL - FAILED 2. F: MITIA to 2500 psi, establish LLR if possible 3. WIE: Eval for an LDL A well bore schematic has been included for reference. «02-26C.pdf» The well has been classified as a Problem well. Please call if you have any questions. Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: 02-26C.pdf 02-26C.pdf Content-Type: application/octet-stream Content-Encoding: base64 .:J-A. ~f ----- 60ÎOr¡" '5¿f 2-~'Ps; 3-t'~ ~f; òk- r' eo +'ìz.- « 4¢~ W;;Jf) 1 of 1 4/1 0/2007 1: 17 PM 02-26C SA OTES: WELL ANGLE> 700@11141'&> 90° @ 12015', PRE- 02-26B SDTRK WELLBORE NOT SHOWN BELOW WHIPSTOCK. 02-26A P&A'D W/CMT, 30.2' '^~='" 2995' ,v==~_·'___·^",v.,,,,_ 99 @ 12695' 10903' 8800' SS 113-3/8" CSG, 72#, L-80, 10'" 12.347" I 2219' --14-1/2" HES X NIP, 10 = 3.813" Minimum ID = 2.377" @ 11370' 2-7/8" STL LNR ST MO TVO 1 3708 3655 2 7170 6085 3 9574 7711 GAS LIFT ~AANORELS OE\! TYPE VLV LATCH 27 MMG OMY RK 51 MMG OMY RK 31 MMG OMY INT PORT OATE o 03/05/06 o 03/05/06 o 09/19/00 14-1/2" LNR, 12.6#, L-80. .0152 bpf, 10'" 3.958" 6222' - 6657' 4-1/2" BKR "KB" PATCH. 10 = 2.45" (10/06/06) -18KR TIEBACK SLEEVE, ID = 7.500" I H 9-5/8" X 7" BKR ZXP PKR. 10 = 6.313" -19-5/8" X 7" BKR HMC HGR , 10 = 6.313" ] I 9-5/8" CSG, 47#, L-80. ID = 8.681" I 9-5/8" eSG MILLOUT WINDOW (02-26B) 9268' - 9286' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" I 10229' --13-1/2" BOT OEPLOY SL V, 10 = 3.00" --13-1/2" HOWCO X NIP, 10 = 2.813"1 --13-1/2" x 3-3/15" XO, 10 = 2.786" I H 7" X 4 -1/2" BKR S-3 PKR, ID = 3.875" I 4-112" HES XN NIP, 10 = 3.800" (MILLED 03/10/05) --17" X 4-1/2" BKR TBACK SlV, ID = 5.250" --14-1/2" WLEG, ID = 3.958" I --1 T' X 4-1/2" BKR ZXP PKR, ID = 4.375" I --17" X 4-1/2" BKR HMC HGR, 10 = 4.375" I --1 EST TOP OF CEMENT I BEHIND PIPE 17" LNR, 26#, L-80, .0383 bpf, 10 = 6.276" I I MECHANICAL WHIPSTOCK (03/08/05) I IRA PIP TAG I I CIBP (03/06/05) I MILLOUT WINDOW (02-26C) 10657' - 10665' PERFORA TION SUIV1MARY REF LOG: MCNLlCCLlGR ON 03/20/05 ANGLE AT TOP PERF: 95 @ 12650' Note: Refer to Production DB for historical perf data ERV AL Opn/Sqz OA TE 12650 - 12850 0 03/20/05 2" 12890 - 12950 0 03/20/05 2-7/8" LNR, 6.16#, L-80. STL, .0058 bpf, 10 = 2.441" COMMENTS ORIGINAL COM PLETION CTD SIDETRACK (02-26A) IG SIDETRACK ( 03/21 NOR CTD SIDETRACK (02- 03/05/06 DA V /PJC GL V C/O 09/27/06 TWSIPAG PULL XX PLUG @ 1011 REV BY COMMENTS GJB/TLH SET PA TCH @ 6222' - 6657' FT CORRECTION PRUDHOE BAY UNIT WELL 02-26C PERfvIIT No: 205-019 API No: 50-029-20774-03 SEC35, T11N, R14E3716' NSL & 6' WEL BP ExploratiQn (Alaska) " .. STATE OF ALASKA . ALASØ"OIL AND GAS CONSERVATION COM . SION REPORT OF SUNDRY WELL OPERATIONS') D . ("'I 2,7' '··';;;'.,.f' t\ , .,? r' ?', f'. , ., 1. Operations Performed: ..., " , .~ ....".."0>.. ""'.. Abandon 0 Repair WellŒ! Plug PerforationsD Stimulate 0 "'"'' "'~:nIÌlät[] i'--'t:¡ ,d!.,~ 10>:' .,' Alter CasingD Pull TubingD Perforate New PoolD WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate D Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 00 ExploratoryD 205-0190 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicD ServiceD 50-029-20774-03-00 7. KB Elevation (ft): 9. Well Name and Number: 58.70 02-26C 8. Property Designation: 10. Field/Pool(s): ADL-0028308 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 13006 feet true vertical 9041.0 feet Plugs (measured) None Effective Depth measured 12973 feet Junk (measured) None true vertical 9037.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 52 20" 91.5# H-40 27 - 79 27.0 - 79.0 1490 470 SURFACE 2636 13-318" 72# L-80 26 - 2661 28.0 - 2675.0 4930 2670 PRODUCTION I 9243 9-5/8" 47# L-80 25 - 25.0 - 6870 4760 PRODUCTION 9-5/8" 47# SOO-95 9268 7447.0 8150 5080 LNR TIEBACK 1308 7" 26# L-80 9105 - 10413 6615.0 - 7316.0 8160 7020 LINER 432 4-112" 12.6# L-80 10225 - 10657 7316.0 - 8792.0 8430 7500 LINER 49 3-1/2" 8.81# L-80 10102 - 10151 8671.0 - 8712.0 10160 10530 LINER 1219 3-3/16" 6.2# L-80 10151 - 11370 8712.0 - 8926.0 8520 7660 LINER 1636 2-7/8" 6.16" L-80 11370 - 13006 8926.0 - 8872.0 13450 13890 Perforation depth: Measured depth: 12650-12850,12890-12950 True vertical depth: 9042-9030,9030-9034 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 22 - 10227 Packers & SSSV (type & measured depth): 4-1/2" Baker Patch @ 6222 - 6657 9-5/8" Baker ZXP Packer @ 9113 7" Baker S-3 Packer @ 10175 7" Baker ZXP Packer @ 10232 4-1/2" HES X Nipple @ 2219 12. Stimulation or cement squeeze summary: ~r:'n)M\j tst't OCT 3 :¡ 2006 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 441 19533 41 --- 1641 Subsequent to operation: 519 25094 49 --- 1241 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations_ ~ OilŒ] GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr Title Petroleum Engineer .II ,J ~ J:.. jI Signature .ÁJ,.S\.. ;;ø, Phone 564-5174 Date 1 0/26/06 u \. Form 10-404 Revised 4/2004 . . 02-26C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY AWGRS 09/27/2006 (pre patch) RAN 10' x 2.25" P.BAILER TO 10112' SLM, RECOVERY BARREL 1/4 FULL OF WHAT APPEARS TO BE CALCIUM CARBONATE & PIECES OF METAL PULLED 3.5" XX-PLUG FROM 10114' SLM DRIFT FOR PRE-PATCH WI 20' x 3.70" DUMMY WHIPSTOCK TO 6900' SLM (TARGET DEPTH = 6700') *** LEFT WELL SHUT IN *** AWGRS 10105/2006 T/I/0=360/vac/330. Temp=SI. TBG & IA FL's (pre patch). TBG FL 1445'. IA FL @ 108'. IA has Integral installed. AWGRS 10106/2006 WELL SHUT IN ON ARRIVAL SET 4-1/2" BAKER PATCH FROM 6622' - 6657'. 400101 340. TURNED WELL OVER TO DSO. MINIMUM ID THROUGH PATCH = 2.45" OAL = 42' Pull wla 41/2" gs JOB COMPLETE. WELL LEFT SHUT IN. FINAL TI 110 = 4501 01 340. AWGRS 10108/2006 T/I/O=30010/320 MIT IA 2500 psi (Restore tubing integrity) Failed due to unstabile pressure readings. lost 110 psi 1 st 15 min, lost 90 psi 2nd 15 min, held for an aditinal15 min & lost 60 psi. Pumped 5 bbls neat meoh, 52 bbls crude down IA to test @ 2500 psi. Bled well to normal pressures. FWHP's=28010/360 AWGRS 10/22/2006 T/I/O=350/530/340. Temp=SI. No AIL. Remove NFT tagging. (DSO to POP well). AWGRS 10/24/2006 TIO = 1500/700/440. Temp = 60 deg. No AL. TIFL - PASSED (post patch) post POP - problem well, day 2. IA FL @ surface. SI well, stacked TBGP from 1500 psi to 2140 psi in 30 mins. lAP decreased to 470 psi, IA FL unchanged. Monitored 1 hr. lAP decreased 470 psi and went on a vac, IA FL fell from surface to 40'. TBGP decreased 20 psi. OAP unchanged. FWHPs = 2120/vac/440. BBLS 1 Diesel --- PT Surface Equipment 5 Methanol Water 52 Crude 58 TOTAL FLUIDS PUMPED Page 1 c TREE = 4-1/16" FMC 5M WELLHEAD = FMC-5M ACTUA TOR = AXLESON KB. ELEV = 58.7' BF. ELEV = 30.2' KOP = 10657' Max Angle = 99.2" @ 12695' Datum MD = 10918' Datum TVO = 8800' SS . 02-26C SAFErYIÐTE5: VVELLAN3.E> 70"@11175' & > 90" @11275'. PÆ- Q2-26BSDrn<VIÆl.1.B::R: f\OT SIÐ.I\rt.I EEl.DJVVlHPSTOO<. Q2-26A P~D WCMT. FROM CTD DRLG DRAFT 113-3/8" CSG, 72#, L-80, 10 = 12.347" I Minimum ID = 2.37" @ 11370' 2-7/8" STL LNR 19-5/8" CSG, 47#, L-80, 10 = 8.681" H 1 TOP OF WHIPSTOCK 9-5/8" CSG MILLOUT WINDOW (02-26B) 9268' - 9286' (OFF WHIPSTOCK) 19-5/8" EZSV RETAINER I TOP OF 3-112" X 3-3116" X 2-7/8" LNR 4-112" TBG, 12.6#. L-80, .0152 bpf. 10 = 3.958"1 17" x 4-1/2" BKR ZXP PKR, 10 = 4.375" I 17" X 4-1/2" BKR HMC HGR, 10 = 4.375" H 17" LNR, 26#, L-80, ID = 6.276" I MECHANICAL WHIPSTOc1 10657' I WINDOW H 10657' - 10665' I I RA PIP TAG H 10666' I ÆRFORA TION SUMMARY REF LOG: MCNLlCCLlGR OF 3/20/2005 TIE-IN LOG: GEOLOGY PDC LOG ANGLE AT TOP ÆRF: 97.35" @ 12660' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 2" 6 12650' - 12850' 0 03/20/04 2" 6 12890' 12950' 0 03/20/04 I PBTD I 14-1/2" LNR, 12.6#. L-80, .0152 bpf, 10 - 3.958" I DA TE REV BY COMMENTS 08/02/82 ORIGINAL COMPLETION 06/28/97 CTD SIDETRACK (02-26A) 09/13/00 RIG SIDETRACK (02-26B) 08/17/03 CMOITLP ÆRFANGLECORRECTION 03/21/05 JUE NORDIC-1 CTD SIDETRACK 04/05/05 WWRITL GL V C/O 2219' - 4-1/2" HES X NIP. 10 = 3.813" I GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH 1 3708 3665 27 MMG-M DMY RK 2 7170 6023 51 MMG-M *DMY RK 3 9574 7711 31 KGB-2-LS DMY INT * EXTENDED PACKING 6222'-6657' -14-1/2"7 BKR PATCH. 10 = 2.45" I PORT OA TE o 03/05/06 o 03/05/06 o 09/19/00 9105' 9113' 9118' - BAKER TIEBACK SLEEVE. 10 = 7.500" I -49-5/8" X 7" BKR ZXP PKR. 10 - 6.313" I -19-5/8" X 7" BKR HMC HGR, 10 = 6.313" I -1 BOT DEPLOY SLEEVE, 6' LONG, 3" 10 ~3-1/2" X NIP, ID - 2.813" I 3-1/2" X 3-3/16" X-OVER 7" X 4 1/2" BKR S-3 PKR, 10 = 3.875" 4-1/2" HES XN NIP, 10 MILLED TO 3.8" I BKR TIEBACK SL V, 10 - 5250" I 4-1/2" WLEG, 10 = 3.958" I ELMO TT NOT LOGGED I I -f PBTO 3-3/16" X 2-7/8" CMT'ED & ÆRFED -i 13006' I ...J CIBP PT TBG TO 3000# OK I I 10832' H20' MARKERJT I DA TE REV BY COMMENTS 03/01/06 OAV/PJC GLV C/O 03/16/06 JLJITLH XX PLUG SET 09/27/06 TWS/PA PULL XX PLUG @ 10114' SLM 10/06/06 GJBITLH PATCH SET PRUDHOE BA Y UNfT WELL: 02-26C ÆRMfT No: 205-019 API No: 50-029-20774-03 SEC 35, T11 N. R14E 3716' NSL & 6' WEL BP Exploration (Alaska) <.". STATE OF ALASKA . ALa OIL AND GAS CONSERVATION COM ION REPd'ftT OF SUNDRY WELL OPERATIONS D D D 1. Operations Abandon D Repair Well 0 Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 8. Property Designation: 58.7 KB ADLO-028309 11. Present Well Condition Summary: Total Depth Effective Depth Casing Conductor Surface Production Liner Liner Liner Perforation depth: measured true vertical measured true vertical Length 80' 2639' 9265' 3055' 432' 2903' RECEIVED OCT 1 9 2006 StimulateD Ot er as Cans r.'>:n . . -'·....ffll~S WaiverD Time Extension D Anchorage s n Re-enter Suspended Well D 5. Permit to Drill Number: 205-0190 Exploratory Service 9. Well Name and Number: 6. API Number: 50-029-20774-03-00 PBU 02-26C 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool 13006 feet Plugs (measured) None 9041 .42 feet Junk (measured) None 12793 feet 9029.52 feet Size MD 20" 91.5# H-40 Surface - 79' 13-3/8" 72# L-80 Surface - 2661' 9-518" 47# L-80 Surface - 9268' 7" 26# L-80 9105' 10411' 4-1/2" 12.6# L-80 10225' - 10657' 3-1/2"x3-3-3/16"x2-7/8" 10103' - 13006' Measured depth: 12650 - 12850 True Vertical depth: 9042.26 - 9030.17 12890 - 12950 9029.96 - 9034.44 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# Packers and SSSV (type and measured depth) 7"x4-1/2" BKR S-3 PKR o o o 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 Gas-Met Water-Bbl Casing Pressure 21058 40 0 o 0 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG Oil-Bbl 370 SHUT IN Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x TVD Surface - 79' Surface - 2661' Surface - 7470' 7356' - 8434' 8272' 8642' 8167' - 9041' - L-80 Burst 14590 5380 6870 7240 8430 10530 8520 1 0570 34' - 10227' 10175' o o o Collapse 470 2670 4760 5410 7500 10160766011160 Tubing pressure 1570 o Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Signature Title WINJ Data Engineer WDSPL Date 10/17/2006 Submit Original Only . . 02-26C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~ 9/26/2006 ***WELL S/I UPON ARRIVAL*** (pre patch) RAN EQU PRONG (HAD METAL RING) RAN 3.5" GS COULDN'T LATCH 3.5" XX PLUG ***CONT ON 9/27/06*** 9/27/2006 ***CONTINUED FROM 9-26-06***(pre patch) RAN 10' x 2.25" P.BAILER TO 10112' SLM, RECOVERY BARREL 1/4 FULL OF WHAT APPEARS TO BE CALCIUM CARBONATE & PIECES OF METAL PULLED 3.5" XX-PLUG FROM 10114' SLM DRIFT FOR PRE-PATCH W/20' x 3.70" DUMMY WHIPSTOCK TO 6900' SLM (TARGET DEPTH = 6700') *** LEFT WELL SHUT IN *** 10/5/2006 T/I/0=360/vac/330. Temp=SI. TBG & IA FL's (pre @ 108'. IA has Integral installed. TBG FL 1445'. IA FL 10/6/2006 WELL SHUT IN ON ARRIVAL SET 4-1/2" BAKER PATCH FROM 6622' - 6657'. 450/0/340. TURNED WELL OVER TO DSO. MINIMUM ID THROUGH PATCH = 2.45" OAL = 42' Pull w/a 41/2" gs JOB COMPLETE. WELL LEFT SHUT IN. FINAL T/ 1/0= FLUIDS PUMPED I METH CRUDE TOTAL BBLS 5 52 57 02-26C (PTD 2050190) Classified as a Problem Well . . Hello all. Well 02-26C (PTD 2050190) has been classified as a Problem well. A patch was set and a subsequent MITIA failed on pressure stabilization. Objective is to bring the well online, allow the patch to reach operating temperatures and re-evaluate tubing integrity with a TIFL. TIO's on 10/08/06 are 300/0/320. A CMIT TxlA passed to 2500 psi on 5/15/06. Current plans are as follows: 1. Operator: POP the well 2. DHD: Re-TIFL Attached is a wellbore schematic. Please call with any questions. «02-26C. pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploratìon, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100,x1154 Emai!: NSUADWWelllntegrityEngineer@bp.com From: Austin, Paul A Sent: Saturday, October 14, 2006 1:31 PM To: NSU, ADW Well Integrity Engineer Subject: 02-26 Swapped from Trouble to Problem Joe, A tubing patch was set on 10/06/06 from 6622' to 6657' in well 02-26 to restore tubing integrity. Following the patch set the well failed a MITIA to 2500 psi. I suggest we swap the status of this well from Trouble to Problem. Such that, we may POP the well, allowing it to stabilize, then perform a TIFL to attempt to establish tubing integrity after the patch is given opportunity to set. I have updated the Planned action in AnnComm to follow this suggestion, but I have not changed the status of the well. have also added this job to the DHD worklist. Let me know if you have any questions or concerns. Thank you, lof2 10/16/20069:35 AM 02-26C (PTD 2050190) Classified as a Problem Well . Paul Austin Well Integrity Engineer x5525 . Content-Description: 02-26C.pdf 02-26C.pdf Content-Type: application/octet-stream Content-Encoding: base64 20f2 10/16/2006 9:35 AM FMC-5M ON 58.7' 30.2' 1 0657' Max Ar;~le = 99.2" @12695' Datum MD = 10918' Datum TVD = 8800' SS . 02-26C FROM eTD DRLG DRAFT SAFETYr.DTE5: WB..LAIG..E> 7(1) @11175 & > 90"@11275'. PÆ-02-26BSIJ'IR(~ !\Dr SI-OI\R'II FEDNIMiPSTOCK. 02-26Ä P&A:D WI GMT. 1'3-3/8" CSG, 72#, L-80, ID = 12.347" 2219' -14-1I2"HESXNIP, 10=3.813" I Minimum ID == 2.31" @ 11310' 2-1/8" STL LNR ST MD TVO 1 3708 3665 2 7170 6023 3 PORT DATE o 03/05/06 o 03/05/06 o 09/19/00 MECHANICAL WHIPSTOCK 10657' I WINDOW H 10657' - 10665' I 1 RA PIP TAG H 10666' I 9105' 9113' 9118' -i BAKER TIEBACK SLEEVE, 10 = 7.500" , -19-5/8" X 7" BKR ZXP PKR, 10 = 6.313" I -i 9-5/8" X 7" BKR HMC HGR , 10 = 6.313" I 19-518" CSG, 47#, L-80, 10 = 8.681" H I TOP OF WHIPSTOCK 9265' 9-5/8" CSG MILL OUT WINDOW (02-268) 9268' - 9286' (OFF WHIPSTOCK) 19-5/8" EZSV RETAINER I -I BOT DEPLOY SLEEVE, 6' LONG, 3" ID ~3-1/2" X NIP, ID=2.81:1" I TOP OF 3-1/2" X 3-3/16" X 2-7 i8" LNR 3-1/2" X 3-3/16" X-OVER 7" X 41/2" BKR S-3 PKR, ID = 3.875" 4-1/2" HES XN NIP, 10 rv11LLED TO 3.8" I BKR TIEBA CK SL V, ID = 5.250" I 4-1/2" WLEG, 10 = 3.958" I ELMO TT NOT LOGGED ~ EST TOP OF CEMENT I 4-1/2" T8G, 12.6#, L-80, .0152 bpf, ID = 3.958"1 IT' X 4-1/2" BKRZXPPKR, 10=4.375" H I T' X 4-1/2" BKR HMC HGR, 10 = 4.375" H IT' LNR, 26#, L-80, 10 = 6.276" I -J LSL SUB, 3-3/16 x 2-7/8 X-OVER I ÆRFORA TION SUMMARY REF LOG: MCNLlCCLlGR OF 3/20/2005 TIE-IN LOG: GEOLOGY PDC LOG ANGLEATTOPÆRF 97.35"@ 126W Note: Refer to Production 08 for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 12650' - 12850' 0 03/20i04 2" 6 12890' - 12950' 0 03/20/04 13006' I I 10832' H20' MARKER JT I I PBTD I 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I DATE REV BY COMMENTS 08/02/82 ORIGINAL COM PLETION 06/28/97 CTD SIDETRACK (02-26A) 09/13/00 RIG SIDETRACK (02-26B) 08/17/03 CMO/TLP ÆRF ANGLE CORRECTION 03/21105 JUE NORDlC-, CrD SIDETRACK 04/05105 WWRlTL GL V C/O 12622' 12707' DA TE REV BY COMMENTS 03101/06 DAV/PJC GLV C/O 03116/06 JLJfTLH XX PLUG SET 09/27/06 TWS/PA PULL XX PLUG @ 10114' SLM 10/06/06 GJBfTLH PATCH SET PRUDHOE BA Y UNrT WELL: 02-26C ÆRMrT No: 205-019 API No: 50-029-20774··03 SEC 35, T11 N, R14E 3716' NSL & 6' WEL BP Exploration (Alaska) Schlum~erger RECEIVED NO. 3907 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth ,:\UG 1 0 2006 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ aska Cil & Gas Cons. Commission Anchorage 9~ -ol~ Field: Prudhoe Bay Well Job# Loa DescriDtion Date BL Color CD 02-16B 11209601 MEM PROD PROFILE 04/25/06 1 15-21 11221558 Vt:y 04/03/05 1 16-01 1105228 INJECTION PROFILE 07/21/05 1 16-01 10980601 INJECTION PROFILE 08/15/05 1 D.S 11-08 11223100 INJECTION PROFILE 02127/06 1 D.S. 02-26C 11223117 LDL 05/16/06 1 09-09 11211484 PROD PROFILE W/DEFT 04/28/06 1 18-33A 11258719 LDL 06/08/06 1 X-07A 11217272 US IT 08/05/06 1 D-03A 11243918 SCMT 06/02/06 1 D-03A 11217271 US IT 08/04/06 1 Z-19 11217273 US IT 08/06/06 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 08/08/06 . . 02-26C (PTD #2050190) Classified as Problem Well All, Well 02-26C (PTD #2050190) has been found to have sustained casing pressure on the IA. The TIO's on 02/23/06 were 2180/2180/420 and the well failed a TIFL. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: Set DGL V in Sta #1 & 2 3. DHD: TIFL ~Á. ôA S;C-P .---. ¿'fP{5I' 4ZO.psí M3-'t-f S43l/fS,' 6870fsi ~M.YtP '25", q ~ 6.1 If" < 4Ç% JvV«f; ct ( p-e- cø 4 C;'Z A well bore schematic has been included for reference. «02-26C.pdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you, )lnna (j)u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: 02-26C.pdf Content-Type: application/octet-stream Content-Encoding: base64 I of I 2/27/2006 12:23 PM TREE = 4-1/16"FMC5M WELLHEAO = FMC-5M ACTUA TOR = AXLESON KB. ELEV = 5B.7' 30.2' KOP = 10657' Max Angle = 99.2" @ 12695' Datum MO = 1091B' Datum TVD - BBOO'SS . 02-26C FROM CTD DRlG DRAFT SNETYNJTE5: W8.l.A/In.E>70"@11175' &> 90" @11Zl5'. Pf6. Q2-26B5IJTR{1IIIElLB:H: f\.Of SI-OIVN æ..cN\fWHPSlOO< Q2.26A P&A:D WI OVIT. 2219' -14-1/2" HES X NIP, ID = 3.B13" 1 13-3/B" CSG, 72#, L-BO, 10 = 12.347" GAS LIFT MANORELS ST MO TVD OEV TYÆ VLV LATCH 1 370B 3665 27 MMG-M DOME RK 2 7170 6023 51 MMG-M SO RK 3 9574 7711 31 KGB-2-LS OMY INT PORT DATE 16 04/03/05 20 04/03/05 o 09/19/00 Minimum ID ::: 2.37" @ 11370' 2-7/8" STL LNR 9105' -1 BAKER TIEBACK SLEEVE, ID = 7.500" I 9113' -i 9-5/8" X 7" BKR ZXP PKR, ID '" 6.313" I 9118' - 9-5/B"X7"BKRHMCHGR.ID=6.313" I 9-5/B" CSG. 47#, L-BO, 10 = 8.681" H ~ TOP OF WHIPSTOCK 9265' 9-5/8" CSG MIL LOUT WINDOW (02-26B) 926B' - 9286' (OFF WHIPSTOCK) MECHANICAL WHIPSTOCK 10657' I WINDOW H 10657' -10665' I I RA PIP TAG H 10666' I 10102' 10121 ' 10151' 10175' 10206' I~ BOT DEPlOY SLEEVE, 6' LONG. 3" 10 IJ3-1í2"' X NIP, 10 = 2.B13" I 3-1/2" X 3-3i16" X-OVfR 7" X 41/2" BKR S-3 PKR, ID = 3.875" 4-1/2" HES XN NIP, 10 MILLED TO 3.8" I BKR TIEBA CK SL V, ID = 5.250" I 4-1/2" WLEG, 10 = 3.958" I ELMO TT NOT LOGGED I I 19-5/B" EZSV RETAINER I TOP OF 3-1/2" X 3-3/16" X 2-7/8" LNR 4-1/2" TBG, 12.6#, L-BO, .0152 bpf, 10 = 3.958"1 7"X4-1/2"BKRZXPPKR,10=4.375" I 17" X 4-1/2" BKR HMC HGR, 10 "4.375" H 17" LNR, 26#, L-BO, 10 = 6.276" I --1P8TD PERFOF~A TION SUMMARY REF LOG: MCNLlCCLlGR OF 3/20/2005 TIE-IN LOG: GEOLOGY PIJC LOG ANGLE AT TOP ÆRF: 97.35" @ 12660' Note: Refer to Production DB for historical perf data SiZE SPF INTERV AL Opn/Sqz DA TE 2" 6 12650' - 12850' Opn 03/20í04 2" 6 12890' - 12950' Opn 03/20104 13006' I I 10832' H20' IVIARKERJT I I PBTD I 14-1/2" LNR, 12.6#, L-80, .0152 bpf, 10= 3.958" I DATE 08/02/82 06/28/97 09/13/00 12/27/00 04/04/02 06/11/03 REV BY COMMENTS ORIGINAL COM PLETION CTD SIDETRACK (02-26A) RIG SIDETRACK (02-26B) SIS-MD CONVERTED TO CANVAS CHlTP CORRECTIONS CMO/TLP KB ELEVATION CORRECTION PRUDHOE BA Y UNIT WELL: 02-26C ÆRMIT No: 205-019 API No: 50-029-20774-03 SEC35, T11N, R14E3716' NSL & 6' WEL BP Exploration (Alaska) • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 02-26C, • ~~1 ~~~a February 16, 2006 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 02-26C: LAS Data & Digital Log Images: 50-029-20774-03 ,~~,+~~~ NOV ~9 1 2007 1 CD Rom 6-`" l ~~ . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 September 30,2005 RE: MWD Formation Evaluation Logs: 02-26C, AJ(-MW-3591162 1 LDWG formatted Disc with verification listing. API#: 50-029-20774-03 )1;L7 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry 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: }.? OrAJ.rí Signed: 1LJ ðJl¡ ^ ~5-- cd C{ 07/14/05 SchlumbBl'gør NO. 3433 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Loa DescrlDtlon Date BL Color D 1-31/M-21 , q)' - 07 J.. 10980540 RST (REVISED)- 04/14/05 1 /Ll~~ 07 -34A C C . ð¡ 3 11001051 RST (REVISE D)- 04/26/05 1 J..f.1.ì 15-14A :1 ù4- :tl~ 10913003 PEX-DSI-AIT 01/16/05 1 1 i J. ) t- Y-23B ). \i J.. i tø ..,. 10913024 PDC-GR 'C- 06/09/05 1 / 1.3 £,. N-08A J.,,~, ~ () q 10919802 LDL 09/24/04 1 K-08A J. \;, \ ~ 111 C 10942219 MEM PPROF 06/24/05 1 W-26A I C\' - ex. \ 11051066 LDL , 06/23/05 1 L5-09 \ cm~ b. '"' 11051037 RST 04/27/05 1 1 I j 1?7 OWDW.NWicc· ^-4l': 10980537 RST ; 03/26/05 1 1 I' :1 ;¿V? C-34 I 93 " O/}- 10831309 RST 07/09/04 1 1 I ~ Jll 01-12A 2~).....I~l 10928620 MCNL 04/03/05 1 1 '~'-I(\ DS 05-41A J..t! <,,- I/~ 10715377 MCNL .. 01/21/04 1 1 ì i-j{ 02-26C ;¡ C;; ~ ... 0 \ q 10928619 MCNL 03/20/05 1 1 i 1 . '-I ;1. -REVISED TO CORRECT API# ON DIGITAL DATA C . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: :] (~;ft·, Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage. AK 99 03 2838 ATTN: Beth ; " ;.1 (/(/ I ~ OMVvpl h:.~ \ _. Received by: . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . DEFINITIVE Re: Distribution of Survey Data for Well 2-26C Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,649.50' MD 10,657.00' MD 13,006.00' MD (if applicable) 23-Apr-05 PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Signed U L'ÜJ Date  2fJ..p~) Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager AUachment(s) lcs,r-Ol(r . STATE OF ALASKA a ALASK L AND GAS CONSERVATION COM-':;ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEIVED APR 1 2 2005 1 a. Well Status: 181 Oil o Gas o Plugged o Abandoned o Suspended OWAG 1 bå ~rit~B~\~ G.rJtgwmss )1 20AAC 25.105 20AAC 25.110 OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic A Øe 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 3/21/2005 205-019 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 3/12/2005 50- 029-20774-03-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 3/18/2005 PBU 02-26C 1560' SNL, 6' WEL, SEC. 35, T11N, R14E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 1991' SNL, 5119' WEL, SEC. 35, T11N, R14E, UM 58.7' Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 2168' SNL, 1659' WEL, SEC. 34, T11 N, R14E, UM 12973 + 9037 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 686759 y- 5949616 Zone- ASP4 13006 + 9041 Ft ADL 028309 ---~- ------- --~- 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 681660 y- 5949064 Zone- ASP4 ~-- (Nipple) 2219' MD Total Depth: x- 679846 y- 5948843 Zone- ASP4 -- -.- ---- ---------- --~-- ____u_n_____ _ 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 181 Yes ONo NI A MSL 1900' (Approx.) 21. Logs Run: MWD GR I EWR, MGR I CCL I CNL 22. CASING, liNER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING L EPTH TVD HOLE AMOUNT SIZE WT.PER FT. GRADE TOP BOTTOM TOP I BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 79' Surface 79' 30" 00 sx Arcticset II 13-3/8" 72# L-80 Surface 2661' Surface 2661' 17-1/2" 300 sx Fondu, 400 sx PF 'C' 9-5/8" 47# L-80/S0095 Surface 9268' Surface 7470' 12-1/4" 00 sx Class 'G', 300 sx PF 'C' 7" 26# L-80 9105' 10411' 7356' 8434' 8-1/2" 48 sx Class 'G' 4-1/2" 12.6# L-80 10225' 10657' 8272' 8642' 6-1/8" 25 sx Class 'G' 3-1/2' x 3-3116' x 2-7/8' 8.81# /6.2# /6.16# L-80 10103' 13006' 8167' 9041' 4-1/8' x 3-314' 128 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 10227' 10175' MD TVD MD TVD 12650' - 12850' 9042' - 9030' 25. ACID, FRACTUf'iE, CEMENT SaUEEZE, ETC, 12890' - 12950' 9030' - 9034' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2500' Freeze Protect with MeOH 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): April 5, 2005 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF WATER-BBl CHOKE SIZE I GAS-Oil RATIO 4/5/2005 5.3 TEST PERIOD .. 340 2,771 8 44.44 8,154 Flow Tubing Casing Pressure CALCULATED .. OIL -BBl GAs-MCF WATER-BBl Oil GRAVITY-API (CORR) Press. 1,404 1,600 24-HoUR RATE 1,539 12,548 36 ./_~n . 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submitc.ore chips; if none, state "none". None 13;l~M RBDMS BFL APR 1 8 2005 ¡ ;ø¡:?J ( GP ; ~\ L_,..,_...<.....r 1I~:)'i.' n Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKER 29. ORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 42SB I Zone 4A 10659' 8643' None Top CGL Base CGL 10735' 10814' 8710' 8782' 23SB I Zone 2B 1 0899' 8855' 22TS 1 0963' 8903' 21TS I Zone 2A 11054' 8957' 21N 11100' 8979' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant PBU 02-26C Well Number 205-019 Permit No. I A roval 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. Prepared By Name/Number: Drilling Engineer: Terrie Hubb/e, 564-4628 Mary Endacott, 564-4388 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". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-26 02-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/5/2005 Rig Release: Rig Number: 1 Spud Date: 7/13/1982 End: 3/5/2005 09:00 - 09:30 0.50 MOB P PRE Safety Meeting on Mob to DS2-26C 09:30 - 00:00 14.50 MOB P PRE Mobilization to DS2 vis Spine, Oxbow and West Dock Road Notified from town of operational changes due to the failed MIT Test on DS2-26 3/6/2005 00:00 - 01 :00 1.00 MOB P PRE Traveled to DS7 and spotted rig Tool Service finished leveling location and flow line has been removed from DS2-26. C-08 well house is still installed (back up well to 2-26). SLB Eline is setup for 0800 hrs to run GR/JB and the then set CIBP to perform PT on tubing prior to MIRU on 2-26. 01 :00 - 18:00 17.00 MOB N WAIT PRE Wait on Eline to set CIBP and PT tubing & liner. PE's fluid packed well bore with 1% Eline set CIBP at 10,770 ft. 18:00 - 19:30 1.50 MOB N WAIT PRE Wait on HOT to PT linerltubing 19:30 - 20:30 1.00 MOB N WAIT PRE RU Little Red, Loaded tubing with 11 bbl and PT tubing to 3000 psi PT tubing to 3000 psi, 1st 15min lost 40 psi, 2nd 15 min lost 20 psi for a total of 60 psi in 30 minutes 20:30 - 21 :30 1.00 MOB N WAIT PRE Called town to report results, make ready to move rig to DS2-26 21 :30 - 23:30 2.00 MOB P PRE SAFETY MEETING with BP Security, Tool Service and rig crew on move Waited on Veco sand truck for 2 hrs 23:30 - 00:00 0.50 MOB P PRE Move rig from DS7 to DS2 3/7/2005 00:00 - 04:30 4.50 MOB P PRE Complete move to 2-26. Held Safety meeting on move over well. Moved rig over well. 04:30 - 08:00 3.50 BOPSU PRE RIG ACCEPTED AT 0430 HRS 3-7-2005 NU BOP. 08:00 - 12:00 4.00 BOPSU WAIT PRE Wait on arrival of cuttings box. Trucking availability and interference with 2ES move. Also waiting on arrival of Peak Crane for coil swap. Peak crane available forced utilization of Manatowak which is frozen. Peak been thawing crane of 2 days current ETA is 2300 hrs. 12:00 - 18:30 6.50 BOPSU P PRE Test BOP. AOGCC rep John Crisp waived witnessing BOP test. Lower Combi rubbers failed on first attempt to test swab valve. Rubbers replaced. Test Witnessed by Bob Laule. 18:30 - 23:00 4.50 RIGU N WAIT PRE Install Pack-off and injector on well and make ready to swap CT Tried to get Eline to set WS or Wireline to make 17 ft dummy WS run and both truck unavailable. Used MCC Security to escort Manatowak Crane in between 2ES rig move to DS3. 23:00 - 00:00 1.00 RIGU N WAIT PRE Peak crane roading from Peak Base Camp to DS2 3/8/2005 00:00 - 00:15 0.25 RIGU P PRE Unload crane and spot at rig 00:15 - 00:45 0.50 RIGU P PRE SAFETY MEETING on Crane lift w/ Peak,Nordic and SLB 00:45 - 02:00 1.25 RIGU P PRE Reel Swap from 2" to 2-3/8" 02:00 - 04:30 2.50 RIGU P PRE RD Crane, stab motor to reel. Stabbed CT in injector 04:30 - 05:45 1.25 RIGU P PRE Cut CT and dress for CTC 05:45 - 09:00 3.25 RIGU P PRE RU Reels hardline Bring BOT tools onto rig floor. 09:00 - 10:30 1.50 RIGU P PRE Fill coil. Pump dart. 55.0 bbl 10:30 - 11 :30 1.00 WHIP P WEXIT MU Whipstock setting BHA. 11 :30 - 12:00 0.50 WHIP P WEXIT RIH to 2,900 ft 12:00 - 12:45 0.75 WHIP P WEXIT Shallow hole test MWD at 1.39 bpm /2100 psi Orienter test at 3,063 ft Printed: 3/22/2005 11: 12: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-26 02-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/5/2005 Rig Release: Rig Number: 1 Spud Date: 7/13/1982 End: 3/812005 12:45 - 14:00 1.25 WHIP P WEXIT RIH to 10,630 ft 14:00 - 15:50 1.83 WHIP P WEXIT Tie-in logging down from 10,630 ft Qmax = 1.5 pbm at 2,290 psi Unable to tie-in PUH to 10,520 ft and try again. Bottoms up gas, Kick while tripping drill, all personnel reacted as per training Corrected -23 ft from 10,606 ft to 10,583 ft. 15:50 - 16:30 0.67 WHIP P WEXIT RIH to 10,670 ft (BOWS) TOW at 10,657 ft. Orient TF from 67L Resultant TF at 152R, 5 times Inc Qp to 2bpm CTP = 4277 psi stable, open choke, CTP = 0 psi, Inc Qp 0.31 bpm deadheading pressure, sheared at 3100 psi, Inc Qp to check TF TF at 175R Set 5.0k down. OK 16:30 - 18:30 2.00 WHIP P WEXIT PUH and painted EOP flag 10,500 ft. GPB in phase-2 driving conditions on all roads and pads. 18:30 - 19:00 0.50 WHIP P WEXIT UD Baker whipstock setting BHA & FAIV with Sperry orienter & MWD. 19:00 - 19:30 0.50 WHIP P WEXIT Held TLM & PJSM. Review procedure, hazards & mitigation for M/U cementing BHA. 19:30 - 19:45 0.25 ZONISO P WEXIT MIU slick cementing BHA #2 with 3" big hole nozzle, 6' 2-3/8" PH6 stinger, XO & Baker CTC (OAL = 7.76'). 19:45 - 21 :00 1.25 ZONISO P WEXIT RIH with cementing BHA #2 to 8500'. Wind picking up to 120mph gusts. One Veco vac truck run off road en route to HWP to load bio-KCL water for the rig. Central dispatch & Tool Services confirm that GPB will be in phase-3 in the next 1 hour. Decide to POOH. 21 :00 - 22:30 1.50 ZONISO P WEXIT POH to surface. Meanwhile demobed cementing crew & empty Veco cmt wash-up truck. Load rig water. GPB in phase-3 driving conditions on all roads and pads. 22:30 - 00:00 1.50 ZONISO N WAIT WEXIT W. O. Weather/Wind. Wind @ 30-120 mph, -65 WC. Phase 3. Meanwhile circ CT with injector stabbed onto well. 3/9/2005 00:00 - 13:15 13.25 ZONISO N WAIT WEXIT Continue W. O. Weather I Wind. Wind @ 50-120 mph, -65 WC. Phase 3. Weather clearing at 1230 hrs. 13:15 - 13:30 0.25 ZONISO N WAIT WEXIT Phase II, Conducted HAZID on moving snow from access road and pad 13:30 - 14:15 0.75 ZONISO N WAIT WEXIT Cleaning off access road and pad. Called for vac trucks and cementers 14:15 - 14:45 0.50 ZONISO N WEXIT Cleaning pad and waiting on vac trucks Phase II on roads and Levell on pads due to our loader keeping access road open 14:45 - 16:45 2.00 ZONISO P WEXIT RIH with cement nozzle BHA Cement and Vac trucks on location Snow blower cleaning location and access roads SAFETY MEETING Cementing pumping & procedures Corrected -24 ft correction Tagged at 10,658 ft, PU 10 and painted Flag 16:45 - 17:25 0.67 ZONISO P WEXIT Thawing fresh water line. Batch mix 5 bbl cement 17:25 - 18:10 0.75 ZONISO P WEXIT Open up to Cementers. Pump 5 bbl fresh water PT P/L to 4000 psi Pump 5 bbl cement 15.9 ppg density Pumped 5 bbl fresh water. SD blow air back to cementers Printed: 3/22/2005 11: 12: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-26 02-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/5/2005 Rig Release: Rig Number: 1 Spud Date: 7/13/1982 End: 3/9/2005 17:25 - 18:10 0.75 ZONISO P WEXIT Switched to pits Displacing cement to nozzle. 18:10 - 18:15 0.08 ZONISO P WEXIT With 2 bbl behind CT PUH laying in 1:1 with 70 psi WHP 18:15 - 18:20 0.08 ZONISO P WEXIT PUH to WCTOC. 10,100 ft. 18:20 - 19:15 0.92 ZONISO P WEXIT WOC and circulated bio water down CT with +/-100psi WHP. GPB in phase 1 on all main roads & phase 3 on all access roads & pads. 19:15 - 20:00 0.75 ZONISO P WEXIT RBIH contaminating cmt with 3.0bpm/2300psi. Tag WS @ 10663'. Make 3 down & 2 up passes from 10500' to TOWS. 20:00 - 21 :45 1.75 ZONISO P WEXIT POOH chasing cmt contaminated fluid OOH & jetting across jewelry. 21:45 - 22:15 0.50 ZONISO P WEXIT OOH. SI master. UD cmt nozzle BHA. 22:15 - 23:00 0.75 ZONISO P WEXIT M/U swizzle stick & jet BOP stack. Flush choke manifold lines. Blowout plugged micromotion. UO swizzle stick & SIB injector. Open MV. 23:00 - 00:00 1.00 STWHIP P WEXIT M/U window milling BHA #3 with a 3.80" HC DP0261 DWM, 3.79' used DSR, Baker straight Xtreme motor, MHA & 2 jts of PH6 tbg (OAL - 81.81 '). M/U injector. 3/10/2005 00:00 - 01 :45 1.75 STWHIP P WEXIT RIH with BHA #3 to +1-3000'. Had to reboot SLB primary computer - lost depth tracking data. Reset CTD to 3000'. Wt check @ 9500': Up = 42k, down = 24k. Continue RIH BHA#3 & tag XN @ 9586'. Correct CTD to 10206'. P/U 10' @ 42k & ease into milling from 10205.5'. 01 :45 - 03:00 1.25 STWHIP P WEXIT Mill XN with 2.7/2.8bpm, 1800/1900psi, 1-2k WOB. Mill thru XN with 3 stalls @ 10205.8'. Dress XN with DSR. Backream & drift XN without pumping - clean with no O/pulls. LEL alarms went off following milling of XN nipple, could have lost TT integrity. 03:00 - 03:30 0.50 STWHIP P WEXIT Continue RIH with BHA #3. Wt check @ 10600': Up = 43.7k, down = 20k. Tag WS/Lnr pinch pt @ 10653.5'. Flag pipe & correct depth to 10657' (pinch pt CTD). 03:30 - 06:30 3.00 STWHIP P WEXIT Start milling window with 2.7/2.8bpm 1800/1950psi, 1-2k WOB. Mill to 10658' with several stalls. GPB in phase-2 driving conditions on the spine road & phase-3 on all access roads & pads. 06:30 - 06:45 0.25 STWHIP P WEXIT Call from Wells Group, Jerry Bixby call for all drilling rigs to go to Phase III weather conditions, not level III as yesterday under same conditions. IMT has been activated Pulled off window. 06:45 - 08:20 1.58 STWHIP N WAIT WEXIT POOH due to Phase III weather conditions. 08:20 - 09:00 0.67 STWHIP N WAIT WEXIT OFF CRITICAL PATH OOH, unstab, LD BHA Window mill at 3.78" 00 and string mill at 3.76" OD. Ordered new mills, will arrive following WOW 09:00 - 10:00 1.00 STWHIP N WAIT WEXIT Rig on standby WOW Phase II/ Level II on Spine and Phase III Level III on the access roads 10:00 -11:10 1.17 STWHIP N WAIT WEXIT New update from Herb Williams, NSU ADW HSE Advisor. Under Level III on pad, one can utilize a loader to keep operating. If loader is unable to maintain roads, then will go to Phases III Level III conditions and stop work. Ordered new window and string mill 11:10 -11:30 0.33 STWHIP N WAIT WEXIT MUMills 11 :30 - 13:35 2.08 STWHIP N WAIT WEXIT RIH, after correcting -24 ft tagged WS at 10,658 ft 13:35 - 17:00 3.42 STWHIP P WEXIT Milling window, hard getting started. Starting over again Qp = 2.8 / 2.82 bpm. CTP = 1868 psi Printed: 3/22/2005 11: 12: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-26 02-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/5/2005 Rig Release: Rig Number: 1 Spud Date: 7/13/1982 End: 3/10/2005 13:35 - 17:00 3.42 STWHIP P WEXIT INOA = 494 I 455 psi Milled from 10,657.0 ft to 10,657.3 and every time we try to go to 10,657.4 ft it stalls. This has happened 15 times. Unable to pass 10657.4 ft. The CCAT is at 35% at 10,650 ft. Phase 2 Level 2 on Spine and Phase 2 I Level 3 on Pads. Loader keeping pad cleared off and access to 2-26C. 17:00 - 18:45 1.75 STWHIP N DPRB WEXIT POOH to look at BHA 18:45-19:15 0.50 STWHIP N DPRB WEXIT OOH. PJSM. SIB injector. SIB PH6 tbgs & UD MHA motor & mills. DWM & DSR look good - gauge 3.80" go & 3.79" no go. Check motor - OK - however will be changed out. 19:15 - 19:30 0.25 STWHIP N DPRB WEXIT PJSM for cutting CT. 19:30 - 20:15 0.75 STWHIP N DPRB WEXIT R/U hydraulic cutter. Cut 150' of CT for fatigue management. 20:15 - 21:00 0.75 STWHIP N DPRB WEXIT Install Baker CTC. Pull test to 35k. M/U MHA & PT MHA & CTC to 3500psi. 21 :00 - 21 :30 0.50 STWHIP N DPRB WEXIT M/U window milling BHA #5 with the rerun 3.79" HC DP0261 DWM, DSR, new Baker straight Xtreme motor, MHA & 2 jts of PH6 tbg (OAL - 81.82'). M/U injector. 21 :30 - 23:30 2.00 STWHIP N DPRB WEXIT RIH with BHA #5. Wt check @ 10600': Up = 45k, down = 23k. Dry tag WS/Lnr pinch pt @ 10682'. P/U & bring on pumps. Retag pinch pt @ 10680. Flag pipe & correct depth to 10658'. P/U & ease into milling from 10657.7'. 23:30 - 00:00 0.50 STWHIP N DPRB WEXIT Mill window from 10657.7' to 10658' with 2.65/2.75bpm 1760/1850psi, 1-2k WOB. Stalling repeatedly @ 10657.8'. PIU, ease back into milling from 10657.7'. 3/11/2005 00:00 - 01:15 1.25 STWHIP N DPRB WEXIT Set brakes & mill @ 10657.7' for 30mins. Attempt to mill past 10657.8' without luck - stalling repeatedly. The DSR could be binding up on TOWS. Decide to POOH & UO DSR. 01:15 - 03:00 1.75 STWHIP N DPRB WEXIT POOH to UO DSR. 03:00 - 03:30 0.50 STWHIP N DPRB WEXIT OOH. PJSM. SIB injector. P/U BHA & UD DSR. DWM & DSR still gauge 3.80" go & 3.79" no go. 03:30 - 05:15 1.75 STWHIP N DPRB WEXIT RIH with BHA #6. Dry tag WS/Lnr pinch pt @ 10683'. Correct depth to 10658'. P/U & bring on pumps. Stall @ 10657.2'. Ease into milling from 10656'. 05:15 - 06:45 1.50 STWHIP N DPRB WEXIT Mill window from 10656' with 2.65/2.75bpm 1740psi, 1-2k WOB. Not seeing any motor work. Stalling repeatedly @ 10656.6'. Unable to pass 10656.6 ft 06:45 . 08:30 1.75 STWHIP N DPRB WEXIT POOH 08:30 - 09:50 1.33 STWHIP N DPRB WEXIT OOH, stand back injector, inspect mills,3.8" OD, no wear at all in frontal and some wear at 3.25" OD LD mill & motor'PU BOT 3.8" starting mill (Length mill 0.75') and new extreme motor. 09:50 - 11 :45 1.92 STWHIP N DPRB WEXIT RIH started adding EMI 920 "Mud lube" to mud system 8 drums = 2% by volume Corrected to flag at -23.5 ft, 10428.2 ft Tagged at 10657' 11 :45 - 13:20 1.58 STWHIP N DPRB WEXIT Milling Started at 10,656.3 ft Stall, PU and worked down to 10,656.6 ft stall Qp=2.64bpm @ 1660 psi Good motor work at 10,656.7 ft. Milled down to 10,657.4 ft. PU RIH slowly to 10,657.4ft. Stalled. Starter mill acted as it should. 100psi to 150 psi motor work when ever added WOB. 13:20 - 14:50 1.50 STWHIP N DPRB WEXIT POOH with starter mill 14:50 - 15:15 0.42 STWHIP N DPRB WEXIT OOH, Mill was on the skate and casing was milled as seen on Printed: 3/22/2005 11: 12: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-26 02-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/5/2005 Rig Release: Rig Number: 1 Spud Date: 7/13/1982 End: 3/11/2005 14:50 - 15:15 0.42 STWHIP N DPRB WEXIT the blades. PU 3.8" DSM and 3.79" Dia reamer 15:15 - 17:00 1.75 STWHIP N DPRB WEXIT RIH, corrected to flag -28 ft 17:00 - 18:40 1.67 STWHIP P WEXIT Milling. Started milling at 1 0656.3ft with normal WOB & motor work Qp = 2.69bpm @ 1758 psi. Milling with 2% Mud Lube in the system. Mill to 10659'. 18:40 - 20:00 1.33 STWHIP P WEXIT Mill window from 10659' to 10660' with 2.65/2.75bpm 1760/1860psi, 3k WOB. Seeing metal shavings on the ditch magnets. 20:00 - 20:35 0.58 STWHIP P WEXIT Mill window from 10660' to 10661' with 2.65/2.75bpm 1760/1860psi, 4k WOB. 20:35 - 21:15 0.67 STWHIP P WEXIT Mill window from 10661' to 10662' with 2.65/2.75bpm 1760/1950psi, 4k WOB. 21:15 - 22:10 0.92 STWHIP P WEXIT Mill window from 10662' to 10663' with 2.65/2.75bpm 1760/2060psi, 4k WOB. 22:10 - 23:10 1.00 STWHIP P WEXIT Control mill window from 10663' to 10664' with 2.65/2.75bpm 1760/2060psi, 4k WOB. 23:10 - 00:00 0.83 STWHIP P WEXIT Control mill window from 10664' to 10665' with 2.65/2.75bpm 1760/1900psi, 3k WOB. 3/12/2005 00:00 - 00:15 0.25 STWHIP P WEXIT Continue control milling & exit liner into formation @ 10665.3'. 00:15 - 00:50 0.58 STWHIP P WEXIT Mill formation to 10675' with 2.65/2.75bpm, 1760/1850psi, 11 fph ave ROP & 3k WOB. Geologist seeing formation in BU samples. 00:50 - 02:15 1.42 STWHIP P WEXIT Backream/dress windowlrat hole several times. Drift window clean. Tentative window depths are: TOWS/TOW = 10657', BOW = 10665', RA PIP Tag = 10665.8'. Meanwhile W.O. mud trucks to arrive onsite - Central dispatch out of trucks. 02:15 - 03:15 1.00 STWHIP P WEXIT Swap wellbore to 8.6 ppg reconditioned flopro mud. 03:15 - 05:15 2.00 STWHIP P WEXIT Paint EOP flag @ 10500' & POOH window milling BHA#8. 05:15 - 06:30 1.25 STWHIP P WEXIT OOH. UD & inspect milling BHA#8. DWM gauge 3.79" go I 3.78" no go & DSR gauge 3.80" go 13.79" no go. Wear on DWM face indicates center crossed the liner wall. 06:30 - 08:30 2.00 DRILL P PROD1 Install CTC, Pull and pressure test 35k 13.5k. PU directional BHA wI 1.37 deg motor 08:30 - 10:25 1.92 DRILL P PROD1 RIH. Corrected to 10,500 ft EOP Flag (Correction -26.4 ft) 10:25 - 10:45 0.33 DRILL P PROD1 Orient TF to LS before going through WS 10:45 - 1 0:50 0.08 DRILL P PROD1 RIH past WS and tagged at 10,676 ft. 10:50 - 11 :00 0.17 DRILL P PROD1 Orient TF to 134L 11:00-11:15 0.25 DRILL P PROD1 Drilling Zone 4 TF at 137L Qp = 2.70 12.80 bpm, CTP = 3500/3650 psi Vp = 304 bbl 11:15 -11:30 0.25 DRILL P PROD1 Orient TF to 128L 11 :30 - 13:00 1.50 DRILL P PROD1 Drilling Zone 4 TF at 134L ROP "slow" Looking for RA Marker Qp = 2.70 12.80 bpm, CTP = 3500/3650 psi Vp = 304 bbl. IAlOA = 492 I 602 psi 13:00 - 13:25 0.42 DRILL P PROD1 Drilling Zone 4 TF at 134L ROP "slow" Still looking for RA Marker Qp = 2.70 I 2.80 bpm, CTP = 3500/3650 psi Vp = 304 bbl. IAlOA = 492 I 602 psi 13:25 - 13:30 0.08 DRILL P PROD1 PUH to tie-in cased hole to RA Marker 13:30 - 14:30 1.00 DRILL P PROD1 RIH to Tie-in. No Correction, Way to go Dave 14:30 - 14:51 0.35 DRILL P PROD1 RIH to 10,700 ft and log up to Tie-in RA Marker Printed: 3/22/2005 11: 12: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-26 02-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/5/2005 Rig Release: Rig Number: 1 Spud Date: 7/13/1982 End: 3/12/2005 14:30 - 14:51 0.35 DRILL P PROD1 TOWSITOW = 10,657 ft RA Marker @ 10,666 ft BOW @ 10,665 ft 14:51 - 17:00 2.15 DRILL P PROD1 Drilling Zone 4 to 3 TF at 111 L ROP 10-30fph Qp = 2.75/2.82 bpm, CTP = 3500 13650 psi Vp = 304 bbl. IAlOA = 533 I 790 psi Bleed down IAlOA to 251/299 psi 17:00 - 18:15 1.25 DRILL P PROD1 Drilling Zone 3 TF at 100L ROP 10-30fph Qp = 2.77 12.88 bpm, CTP = 3550 /3850 psi Vp = 299 bbl. IAlOA = 303 I 490 psi. Drill to 10770'. 18:15 -18:25 0.17 DRILL P PROD1 Orient TF to 50L. P/U wt = 30k, Run-in wt = 17k. PVT = 299bbls. lAP = 315psi, OAP = 515psi. 18:25 - 20:30 2.08 DRILL P PROD1 Drill to 10785' with 50-60L TF, 2.55/2.55bpm, 3300/3550psi, 1 Of ph ave ROP, 7k WOB & occasional stalls. Very slow drilling but will attempt to grind-on to end of zone-3 @ +1-10820'. Geo seeing 85% Chert & 1-2% Pyrite. 20:30 - 20:35 0.08 DRILL P PROD1 Orient TF to HS. P/U wt = 28k, Run-in wt = 15k. 20:35 - 00:00 3.42 DRILL P PROD1 Drill to 10811' with 5-15L TF, 2.5/2.5bpm, 3200/3500psi, 8fph ave ROP, & 4k WOB. Very slow progress. Decide to POOH. 3/13/2005 00:00 - 02:00 2.00 DRILL P PROD1 POOH drilling BHA #9. 02:00 - 02:30 0.50 DRILL P PROD1 OOH. PJSM. SIB injector. Flush & UD BHA #9. Bit gauge 7/3/1 with some ring wear on the pilot. 02:30 - 02:45 0.25 BOPSU P PROD1 Conduct weekly BOP function test. 02:45 - 04:20 1.58 DRILL P PROD1 M/U drilling BHA #10 with BHI 1.37deg motor & rebuilt HTC RWD 3-3/4" x 4-1/8" bicenter bit #6, Sperry MWD/GR-RES, orienter & MHA. Scribe tools & initialize EWR. M/U injector. 04:20 - 06:30 2.17 DRILL P PROD1 RIH BHA #10. SHT MWD & orienter - OK. RIH to btm. Tagged bottom at 10,811 ft 06:30 - 07:05 0.58 DRILL P PROD1 PUH conducting MAD Pass Corrected 0.5 ft 07:05 - 07:20 0.25 PROD1 Orient TF to 60 R 07:20 - 08:20 1.00 DRILL P PROD1 Drilling Lower Zone 3 TF at 62 R ROP 20-60 fph Qp = 2.75/2.82 bpm, CTP = 3300 I 3450 psi Vp = 295 bbl. IAlOA = 3821410 psi. 08:20 - 08:35 0.25 DRILL P PROD1 Orient TF 08:35 - 10:55 2.33 DRILL P PROD1 Drilling Lower Zone 2C TF at 23 L to 3 R ROP 30-60 fph Qp = 2.75/2.82 bpm, CTP = 3300 13450 psi Vp = 293 bbl. IAlOA = 424 I 498 psi. 1 0:55 - 11: 15 0.33 DRILL P PROD1 Orient TF around 11 :15 - 12:05 0.83 DRILL P PROD1 Drilling Zone 2 TF at 20 L Walking Right ROP 70 fph Qp = 2.71/2.80 bpm, CTP = 3400/3550 psi Vp = 293 bbl. IAlOA = 468 I 596 psi. 12:05 - 12:20 0.25 DRILL P PROD1 Orient TF around 12:20 - 12:55 0.58 DRILL P PROD1 Drilling Zone 2 TF at 46 L ROP 60-70 fph Qp = 2.74/2.80 bpm, CTP = 3400 13650 psi Vp = 291 bbl. IAlOA = 468 I 604 psi. 12:55 - 13:30 0.58 DRILL P PROD1 Wiper trip tp window 13:30 - 16:00 2.50 DRILL P PROD1 Drilling Zone 2 TF at 46 L ROP 20-70 fph Qp = 2.74/2.80 bpm, CTP = 3400 /3650 psi Vp = 289 bbl. IAlOA = 475/636 psi. Made mini. wiper at 11,090 ft, 11,1406 ft. Ordered Mud swap @ 11,108 ft 16:00 - 17:35 1.58 DRILL P PROD1 Drilling Lower Zone 2/21 N Shale. TF at 1 R; ROP 30-50fph Printed: 3/22/2005 11: 12: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-26 02-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/5/2005 Rig Release: Rig Number: 1 Spud Date: 7/13/1982 End: 3/13/2005 16:00 - 17:35 1.58 DRILL P PROD1 Qp = 2.74/2.80 bpm, CTP = 3500 13950 psi Vp = 282 bbl. IAlOA = 481/318 psi. Mini Wiper at 11,136 ft Started Mud swap at 17:00 hrs 17:35 - 18:00 0.42 DRILL P PROD1 Wiper trip to 10,900 ft. Started new mud down CT 18:00 - 18:30 0.50 DRILL P PROD1 Drilling Lower Zone 2 I 21 N Shale. TF at 1 R; ROP 70-110 fph Qp = 2.70/2.80 bpm, CTP = 3450 13700 psi IAlOA = 286/416 psi. Drill to 11,195'. 18:30 - 20:10 1.67 DRILL P PROD1 Drill & land build section above 14N @ 11274' with 15-30R TF, 2.65/2.65bpm, 3200/3500psi, 60-80fph ave ROP, & 1-2k WOB. 20:10 - 20:25 0.25 DRILL P PROD1 Orient TF to 90L. P/U wt = 36k, Run-in wt = 17k. PVT = 326bbls. lAP = 255psi, OAP = 315psi. 20:25 - 20:50 0.42 DRILL P PROD1 Drill to 11300' with 90-95L TF, 2.65/2.65bpm, 3200/3500psi, 60-80fph ave ROP, & 3k WOB. 20:50 - 21:10 0.33 DRILL P PROD1 Wiper trip clean to the window. 21:10 - 21:30 0.33 DRILL P PROD1 Log up GR & tie-into RA Pip tag - no correction. 21 :30 - 21 :45 0.25 DRILL P PROD1 RBIH clean to btm. 21 :45 - 22:35 0.83 DRILL P PROD1 Drill to 11323' with 90-95L TF, 2.65/2.65bpm, 3100/3350psi, 0.171 DRILL 40fph ave ROP, & 3k WOB. Drilling ratty. 22:35 - 22:45 P PROD1 Short 100' wiper. 22:45 - 23:15 0.50 DRILL P PROD1 Drill to 11333' with 90L TF, 2.65/2.65bpm, 3100/3400psi, 25fph ave ROP, & 3k WOB. Drilling ratty & stalling. 23:15 - 23:40 0.42 DRILL P PROD1 Orient TF around to 120L. P/U wt = 40k, Run-in wt = 17k. 23:40 - 00:00 0.33 DRILL P PROD1 Drill to 11340' with 115L TF, 2.65/2.65bpm, 3100/3300psi, 40fph ave ROP, & 3k WOB. 3/14/2005 00:00 - 00:35 0.58 DRILL P PROD1 Drill to 11353' with 90-115L TF, 2.65/2.65bpm, 3100/3300psi, 40fph ave ROP & 3k WOB. 00:35 - 01 :30 0.92 DRILL P PROD1 Orient & drill to 11372' with 80L TF, 2.65/2.65bpm, 3100/3300psi, 40fph ave ROP & 3k WOB. Geo seeing 65% Chert in BU samples. Decide to POOH to check bit. 01 :30 - 03:30 2.00 DRILL P PROD1 POOH drilling BHA #10. 03:30 - 04:45 1.25 DRILL P PROD1 OOH. PJSM. SIB injector. UD bit - gauge 6/2/1 with some ring wear on the pilot. 04:45 - 05:30 0.75 DRILL P PROD1 MIU drilling BHA #11 with BHI 1.37deg motor & new HYC DS100 3-3/4" x 4-1/4" bicenter bit #7, Sperry MWD/GR-RES, orienter & MHA. Scribe tools, download & initialize EWR. MIU injector. 05:30 - 07:28 1.97 DRILL P PROD1 RIH BHA #11. SHT MWD & orienter @ 3000' - OK. At 10,635, check orientation, 165R, RIH to 10,715 to Tie-in 07:28 - 07:45 0.28 DRILL P PROD1 Tie-in PUH from 10,710 ft Corrected -5 ft 07:45 - 07:55 0.17 DRILL P PROD1 RIH. Set down at 11,126 ft; 21 N shale 07:55 - 08:10 0.25 DRILL P PROD1 Orient TF to HS from LS. Pulled tight RIH wI correct TF and had a little trouble but went through with reduced Qp. Polar Bear report/sighting between DS2 and Dump/Pit 08:10 - 08:25 0.25 DRILL P PROD1 RI H and tagged at 11,368 ft. 08:25 - 08:45 0.33 DRILL P PROD1 Orient TF to 80L 08:45 - 10:30 1.75 DRILL P PROD1 Drilling Lower Zone 2C 114N TF at 75 L ROP 0-25 fph with several stalls. Qp = 2.75/2.82 bpm, CTP = 3160 13350 psi Vp = 286 bbl. IAlOA = 405/345 psi. Geologist looking at sample of 11,368 ft. Shale with trace of chert should drill faster than 5 fph 10:30 - 10:35 0.08 DRILL P PROD1 Orient TF up to build to 8,960 ft TVD and get out of this shale. Printed: 3/22/2005 11: 12: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-26 02-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/5/2005 Rig Release: Rig Number: 1 Spud Date: 7/13/1982 End: 3/14/2005 10:35 - 13:05 2.50 DRILL P PROD1 Drilling Lower Zone 2 to 1 or 14N TF@23 L ROP = 6 fph Qp = 2.75/2.82 bpm, CTP = 3450 14015 psi Vp = 286 bbl. IAlOA = 405 I 345 psi. Orient TF at 11,379 ft to HS to climb TVD to 8960 ft Unable to get HYC DS100HGJNU to drill. Drilled 29 ft in 4.5 hrs ROP = 6fph. This design is too blunt on the spear point. 13:05 - 15:30 2.42 DRILL N DFAL PROD1 POOH to change out bits TL Town Hall Meeting at 14:30 hrs 15:30 - 16:00 0.50 DRILL N DFAL PROD1 Change out bit DS100 was a 1-1 with the nose jets plugged with hard shale. 1 side jet was washed out and pointing upward. No hydraulic or jet velocity at nose and the cutters were untouched. 16:00 - 18:00 2.00 DRILL N DFAL PROD1 RIH, SHT at 500 ft and orienter test at 3,200 ft At 10,624 ft, Corrected to 10,600 ft RIH open hole to tie-in 18:00 - 18:25 0.42 DRILL N PROD1 PUH logging RA Marker. Corrected CTD -8'. 18:25 - 18:50 0.42 DRILL N PROD1 RIH. Saw wt bobbles from 11126' (21 N shale). Drop rate to 1.5bpm & run thru @ 30L TF. Continue RIH & tagged btm @ 11396'. 18:50 - 19:25 0.58 DRILL P PROD1 Drill to 11415' with 60-70L TF, 2.6/2.6bpm, 3200/3500psi, 35fph ave ROP & 3k WOB. 19:25 - 20:10 0.75 DRILL P PROD1 Orient 2 clicks & drill to 11445' with 30-50L TF, 2.5/2.5bpm, 3100/3300psi, 40fph ave ROP & 3k WOB. 20: 10 - 20:30 0.33 DRILL P PROD1 Orient TF around to 80-90L. 20:30 - 21 :20 0.83 DRILL P PROD1 Orient & drill to 11481' with 80-95L TF, 2.5/2.5bpm, 3050/3300psi, 45fph ave ROP & 2k WOB. 21 :20 - 21 :35 0.25 DRILL P PROD1 Orient TF around to 140L. P/U wt = 38k, Run-in wt = 17k. PVT = 263bbls. lAP = 465psi, OAP = 400psi. Meanwhile held table-top fire drill with Nordic new hand. 21 :35 - 22:45 1.17 DRILL P PROD1 Drill to 11550' with 140-145L TF, 2.65/2.65bpm, 3300/3450psi, 80fph ave ROP & 3k WOB. 22:45 - 23:45 1.00 DRILL P PROD1 Wiper trip clean to window. RBIH to btm - saw slight wt bobbles across 11100' shale. 23:45 - 00:00 0.25 DRILL P PROD1 Orient TF around to 80R. 3/15/2005 00:00 - 02:15 2.25 DRILL P PROD1 Orient & drill to 11663' with 100R TF, 2.6/2.6bpm, 3200/3650psi, 80-120fph ave ROP & 2-4k WOB. 02:15 - 02:30 0.25 DRILL P PROD1 Short 100' wiper trip. 02:30 - 02:50 0.33 DRILL P PROD1 Orient & drill to 11670' with 100R TF, 2.6/2.6bpm, 3200/3650psi, 40-60fph ave ROP & 2k WOB. Observe some ratty drilling, -ve/+ve drilling breaks & 0.3bpm losses from 11670'. 02:50 - 03:30 0.67 DRILL P PROD1 Drill to 11691' with 100R TF, 2.6/2.4bpm, 3200/3650psi, 40-60fph ave ROP & 2k WOB. 03:30 - 04:30 1.00 DRILL P PROD1 Wiper trip clean to window. RBIH to btm. Losses have improved. 04:30 - 04:40 0.17 DRILL P PROD1 Orient TF to 70R. 04:40 - 05:15 0.58 DRILL P PROD1 Drill to 11700' with 40R TF, 2.65/2.65bpm, 3200/3450psi, 20fph ave ROP & 2k WOB. 05:15 - 05:45 0.50 DRILL P PROD1 Drill to 11707' with 95R TF, 2.65/2.65bpm, 3200/3450psi, 30fph ave ROP & 2k WOB. 05:45 - 06:00 0.25 DRILL P PROD1 Orient TF around to 60R. 06:00 - 06:27 0.45 DRILL P i PROD1 Drilling Zone 2 TF @ 59R. I Qp = 2.66/2.71 bpm, CTP = 3300 13350 psi Printed: 3/22/2005 11: 12: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-26 02-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/5/2005 Rig Release: Rig Number: 1 Spud Date: 7/13/1982 End: 3/15/2005 06:00 - 06:27 0.45 DRILL P PROD1 IAlOA = 441 1449 psi. New mud going around 06:27 - 06:30 0.05 DRILL P PROD1 Oriented 2 clicks 06:30 - 08:45 2.25 DRILL P PROD1 Drilling Zone 2 TF @ 87-100L. ROP = 80-100 fph, 40 API sand Qp = 2.70 12.71 bpm, Losing 0.2 bpm fluid loss CTP = 3200 I 3350 psi; IAlOA = 441/449 psi. 08:45 - 09:05 0.33 DRILL P PROD1 Orient TF 09:05 - 10:00 0.92 DRILL P PROD1 Drilling Zone 2 TF @ 137R. ROP = 80-100 fph. Qp = 2.69/2.71 bpm, Losing <0.1 bpm fluid loss CTP = 3200 I 3350 psi; IAlOA = 405 I 383 psi. 10:00 - 10:45 0.75 DRILL P PROD1 Wiper trip to tie-in 10:45 - 10:55 0.17 DRILL P PROD1 At 10715 ft, PUH tie-in at RA Marker No correction 10:55 - 11 :40 0.75 DRILL P PROD1 RIH to btm. 11 :40 - 11 :50 0.17 DRILL P PROD1 Orient TF to 140L. P/U wt = 38k, Run-in wt = 17k. PVT = 305bbls. lAP = 450psi, OAP = 400psi. Geo wants to be @ 8966' sstvd @ +1-12000' md. 11 :50 - 12:05 0.25 DRILL P PROD1 Drill to 11880' with 135L TF, 2.7/2.7bpm, 3100/3450psi, 50fph ave ROP & 3k WOB. 12:05 - 14:15 2.17 DRILL P PROD1 Orient & drill to 11894' with 95-120L TF, 2.7/2.7bpm, 3100/3500psi, 60fph ave ROP & 3k WOB. 14:15 - 14:45 0.50 DRILL P PROD1 Orient & drill to 12000' (8967' sstvd) with 25L TF, 2.7/2.7bpm, 3100/3500psi, 80fph ave ROP & 6k WOB. 14:45 - 16:25 1.67 DRILL P PROD1 Wiper trip clean to window. RBIH to btm clean. 16:25 - 16:40 0.25 DRILL P PROD1 Orient TF to 75R. 16:40 - 17:10 0.50 DRILL P PROD1 Orient & drill to 12020' with 60R TF, 2.7/2.7bpm, 3100/3500psi, 60fph ave ROP & 2k WOB. 17:10 - 19:50 2.67 DRILL P PROD1 Orient & drill to 12063' with 90-11 OR TF, 2.65/2.25bpm, 3100/3500psi, 30-60fph ave ROP & 2-4k WOB. O.4bpm losses from 12040'. 19:50 - 20:10 0.33 DRILL P PROD1 Orient TF to 90 R 20:10 - 20:50 0.67 DRILL P PROD1 Drill ahead to 12,120' MD. - 3000 psi free spin - 2.6 I 2.5 bpm @ 3400 psi - Still losing approx 0.2 bpm 20:50 - 21 :20 0.50 DRILL P PROD1 Orient TF to 50 R. 21:05 - 22:15 1.17 DRILL P PROD1 Drill ahead to 12,150' MD - 3100 psi free spin - 2.7/2.6 psi at 3450 psi - Losing at 0.2 bpm (10 bph). 22:15 - 23:45 1.50 DRILL P PROD1 Wiper trip to window. - Shales have cleaned up. No overpulls or stacking during trip. 23:45 - 00:00 0.25 DRILL P PROD1 Drill ahead to 12,160' MD - 3100 psi free spin - 2.7/2.6 psi at 3500 psi - Losing at 0.1 bpm (5 bph). 3/16/2005 00:00 - 03:10 3.17 DRILL P PROD1 Drill ahead to 12,284' MD - 3100 psi free spin - 2.7 12.6 psi at 3500 psi - Losing at 0.1 bpm (5 bph). 03: 1 0 - 03:30 0.33 DRILL P PROD1 Orient TF to 80 R. 03:30 - 03:45 0.25 DRILL P PROD1 Drill ahead to 12,300' MD - 3100 psi free spin - 2.7/2.6 psi at 3500 psi Printed: 3/22/2005 11 :12:18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-26 02-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/5/2005 Rig Release: Rig Number: 1 Spud Date: 7/13/1982 End: 3/16/2005 03:30 - 03:45 0.25 DRILL P PROD1 - Losing at 0.1 bpm (5 bph). - Tentative Fault Zone at 12,172' MD to 12,201' MD. 03:45 - 05:45 2.00 DRILL P PROD1 Wiper trip to window. Tie in. -3.5' correction. - Stack up on shale at 11,900' MD. Orient LOHS, RIH through OK. 05:45 - 05:55 0.17 DRILL P PROD1 Drill ahead to 12317' MD - Oriented at 90 R - 3150 psi free spin - 2.6/2.6 psi at 3400 psi - Drilling with minimal losses. 05:55 - 06:40 0.75 DRILL P PROD1 Orient 1 click & drill to 12343' with 110-115R TF, 2.65/2.65bpm, 3150/3400psi, 45fph ave ROP & 3k WOB. Plan to hold 88degs inclination until we see evidence of HOT. 06:40 - 06:55 0.25 DRILL P PROD1 Orient TF around to 90R. P/U wt = 37k, Run-in wt = 15k. PVT = 281 bbls. lAP = 450psi, OAP = 440psi. 06:55 - 08:15 1.33 DRILL P PROD1 Drill to 12376' with 80R TF, 2.6/2.6bpm, 3300/3650psi, 40fph aye ROP & 3k WOB. Stacking @ 12376'. 08:15 - 08:30 0.25 DRILL P PROD1 Short 100' wiper trip. 08:30 -11:15 2.75 DRILL P PROD1 Drill to 12385' with 80-1 OOR TF, 2.6/2.6bpm, 3300/3650psi, 1 Of ph ave ROP & 6k WOB. Stacking & not making any progress. Not seeing much motor work. Geo seeing 60% Chert in BU samples. Decide to POOH to check bit. 11:15-14:00 2.75 DRILL P PROD1 POOH drilling BHA #12. 14:00 - 14:30 0.50 DRILL P PROD1 OOH. PJSM. SIB injector. UD bit - gauge 8/3/1 with a completely rung-out pilot. Changeout motor & MWD guts. Check orienter - not leaking oil, however will changeout due to possible weak springs. 14:30 - 16:45 2.25 DRILL P PROD1 M/U drilling BHA #13 with rebuild HC 3-3/4" STX404 PDC bit #9, new BHI 1.37deg motor & Sperry MWD/GR-RES, orienter & MHA. Scribe tools, download & initialize EWR. M/U injector. 16:45 - 19:00 2.25 DRILL P PROD1 RIH BHA #13. SHT MWD & orienter @ 3000' - OK. RIH. 19:00 - 19:30 0.50 DRILL P PROD1 Tie in to RA marker, -4' correction. 19:30 - 20:00 0.50 DRILL P PROD1 Continue to RIH. 20:00 - 20:15 0.25 DRILL P PROD1 Orient TF to 90 L. 20:15 - 21:00 0.75 DRILL P PROD1 Drill ahead to 12,426' MD - 3200 psi free spin - 2.6 I 2.6 psi at 3500 psi - Losses at 0.1-0.2 bpm. - Begin mud swap to new flo pro system. 21 :00 - 21 :20 0.33 DRILL P PROD1 Orient TF to 120 L. 21 :20 - 00:00 2.67 DRILL P PROD1 Drill ahead to 12,487' MD. - 3200 psi free spin - 2.61 2.6 psi at 3600 psi - ROP: 40 - 100 fph - Losses at 0.1-0.2 bpm. - Taking samples every 25 feet, looking for HOT. - Fluid swap complete. 3/17/2005 00:00 - 02:30 2.50 DRILL P PROD1 Drill ahead to 12,550' MD. - 3100 psi free spin - 2.6/2.6 psi at 3500 psi - Losses at 0.1-0.2 bpm. - Taking samples every 25 feet, looking for HOT. Printed: 3/22/2005 11:12:18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-26 02-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/5/2005 Rig Release: Rig Number: 1 Spud Date: 7/13/1982 End: 3/17/2005 00:00 - 02:30 2.50 DRILL P PROD1 - Drilling shale from 12,475' MD to 12,500' MD, ROP at 15 fph. 02:30 - 04:15 1.75 DRILL P PROD1 Wiper trip to window. - PU 40k - 400 psi motor work at 11,100' MD while POOH. - SO 17k 04:20 - 04:40 0.33 DRILL P PROD1 Orient TF to 90 L. 04:40 - 06:30 1.83 DRILL P PROD1 Drill ahead to 12572'. - 3200 psi free spin - 2.7/2.6 psi at 3600 psi - Losses at 0.1-0.2 bpm. - Still taking samples every 25 feet, no evidence of HOT. - PVT = 252bbls. lAP = 490psi, OAP = 455psi. 06:30 - 07:15 0.75 DRILL P PROD1 Attempt to drill - not getting much motor work. Pulling heavy on PIUs. Wipe up hole. 10k Olpull @ 12536' & 12525'. RBIH & work BHA past tight spots. Continue wiping hole to 12450'. RBIH clean to btm. P/U wt = 36k, Run-in wt = 16k. PVT = 246bbls. 07:15 - 07:30 0.25 DRILL P PROD1 Grind on to 12573' with 30L TF, 2.71/2.68bpm, 3200/3350psi & 13-15k WOB. Stacking wt. PVT = 246bbls. 07:30 - 07:45 0.25 DRILL P PROD1 Orient TF to 90R. PIU wt = 36k, Run-in wt = 15k. PVT = 243bbls. Should be @ 90degs @ the bit. Plan to level out in the upper sand. 07:45 - 08:00 0.25 DRILL P PROD1 Attempt to grind on with 90R TF, 2.71/2.68bpm, 3200/3350psi & 13-15k WOB. Getting good wt transfer but not much RT. Stacking WOB probably due to worn bit cutters. Decide to POOH for bit change. PVT = 246bbls. 08:00 - 12:00 4.00 DRILL P PROD1 POOH BHA # 13. MAD pass RES @ 1 Of pm in sand sections from 12573' to 11950' & from 11750' to 11600'. 12:00 - 13:45 1.75 DRILL P PROD1 OOH. PJSM. SIB injector. UD bit - gauge 2/2/1 with broken backreaming cutters & two plugged jets. Download & initialize EWR. M/U drilling BHA #14 with rebuild HC 3-3/4"x 4-1/8" RWDST bicenter bit #10, BHI 1.37deg motor & Sperry MWD/GR-RES, orienter & MHA. M/U injector. 13:45 - 15:45 2.00 DRILL P PROD1 RIH BHA #14. SHT MWD & orienter @ 3000' - OK. RIH to below window. 15:45 - 16:00 0.25 DRILL P PROD1 Log up & tie into RA Pip tag - -8.5' correction. 16:00 - 17:20 1.33 DRILL P PROD1 RIH & tag @ 11100' & 12385'. P/U, orient to as drilled TF, reduce pump rate & run thru. Continue RIH to btm tagged @ 12571'. 17:20 - 17:30 0.17 DRILL P PROD1 Orient TF to 65R. P/U wt = 38k, Run-in wt = 17k. PVT = 197bbls. 17:30 - 17:50 0.33 DRILL P PROD1 Drill to 12588' with 45R TF, 2.7/2.7bpm, 3100/3500psi & 6k WOB. Drilling ratty with TF flopping from 40R to 75R to 90R. 17:50 - 18:15 0.42 DRILL P PROD1 Orient TF around to HS. 18:15 - 21:00 2.75 DRILL P PROD1 Drill ahead to 12,673' MD - 3200 psi free spin - 2.7/2.7 psi at 3700 psi - Losses at 0.1 bpm. - Still taking samples every 25 feet, no evidence of HOT. - PVT = 190 bbls. lAP = 485 psi, OAP = 430 psi. - PVT = 177 bbls at wiper trip. 21:00-23:15 2.25 DRILL P PROD1 Wiper trip to window. - Overpull and motor work at 12,000' MD. Printed: 3/22/2005 11: 12: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-26 02-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/5/2005 Rig Release: Rig Number: 1 Spud Date: 7/13/1982 End: 3/17/2005 21:00-23:15 2.25 DRILL P PROD1 - Fill pits with 95 bbls of flo pro - PU 39k; SO 15k at window. - Stacked up at 11,100' MD, slight motor work at 12,100' MD. 23:00 - 23:30 0.50 DRILL P PROD1 Orient 100 L. 23:30 - 00:00 0.50 DRILL P PROD1 Drill ahead to 12,687' MD. - 3200 psi free spin - 2.7 12.7 psi at 3700 psi - Losses at 0.1 bpm. - Still taking samples every 25 feet, no evidence of HOT. - PVT = 255 bbls. lAP = 460 psi, OAP = 460 psi. - Erratic tool face, orienting required. 3/18/2005 00:00 - 02:30 2.50 DRILL P PROD1 Drill ahead to 12,800' MD - 3200 psi free spin - 2.7/2.7 psi at 3700 psi - Losses at 0.1 bpm. - Taking samples every 50 feet. - Sticky on bottom (differential). - PVT = 252 bbls. lAP = 460 psi, OAP = 460 psi. - PVT = 241 bbls. 02:30 - 05:00 2.50 DRILL P PROD1 Wiper trip to window. - 5k stackup at 11,100' MD. - Stackup and motor work at 12,000' MD. Pick up, run back through OK. - Ratty through shales at 12,100' MD. - SO 12.5k at TD. 05:00 - 05:30 0.50 DRILL P PROD1 Orient TF to 90 L. - Became stuck while orienting. Follow Stuck Pipe SOP, allowing coil to relax in neutral position for 15 minutes. - PVT = 226 bbls. 05:30 - 06:30 1.00 DRILL N STUC PROD1 Wait on crude. Meanwhile circ btms up. Work stuck pipe in stages to max 90k - no luck. Attempt to orient 2x - not getting clicks & CTP rise to 4100psi. Seems like we're stuck across the BHA. 06:30 - 10:45 4.25 DRILL N STUC PROD1 Relax pipe @ neutral wt for 20m ins 3x & pushlpull to -6k/80k without success. Fatigue of CT across gooseneck @ +1-10%. Crude truck arrives onsite. Conduct Reid vapor pressure - 0.7psi @ 100F. 10:45 - 11 :00 0.25 DRILL N STUC PROD1 Held PJSM & HAlHM. Discussed used crude disposal & well control risks - worst case reduction in overbalance = 75psi. 11 :00 - 11 :40 0.67 DRILL N STUC PROD1 Pump 10bbls of crude. Zero In-Total. Displace crude with mud. Pump out 2bbls of crude out of bit. SID pumps. Observe CT work free while pushing pipe down to neutral wt. Circ out all crude. 11 :40 - 13:00 1.33 DRILL N STUC PROD1 Wiper trip to window. Had 10k O/pull @ 12100' shale. 13:00 - 13:15 0.25 DRILL N STUC PROD1 Log up & tie into RA Pip tag - +8' correction. 13:15 - 14:25 1.17 DRILL N STUC PROD1 Continue RIH to btm tagged @ 12809'. 14:25 - 14:30 0.08 DRILL P PROD1 Drill to 12815' with 80R TF, 2.7/2.7bpm, 3200/3600psi, 2k WOB & 65fph ave ROP. 14:30 - 15:00 0.50 DRILL P PROD1 Orient TF around to 80R. 15:00 - 18:30 3.50 DRILL P PROD1 Drill to 12912' with 80-95R TF, 2.7/2.7bpm, 3300/3700psi, 3k WOB & 50fph ave ROP. 18:30 - 19:30 1.00 DRILL N STUK PROD1 Stuck pipe while drilling ahead. - Attempt to free, no go. Printed: 3/22/2005 11: 12: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-26 02-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/5/2005 Rig Release: Rig Number: 1 Spud Date: 7/13/1982 End: 3/18/2005 18:30 - 19:30 1.00 DRILL N STUK PROD1 - Pump 5 bbls crude. - Pull free with 2 bbls crude outside pipe. 19:30 - 20:00 0.50 DRILL P PROD1 Orient TF to 90 R. 20:00 - 20:45 0.75 DRILL P PROD1 Drill ahead to 12,955' MD. - 3300 psi free spin - 2.7/2.7 psi at 3700 psi - Losses at 0.1 bpm. - Taking samples every 50 feet. - Sticky on bottom (differential). - PVT = 320 bbls. lAP = 460 psi, OAP = 460 psi. - Dumped 34 bbls to cuttings box (crude contaminated) - New PVT = 280 bbls. 20:45 - 21 :30 0.75 DRILL P PROD1 Orient TF to 90 R - Orienter giving 10 degree clicks 21:30 - 22:15 0.75 DRILL P PROD1 Drill ahead to final TD at 13,000' MD - 3300 psi free spin - 2.6/2.6 psi at 3700 psi - Losses at 0.1 bpm. - Taking samples every 50 feet. - Sticky on bottom (differential). - PVT = 280 bbls. lAP = 460 psi, OAP = 500 psi. - PVT = 272 bbls at final TD. 22:15 - 23:30 1.25 DRILL P PROD1 Wiper trip to window. - PU 40k - Overpull at 12,550' MD. - Motor work at 11,830' MD. 23:30 - 00:00 0.50 DRILL P PROD1 Tie in to RA marker. +3' correction. 3/19/2005 00:00 - 01:15 1.25 DRILL P PROD1 Wiper trip to TD - SO 15k - Motor work at 11,100' MD. - Stackup (5k) at 11,900' MD. - Stackup, stall 12,600' MD. PU, RIH OK. - Begin pumping pill. - Tag up at 13,006' MD. 01:15 - 01:30 0.25 DRILL P PROD1 Continue circulating pill down coil. 01 :30 - 02:20 0.83 DRILL P PROD1 POOH, laying in liner pill. - Overpull at 12,550' MD. 02:20 - 04:00 1.67 DRILL P PROD1 Continue to POOH. - Flag 10,047' EOP (liner 50' from TD) - Flag 7,754' EOP (liner at window) 04:00 - 06:00 2.00 DRILL P PROD1 Standback injector. Lay down BHA. Download RES tool. Continue laying down BHA. 06:00 - 06:30 0.50 CASE P RUNPRD Rig up liner running equipment. 06:30 - 06:45 0.25 CASE P RUNPRD Held PJSM on M/U & RIH with liner. 06:45 - 11 :00 4.25 CASE P RUNPRD M/U 2-7/8" STL rotating guide shoe, 1 shoe jt, float collar & landing collar. M/U 54jts of 2-7/8" STL 6.16# L-80, 2-7/8" pup & LSL sub. M/U 39jts of 3-3/16" 6.2# L-80 TCII, XO, 1 jt of 3-1/2" 9.3# L80 STL, X nipple & 3-1/2" pups. 11 :00 - 11 :30 0.50 CASE N SFAL RUNPRD Inadvertently, flare-up body of CTLRT while making it up. W.O. another CTLRT from BOT. 11 :30 - 12:45 1.25 CASE P RUNPRD M/U new Baker CTLRT. M/U Baker CTC. Pull test to 35k & Printed: 3/22/2005 11: 12: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-26 02-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/5/2005 Rig Release: Rig Number: 1 Spud Date: 7/13/1982 End: 3/19/2005 11 :30 - 12:45 1.25 CASE P RUNPRD P/test to 3500 psi - OK. 12:45 - 13:30 0.75 CASE P RUNPRD M/U dart catcher. Load & launch wiper dart. Chase dart with mud & pig CT. Dart bumped on catcher @ 54.3bbls. 13:30 - 13:45 0.25 CASE N SFAL RUNPRD BOT swivel lock up while being M/U. Fetch replacement swivel (....good to be near Deadhorse). 13:45 - 14:10 0.42 CASE P RUN PRO M/U BOT swivel & M/U injector. 14:10-16:10 2.00 CASE P RUNPRD RIH with liner (OAL - 2912.59') on CT. See flag @ 10685.3'. Correct CTD -18.3' to 10667'. Check up wt - 37k, down wt- 18k. RIH smoothly thru window & continue RIH @ +1-50fpm. See 2nd flag 2' deep. Tag TD @ 13015' CTD. P/U @ 48k. RBIH @ 20k & retag TD @ same depth. Correct CTD to 13006' . 16:10-16:50 0.67 CASE P RUN PRO PUH to ball drop position. Load 5/8" steel ball & circ with mud @ 2.5/2.5bpm, 2500psi. RBIH & set down 10k down on CTLRT. Slow down @ 38 bbls away. Ball on seat @ 41.1bbls. Pressure up to 3950psi & release CTLRT. P/U @ 31k & confirm release. 16:50 - 17:30 0.67 CASE N WAIT RUNPRD W. O. KCL. Hot water plant is running low on water. Meanwhile circ well with flopro mud at 2.0/1.82bpm & 2500psi. 17:30 - 20:15 2.75 CASE P RUNPRD Displace well to 2% KCL. Mix 30 bbl bio pill. 20:15 - 20:30 0.25 CEMT P RUNPRD PJSM on cement job. 20:30 - 21:15 0.75 CEMT P RUNPRD Batch up 30 bbls cement. - Cement at density. 21:15-22:20 1.08 CEMT P RUNPRD Cement liner. - Fill lines with FW to pressure test. - Pressure test lines to 4000 psi. - Pump 1 bbl fresh water. - Zero in MM when cement going down hole, density at 15.91 ppg). - Pump cement: 26.4 bbls. - Flush lines. Load dart. - Calculated liner volume = 19.2 bbls. Coil dart volume: 54.3 bbls. - Pump bio water: 25 bbls. - Follow with 2% KCI at 3.2 bpm. - Zero MM at 45.2 bbls. - Slow pump rate to 1.0 bpm at 46.7 bbls away. - Latch at 54.7 bbls. - Shear at 3376 psi. - Pump at 2.3 I 2.1 bpm at 1600 psi. - Return rate fluctuating between 1.5 and 2.5, pump pressure increasing. Decrease rate to 2.0 bpm, out rate and pressure stabilized at 1.9 11.8 bpm and 2100 psi. - Bump plug at 73.1 bbls. - Pressure up to 2600 psi. - Bleed off, check floats. Floats OK. - 25.5 bbls cement behind pipe. 22:20 - 00:00 1.67 CEMT P RUNPRD POOH replacing voidage. 3/20/2005 00:00 - 00:30 0.50 CEMT P RUNPRD Stand back injector. Lay down CTLRT. 00:30 - 01 :00 0.50 EVAL P LOWER1 Prep floor for running CSH. 01 :00 - 01 :30 0.50 EVAL N WAIT LOWER1 Wait on SLB logging engineer, stuck behind rig move. Printed: 3/22/2005 11: 12: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-26 02-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/5/2005 Rig Release: Rig Number: 1 Spud Date: 7/13/1982 End: 3/20/2005 01 :30 - 02:15 0.75 EVAL P LOWER1 Program tools. Bring to floor. 02:15 - 02:45 0.50 EV AL P LOWER1 PJSM. 02:45 - 03:15 0.50 EV AL P LOWER1 PU logging BHA and source. 03:15 - 06:00 2.75 EVAL P LOWER1 PU 94 joints of CSH from the shed. - Cement at 800 psi compressive strength at 04:30. 06:00 - 07:30 1.50 EVAL P LOWER1 RIH with logginglcleanout assembly on CT to 9900'. 07:30 - 09:30 2.00 EVAL P LOWER1 Log down @ 30fpm from 9900'. Reciprocate 2x across LSL sub @ 1.5bpm. Start pumping down 150kcps Flo-Pro perf pill. Continue logging down to PBTD tagged @ 12994'. Tested H2S & LEL Alarms. 09:30 - 10:30 1.00 EVAL P LOWER1 Log up @ 60fpm from PBTD to 9900' while laying-in 150kcps perf pill in liner. 10:30 - 12:15 1.75 EVAL P LOWER1 POOH logginglcleanout BHA#16. 12:15 - 12:30 0.25 EVAL P LOWER1 PJSM for UD & RIB CSH. 12:30 - 13:30 1.00 EVAL P LOWER1 RIB 47 stands & UD 2 jts of 1-1/4" CSH. 13:30 - 13:45 0.25 EVAL P LOWER1 PJSM for UD SWS MCNUCCUGR logging tool. 13:45 - 14:15 0.50 EVAL P LOWER1 UD SWS MCNUCCUGR logging tool, motor & mill. Check log data quality - OK. 14:15 - 15:00 0.75 CEMT P RUNPRD Cement> 2000psi compressive strength. Line up & Pltest well bore for 30mins as follows: Time WHP CTP lAP OAP Onset -26 0 386 291 0 2020 0 509 410 10 1842 0 496 397 20 1791 0 490 393 30 1743 0 486 389 => Passed: Leaked 14% of test pressure in 30 mins. Will not set L TP. 15:00 - 15:45 LOWER1 Load perf guns into pipe shed. R/U safety jt & prep to M/U perf guns. Meanwhile download CNL data. From log data, PBTD = 12969.57' & TOL = 10091'. 15:45 - 16:00 LOWER1 PJSM on perforation job. Fax CNL log to ANG Geo. ANC Geo revise preliminary perf picks to 12650' - 12850' & 12890'- 12950' . 16:00 - 16:45 0.75 LOWER1 M/U 15jts of 2" HSD 6spf 2006PJ guns & blanks with CBF firing system. 16:45 - 18:00 1.25 PERFO LOWER1 M/U 43 doubles of 1-1/4" CSH tbg. MIU injector. 18:00 - 18:30 0.50 PERFO LOWER1 RIH with perforating BHA#17 circ perf pill @ min rate. 18:30 - 19:00 0.50 PERFO LOWER1 Repair levelwind override. 19:00 - 20:30 1.50 PERFO LOWER1 RIH with perf guns. 20:30 - 21 :20 0.83 PERFO LOWER1 Tag TD. PU and correct depth to 12,969.6' MD. Pump 10 bbls perf pill. Drop 5/8" phenolic ball. Pump 10 bbls perf pill. Chase ball to seat at 2.0 bpm. Slow pump rate to 0.7 bpm at 38 bbls away. Ball on seat at 49.6 bbls. SO pumps. RIH 5 feet. PUH, pressure up on ball. Ball shear at 2800 psi, 12,952' MD. 21:20 - 22:15 0.92 PERFO P LOWER1 POOH with guns in liner. - Pump at 0.6 bpm. - Hold backpressure of 300 psi. 22:15 - 22:45 0.50 PERFO LOWER1 SD pumps and open choke. Flow check for 30 minutes. 22:45 - 23:45 1.00 PERFO LOWER1 POOH with perf guns, filling hole from the backside.. Printed: 3/22/2005 11: 12: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 02-26 02-26 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 3/5/2005 Rig Release: Rig Number: 1 Spud Date: 7/13/1982 End: 00: 15 - 02:00 1.75 02:00 - 04:00 2.00 04:00·05:15 1.25 WHSUR P 05:15 - 06:15 1.00 RIGD P 06:15·06:45 0.50 RIGD P 06:45 - 07:00 0.25 RIGD P 07:00 - 10:00 3.00 RIGD P Flowcheck at surface. Continue to flowcheck well. - Prep rig floor. LOWER1 Rack back 43 stands CSH. LOWER1 Lay down 15 perf guns. Load out guns. POST MU Nozzle. RIH to 2500' MD. Freeze protect with 60/40 MEOH. POOH. POST Blow down reel with N2 & bleed off. POST SIB injector & UD nozzle BHA. Meanwhile clean out pits & tanks. POST PJSM for N/D BOP. POST NID BOP. N/U & Pltest tree cap. Release rig @ 10:00Hrs on 3/21/04. Printed: 3/22/2005 11: 12: 18 AM Halliburton Sperry-Sun North Slope Alaska BPXA 02-26 - 2-26C . Job No. AKMW3591162, Surveyed: 18 March, 2005 Survey Report 7 April, 2005 Your Ref: API 500292077403 Surface Coordinates: 5949616.08 N, 686759.48 E (70016' 02.0830" N, 148029' 23.0453" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 58.70ft above Mean Sea Level . SpE!l"""l"""g-sul! DRILLINGSeRvu::es A Halliburton Company Survey Ref: svy4513 Halliburton Sperry-Sun Survey Report for 02·26 - 2-26C Your Ref: API 500292077403 Job No. AKMW3591162, Surveyed: 18 March, 2005 North Slope Alaska BPXA Measured True 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) 10649.50 33.750 295.580 8576.75 8635.45 443.86 S 4841 .47 W 5949052.24 N 681930.51 E 4859.48 Tie On Point MWD Magnetic 10657.00 33.580 296.830 8582.99 8641.69 442.02 S 4845.20 W 5949053.99 N 681926.73 E 9.513 4862.96 Window Point 10688.65 29.880 290.000 8609.92 8668.62 435.37 S 4860.43 W 5949060.26 N 681911.34E 16.278 4877.26 10719.91 26.630 281.000 8637.46 8696.16 431.37 S 4874.64 W 5949063.91 N 681897.04 E 17.117 4890.87 10739.23 24.230 277.660 8654.91 8713.61 430.01 S 4882.82 W 5949065.06 N 681888.83 E 14.467 4898.83 . 10770.06 20.480 268.920 8683.42 8742.12 429.27 S 4894.49 W 5949065.51 N 681877.15 E 16.225 4910.32 10802.33 25.200 263.530 8713.16 8771.86 430.15 S 4906.97 W 5949064.32 N 681864.69 E 15.985 4922.81 10831.52 28.280 267.930 8739.23 8797.93 431.10 S 4920.06 W 5949063.05 N 681851.63 E 12.537 4935.92 10863.36 31 .450 273.400 8766.84 8825.54 430.88 S 4935.89 W 5949062.87 N 681835.80 E 13.118 4951.61 10892.67 35.330 268.990 8791.31 8850.01 430.58 S 4952.01 W 5949062.78 N 681819.68 E 15.607 4967.57 10923.89 40.350 271.810 8815.96 8874.66 430.42 S 4971 .15 W 5949062.46 N 681800.54 E 17.004 4986.55 10955.56 45.370 273.040 8839.17 8897.87 429.50 S 4992.66 W 5949062.85 N 681779.01 E 16.069 5007.79 10984.82 49.780 273.750 8858.90 8917.60 428.21 S 5014.22 W 5949063.60 N 681757.43 E 15.178 5029.03 11018.26 55.070 272.340 8879.29 8937.99 426.82 S 5040.67 W 5949064.34 N 681730.95 E 16.168 5055.12 11051.10 58.850 271.460 8897.19 8955.89 425.91 S 5068.18 W 5949064.56 N 681703.42 E 11.727 5082.31 11081.57 62.380 267.930 8912.14 8970.84 426.07 S 5094.72 W 5949063.75 N 681676.90 E 15.364 5108.67 11110.60 65.200 263.530 8924.97 8983.67 428.02 S 5120.68 W 5949061.16 N 681650.99 E 16.709 5134.68 11140.89 70.130 262.470 8936.47 8995.17 431.43 S 5148.48 W 5949057.05 N 681623.29 E 16.594 5162.68 11170.40 74.450 261.240 8945.45 9004.15 435.42 S 5176.30 W 5949052.37 N 681595.57 E 15.168 5190.78 11203.14 79.380 264.940 8952.86 9011.56 439.24 S 5207.95 W 5949047.77 N 681564.03 E 18.650 5222.66 11238.15 84.490 266.520 8957.77 9016.47 441.82 S 5242.50 W 5949044.33 N 681529.55 E 15.264 5257.27 11272.58 89.160 270.400 8959.68 9018.38 442.74 S 5276.85 W 5949042.56 N 681495.24 E 17.621 5291.47 . 11303.12 89.340 264.760 8960.08 9018.78 444.03 S 5307.35 W 5949040.51 N 681464.78 E 18.475 5321.90 11333.32 88.720 260.360 8960.59 9019.29 447.94 S 5337.28 W 5949035.86 N 681434.95 E 14.711 5352.09 11361.15 87.840 256.480 8961.43 9020.13 453.52 S 5364.53 W 5949029.61 N 681407.86 E 14.290 5379.81 11394.87 87.580 252.780 8962.77 9021.47 462.45 S 5397.01 W 5949019.88 N 681375.60 E 10.991 5413.14 11427.35 91.370 249.780 8963.07 9021.77 472.87 S 5427.76W 5949008.69 N 681345.12 E 14.881 5444.93 11460.41 93.660 244.850 8961.62 9020.32 485.60 S 5458.22 W 5948995.21 N 681314.98 E 16.429 5476.72 11493.14 94.360 242.210 8959.33 9018.03 500.15 S 5487.45 W 5948979.94 N 681286.13 E 8.326 5507.50 11527.11 91 .450 238.510 8957.61 9016.31 516.93 S 5516.93 W 5948962.44 N 681257.08 E 13.845 5538.80 11560.55 89.250 235.860 8957.40 9016.10 535.05 S 5545.02 W 5948943.63 N 681229.44 E 10.299 5568.90 11594.45 89.780 245.380 8957.69 9016.39 551.66 S 5574.53 W 5948926.29 N 681200.35 E 28.125 5600.21 11624.63 89.340 251.020 8957.92 9016.62 562.86 S 5602.54 W 5948914.39 N 681172.63 E 18.744 5629.37 11657.01 88.190 257.190 8958.62 9017.32 571.72 S 5633.66 W 5948904.76 N 681141.74 E 19.378 5661.34 11688.12 87.050 261.770 8959.92 9018.62 577.40 S 5664.21 W 5948898.33 N 681111.34 E 15.159 5692.36 7 April, 2005 - 15:39 Page 2 of 5 Dril/Quest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 02-26 - 2-26C Your Ref: API 500292077403 Job No. AKMW3591162, Surveyed: 18 March, 2005 North Slope Alaska BPXA Measured True 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) 11724.39 88.270 266.980 8961.40 9020.10 580.95 S 5700.26 W 5948893.89 N 681075.39 E 14.741 5728.57 11758.50 89.690 262.820 8962.00 9020.70 583.98 8 5734.22 W 5948890.02 N 681041.51 E 12.885 5762.65 11784.74 90.660 258.240 8961.92 9020.62 588.30 8 5760.10 W 5948885.06 N 681015.75 E 17.841 5788.86 11817.43 90.400 257.190 8961.62 9020.32 595.25 8 5792.04 W 5948877.32 N 680983.99 E 3.309 5821.41 11849.61 89.780 253.310 8961.57 9020.27 603.448 5823.15 W 5948868.35 N 680953.09 E 12.210 5853.29 11886.48 87.400 251.370 8962.48 9021.18 614.628 5858.27 W 5948856.31 N 680918.26 E 8.327 5889.51 . 11917.16 88.020 243.790 8963.71 9022.41 626.31 8 5886.59 W 5948843.92 N 680890.24 E 24.769 5919.04 11951.33 86.870 239.560 8965.23 9023.93 642.50 8 5916.63 W 5948826.99 N 680860.61 E 12.817 5950.83 11985.71 86.700 236.920 8967.16 9025.86 660.57 8 5945.81 W 5948808.21 N 680831.89 E 7.683 5981.99 12014.75 90.130 236.750 8967.96 9026.66 676.44 8 5970.11 W 5948791.73 N 680807.99 E 11.826 6008.05 12045.56 90.130 241.150 8967.89 9026.59 692.33 S 5996.50 W 5948775.19 N 680782.01 E 14.281 6036.17 12076.09 89.780 249.080 8967.92 9026.62 705.178 6024.17 W 5948761.67 N 680754.66 E 26.000 6065.20 12106.10 86.610 252.080 8968.86 9027.56 715.148 6052.45 W 5948751.00 N 680726.63 E 14.539 6094.49 12136.48 89.870 256.830 8969.79 9028.49 723.27 8 6081.69 W 5948742.15 N 680697.60 E 18.956 6124.51 12172.34 87.050 262.300 8970.76 9029.46 729.768 6116.93 W 5948734.79 N 680662.54 E 17.155 6160.27 12206.46 86.610 266.700 8972.65 9031.35 733.03 8 6150.83 W 5948730.68 N 680628.73 E 12.940 6194.32 12240.49 90.130 270.230 8973.62 9032.32 733.94 8 6184.83 W 5948728.93 N 680594.77 E 14.645 6228.17 12271.79 89.160 275.690 8973.81 9032.51 732.32 S 6216.07 W 5948729.77 N 680563.49 E 17.717 6258.99 12300.93 89.600 280.450 8974.12 9032.82 728.23 8 6244.91 W 5948733.14 N 680534.56 E 16.404 6287.11 12333.55 88.190 286.790 8974.75 9033.45 720.56 8 6276.59 W 5948740.03 N 680502.69 E 19.907 6317.62 12361.87 89.250 292.250 8975.39 9034.09 711.108 6303.27 W 5948748.82 N 680475.79 E 19.635 6342.95 12399.66 89.690 294.370 8975.74 9034.44 696.158 6337.97W 5948762.91 N 680440.73 E 5.729 6375.57 . 12431.48 89.600 289.610 8975.93 9034.63 684.24 8 6367.47 W 5948774.08 N 680410.95 E 14.962 6403.39 12462.19 86.170 286.260 8977.07 9035.77 674.798 6396.66 W 5948782.80 N 680381.53 E 15.606 6431.21 12494.75 83.260 280.970 8980.07 9038.77 667.168 6428.15 W 5948789.65 N 680349.86 E 18.481 6461.54 12525.94 85.730 275.160 8983.06 9041.76 662.81 8 6458.87 W 5948793.24 N 680319.04 E 20.161 6491.51 12555.33 88.190 271.110 8984.62 9043.32 661.20 S 6488.17 W 5948794.11 N 680289.71 E 16.106 6520.39 12596.94 90.220 274.100 8985.20 9043.90 659.31 S 6529.73 W 5948794.97 N 680248.12 E 8.685 6561.41 12630.61 91 .450 275.510 8984.71 9043.41 656.49 8 6563.27 W 5948796.96 N 680214.51 E 5.557 6594.36 12663.52 98.060 277 .450 8981.98 9040.68 652.80 8 6595.84 W 5948799.85 N 680181.86 E 20.926 6626.23 12695.11 99.210 279.040 8977.24 9035.94 648.32 8 6626.75 W 5948803.56 N 680150.86 E 6.166 6656.36 12726.03 95.330 275.690 8973.33 9032.03 644.39 8 6657.16 W 5948806.73 N 680120.36 E 16.520 6686.07 12757.50 92.600 271.990 8971.15 9029.85 642.298 6688.47 W 5948808.05 N 680089.00 E 14.588 6716.89 12783.59 89.340 268.640 8970.71 9029.41 642.158 6714.55 W 5948807.55 N 680062.93 E 17.914 6742.76 12813.41 88.990 267.930 8971.14 9029.84 643.04 8 6744.36 W 5948805.92 N 680033.15 E 2.654 6772.45 7 April, 2005 - 15:39 Page 3 of 5 DrillQuest 3.03.06.008 North Slope Alaska Measured True Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 12849.43 89.960 273.930 8971.47 9030.17 12881.56 90.750 278.150 8971.27 9029.97 12915.16 85.550 282.910 8972.36 9031.06 12946.65 83.520 286.610 8975.36 9034.06 12978.33 82.640 292.430 8979.18 9037.88 13006.00 82.640 292.430 8982.72 9041 .42 Halliburton Sperry-Sun Survey Report for 02-26 - 2-26C Your Ref: API 500292077403 Job No. AKMW3591162, Surveyed: 18 March, 2005 BPXA Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (0/100ft) 642.46 S 6780.35 W 5948805.61 N 679997.15 E 16.873 6808.11 639.08 S 6812.30 W 5948808.19 N 679965.14 E 13.362 6839.40 632.94 S 6845.29 W 5948813.50 N 679932.00 E 20.973 6871.40 624.96 S 6875.60 W 5948820.73 N 679901.50 E 13.355 6900.51 614.46 S 6905.23 W 5948830.50 N 679871.62 E 18.447 6928.64 603.99 S 6930.59 W 5948840.33 N 679846.00 E 0.000 6952.54 Projected Survey . 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 263.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13006.00ft., The Bottom Hole Displacement is 6956.86ft., in the Direction of 265.019° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 10649.50 10657.00 13006.00 8635.45 8641.69 9041 .42 443.86 S 442.02 S 603.99 S 4841.47W 4845.20 W 6930.59 W Comment Tie On Point Window Point Projected Survey . 7 April, 2005 - 15:39 Page 4 of 5 DrillQuest 3.03.06.008 North Slope Alaska Survey tool program for 02-26 - 2-26C From Measured Vertical Depth Depth (ft) (ft) 0.00 9194.70 10649.50 0.00 7418.43 8635.45 Halliburton Sperry-Sun Survey Report for 02-26 - 2-26C Your Ref: API 500292077403 Job No. AKMW3591162, Surveyed: 18 March, 2005 BPXA To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 9194.70 10649.50 13006.00 7418.43 8635.45 9041.42 CB-GYRO-MS (02-26A) MWD+IIFR+MS (02-26B) MWD Magnetic (2-26C) . . 7 April, 2005 - 15:39 Page 5 of 5 DrillQuest 3.03.06.008 . . i'~ ¡ , I~ ~ ¡ LJ FRANK H. MURKOWSKI, GOVERNOR AlfASKA. OIL Al'tD GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe 02-26C BP Exploration (Alaska) Inc. Permit No: 205-019 Surface Location: 1560' SNL, 6' WEL, SEC. 35, T11N, R14E, UM Bottomhole Location: 2214' SNL, 1548' WEL, SEC. 34, T11N, R14E, UM Dear Ms. Endacott: 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 . ess any required test. Contact the Commission's petroleum field inspector at (907 59-36 ager). S' cer 1 , DATED thisl1"day of February, 2005 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. WGA- '2H Iz.co';) }I, ,. 1 a. Type of work o Drill BRedrill 11 b. Current Well Class o Exploratory. DeveloþrneTltOit . 0 Ml/ftIþté'~h'e' ORe-Entry o Stratigraphic Test o Service 0 Developm~tGa~ 0 Single Zone 2. Operator Name: 5. Bond: 181 Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S1OO302630-277 PBU 02-26C 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 12900 TVD 8952ss Prudhoe Bay Field I Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028309 1560' SNL, 6' WEL, SEC. 35, T11N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 1720' SNL, 4802' WEL, SEC. 35, T11 N, R14E, UM March 10, 2005 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2214' SNL, 1548' WEL, SEC. 34, T11N, R14E, UM 2560 29,000' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x-686759 Y-5949616 Zone- ASP4 (Height above GL): 58.7' feet 07-05 is 1038' away at 11856' MD 16. Deviated Wells: Kickoff Depth: 10665 feet 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Maximum Hole Angle: 91 decrees Downhole: 3250 Surface: 2355 ..... 18.. casing program: Specifications Setting Depth . ullantity.ofce~C90t Size Top Bottom (cJ,or sacks Hole Casina Weiaht Grade Couclina Lenath MD TVD MD TVD Oncludina staae data) 4-1/8' x 3-314' 3-3116' x 2-7/8' 6.2# 16.16# L-80 rrClI/ST 2300' 10600' 8536' 12900' 8952' 92 sx Class 'G' /' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Qpèrations) > Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft):1 Junk (measured): 12707 9034 None 12622 9033 None Casing Length Size Cement Volume MD TVD !=:trlJMIIr::l1 r 79' 20" 1400 sx Arcticset II 79' 79' 2661' 13-3/8" 12300 sx Fondu, 400 sx PF 'C' 2661' 2661' 9268' 9-5/8" 500 sx Class 'G', 300 sx PF 'C' 9268' 7470' Pr~~' '^..~^ Liner 1306' 7" 248 sx Class 'G' 9105' - 10411' 7356' - 8434' Liner 2482' 4-1/2" 325 sx Class 'G' 10225' - 12707' 8272' - 9034' /) Perforation Depth MD (ft): 11260' - 12618' IPerfOration Depth TVD (ft): 9033' -~ 20. Attachments 181 Filing Fee, $100 181 BOP Sketch 181 Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report 181 Drilling Fluid Program 181 20 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mary Endacott, 564-4388 Printed Name Mary Endacott /, Title CT Drilling Engineer Sianature '11/1/1 !\A;/ C411/1j;ÍJ¡:¡Zlit! Date z- '2-05 Prepared By Name/Number. Phone 564-4388 Terrie Hubble, 564-4628 / / Commission Use Only Permit To Drill v API Number: I Permit Approval I See cover letter for Number:~.<_ð J $> 50- 029-20774-03-00 Date: other requirements Conditions of Approval: Samples Required LJ Yes gNo Mud Log Required DYes ÆNO Hy n Sulfide Measures ~Yes DNo Directional Survey Required ~Yes LJ No Other: lfit} ,10 ~Ç-OO , f'~/. ~ iv/oS' _mved lJT ~~ APPROVED BY ( . . ....... r THE COMMISSION Date Form 10-401 ReviSlf"d 0êf2004 '" .- ~ &(Jbmit If! Duplicate - .. STATE OF ALASKA . ,. ALA~ OIL AND GAS CONSERVATION~MMISSldN PERMIT TO DRILL 20 AAC 25 005 / . BP 2-26C Sidetrack . Mud Program: · Milling: 8.4 - z:?pg brine with biozan · Drilling: 8.5 CJtppg Flo Pro Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 33/16" x 2 7/8" solid cemented liner com~letj .0,600'-12,900'. / · The liner cement volume is planned to be 9b s of 15.8 ppg class G. Casinl!!Liner Information 13 3/8", L-80, 72#, Burst 5380 psi; collapse 2670 psi 95/8", L-80 47#, Burst 6870, collapse 4750 psi 7", L-80, 26#, Burst 7240, collapse 5410 psi 4 V2", 12.6#, L-80, Burst 8430, collapse 7500 psi Planned Liner 33/16" L-80 TCII, 6.2#, Burst 8520 psi; collapse 7660 psi (hole size 4.125") ). 2 7/8" L-80 STL 6.16#, Burst 10570 psi; collapse 11170 psi (hole size 3.75") ) Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 91deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · Distance to nearest property line: 29,000 ft · Distance to nearest well (7-05) within pool: 1038ft at 11856ft / Logging · MWD directional Gamma Ray and Resistivity will be run over all of the openhole section. · MCNL will be run cased hole. Hazards · Max recorded HzS on pad is lOOppm on we1l2-29A 8/92. · One mapped fault crossing with large throw, lost circulation risk is medium. Reservoir Pressure · Res. press. is estimated to be 3250 psi at 88oo'ss (7.1 ppg EMW). " Max. surface pressure with gas (0.10 psi/ft) to surface is 2355 psi. /' lREE = 4-1/16" FfIIC 5M WELLHEAD = FfIIC-5M AClUATOR- AXLESON KB. ELEV = 58.1' BF. ELEV = 30.2' KOP= 2995' tv1ax Angle = 94 @ 11332' Datum tvD = 10918' Datum 1V D - 8800' SS 02-268 / SAÆTY NOTES: WELL ANGlE> 70° @ 11175' & > 900@ 11275'. PRE- 02-26B SDTRKWELLBORE NOT SHOWN BB..OW WHIPSTOCK 02-26A P&A'D W/CMT. . I I 2219' 113-3/8" CSG, 72#, L-80, ID = 12.347" H 2661' -....J ~ ST tvÐ TVD 1 3708 3665 2 7170 6023 3 9574 7711 Minimum ID = 3.725" @ 10206' 4-1/2" HES XN Nipple ~ l ¡ - 9105' - 9113' - 9118' 19-5/8" CSG, 47#, L-80, ID = 8.681" H ~ 4-1/2" HES X NIP, ID = 3.813" I GAS LIFr Mð.NDRB.S DB! ìY PE VL V LA TQ-j 27 Mfv'G-M DOME RK 51 Mfv'G-M SlO RK 31 KGB-2-LS r:N INT PORT DATE 16 09/19/00 20 09/19/00 o 09/19/00 BAKffi TIEBACK SLEB! E, ID = 7.500" 9-5/8" Xl" BKRZXP A<R, ID =6.313" I 9-5/8" Xl"' BKRHfIIC HGR, ID= 6.313" ITOPOFWHIPSTOO< 9265' 9-518" CSG MLLOUTWINDOW (02-26B) 9268' - 9286' (OFF WHIPSTOCK) ~~ ~' \L :0206' \~ 10225' 10227' ~ I 10229' ~ ~ 1 10232' 10239' V 10175' 19-518" EZSV RETAIt\ER 9292' I 4-1/2" TBG, 12.6#, L-80. .0152 bpf, ID = 3.958" IT' X4-1/2" BKR ZXPPKR. ID- 4.375" 17" X 4-1/2" BKR I-fv1C HGR. ID = 4.375" IT' LNR. 26#, L-BO, ID = 6.276" 10413' PffiFORA TION SUfvfv1ARY REF LOG: BHCS ON 07/28/82 ANGLEATTOPÆRF: 87 @ 11260' I\bte: Refer to Production DB for historical perf da1a SIZE SPF INfERII AL ODnlSaz DA TE 2-1/2" 4 11260 - 12618 0 09/11/00 7" X 4 1/2" BKR S-3 PKR, ID = 3.875" I 4-1/2" HES XN NIP, ID - 3.725" I BKR TIEBACK SL V, ID = 5.250" I 4-1/2" WLB3, D 3.958" I H B.tvÐTTNOTLOGGBJ I 10832' 20' Mð.RKffi JT I ~:). ~~ y;v 12707' A3TD 12622' 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" DATE 08102182 06128197 09113/00 12127/00 04104/02 06111/03 REV BY COMIvENTS ORIGINAL COMPLETION CTD SIDETRACK (02-26A) RIG SIDETRACK (02-268) SIS-MD CONVERTED TO CANVAS CHrrp CORRECTIONS Cfv10rrLP KB ELEVA TION CORRECTION DATE REV BY OOfvfv1ENfS 08/17/03 aAOITLP ÆRFANGLEOORREGrION PRUDHOE BAY UNIT WB.L: 02-26B ÆRMfT I\b: 2001220 APII\b: 50-029-20774-02 SEC 35, T11N, R14E 3716' NSL & 6' WEL BP Exploration (Alaska) 9-5/8" CSG 9288' - 9286' (OFF BP . BP-GDB Baker Hughes INTEQ Planning Report . 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 Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: PB DS 02 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5948800.37 ft 687638.44 ft Latitude: 70 15 Longitude: 148 28 North Reference: Grid Convergence: 53.847 N 58.060 W True 1.43 deg Well: 02-26 Slot Name: 26 02-26 Well Position: +N/-S 837.41 ft Northing: 5949616.08 ft Latitude: 70 16 2.083 N +E/-W -858.41 ft Easting : 686759.48 ft Longitude: 148 29 23.045 W Position Uncertainty: 0.00 ft +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 02-268 10615.50 ft Mean Sea Level 24.99 deg 80.85 deg Direction deg 263.00 Wellpath: Plan#5, 2-26C 500292077403 Current Datum: 02-268 @ 58.70 (02-268) Magnetic Data: 1/28/2005 Field Strength: 57636 nT Vertical Section: Depth From (TVD) ft 28.70 Height 58.70 ft Targets 02-26C, Polygon 1 58.70 0.00 0.00 5949616.08 686759.48 70 16 2.083 N 148 29 23.045 W -Polygon 1 58.70 -686.38 -5238.44 5948800.00 681540.00 70 15 55.315 N 148 31 55.504 W -Polygon 2 58.70 -1033.66 -5796.26 5948439.00 680991.00 70 1551.895 N 148 32 11.731 W -Polygon 3 58.70 -1086.19 -6017.64 5948381.00 680771.00 70 1551.377 N 148 32 18.173 W -Polygon 4 58.70 -1217.77 -6480.08 5948238.00 680312.00 70 15 50.079 N 148 32 31.628 W -Polygon 5 58.70 -1268.73 -6724.43 5948181.00 680069.00 70 15 49.575 N 148 32 38.738 W -Polygon 6 58.70 -885.53 -6766.94 5948563.00 680017.00 70 15 53.344 N 148 32 39.985 W -Polygon 7 58.70 -614.92 -6868.26 5948831.00 679909.00 70 15 56.004 N 148 32 42.941 W -Polygon 8 58.70 -569.06 -6620.03 5948883.00 680156.00 70 15 56.458 N 148 32 35.717 W -Polygon 9 58.70 -554.54 -6116.49 5948910.00 680659.00 70 15 56.605 N 148 32 21.062 W -Polygon 10 58.70 -528.79 -5944.79 5948940.00 680830.00 70 15 56.859 N 148 32 16.066 W -Polygon 11 58.70 -331.62 -5384.69 5949151.00 681385.00 70 15 58.803 N 148 31 59.768 W -Polygon 12 58.70 -686.38 -5238.44 5948800.00 681540.00 70 15 55.315 N 148 31 55.504 W 02-26C fault 1 58.70 -101.02 -4760.74 5949397.00 682003.00 70 16 1.075 N 1483141.612W -Polygon 1 58.70 -101.02 -4760.74 5949397.00 682003.00 70 16 1.075 N 1483141.612W -Polygon 2 58.70 -78.53 -4820.20 5949418.00 681943.00 70 16 1.295 N 148 31 43.343 W -Polygon 3 58.70 158.91 -5519.57 5949638.00 681238.00 70 16 3.626 N 148 32 3.704 W 02-26C fault 2 58.70 -1761.40 -5737.29 5947713.00 681068.00 70 15 44.738 N 148 32 9.999 W -Polygon 1 58.70 -1761.40 -5737.29 5947713.00 681068.00 70 15 44.738 N 148 32 9.999 W -Polygon 2 58.70 -828.58 -5958.23 5948640.00 680824.00 70 15 53.911 N 148 32 16.450 W -Polygon 3 58.70 60.16 -6579.41 5949513.00 680181.00 70 16 2.646 N 148 32 34.551 W -Polygon 4 58.70 -828.58 -5958.23 5948640.00 680824.00 70 15 53.911 N 148 32 16.450 W 02-26C T1.4 9010.70 -631.94 -6827.67 5948814.99 679950.00 70 15 55.837 N 148 3241.759 W 02-26C T1.1 9018.70 -429.03 -5289.07 5949056.00 681483.00 70 15 57.845 N 148 31 56.983 W 02-26C T1.2 9021.70 -609.40 -5760.72 5948864.00 681016.00 70 15 56.068 N 148 32 10.707 W 02-26C T1.3 9021.70 -714.91 -6144.47 5948748.99 680635.00 70 15 55.027 N 148 32 21.873 W . BP-GDB Baker Hughes INTEQ Planning Report . 10649.50 8635.45 TIP 10665.00 8648.36 KOP 10685.00 8665.23 3 - End of 9?/100' DLS 10725.00 8700.18 4 10800.00 8769.14 5 11263.75 9019.61 6 11488.75 9020.72 7 11738.75 9021.73 8 11838.75 9022.07 9 11988.75 9022.21 10 12208.75 9021.88 11 12383.75 9019.93 12 12633.75 9015.17 13 12900.00 9011.18 TO Plan: Plan #5 Date Composed: 1/28/2005 Version: 4 Principal: Yes Tied-to: From: Definitive Path Plan Section Information 10615.50 34.18 295.79 8607.25 -452.11 -4824.42 0.00 0.00 0.00 0.00 10649.50 33.75 295.58 8635.45 -443.88 -4841.53 1.31 -1.26 -0.62 195.17 10665.00 33.42 298.18 8648.36 -440.00 -4849.18 9.52 -2.13 16.77 104.00 10685.00 31.62 298.18 8665.23 -434.93 -4858.66 9.00 -9.00 0.00 180.00 10725.00 26.58 291.47 8700.18 -426.69 -4876.24 15.00 -12.61 -16.77 210.00 10800.00 20.14 267.85 8769.14 -421.02 -4904.85 15.00 -8.59 -31.50 225.00 11263.75 89.70 267.85 9019.61 -434.40 -5261.22 15.00 15.00 0.00 0.00 11488.75 89.75 234.10 9020.72 -506.70 -5470.86 15.00 0.02 -15.00 270.00 11738.75 89.80 271.60 9021.73 -579.11 -5705.50 15.00 0.02 15.00 90.00 11838.75 89.81 256.60 9022.07 -589.36 -5804.69 15.00 0.01 -15.00 270.00 11988.75 90.09 234.10 9022.21 -651.52 -5940.14 15.00 0.19 -15.00 270.70 12208.75 90.08 267.10 9021.88 -723.59 -6144.80 15.00 -0.01 15.00 90.00 12383.75 91.17 293.33 9019.93 -692.83 -6315.51 15.00 0.63 14.99 87.50 12633.75 90.93 255.82 9015.17 -673.24 -6560.24 15.00 -0.10 -15.00 270.00 12900.00 90.71 295.77 9011.18 -646.91 -6819.77 15.00 -0.08 15.00 90.00 10615.50 34.18 295.79 8548.55 -452.11 -4824.42 5949044.45 681948.06 4843.55 0.00 0.00 MWD 10649.50 33.75 295.58 8576.75 -443.88 -4841.53 5949052.25 681930.74 4859.54 1.31 195.17 MWD 10665.00 33.42 298.18 8589.66 -440.00 -4849.18 5949055.94 681923.00 4866.66 9.52 104.00 MWD 10685.00 31.62 298.18 8606.53 -434.93 -4858.66 5949060.78 681913.40 4875.45 9.00 180.00 MWD 10700.00 29.69 295.91 8619.43 -431.45 -4865.47 5949064.09 681906.51 4881.78 15.00 210.00 MWD 10725.00 26.58 291.47 8641 .48 -426.69 -4876.24 5949068.57 681895.62 4891.90 15.00 211.95 MWD 10750.00 24.06 284.96 8664.08 -423.33 -4886.37 5949071.68 681885.41 4901.54 15.00 225.00 MWD 10775.00 21.88 277.13 8687.10 -421.43 -4895.92 5949073.34 681875.81 4910.79 15.00 230.89 MWD 10800.00 20.14 267.85 8710.44 -421.02 -4904.85 5949073.54 681866.88 4919.60 15.00 238.10 MWD 10825.00 23.89 267.85 8733.62 -421.37 -4914.21 5949072.95 681857.53 4928.93 15.00 0.00 MWD 10850.00 27.64 267.85 8756.13 -421.78 -4925.07 5949072.28 681846.69 4939.76 15.00 0.00 MWD 10875.00 31.39 267.85 8777.88 -422.24 -4937.37 5949071.51 681834.40 4952.03 15.00 0.00 MWD . BP-GDB Baker Hughes INTEQ Planning Report . 10900.00 35.14 267.85 8798.78 -422.75 -4951.07 5949070.65 681820.72 4965.69 15.00 0.00 MWD 10925.00 38.89 267.85 8818.74 -423.32 -4966.11 5949069.72 681805.70 4980.68 15.00 0.00 MWD 10950.00 42.64 267.85 8837.67 -423.93 -4982.41 5949068.70 681789.42 4996.94 15.00 0.00 MWD 10975.00 46.39 267.85 8855.50 -424.59 -4999.93 5949067.61 681771.93 5014.40 15.00 0.00 MWD 11000.00 50.14 267.85 8872.14 -425.29 -5018.56 5949066.45 681753.31 5032.99 15.00 0.00 MWD 11025.00 53.89 267.85 8887.52 -426.03 -5038.25 5949065.22 681733.65 5052.62 15.00 0.00 MWD 11050.00 57.64 267.85 8901.58 -426.80 -5058.90 5949063.93 681713.03 5073.21 15.00 0.00 MWD 11075.00 61.39 267.85 8914.27 -427.61 -5080.42 5949062.59 681691.53 5094.67 15.00 0.00 MWD 11100.00 65.14 267.85 8925.51 -428.45 -5102.73 5949061.20 681669.26 5116.91 15.00 0.00 MWD 11125.00 68.89 267.85 8935.27 -429.31 -5125.73 5949059.76 681646.29 5139.84 15.00 0.00 MWD 11150.00 72.64 267.85 8943.51 -430.20 -5149.31 5949058.29 681622.74 5163.35 15.00 0.00 MWD 11175.00 76.39 267.85 8950.18 -431.10 -5173.38 5949056.79 681598.70 5187.36 15.00 0.00 MWD 11183.07 77.60 267.85 8952.00 -431.40 -5181.23 5949056.30 681590.86 5195.19 15.00 360.00 02-26C 11200.00 80.14 267.85 8955.27 -432.02 -5197.84 5949055.27 681574.28 5211.74 15.00 0.00 MWD 11225.00 83.89 267.85 8958.74 -432.95 -5222.57 5949053.73 681549.57 5236.41 15.00 0.00 MWD 11250.00 87.64 267.85 8960.59 -433.89 -5247.48 5949052.17 681524.70 5261.24 15.00 0.00 MWD 11263.75 89.70 267.85 8960.91 -434 .40 -5261.22 5949051.32 681510.97 5274.94 15.00 0.00 MWD 11275.00 89.70 266.16 8960.97 -434.99 -5272.45 5949050.45 681499.76 5286.16 15.00 270.00 MWD 11300.00 89.70 262.41 8961.10 -437.48 -5297.32 5949047.35 681474.96 5311.15 15.00 270.01 MWD 11325.00 89.70 258.66 8961.23 -441.59 -5321.98 5949042.63 681450.42 5336.12 15.00 270.03 MWD 11350.00 89.71 254.91 8961.36 -447.30 -5346.31 5949036.31 681426.23 5360.97 15.00 270.05 MWD 11375.00 89.71 251.16 8961.48 -454.59 -5370.22 5949028.43 681402.52 5385.59 15.00 270.07 MWD 11400.00 89.72 247.41 8961.61 -463.43 -5393.60 5949019.01 681379.37 5409.87 15.00 270.09 MWD 11425.00 89.73 243.66 8961.73 -473.78 -5416.35 5949008.10 681356.88 5433.72 15.00 270.10 MWD 11450.00 89.73 239.91 8961.85 -485.60 -5438.37 5948995.74 681335.15 5457.02 15.00 270.12 MWD 11475.00 89.74 236.16 8961.96 -498.83 -5459.58 5948981.99 681314.29 5479.68 15.00 270.14 MWD 11488.75 89.75 234.10 8962.02 -506.70 -5470.86 5948973.85 681303.20 5491.84 15.00 270.16 MWD 11500.00 89.75 235.79 8962.07 -513.16 -5480.07 5948967.16 681294.16 5501.76 15.00 90.00 MWD 11525.00 89.75 239.54 8962.18 -526.53 -5501.19 5948953.27 681273.38 5524.35 15.00 89.99 MWD 11550.00 89.75 243.29 8962.29 -538.49 -5523.14 5948940.77 681251.74 5547.59 15.00 89.98 MWD 11575.00 89.76 247.04 8962.39 -548.99 -5545.82 5948929.71 681229.32 5571.39 15.00 89.96 MWD 11600.00 89.76 250.79 8962.50 -557.98 -5569.14 5948920.14 681206.23 5595.63 15.00 89.94 MWD 11625.00 89.77 254.54 8962.60 -565.43 -5593.00 5948912.10 681182.57 5620.22 15.00 89.93 MWD 11650.00 89.77 258.29 8962.70 -571.30 -5617.29 5948905.63 681158.43 5645.05 15.00 89.91 MWD 11675.00 89.78 262.04 8962.80 -575.57 -5641.92 5948900.75 681133.91 5670.01 15.00 89.90 MWD 11700.00 89.79 265.79 8962.89 -578.23 -5666.78 5948897.48 681109.13 5695.01 15.00 89.88 MWD 11725.00 89.80 269.54 8962.98 -579.25 -5691.75 5948895.84 681084.19 5719.92 15.00 89.87 MWD 11738.75 89.80 271.60 8963.03 -579.11 -5705.50 5948895.64 681070.44 5733.55 15.00 89.86 MWD 11750.00 89.80 269.91 8963.07 -578.96 -5716.75 5948895.51 681059.20 5744.69 15.00 270.00 MWD 11775.00 89.80 266.16 8963.16 -579.82 -5741.73 5948894.03 681034.25 5769.59 15.00 270.01 MWD 11800.00 89.80 262.41 8963.24 -582.31 -5766.60 5948890.93 681009.45 5794.58 15.00 270.02 MWD 11825.00 89.81 258.66 8963.33 -586.42 -5791.26 5948886.21 680984.90 5819.55 15.00 270.03 MWD 11838.75 89.81 256.60 8963.37 -589.36 -5804.69 5948882.93 680971.55 5833.25 15.00 270.04 MWD 11850.00 89.83 254.91 8963.41 -592.13 -5815.59 5948879.89 680960.72 5844.40 15.00 270.70 MWD 11875.00 89.88 251.16 8963.47 -599.42 -5839.50 5948872.01 680937.00 5869.02 15.00 270.71 MWD 11900.00 89.92 247.41 8963.52 -608.26 -5862.88 5948862.59 680913.85 5893.30 15.00 270.71 MWD 11925.00 89.97 243.66 8963.54 -618.61 -5885.63 5948851.68 680891.36 5917.15 15.00 270.72 MWD 11950.00 90.02 239.91 8963.54 -630.43' -5907.65 5948839.32 680869.64 5940.45 15.00 270.73 MWD 11975.00 90.07 236.16 8963.53 -643.66 -5928.86 5948825.57 680848.77 5963.11 15.00 270.73 MWD 11988.75 90.09 234.10 8963.51 -651.52 -5940.14 5948817.43 680837.69 5975.27 15.00 270.72 MWD 12000.00 90.09 235.79 8963.49 -657.98 -5949.35 5948810.75 680828.64 5985.19 15.00 90.00 MWD 12025.00 90.09 239.54 8963.45 -671.35 -5970.47 5948796.86 680807.86 6007.78 15.00 90.00 MWD 12050.00 90.09 243.29 8963.41 -683.31 -5992.42 5948784.36 680786.22 6031.03 15.00 90.01 MWD . BP-GDB Baker Hughes INTEQ Planning Report . 12075.00 90.09 247.04 8963.37 -693.81 -6015.10 5948773.30 680763.81 6054.82 15.00 90.01 MWD 12100.00 90.09 250.79 8963.33 -702.81 -6038.42 5948763.73 680740.72 6079.06 15.00 90.02 MWD 12125.00 90.09 254.54 8963.29 -710.25 -6062.28 5948755.69 680717.05 6103.65 15.00 90.03 MWD 12150.00 90.08 258.29 8963.26 -716.13 -6086.58 5948749.22 680692.91 6128.48 15.00 90.03 MWD 12175.00 90.08 262.04 8963.22 -720.40 -6111.21 5948744.34 680668.39 6153.45 15.00 90.04 MWD 12200.00 90.08 265.79 8963.19 -723.05 -6136.06 5948741.07 680643.62 6178.44 15.00 90.04 MWD 12208.75 90.08 267.10 8963.18 -723.59 -6144.80 5948740.31 680634.90 6187.18 15.00 90.05 MWD 12225.00 90.18 269.54 8963.14 -724.07 -6161.04 5948739.43 680618.67 6203.35 15.00 87.50 MWD 12250.00 90.35 273.28 8963.02 -723.45 -6186.02 5948739.43 680593.68 6228.08 15.00 87.51 MWD 12275.00 90.51 277.03 8962.84 -721.21 -6210.92 5948741.06 680568.74 6252.52 15.00 87.52 MWD 12300.00 90.67 280.78 8962.58 -717.34 -6235.61 5948744.31 680543.96 6276.55 15.00 87.55 MWD 12325.00 90.82 284.52 8962.26 -711.87 -6260.00 5948749.18 680519.45 6300.09 15.00 87.59 MWD 12350.00 90.97 288.27 8961.86 -704.81 -6283.97 5948755.63 680495.30 6323.03 15.00 87.64 MWD 12375.00 91.12 292.02 8961.41 -696.21 -6307.44 5948763.65 680471.64 6345.27 15.00 87.70 MWD 12383.75 91.17 293.33 8961.23 -692.83 -6315.51 5948766.83 680463.48 6352.87 15.00 87.77 MWD 12400.00 91.17 290.89 8960.90 -686.72 -6330.56 5948772.56 680448.29 6367.06 15.00 270.00 MWD 12425.00 91.17 287.14 8960.39 -678.58 -6354.19 5948780.12 680424.47 6389.52 15.00 269.95 MWD 12450.00 91.16 283.39 8959.88 -672.00 -6378.29 5948786.10 680400.21 6412.65 15.00 269.87 MWD 12475.00 91.14 279.64 8959.38 -667.01 -6402.78 5948790.48 680375.60 6436.34 15.00 269.80 MWD 12500.00 91.12 275.89 8958.89 -663.63 -6427.54 5948793.24 680350.77 6460.51 15.00 269.72 MWD 12525.00 91.09 272.14 8958.40 -661.88 -6452.47 5948794.37 680325.80 6485.04 15.00 269.65 MWD 12550.00 91.06 268.39 8957.93 -661.77 -6477.46 5948793.86 680300.82 6509.83 15.00 269.58 MWD 12575.00 91.03 264.64 8957.47 -663.29 -6502.41 5948791.72 680275.92 6534.77 15.00 269.50 MWD 12600.00 90.99 260.89 8957.03 -666.43 -6527.20 5948787.96 680251.21 6559.77 15.00 269.44 MWD 12625.00 90.95 257.14 8956.61 -671.20 -6551.73 5948782.59 680226.81 6584.70 15.00 269.37 MWD 12633.75 90.93 255.82 8956.47 -673.24 -6560.24 5948780.33 680218.35 6593.39 15.00 269.31 MWD 12650.00 90.93 258.26 8956.20 -676.89 -6576.07 5948776.30 680202.62 6609.55 15.00 90.00 MWD 12675.00 90.93 262.01 8955.80 -681.17 -6600.70 5948771.41 680178.11 6634.51 15.00 90.04 MWD 12700.00 90.92 265.76 8955.40 -683.83 -6625.55 5948768.13 680153.34 6659.50 15.00 90.10 MWD 12725.00 90.91 269.51 8955.00 -684.86 -6650.52 5948766.48 680128.40 6684.41 15.00 90.16 MWD 12750.00 90.89 273.26 8954.61 -684.25 -6675.50 5948766.47 680103.41 6709.13 15.00 90.22 MWD 12775.00 90.87 277.01 8954.22 -682.02 -6700.40 5948768.09 680078.47 6733.57 15.00 90.28 MWD 12800.00 90.84 280.76 8953.85 -678.15 -6725.09 5948771.34 680053.69 6757.61 15.00 90.34 MWD 12825.00 90.82 284.51 8953.49 -672.69 -6749.48 5948776.20 680029.18 6781.15 15.00 90.39 MWD 12850.00 90.79 288.26 8953.14 -665.63 -6773.45 5948782.65 680005.03 6804.08 15.00 90.45 MWD 12875.00 90.75 292.01 8952.80 -657.03 -6796.92 5948790.67 679981.36 6826.33 15.00 90.50 MWD / 12900.00 90.71 295.77 8952.48 -646.91 -6819.77 5948800.23 679958.27 6847.78 15.00 90.55 MWD BP Amoco WEUPATH DETAILS Plon.S, 2-26C 5002e2077403 P...n' Well...th; 0..... neonMDI 10611.50 Rlg= NonIlc1 58.7Oft R....D.t""'; 02-2..@5"70(02·268) V.Sectkt" ~r:J !; ~~= :::=I~D ..... 263.00' 0.00 0.00 28.70 REFERENCE INFORMATION Co-ordinate (NIE) Reference: Well Centre: 02-26, True North v;~~~~~~~ ~::~~~:~ ~~t~~~ ~~g~~~~6~)eJ Measured Depth Reference: 02-268 @ 58.70 (02·268) 58.70 Calculation Method: Minimum Curvature Plan: Plan #5 (02-261PJan#5, 2-26C) Created By: Brii Potnis COr:tBct ßeh Azimuths to True North Magnetic North: 24.990 Magnetic Field Strength: 57636nT Dip Angle: 80.850 Date: 1/28/2005 Model: bggm2004 T M ¡L / g~~~î ~g~=~gl 02-26 ¡02-26AÞB11 02-26 02-26APB2 02-26 02-268) Plan#S, 2-26C Plan#S . . ë -300 æ -400 o o ... .... - + J: 1:: o ~ "':'" - .c ... ~ 0_ eI) -1400 -1500' DLtoII T...... Vhc T..... 0.00 0.00 4143.55 1.31 1115.17 4115V.M 1.52 104.00 41!186.C!1C!i 0.00 1110.00 4875.41 15.00 210.00 .Bltt.1O t5.00 225.00 41111.10 ts.OO 0.00 5274.14 15.00 uo.oo .......... 15.00 ..00 5733.55 15.00 Z7U.OO 51133.26 15.00 Z70.TO H7S.27 15.00 110.00 11187.18 15.00 11'7.50 IIJllZAT 15.00 270.00 HI3.H 15.00 110.00 H47.T8 +IEJ.JN sm.pe 0.00 Polygon 04710.14 Polygon ~r:; =~'r' _5_.07 Point -5710.72 Point ..144047 Point TARGET DETAILS T\ID +NI-S 0.00 0.00 ~I'~ê SECTION DETAILS he: MD Inc Al;1 TVD +NJ-S +e¡-w 1 101118..5034,1' 2115.78 81M11..51 -452.11 --411204.42 IJIIIIIIIIIII 12122oa.15 110.08 2117.10 8!11i3.18 _723." -61....0 ~: ~æ~ ::ìf i:r~ :æ~ ~~ =~ .,- g~~''::1lr'''1 D2-2IChluIt2 oz-21lCru 02·26CT1. 02-26CT1.2 02-26CTU n. ~~Efld · · ; · :. " " " TO 81148.551N15.50 8118...10665,00 81106.5310685.00 :;~:::: ~=::: :::::: ~~:.N: 8.1».0311738.75 8.1».3711838.75 .81».5111988.75 8.83.1812.2C18.75 .881.2312383.75 8858.4712833.75 8952.48121K1C1.00 AM ii' . '" ' ., .. "r ii' -7100 -7000 -6900-6800 -6700 -6600 -6500 -6400-6300 -6200 -61 00 ·6000 -5900 -5800 -5700-5600 -5500-5400 -5300 -5200 -51 00 -5000 -4900 -4800 -4700 -4600 -4500 '-rTf"' ..)"",...,...... 4200 4300 4400 4500 46'00 47'00 4800 4900 5000 51'00 52'00 5300 5400 5500 5600 5700 5800 5900 6000 6100 6200 6300 6400 6500 6600 6700 6800 6900 7000 7100 7200 73'00 74'00 7500 76'00 7700 7800 Vertical Section at 263.000 [100ft/in] ... C '-8 æ 88 ... ... 8· .c .. 2'8 Q _81 1\1 U :e8 GI >8; GI ~8' .. ... . 9000"-] , ¡ : ; . . 1 1 Nordic 1 big hole All Measurements are from top of Riser 2/2/2005 ~ Q) en .- cr.: bttm of bag BAG 71/16" 5000psi top of bag middle of slips Blind/Shears .......................... middle of pipes TOTs ....................·····7 1/16" 5000psi middle of flow cross Mud Cross Mud Cross 71/16" 5000psi middle of blind/shears .......................... middle of pipelslips TOTs ·······7 1/16" 5000 . ............ pSI ...."...... Flow Tee ·. 178 89-6/1252 DATE Mastercard Check ' TERRIE '- HUBBLE BP EXPLORATIONAKINC pOBOX 196612 MB7-5 . ANCHORAGE,AK.99519-6612 L . o ¡. 78 ¡,SSb"a b 22 7 II MEMO .: ¡. 2 5 2000 b 0': q q ¡. a. I" . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME Æ« 02 - 26' C PTD# 20S -0 I r >< Development Service Exploration Stratigraphic CHECK WHAT ADD-ONS "CLUE"· APpmS (OPTIONS) ~T) Tbe permit is for a new weJlbore segment of LATERAL e~isting weD . Permit No, API No. . (If API Dumber ProductioD. sbould cODtiDue to be reponed as last two. (2) digits a function' of tbe original API number. stated are between 60-69) above. PILOT HOLE In accordance witb' 20 AAC 25.00S(f), aU (PH) records, data and logs acquired. 'or tbe pilot bole must be clearly differentiated 1n botb name (name on permit plus PH) .' and API Dumber (50 - 70/80) from records, data and logs acquired for we)) (name on permit). SPACING Tbe permit is approved subject ·10 fuD EXCEPTION compliance witb 20 AAC 25~055~ Approval to perforate and produce is contingent upon issuance of " conservation order approving a spacing eJ reption. (Companv Name) assumes tbe liabiHty of auy protest to tbe sparing .~Jcep1ion tbat JDay occur. : DRY DITCH AU dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater 1ban 30' .- sample intervals from below tbe permafrost or from where samples are fint caught aud ] 0' samplebiter:vals througb target zones. .. . - D D Well bore seg Annular Disposal 640150 Well Name: PRUDHOE BAY UNJI02-26C Program DEV - INC Initial ClasslType DEV l J:OIL- GeoArea 890 Unit J..L650 _ On/Off Shore On - - - - . ii Administration Permit fee attache.d _ _ _ Yes - - - - - - - - - - 12 _Lease number appropriate _ - - - - Yes - - - - - - - - - - - 3 _UJ1[qUe wellname_aod oumb_er - - - - . _ _ _ _ _ _ _ _ Yes - -- - - - - - - - - - - - - - - - - - ~ - - 4 WelUocated [na d_efil1e.d ppol_ - - - - Yes - - - - - - - - - - - - - - - - - - - 5 WeJUocated prQper _d[stance_ from driJling ul1itboul1dary_ Yes - - - - - - 6 WelUocated proper _d[staoçe from ottler welJs_ _ _ _ _ _ _ _Yes - - - - - - - - - - - - - - 7 S_utficiel1tacreage_ayailable In_dJilJiog unit _ _ _ _ _ _ _ _ _ _ Yes - - - - - 8 Jtdeviated, js weJlbore plaUl1cJu_ded _ Yes - - - - - - - - - - - - - - - - - - ,9 Operator ol1ly: affected party _ _ - - - - - - - - _ _ _ _ _ _ Yes - - - - - - 10 _Oper_ator tlas_appropr[ate_bond [nJorce _ _ _ _ _ _ _ _ _ _ - - -- _ _ _ _ _ _ Yes - -- - - - - - - - - - - - - - - - - - - -- 11 Permit can be [ssued wittlout conservatiOI1 order _ _ _ _ _ _ _ Yes Appr Date 12 Permit c.ao be [ssued wittlout admil1istratÌ\le_approvaJ _ _ - - - - - - - Yes - - - - - - - - - - - - - RPC 2/8/2005 13 Can permit be approved before 15-day wait Yes 14 Well Jocated w[thil1 area alld_strataauthor[zed by_lojectioo Order # (put 10# in cQmmeots)_ (For NA - - - - - - - - - - - - - - 15 _AJI wel)s_wit!1[nJl4J'lJile_area_of reyiew ideotlfied (For servjcewellooly:L _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA - - - - - - - - - - - - - - - - - - - - - - - 16 PJe-produ_ced injector; .duration of pre-produetipo less. than_ 3 mOl1ths_ (For service well only) _ _NA - - - - - - - - - - - 17 ACMPFïodjngof Con,si,stency_h_as been issued fort/:1is pr_oject _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA - - .- - - - - - - - Engineering 118 _C_ooductor strillgþJov[ded _ _ _ _ _ NA - - - - - 119 S_ud'acecasil1gpJotec.ts. alLknowll USDWs _ - - - - - - - - _ _ ___ _ NA - - - - - - - 120 CMT vol adequ_ate_ to circulate oncooductO( & SUJt CJ>g _ NA 121 CMT vol adequ_ate to tie-in Jongstring to surf csg_ _ _ NA - - - - - - - - - - 122 _CMT will coyer_aJl koownpro_duetiye /:1orizons - - - - - - Yes 23 Casiog desigos adeCluate for C._T" B& permafrost _ _ _ _ Yes 24 Adequate Jankage_oJ reserve pit _ _ _ _ _ _ _ _ - - - - - - - Yes CTDU. - - 25 JtaJ'e-.drilL has_a_ tOA03 for abandonmeJ1t beeo apPJoved _ Yes * 26 A.dequ.ateJ''1lelll:1ore separatioJ1-p(oposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - . _ _ _ _ _ _Yes - -- - - - - - - - - - - - - - - - - - - - ~ 27 Jfdiverter Jeq!Jired. does it meet regulatiOl1s - - - - - - - - - - - - - _ _ _ _NA Sidetrack. . - - - - - - - - - - Appr Date 28 _DJiUiog fJuidprogJam sc.hematic& e~uipJistadequate_ _ _ . _ _ _ _ _ Yes Max MW8J,! PP9· . . _ _ WGA 2/8/2005 29 _B_OPEs._dQ they meet reguJatiOIJ - - - - - - . Yes - - - - - - - - - - - - 30 _BOPEpress rati(lg app(op(iate;test to (put psig in_commeots) _ - - - - - Yes Test to _3500_ psi. MSF' 2355 psi. 31 Chokel1J!!nifold compJies w/API RF'-53 (May 84) - - - - - - - - Yes - - - - - 32 WQrk will PCC_U( withputoperation _shutdown_ - - - - - - - Yes 33 Is_ pres_eoce oJ H2S gas prob_able - - - - - - Yes 1QOppm, 34 Mect)an[caLC9odjUon of wells withil1 AOR verified (Fpr s_ervice well only) _ - - - - - NA ~ Geology 35 Permit c_ao be [sSl!ed w/o hydrogen s_ulfide meaS!Jre$. _ _ _ _ _ _ _ _ No 36 _D_ata_PJeseoted on pote_ntial 9veJpres_surezooe$. _ NA Appr Date 37 SeLsmlc_analysjs_ of sbaJlow g!!szooes_ NA - - - - - - - - - - - RPC 2/8/2005 38 Seal:1edcOl1ditio(l survey _(if off-shore) . ... _ _ _NA - - - - - - - - - - - - - - - - - - 39 _ Conta_ct oamelp!1OlleJonlleelsly progress reports [e)(p1orato(Y _only] - - - - _ _NA - - Geologic Date: Engineering Date þle, Date Commissioner Commissioner: r:JT S <-.J f J~ ~~a.r . . 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 infomlation, 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 Drilling Services LIS Scan Utility . $Revision: 3 $ LisLib $Revision: 4 $ Thu Sep 29 15:43:02 2005 /1J)') Ree~e~~~~:r name. . . . . . . . . . . . . LISTPE ). \:) )" -0 I cr Date.................... .05/09/29 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. . . . . . . . . . . . . . . . . . . . .05/09/29 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 MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 2-26C 500292077403 BP Exploration (Alaska) Inc. Sperry Drilling Services 29-SEP-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0003591162 S. LATZ J. EGBEJIMBA MWD RUN 3 MW0003591162 S. LATZ J. EGBEJIMBA MWD RUN 4 MW0003591162 S. LATZ J. EGBEJIMBA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0003591162 S. LATZ J. EGBEJIMBA MWD RUN 6 MW0003591162 S. LATZ J. EGBEJIMBA MAD RUN 6 MW0003591162 S. LATZ J. EGBEJIMBA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 MW0003591162 S. LATZ J. EGBEJIMBA # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) 35 11N 14E 3716 6 . KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 58.70 . # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.125 4.500 10665.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 10657'MD/ 8583'TVDSS IN THE 2-26B WELLBORE. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL AND NATURAL GAMMA RAY (PCG). THE PURPOSE OF RUN 1 WAS TO TIE-IN TO THE PARENT WELLBORE, SET THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RATHOLE. TIE-IN GR DATA WERE MERGED WITH RUN 2 MWD DATA. THE WELL WAS KICKED OFF DURING RUN 2. 5. MWD RUNS 3 - 7 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MAD PASS EWR4 DATA OVER THE RUN 2 INTERVAL WERE ACQUIRED PRIOR TO THE COMMENCEMENT OF DRILLING OF RUN 3, AND WERE MERGED WITH RUN 3 MWD DATA . MAD PASS DATA WERE ALSO ACQUIRED WHILE POOH AFTER RUN 6 IN AN ATTEMPT TO IDENTIFY A LOST CIRCULATION ZONE. THESE RUN 6 MAD DATA ARE PRESENTED SEPARATELY. 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY RUN IN THE 2-26C WELLBORE ON 20 MARCH 2005. THESE LOG DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 25 AUGUST 2005. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 - 7 REPRESENT WELL 2-26C WITH API#: 50-029-20774-03. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13006'MD/8983'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRB SMOOTHED GAMMA RAY - B BANK OF G-M TUBES. SGRC SMOOTHED GAMMA RAY COMBINED. SGRD SMOOTHED NATURAL GAMMA RAY. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED SPACING) . SEDP = SMOOTHED SPACING) . SFXE = SMOOTHED . . PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM PHASE SHIFT-DERIVED RESISTIVITY (DEEP FORMATION EXPOSURE TIME. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/29 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 GR RPM RPS RPX FET RPD ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 10500.5 10664.5 10664.5 10664.5 10664.5 10664.5 10677.5 STOP DEPTH 12958.5 12971.5 12971.5 12971.5 12971.5 12971.5 13002.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 10500.5 10502.5 10505.5 10509.0 10515.5 10519.0 10523.5 10527.5 10531.0 10537.5 10539.0 10547.5 10550.5 10650.0 10657.5 10666.5 10669.5 10679.0 10684.0 10695.5 10705.5 10714.0 10717.0 10719.0 10723.0 10726.0 10735.5 10740.5 GR 10500.0 10502.0 10505.5 10508.0 10515.0 10518.5 10523.0 10527.0 10531.0 10537.0 10539.0 10546.0 10549.5 10649.0 10656.5 10665.0 10667.5 10677.5 10681.5 10694.0 10704.5 10712.5 10715.5 10717.5 10721. 0 10724.5 10735.0 10739.0 10745.5 10762.0 10772.5 10783.5 10817.0 10834.0 10844.0 10878.0 10884.0 10901.5 10907.0 10924.0 10936.5 10968.0 10992.5 11006.5 11023.5 11047.5 11052.0 11061.0 11073.5 11086.5 11098.5 11106.5 11111.5 11126.5 11135.0 11144.5 11154.5 11175.5 11197.5 11200.0 11227.0 11230.0 11235.0 11245.0 11300.5 11314.0 11321.5 11347.0 11371.5 11386.5 11398.0 11402.5 11423.5 11435.0 11442.5 11445.0 11457.5 11460.0 11494.0 11516.0 11525.0 11540.0 11548.0 11626.0 11638.5 11656.5 11660.0 11691.5 11698.5 11714.0 11726.5 11746.0 11807.0 11847.5 11852.0 11857.0 . 10743.5 10762.0 10771.0 10782.0 10816.5 10833.5 10843.0 10876.5 10884.0 10900.0 10906.0 10922.0 10936.5 10967.5 10991.5 11006.0 11022.5 11047.5 11051.0 11060.5 11074.0 11086.5 11099.0 11106.5 11111.5 11126.0 11135.0 11144.0 11153.0 11177.5 11197.0 11200.5 11227.5 11230.5 11236.0 11244.0 11297.0 11308.5 11317.5 11343.0 11370.5 11384.5 11397.0 11400.5 11423.5 11435.0 11441.0 11442.5 11457.5 11460.0 11491.5 11513.5 11523.0 11539.0 11548.5 11625.0 11636.5 11655.5 11658.0 11692.5 11696.5 11714.5 11725.0 11745.5 11807.0 11848.5 11851.5 11855.0 . 11866.0 11880.5 11930.5 11968.5 11980.5 11987.0 12006.5 12052.0 12056.0 12133.5 12164.0 12168.5 12191.0 12201.5 12213.0 12219.5 12234.0 12240.0 12277.5 12328.0 12365.0 12375.0 12376.5 12400.5 12422.0 12433.0 12444.5 12448.5 12465.0 12478.5 12551.0 12561.0 12645.5 12690.0 12742.0 12769.5 12818.5 12823.5 12839.0 12849.0 12869.5 12875.0 13002.5 $ . 11865.5 11879.0 11931.5 11970.5 11983.0 11988.0 12008.5 12058.0 12062.0 12143.0 12170.0 12173.5 12197.5 12205.5 12218.0 12224.5 12238.0 12242.5 12282.5 12330.5 12369.0 12377.5 12378.5 12403.0 12424.5 12438.0 12447.5 12453.0 12469.5 12482.0 12556.5 12565.5 12651.5 12693.5 12746.5 12773.0 12824.0 12829.0 12845.0 12854.0 12872.5 12878.5 13006.0 . # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ BIT RUN NO 2 3 4 5 6 7 MERGE TOP 10500.0 10811.0 11368.0 11396.0 12384.0 12573.0 MERGE BASE 10811.0 11368.0 11396.0 12384.0 12573.0 13005.5 # REMARKS: MERGED MAIN PASS. $ # 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 MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10500.5 13002.5 11751.5 5005 10500.5 13002.5 ROP MWD FT/H 0.06 1811.38 63.3887 4651 10677.5 13002.5 GR MWD API 16.88 495.36 54.2541 4804 10500.5 12958.5 RPX MWD OHMM 2.95 120.74 15.7415 4615 10664.5 12971.5 RPS MWD OHMM 3.18 1976.77 19.8372 4615 10664.5 12971.5 RPM MWD OHMM 3.49 1973.91 21.6984 4615 10664.5 12971.5 RPD MWD OHMM 5.7 2000 28.6361 4615 10664.5 12971.5 FET MWD HOUR 0.27 111.08 3.23602 4615 10664.5 12971.5 First Reading For Entire File......... .10500.5 Last Reading For Entire File.......... .13002.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/09/29 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..... ..05/09/29 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE RPM RPD RPS RPX FET GR RAT 2 and clipped curves¡ all MAD runs merged using earliest passes. .5000 START DEPTH 10651.0 10651.0 10651.0 10651.0 10651.0 10651.5 10653.5 STOP DEPTH 12535.5 12535.5 12535.5 12535.5 12535.5 12523.0 12567.5 . . $ # MERGED DATA SOURCE PBU TOOL CODE MWD $ MAD RUN NO. MAD PASS NO. 6 1 MERGE TOP 10650.0 MERGE BASE 12573.0 # REMARKS: MERGED MAD PASS. $ # 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 RAT MAD FT/H 4 1 68 4 2 SGRB MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10651 12567.5 11609.3 3834 10651 12567.5 RAT MAD FT/H 65 3146 1260.87 3829 10653.5 12567.5 SGRB MAD API 5.5 266 52.8647 3744 10651.5 12523 RPX MAD OHMM 0.3 2000 15.2028 3770 10651 12535.5 RPS MAD OHMM 0.58 2000 24.0303 3770 10651 12535.5 RPM MAD OHMM 2.96 2000 35.3817 3770 10651 12535.5 RPD MAD OHMM 0.05 2000 37.7149 3770 10651 12535.5 FET MAD HOUR 6.06 210.35 63.2759 3770 10651 12535.5 First Reading For Entire File......... .10651 Last Reading For Entire File.......... .12567.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/29 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...... .05/09/29 . 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 GR ROP $ 3 . header data for each bit run in separate files. 2 .5000 START DEPTH 10500.0 10676.0 STOP DEPTH 10781.0 10811.0 # 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 PCG $ BOTTOM) TOOL TYPE Natural gamma ray # 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 13-MAR-05 Insite Memory 10811.0 10500.0 10811.0 20.5 24.2 TOOL NUMBER TLG 011 4.125 10665.0 Flo Pro 8.70 65.0 9.3 21000 6.4 .000 .000 .000 .000 .0 129.0 .0 .0 . Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name DEPT ROP GR Service Order Nsam 1 1 1 Units FT FT/H API Size 4 4 4 MWD020 MWD020 . Rep 68 68 68 Code Channel 1 2 3 Offset o 4 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10500 10811 10655.5 623 10500 10811 ROP MWD020 FT/H 0.42 76.27 17.6813 271 10676 10811 GR MWD020 API 18.78 495.36 44.3473 450 10500 10781 First Reading For Entire File......... .10500 Last Reading For Entire File.......... .10811 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/29 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...... .05/09/29 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPX RPS RPM FET GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 10663.0 10663.0 10663.0 10663.0 10663.0 10781.5 10811.5 # STOP DEPTH 11337.0 11337.0 11337.0 11337.0 11337.0 11324.0 11368.0 . 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 GM EWR4 $ BOTTOM) TOOL TYPE Dual GR 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. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 14-MAR-05 Insite 4.3 Memory 11368.0 10811.0 11368.0 25.2 89.3 TOOL NUMBER 78005 171170 4.125 10665.0 Flo Pro 8.60 65.0 9.3 22000 6.6 .160 .000 .180 .210 65.0 138.2 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP 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 10663 11368 11015.5 1411 10663 11368 ROP MWD030 FT/H 0.1 262.71 59.3498 1114 10811.5 11368 GR MWD030 API 16.88 181.06 43.8965 1086 10781.5 11324 RPX MWD030 OHMM 3.49 120.74 22.3423 1349 10663 11337 RPS MWD030 OHMM 4.87 1976.77 32.9022 1349 10663 11337 RPM MWD030 OHMM 5.77 1973.91 37.5221 1349 10663 11337 RPD MWD030 OHMM 8.2 2000 58.0439 1349 10663 11337 FET MWD030 HOUR 0.39 111.08 5.71099 1349 10663 11337 First Reading For Entire File......... .10663 Last Reading For Entire File.......... .11368 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/29 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/29 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD FET RPS RPX RPM ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 11324.5 11337.5 11337.5 11337.5 11337.5 11337.5 11368.5 STOP DEPTH 11352.0 11365.5 11365.5 11365.5 11365.5 11365.5 11396.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): 14-MAR-05 Insite 4.3 Memory 11396.0 . 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 GM EWR4 $ BOTTOM) TOOL TYPE Dual GR 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. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 11368.0 11396.0 87.8 87.9 TOOL NUMBER 78005 171170 4.125 10665.0 Flo Pro 8.60 65.0 9.3 22000 6.6 .100 .050 .160 .170 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 Name Service Unit DEPT FT Min 11324.5 Max 11396 Mean Nsam 11360.3 144 . 65.0 141.0 65.0 65.0 First Reading 11324.5 Last Reading 11396 · .368.5 ROP MWD040 FT/H 0.07 118.99 15.5973 56 11396 GR MWD040 API 51. 09 76.79 60.2857 56 11324.5 11352 RPX MWD040 OHMM 9.11 12.93 10.7237 57 11337.5 11365.5 RPS MWD040 OHMM 10.01 13.3 11.733 57 11337.5 11365.5 RPM MWD040 OHMM 10.79 14.57 12.8288 57 11337.5 11365.5 RPD MWD040 OHMM 14.19 17.02 15.6475 57 11337.5 11365.5 FET MWD040 HOUR 8.88 12.03 10.3239 57 11337.5 11365.5 First Reading For Entire File......... .11324.5 Last Reading For Entire File.......... .11396 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/29 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/09/29 Maximum Physical Record. .65535 File Type. .. .. .. .. .. .. . .. LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPD RPS RPX FET ROP $ 6 header data for each bit run in separate files. 5 .5000 START DEPTH 11352.5 11366.0 11366.0 11366.0 11366.0 11366.0 11396.5 STOP DEPTH 12340.0 12353.5 12353.5 12353.5 12353.5 12353.5 12384.0 # 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: 16-MAR-05 Insite 4.3 Memory 12384.0 11396.0 12384.0 86.6 94.4 # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ . BOTTOM) TOOL TYPE Dual GR 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 Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . TOOL NUMBER 78005 171170 4.125 10665.0 Flo Pro 8.60 65.0 9.4 23000 6.2 .090 .040 .140 .140 65.0 153.0 65.0 65.0 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11352.5 12384 11868.3 2064 11352.5 12384 ROP MWD050 FT/H 0.06 159.1 62.4308 1976 11396.5 12384 GR MWD050 API 17.7 174.95 52.9769 1976 11352.5 12340 RPX MWD050 OHMM 2.95 50.37 13.8675 1976 11366 12353.5 RPS MWD050 OHMM 3.18 42.79 14.9961 1976 11366 12353.5 RPM MWD050 OHMM 3.49 40.38 15.8779 1976 11366 12353.5 RPD MWD050 OHMM 5.7 32.65 17.0416 1976 11366 12353.5 FET MWD050 HOUR 0.27 17.76 1. 44416 1976 11366 12353.5 . . First Reading For Entire File......... .11352.5 Last Reading For Entire File.......... .12384 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/29 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.007 Physical EOF File Header Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/29 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPX RPS RPD RPM ROP $ 7 header data for each bit run in separate files. 6 .5000 START DEPTH 12340.0 12354.0 12354.0 12354.0 12354.0 12354.0 12384.5 # 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 GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. # BOREHOLE AND CASING DATA STOP DEPTH 12530.5 12544.0 12544.0 12544.0 12544.0 12544.0 12573.0 17-MAR-05 Insite 4.3 Memory 12573.0 12384.0 12573.0 83.3 89.7 RESIS. 4 TOOL NUMBER 78005 171170 . 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. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 3.750 . 10665.0 Flo Pro 8.60 65.0 9.5 23000 11.6 .090 70.0 .040 155.0 .140 65.0 .160 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12340 12573 12456.5 467 12340 12573 ROP MWD060 FT/H 1. 86 493.71 60.6224 378 12384.5 12573 GR MWD060 API 26.45 180.98 74.2013 382 12340 12530.5 RPX MWD060 OHMM 4.37 17.7 10.8109 381 12354 12544 RPS MWD060 OHMM 4.65 16.36 10.9782 381 12354 12544 RPM MWD060 OHMM 5 16.63 11.3724 381 12354 12544 RPD MWD060 OHMM 6.52 18.55 12.3299 381 12354 12544 FET MWD060 HOUR 0.48 13.01 3.45638 381 12354 12544 First Reading For Entire File......... .12340 Last Reading For Entire File.......... .12573 File Trailer . Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/29 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.008 Physical EOF File Header Service name............ .STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/29 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 8 . header data for each bit run in separate files. 7 .5000 START DEPTH 12531.0 12544.5 12544.5 12544.5 12544.5 12544.5 12573.5 # 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 GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. # 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): STOP DEPTH 12962.0 12975.0 12975.0 12975.0 12975.0 12975.0 13005.5 18-MAR-05 Insite 4.3 Memory 13006.0 12573.0 13006.0 82.6 99.2 RESIS. 4 TOOL NUMBER 78005 171170 4.125 10665.0 Flo Pro 8.60 65.0 . 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: 8.5 23000 5.6 . .090 .040 .140 .160 70.0 164.8 65.0 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.....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 MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12531 13005.5 12768.3 950 12531 13005.5 ROP MWD070 FT/H 1. 21 1811.38 89.6088 865 12573.5 13005.5 GR MWD070 API 19.11 167.54 65.3107 863 12531 12962 RPX MWD070 OHMM 3.47 18.64 12.1075 862 12544.5 12975 RPS MWD070 OHMM 3.62 24.05 13.2708 862 12544.5 12975 RPM MWD070 OHMM 4.15 27.13 14.0499 862 12544.5 12975 RPD MWD070 OHMM 7.54 23.19 15.3666 862 12544.5 12975 FET MWD070 HOUR 0.31 15.31 2.94667 862 12544.5 12975 First Reading For Entire File......... .12531 Last Reading For Entire File.......... .13005.5 File Trailer Service name............ .STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/29 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.009 . Physical EOF File Header Service name............ .STSLIB.009 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/29 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR RAT $ 9 . for each pass of each run in separate files. header data .5000 6 1 START DEPTH 10650.0 10650.0 10650.0 10650.0 10650.0 10650.5 10652.5 # 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 GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # STOP DEPTH 12540.5 12540.5 12540.5 12540.5 12540.5 12527.5 12572.0 RES IS. 4 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: 17-MAR-05 Insite 4.3 Memory 12572.0 10653.0 12572.0 83.3 89.7 TOOL NUMBER 78005 171170 4.125 10665.0 Flo Pro 8.60 65.0 9.5 23000 11. 6 .090 .040 70.0 155.0 . MUD FILTRATE AT MT: MUD CAKE AT MT: .140 .160 . 65.0 # 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. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD061 FT/H 4 1 68 4 2 SGRB MAD061 API 4 1 68 8 3 RPX MAD061 OHMM 4 1 68 12 4 RPS MAD061 OHMM 4 1 68 16 5 RPM MAD061 OHMM 4 1 68 20 6 RPD MAD061 OHMM 4 1 68 24 7 FET MAD061 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10650 12572 11611 3845 10650 12572 RAT MAD061 FT/H 65 3146 1261.01 3840 10652.5 12572 SGRB MAD061 API 5.5 266 52.6567 3755 10650.5 12527.5 RPX MAD061 OHMM 0.3 2000 14.6614 3782 10650 12540.5 RPS MAD061 OHMM 0.58 2000 22.9539 3782 10650 12540.5 RPM MAD061 OHMM 2.96 2000 34.0924 3782 10650 12540.5 RPD MAD061 OHMM 0.05 2000 37.6624 3782 10650 12540.5 FET MAD061 HOUR 6.06 210.35 63.1667 3782 10650 12540.5 First Reading For Entire File......... .10650 Last Reading For Entire File.......... .12572 File Trailer Service name............ .STSLIB.009 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/09/29 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.010 Physical EOF Tape Trailer . Service name...... . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/09/29 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS writing Library. Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/09/29 Origin.................. .STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File . Scientific Technical Services Scientific Technical Services
